ML14339A414: Difference between revisions

From kanterella
Jump to navigation Jump to search
(Created page by program invented by StriderTol)
(Created page by program invented by StriderTol)
Line 17: Line 17:


=Text=
=Text=
{{#Wiki_filter:BVPS-2 UFSAR Rev. 1 1-i CHAPTER 1 TABLE OF CONTENTS Section Title Page 1 INTRODUCTION AND GENERAL DESCRIPTION OF PLANT.....1.1-1  
{{#Wiki_filter:BVPS-2 UFSAR Rev. 1 1-i CHAPTER 1 TABLE OF CONTENTS Section Title Page 1 INTRODUCTION AND GENERAL DESCRIPTION OF PLANT.....1.1-1  


==1.1 INTRODUCTION==
==1.1 INTRODUCTION==
......................................1.1-1 1.2 GENERAL PLANT DESCRIPTION.........................1.2-1 1.2.1 General...........................................1.2-1 1.2.2 Site..............................................1.2-2 1.2.3 Structures........................................1.2-2 1.2.4 Nuclear Steam Supply System.......................1.2-2 1.2.5 Instrumentation and Control Systems...............1.2-4 1.2.6 Radioactive Waste System..........................1.2-5 1.2.7 Fuel Handling.....................................1.2-6 1.2.8 Turbine and Turbine Auxiliaries...................1.2-6 1.2.9 Electrical Systems................................1.2-9 1.2.10 Engineered Safety Features Systems................1.2-9 1.2.11 Cooling Water and Other Auxiliary Systems.........1.2-10 1.3 COMPARISON TABLES.................................1.3-1 1.3.1 Comparisons with Similar Facility Designs.........1.3-1 1.3.2 Comparison of Final and Preliminary Information...1.3-3 1.3.3 References for Section 1.3........................1.3-3 1.4 IDENTIFICATION OF AGENT AND CONTRACTORS...........1.4-1 1.4.1 Applicant.........................................1.4-1 1.4.2 Architect Engineer................................1.4-2 1.4.3 Nuclear Steam Supply System Manufacturer..........1.4-4 1.4.4 Turbine Generator Vendor..........................1.4-12 1.4.5 Consultants.......................................1.4-12 1.5 REQUIREMENTS FOR FURTHER TECHNICAL INFORMATION....1.5-1 1.5.1 Blowdown Heat Transfer Testing....................1.5-1 1.5.2 Reference for Section 1.5.........................1.5-3 1.6 MATERIAL INCORPORATED BY REFERENCE................1.6-1 1.7 DRAWINGS AND OTHER DETAILED INFORMATION...........1.7-1 1.7.1 Electrical, Instrumentation, and Control Drawings.1.7-1 1.7.2 Piping and Instrumentation Diagrams...............1.7-1 1.7.3 Other Detailed Information (Special Reports  and Programs).....................................1.7-1 BVPS-2 UFSAR Rev. 7 1-ii 1.8 CONFORMANCE TO NRC REGULATORY GUIDES..............1.8-1 1.9 STANDARD REVIEW PLAN CONFORMANCE EVALUATION.......1.9-1 1.10 NUREG 0737 ACTION ITEMS...........................1.10-1 1.11 ASME CODE CASES...................................1.11-1 1.12 EQUIVALENT MATERIALS..............................1.12-1 BVPS-2 UFSAR Rev. 16 1-iii LIST OF TABLES   Table Number  Title  1.3-1 Design Comparison (Historical) 1.3-2 Comparison of Final and Preliminary Information (Historical) 1.4-1 Westinghouse Pressurized Water Reactor Nuclear Power Plants (Historical) 1.5-1 Delayed Departure From Nucleate Boiling Phase I Test Parameters (Historical) 1.5-2 Delayed Departure From Nucleate Boiling Phase II Test Parameters (Historical) 1.6-1 Material Incorporated by Reference (Historical) 1.7-1 Deleted 1.7-2 Deleted 1.7-3 Special Reports and Programs 1.8-1 Regulatory Guides  1.9-1 Standard Review Plan Conformance (Historical) 1.9-2 SRP Conformance Statements (Historical) 1.10-1 NUREG 0737 Conformance 1.11-1 ASME Code Case References BVPS-2 UFSAR Rev. 20  1-iv LIST OF FIGURES   Figure Number  Title  1.2-1 Site Plan  
......................................1.1-1  
 
1.2 GENERAL PLANT DESCRIPTION.........................1.2-1 1.2.1 General...........................................1.2-1 1.2.2 Site..............................................1.2-2 1.2.3 Structures........................................1.2-2 1.2.4 Nuclear Steam Supply System.......................1.2-2 1.2.5 Instrumentation and Control Systems...............1.2-4 1.2.6 Radioactive Waste System..........................1.2-5 1.2.7 Fuel Handling.....................................1.2-6 1.2.8 Turbine and Turbine Auxiliaries...................1.2-6 1.2.9 Electrical Systems................................1.2-9 1.2.10 Engineered Safety Features Systems................1.2-9 1.2.11 Cooling Water and Other Auxiliary Systems.........1.2-10 1.3 COMPARISON TABLES.................................1.3-1  
 
1.3.1 Comparisons with Similar Facility Designs.........1.3-1 1.3.2 Comparison of Final and Preliminary Information...1.3-3 1.3.3 References for Section 1.3........................1.3-3 1.4 IDENTIFICATION OF AGENT AND CONTRACTORS...........1.4-1  
 
1.4.1 Applicant.........................................1.4-1 1.4.2 Architect Engineer................................1.4-2 1.4.3 Nuclear Steam Supply System Manufacturer..........1.4-4 1.4.4 Turbine Generator Vendor..........................1.4-12 1.4.5 Consultants.......................................1.4-12  
 
1.5 REQUIREMENTS FOR FURTHER TECHNICAL INFORMATION....1.5-1  
 
1.5.1 Blowdown Heat Transfer Testing....................1.5-1 1.5.2 Reference for Section 1.5.........................1.5-3  
 
1.6 MATERIAL INCORPORATED BY REFERENCE................1.6-1 1.7 DRAWINGS AND OTHER DETAILED INFORMATION...........1.7-1  
 
1.7.1 Electrical, Instrumentation, and Control Drawings.1.7-1 1.7.2 Piping and Instrumentation Diagrams...............1.7-1 1.7.3 Other Detailed Information (Special Reports  and Programs).....................................1.7-1  
 
BVPS-2 UFSAR Rev. 7 1-ii 1.8 CONFORMANCE TO NRC REGULATORY GUIDES..............1.8-1 1.9 STANDARD REVIEW PLAN CONFORMANCE EVALUATION.......1.9-1  
 
1.10 NUREG 0737 ACTION ITEMS...........................1.10-1 1.11 ASME CODE CASES...................................1.11-1  
 
1.12 EQUIVALENT MATERIALS..............................1.12-1  
 
BVPS-2 UFSAR Rev. 16 1-iii LIST OF TABLES Table Number  Title  1.3-1 Design Comparison (Historical) 1.3-2 Comparison of Final and Preliminary Information (Historical)  
 
1.4-1 Westinghouse Pressurized Water Reactor Nuclear Power Plants (Historical)  
 
1.5-1 Delayed Departure From Nucleate Boiling Phase I Test Parameters (Historical)  
 
1.5-2 Delayed Departure From Nucleate Boiling Phase II Test Parameters (Historical)  
 
1.6-1 Material Incorporated by Reference (Historical) 1.7-1 Deleted 1.7-2 Deleted  
 
1.7-3 Special Reports and Programs 1.8-1 Regulatory Guides  1.9-1 Standard Review Plan Conformance (Historical) 1.9-2 SRP Conformance Statements (Historical) 1.10-1 NUREG 0737 Conformance 1.11-1 ASME Code Case References  
 
BVPS-2 UFSAR Rev. 20  1-iv LIST OF FIGURES Figure Number  Title  1.2-1 Site Plan  


1.7-1 Legend:  Piping and Instrumentation Diagrams  
1.7-1 Legend:  Piping and Instrumentation Diagrams  


BVPS-2 UFSAR Rev. 20  1.1-1 CHAPTER 1 INTRODUCTION AND GENERAL DESCRIPTION OF PLANT
BVPS-2 UFSAR Rev. 20  1.1-1 CHAPTER 1 INTRODUCTION AND GENERAL DESCRIPTION OF PLANT  


==1.1 INTRODUCTION==
==1.1 INTRODUCTION==


Beaver Valley Power Station Unit 1 (BVPS-1) and BVPS-2 are located on a site in Shippingport Borough on the Ohio River in Beaver County, Pennsylvania. BVPS-2 uses a pressurized water reactor nuclear steam supply system (NSSS) and turbine generator, both furnished by Westinghouse Electric Corporation.
Beaver Valley Power Station Unit 1 (BVPS-1) and BVPS-2 are located on a site in Shippingport Borough on the Ohio River in Beaver County, Pennsylvania. BVPS-2 uses a pressurized water reactor nuclear steam supply system (NSSS) and turbine generator, both furnished by Westinghouse Electric Corporation.
It is similar in design concept to several projects already licensed or under review by the USNRC. The balance of the unit, including the containment structure, is designed and constructed by the Applicants, with the assistance of their agent, Stone &
It is similar in design concept to several projects already licensed or under review by the USNRC. The balance of the unit, including the containment structure, is designed and constructed  
Webster Engineering Corporation.
 
The NSSS was originally designed for a warranted power output of 2,660 MWt, which was the license application rating, with an equivalent station net electrical output of approximately 836.0 MWe, assuming an atmospheric wet bulb of 44.85F coincident with a dry bulb temperature of 53.4F. The NSSS output of 2,660 MWt resulted from a core power (i.e., rated thermal power) of 2,652 MWt and 8 MWt from the reactor coolant pumps. The engineered safety features system design was originally based on 2,780 MWt core power. The reinforced concrete containment structure design was originally based on a core power of 2713 MWt and operation at subatmospheric pressure (approximately 9.5 psia). The NSSS design was based upon an expected ultimate output of approximately 2,774 MWt. This NSSS output resulted from a core power of 2,766 MWt and 8 MWt from the reactor coolant pumps with an equivalent station net electrical output of approximately 870.0 MWe, assuming an atmospheric wet bulb of 44.68F coincident with a dry bulb temperature of 53.2F. However, all safety analyses were originally based on power levels that conservatively reflect plant operating conditions.   
by the Applicants, with the assistance of their agent, Stone &  
 
Webster Engineering Corporation.  
 
The NSSS was originally designed for a warranted power output of 2,660 MWt, which was the license application rating, with an  
 
equivalent station net electrical output of approximately 836.0 MWe, assuming an atmospheric wet bulb of 44.85F coincident with a dry bulb temperature of 53.4F. The NSSS output of 2,660 MWt resulted from a core power (i.e., rated thermal power) of 2,652 MWt and 8 MWt from the reactor coolant  
 
pumps. The engineered safety features system design was  
 
originally based on 2,780 MWt core power. The reinforced concrete containment structure design was originally based on a core power of 2713 MWt and operation at subatmospheric pressure  
 
(approximately 9.5 psia). The NSSS design was based upon an expected ultimate output of approximately 2,774 MWt. This NSSS output resulted from a core power of 2,766 MWt and 8 MWt from  
 
the reactor coolant pumps with an equivalent station net electrical output of approximately 870.0 MWe, assuming an  
 
atmospheric wet bulb of 44.68F coincident with a dry bulb temperature of 53.2F. However, all safety analyses were originally based on power levels that conservatively reflect  
 
plant operating conditions.   
 
The core power level (i.e., rated thermal power) was increased
 
in Fall 2001 to 2,689 MWt, taking advantage of the feedwater flow Measurement Uncertainty Recapture (MUR). The corresponding
 
NSSS thermal power level was 2,697 MWt, which included 8 MWt
 
from the reactor coolant pumps. The core power level was subsequently licensed to 2,900 MWt in 2006 per Amendment 156.
The corresponding NSSS thermal power level is 2,910 MWt, which includes 10 MWt of heat from non-reactor sources (primarily reactor coolant pump heat). The containment conversion to an
 
atmospheric containment (License Amendment 153) was based on the
 
uprated core power level of 2900 MWt. Analyses and engineering evaluations, as appropriate, at these increased thermal power levels were performed in the areas of thermal-hydraulic and nuclear characteristics of the reactor core, postulated accidents, and plant systems and components. The corresponding
 
uprated gross electrical output is 1,009 MWe.
 
BVPS-2 UFSAR Rev. 16 1.1-2 The remainder of Chapter 1 summarizes the principal design features and safety criteria of BVPS-2. Comparisons with other pressurized water reactor nuclear power stations now proposed or authorized for operation which employ essentially the same
 
technology and basic engineering features are provided. The facilities shared between BVPS-1 and BVPS-2 are also discussed in Chapter 1.
 
The Final Safety Analysis report was originally prepared in accordance with the guidelines of Regulatory Guide 1.70,


The core power level (i.e., rated thermal power) was increased in Fall 2001 to 2,689 MWt, taking advantage of the feedwater flow Measurement Uncertainty Recapture (MUR). The corresponding NSSS thermal power level was 2,697 MWt, which included 8 MWt from the reactor coolant pumps. The core power level was subsequently licensed to 2,900 MWt in 2006 per Amendment 156.
Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants (Revision 3, November 1978) as discussed in Section 1.8.  
The corresponding NSSS thermal power level is 2,910 MWt, which includes 10 MWt of heat from non-reactor sources (primarily reactor coolant pump heat). The containment conversion to an atmospheric containment (License Amendment 153) was based on the uprated core power level of 2900 MWt. Analyses and engineering evaluations, as appropriate, at these increased thermal power levels were performed in the areas of thermal-hydraulic and nuclear characteristics of the reactor core, postulated accidents, and plant systems and components. The corresponding uprated gross electrical output is 1,009 MWe.
 
BVPS-2 UFSAR Rev. 16 1.1-2 The remainder of Chapter 1 summarizes the principal design features and safety criteria of BVPS-2. Comparisons with other pressurized water reactor nuclear power stations now proposed or authorized for operation which employ essentially the same technology and basic engineering features are provided. The facilities shared between BVPS-1 and BVPS-2 are also discussed in Chapter 1.
BVPS-2 UFSAR Rev. 14 1.2-1 1.2  GENERAL PLANT DESCRIPTION 1.2.1 General
The Final Safety Analysis report was originally prepared in accordance with the guidelines of Regulatory Guide 1.70, Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants (Revision 3, November 1978) as discussed in Section 1.8.  
 
Beaver Valley Power Station - Unit 2 (BVPS-2) incorporates a three-loop, closed-cycle, pressurized water nuclear steam supply system (NSSS), a tandem compound turbine generator, engineered safeguards systems, radioactive waste systems, a fuel handling system, and other facilities and auxiliaries required for a nuclear power plant.  


BVPS-2 UFSAR Rev. 14 1.2-1 1.2  GENERAL PLANT DESCRIPTION  1.2.1  General Beaver Valley Power Station - Unit 2 (BVPS-2) incorporates a three-loop, closed-cycle, pressurized water nuclear steam supply system (NSSS), a tandem compound turbine generator, engineered safeguards systems, radioactive waste systems, a fuel handling system, and other facilities and auxiliaries required for a nuclear power plant.
Beaver Valley Power Station - Unit 1 (BVPS-1) facilities shared by BVPS-2 include the following:  
Beaver Valley Power Station - Unit 1 (BVPS-1) facilities shared by BVPS-2 include the following:  
: 1. Intake structure (Section 9.2.1), 2. Alternate intake structure (Section 9.2.1), 3. Control building,  
: 1. Intake structure (Section 9.2.1),  
: 4. Portions of the service building,
: 2. Alternate intake structure (Section 9.2.1),  
: 3. Control building,  
: 4. Portions of the service building,  
: 5. Portions of the auxiliary building, including the solid waste extension boron recovery system (BRS)  
: 5. Portions of the auxiliary building, including the solid waste extension boron recovery system (BRS)  
(Section 9.3.4.6), gaseous waste system (Section 11.3), liquid waste system (Section 11.2), and primary grade water system (Section 9.2.8), 6. Portions of the turbine building, including the demineralized water makeup system (Section 9.2.3),
 
: 7. Ultimate heat sink (Section 9.2.5), 8. Primary grade water storage tanks,  
(Section 9.3.4.6), gaseous waste system (Section 11.3), liquid waste system (Section 11.2), and primary grade water system (Section 9.2.8),  
: 9. Meteorological tower,
: 6. Portions of the turbine building, including the demineralized water makeup system (Section 9.2.3),  
: 10. Interconnecting tunnels, 11. Cooling tower elevated release point,  
: 7. Ultimate heat sink (Section 9.2.5),  
: 12. Potable and sanitary water system (Section 9.2.4),
: 8. Primary grade water storage tanks,  
: 13. Site drainage system, 14. Fire protection system (Section 9.5.1),  
: 9. Meteorological tower,  
: 15. Portions of the communications systems (Section 9.5.2),  16. Emergency diesel generators during a station blackout event (Section 8.3.1.1.19)
: 10. Interconnecting tunnels,  
BVPS-2 UFSAR Rev. 12 1.2-2 1.2.2  Site The site, comprising approximately 453 acres, is located on the south bank of the Ohio River in Beaver County, approximately 25 miles northwest of Pittsburgh. The site area and adjacent Ohio River provide a minimum exclusion radius of 1,500 feet. The nearest continuously occupied residence is located about 2,300 feet from the reactor. The low population zone area distance is 3.6 miles. The population center distance is 17 miles. The area is primarily industrial with some agricultural activity. A more complete description of the site is presented in Section 2.1.
: 11. Cooling tower elevated release point,  
1.2.3  Structures The general arrangement of structures for BVPS-2 is as shown on Figure 1.2-1. The major building areas include the containment structure, auxiliary building, fuel and decontamination building, safeguards area, main steam and cable vault area, turbine building, service building, diesel generator building, waste handling building, condensate polishing building, cooling tower, refueling water storage tank (RWST) enclosure, primary demineralized water storage tank enclosure, emergency outfall structure, cooling tower pump house, gaseous waste storage area, and the control building.
: 12. Potable and sanitary water system (Section 9.2.4),  
Except for the steel framed turbine building and cooling tower pump house, the structures are constructed predominantly of reinforced concrete. The containment is a steel-lined, reinforced concrete cylinder with a hemispherical dome and flat base. The cooling tower is a natural draft hyperbolic type with a reinforced concrete shell. Structures housing safety-related equipment are the containment structure, safeguards area, main steam and cable vault, auxiliary building, fuel and decontamination building, control building, diesel generator building, service building, RWST enclosure, and primary demineralized water storage tank enclosure.
: 13. Site drainage system,  
: 14. Fire protection system (Section 9.5.1),  
: 15. Portions of the communications systems (Section 9.5.2),  16. Emergency diesel generators during a station blackout event (Section 8.3.1.1.19)  
 
BVPS-2 UFSAR Rev. 12 1.2-2 1.2.2  Site The site, comprising approximately 453 acres, is located on the south bank of the Ohio River in Beaver County, approximately 25  
 
miles northwest of Pittsburgh. The site area and adjacent Ohio River provide a minimum exclusion radius of 1,500 feet. The nearest continuously occupied residence is located about 2,300 feet from the reactor. The low population zone area distance is 3.6 miles. The population center distance is 17 miles. The area is primarily industrial with some agricultural activity. A more complete description of the site is presented in Section 2.1.
1.2.3  Structures The general arrangement of structures for BVPS-2 is as shown on  
 
Figure 1.2-1. The major building areas include the containment structure, auxiliary building, fuel and decontamination building, safeguards area, main steam and cable vault area, turbine building, service building, diesel generator building, waste handling building, condensate polishing building, cooling tower, refueling water storage tank (RWST) enclosure, primary demineralized water storage tank enclosure, emergency outfall structure, cooling tower pump house, gaseous waste storage area, and the control building.  
 
Except for the steel framed turbine building and cooling tower pump house, the structures are constructed predominantly of reinforced concrete. The containment is a steel-lined, reinforced concrete cylinder with a hemispherical dome and flat base. The cooling tower is a natural draft hyperbolic type with  
 
a reinforced concrete shell.
Structures housing safety-related equipment are the containment structure, safeguards area, main steam and cable vault, auxiliary building, fuel and decontamination building, control building, diesel generator building, service building, RWST enclosure, and primary demineralized water storage tank enclosure.  
 
The BVPS-2 structures are separate from BVPS-1 structures. Passage between BVPS-1 and BVPS-2 is via a personnel bridge between the auxiliary building of BVPS-2 and the coolant recovery area of BVPS-1, and via an underground passageway between the auxiliary building of BVPS-2 and entrance area of BVPS-1.
The BVPS-2 structures are separate from BVPS-1 structures. Passage between BVPS-1 and BVPS-2 is via a personnel bridge between the auxiliary building of BVPS-2 and the coolant recovery area of BVPS-1, and via an underground passageway between the auxiliary building of BVPS-2 and entrance area of BVPS-1.
Further information on the function, design, and layout of the plant structures is presented in Section 3.8.
Further information on the function, design, and layout of the plant structures is presented in Section 3.8.  
1.2.4  Nuclear Steam Supply System The NSSS consists of a pressurized water reactor, reactor coolant system (RCS), and associated auxiliary systems. The RCS is arranged as three reactor coolant loops connected in parallel to the reactor vessel, each containing a reactor coolant pump (RCP) and a steam generator. An electrically heated pressurizer is connected to the hot leg of one reactor coolant loop.  
 
1.2.4  Nuclear Steam Supply System  
 
The NSSS consists of a pressurized water reactor, reactor coolant system (RCS), and associated auxiliary systems. The RCS is arranged as three reactor coolant loops connected in parallel to the reactor vessel, each containing a reactor coolant pump (RCP) and a steam generator. An electrically heated pressurizer is connected to the hot leg of one reactor coolant loop.
 
BVPS-2 UFSAR Rev. 12 1.2-3  High pressure water circulates through the reactor core to remove the heat generated by the nuclear chain reaction. The heated water exits from the reactor vessel and passes, via the coolant loop piping to the steam generators. Here it gives up its heat to the feedwater to generate steam for the turbine generator. The cycle is completed when the water is pumped back to the reactor vessel. The entire RCS is composed of leaktight components to ensure that fluids are confined to the system.
 
The core is of the multi-region type, which may utilize varying enrichments between regions.
 
In the initial core loading, three fuel enrichments are used. Fuel assemblies with the highest enrichments are placed at the core periphery, or outer region, and the two groups of lower enrichment fuel assemblies are arranged in a selected pattern in the central region. In subsequent refuelings, a portion of the fuel is replaced and new fuel is loaded in accordance with the core reload design.
Rod cluster control assemblies are used for reactor control and consist of clusters of cylindrical absorber rods. The absorber rods move within guide tubes in certain fuel assemblies. Above the core, each cluster of absorber rods is attached to a spider
 
connector and drive shaft, which is raised and lowered by a drive mechanism mounted on the reactor vessel head. Downward trip of the rod cluster is by gravity.
 
The RCPs are Westinghouse Electric Corporation (Westinghouse) vertical, single-stage, centrifugal pumps of the shaft-seal type. The system piping arrangement and the coastdown feature of the RCPs upon loss of electrical power are designed so that adequate coolant flow is maintained to cool the reactor core under all required circumstances considered in the safety analysis.
 
The steam generators are Westinghouse vertical U-tube units which contain Inconel tubes. Integral moisture separation equipment reduces the moisture content of the effluent steam to
 
one-quarter of one percent, or less. The reactor coolant loop stop and bypass valves are motor-operated gate valves remotely controlled from the main control room.
The reactor coolant piping and all of the pressure-containing and heat transfer surfaces in contact with primary coolant are
 
stainless steel or stainless  steel clad except the steam generator tubes and fuel tubes, which are Inconel and  Zircaloy, respectively. The steam generator tube sheet is Inconel clad on the primary side, and the steam generator channel head divider plate is Inconel. Reactor core internals, including control rod drive shafts, are primarily stainless steel.
 
BVPS-2 UFSAR Rev. 16 1.2-4  An electrically heated pressurizer, connected to one reactor coolant loop, maintains RCS pressure during normal operation, limits pressure variations during plant load transients, and
 
keeps system pressure within design limits during abnormal conditions.
 
Auxiliary systems and components are provided to charge makeup water to the RCS, purify reactor coolant water, provide chemicals for corrosion inhibition and reactivity control, cool system components, remove decay heat when the reactor is shut down, and provide for emergency safety injection.
 
1.2.5  Instrumentation and Control Systems The instrumentation and controls for the reactor protection system, engineered safety features actuation system, and other safety-related systems, meet the requirements of IEEE Standard 279-1971, "Criteria for Nuclear Power Plant Protection Systems."
In addition, other applicable criteria are met as described in Sections 3.1 and 7.1.2.
 
The nonsafety-related instrumentation and controls provide reliable control and allow continuous monitoring of the plant status without degradation of safety-related instrumentation.
 
Design details are described in Section 7.7.
The application of instrumentation and controls to individual
 
systems is detailed in the FSAR section describing the system.
The reactor is controlled by a coordinated combination of chemical shim and control rod assemblies, which are required for load-follow transients and for start-up and shutdown. The chemical shim is a soluble neutron absorber, boron, in the form of boric acid. The boric acid is added during cold shutdown, partially removed at start-up, and adjusted in concentration during core lifetime to compensate for such effects as fuel
 
depletion and accumulation of fission products which tend to slow the nuclear chain reaction.  


BVPS-2 UFSAR Rev. 12 1.2-3  High pressure water circulates through the reactor core to remove the heat generated by the nuclear chain reaction. The heated water exits from the reactor vessel and passes, via the coolant loop piping to the steam generators. Here it gives up its heat to the feedwater to generate steam for the turbine generator. The cycle is completed when the water is pumped back to the reactor vessel. The entire RCS is composed of leaktight components to ensure that fluids are confined to the system.
The control system allows the plant to accept step load increases of 10 percent and ramp load increases of 5 percent/minute over a load range of 15 percent to, but not exceeding, 100 percent power under normal operating conditions subject to xenon limitations. Equal step and ramp load reductions are possible, over the range of 100 to 15 percent of  
The core is of the multi-region type, which may utilize varying enrichments between regions.
In the initial core loading, three fuel enrichments are used. Fuel assemblies with the highest enrichments are placed at the core periphery, or outer region, and the two groups of lower enrichment fuel assemblies are arranged in a selected pattern in the central region. In subsequent refuelings, a portion of the fuel is replaced and new fuel is loaded in accordance with the core reload design. Rod cluster control assemblies are used for reactor control and consist of clusters of cylindrical absorber rods. The absorber rods move within guide tubes in certain fuel assemblies. Above the core, each cluster of absorber rods is attached to a spider connector and drive shaft, which is raised and lowered by a drive mechanism mounted on the reactor vessel head. Downward trip of the rod cluster is by gravity.
The RCPs are Westinghouse Electric Corporation (Westinghouse) vertical, single-stage, centrifugal pumps of the shaft-seal type. The system piping arrangement and the coastdown feature of the RCPs upon loss of electrical power are designed so that adequate coolant flow is maintained to cool the reactor core under all required circumstances considered in the safety analysis.
The steam generators are Westinghouse vertical U-tube units which contain Inconel tubes. Integral moisture separation equipment reduces the moisture content of the effluent steam to one-quarter of one percent, or less. The reactor coolant loop stop and bypass valves are motor-operated gate valves remotely controlled from the main control room. The reactor coolant piping and all of the pressure-containing and heat transfer surfaces in contact with primary coolant are stainless steel or stainless  steel clad except the steam generator tubes and fuel tubes, which are Inconel and  Zircaloy, respectively. The steam generator tube sheet is Inconel clad on the primary side, and the steam generator channel head divider plate is Inconel. Reactor core internals, including control rod drive shafts, are primarily stainless steel.


BVPS-2 UFSAR Rev. 16 1.2-4  An electrically heated pressurizer, connected to one reactor coolant loop, maintains RCS pressure during normal operation, limits pressure variations during plant load transients, and keeps system pressure within design limits during abnormal conditions.
full power.
Auxiliary systems and components are provided to charge makeup water to the RCS, purify reactor coolant water, provide chemicals for corrosion inhibition and reactivity control, cool system components, remove decay heat when the reactor is shut down, and provide for emergency safety injection.
Technical Specifications require an anticipatory reactor trip following turbine trip above approximately 49% of full reactor power. The turbine bypass system's capability to permit a 50 percent external load rejection without turbine or reactor trip is discussed in Section 10.4.4.  
1.2.5  Instrumentation and Control Systems  The instrumentation and controls for the reactor protection system, engineered safety features actuation system, and other safety-related systems, meet the requirements of IEEE Standard 279-1971, "Criteria for Nuclear Power Plant Protection Systems."
In addition, other applicable criteria are met as described in Sections 3.1 and 7.1.2.
The nonsafety-related instrumentation and controls provide reliable control and allow continuous monitoring of the plant status without degradation of safety-related instrumentation.
Design details are described in Section 7.7. The application of instrumentation and controls to individual systems is detailed in the FSAR section describing the system. The reactor is controlled by a coordinated combination of chemical shim and control rod assemblies, which are required for load-follow transients and for start-up and shutdown. The chemical shim is a soluble neutron absorber, boron, in the form of boric acid. The boric acid is added during cold shutdown, partially removed at start-up, and adjusted in concentration during core lifetime to compensate for such effects as fuel depletion and accumulation of fission products which tend to slow the nuclear chain reaction.
The control system allows the plant to accept step load increases of 10 percent and ramp load increases of 5 percent/minute over a load range of 15 percent to, but not exceeding, 100 percent power under normal operating conditions subject to xenon limitations. Equal step and ramp load reductions are possible, over the range of 100 to 15 percent of full power. Technical Specifications require an anticipatory reactor trip following turbine trip above approximately 49% of full reactor power. The turbine bypass system's capability to permit a 50 percent external load rejection without turbine or reactor trip is discussed in Section 10.4.4.
BVPS-2 UFSAR Rev. 15 1.2-5 Control of the reactor and the turbine generator is accomplished from the main control room, which contains all instrumentation and control equipment required for start-up, operation, and shutdown, including normal and accident conditions. The turbine generator controls are designed for manual operation with the operator selecting the load set point and loading rate. The NSSS can follow the turbine generator from loads of 15 to 100 percent power. If during rapid turbine generator loading (5 percent/minute), the response of the control rods and chemical shim is not adequate to supply the needed reactivity, the reactor coolant temperature will drop, resulting in an increase of reactivity.
1.2.6  Radioactive Waste System  Radioactive wastes are collected, processed, and disposed of in a safe manner complying with appropriate regulations:  in particular, the U.S. Nuclear Regulatory Commission Regulations, 10 CFR 20 and 10 CFR 50, Appendix I Annex. The three interrelated radioactive waste treatment systems for radioactive liquid, gaseous, and solid wastes are described in detail in Chapter 11.
The radioactive liquid waste system, in combination with the steam generator blowdown system, collects and purifies radioactive liquid waste generated during operation and refueling for either recycling within the plant or discharge. The process operations available to treat liquid wastes are filtration, evaporation, and demineralization. Connections are provided to process liquid wastes with BVPS-1 facilities, when necessary. The system is described in Section 11.2. Radioactive gaseous wastes are treated before release to the environment. Degasification and purification of the reactor coolant letdown reduces the in-containment radiation exposures and the in- plant consequences of any reactor coolant leakage. The degasification and purification processes produce gaseous streams, which, together with hydrogenated vents, are passed through  charcoal delay beds  to provide holdup time for the decay of noble gases and the removal of iodine. Air ejector vents are selectively delayed in separate charcoal beds. Aerated streams, produced by other phases of plant operation, are passed through high efficiency particulate air (HEPA) filters for particulate removal and charcoal adsorbers for iodine removal, as needed. Periodic batch disposal of degasifier effluent gases (primarily hydrogen) are sent to the BVPS-1 gaseous waste disposal system for discharge. Degasifier gases may be recycled back to the volume control tank. Sweep gases are filtered by a HEPA filter and, along with the containment vacuum pump discharge, are sent to BVPS-1 for final release to the environment. The plant is also equipped with seven gaseous waste storage tanks to provide the available storage space for hydrogen gas, prior to batch discharging for one unit going to cold shutdown. This system is described in Section 11.3.  


BVPS-2 UFSAR Rev. 20 1.2-6 The radioactive solid waste system provides packaging and storage facilities for the eventual shipment offsite and ultimate disposal of solid radioactive waste material.
BVPS-2 UFSAR Rev. 15 1.2-5 Control of the reactor and the turbine generator is accomplished from the main control room, which contains all instrumentation and control equipment required for start-up, operation, and shutdown, including normal and accident conditions. The turbine generator controls are designed for manual operation with the operator selecting the load set point and loading rate. The NSSS can follow the turbine generator from loads of 15 to 100 percent power. If during rapid turbine generator loading (5 percent/minute), the response of the control rods and chemical shim is not adequate to supply the needed reactivity, the reactor coolant temperature will drop, resulting in an increase of reactivity. 
Available process operations include dewatering and pH adjustment of beaded resins, powdered resins, evaporator bottoms, and solidification of the waste with an in-drum cement system. Dry radioactive waste produced in the operation and maintenance of BVPS-2 may be baled or packaged, for shipment to an authorized offsite disposal location. Provisions for shielding during the processing and shipping preparations are included. As a backup, connections are provided to process beaded resin and evaporator bottoms with the BVPS-1 solidification facilities. This system is described in Section 11.4.  
 
1.2.6  Radioactive Waste System Radioactive wastes are collected, processed, and disposed of in a safe manner complying with appropriate regulations:  in particular, the U.S. Nuclear Regulatory Commission Regulations, 10 CFR 20 and 10 CFR 50, Appendix I Annex. The three interrelated radioactive waste treatment systems for radioactive liquid, gaseous, and solid wastes are described in detail in Chapter 11.
 
The radioactive liquid waste system, in combination with the steam generator blowdown system, collects and purifies radioactive liquid waste generated during operation and refueling for either recycling within the plant or discharge. The process operations available to treat liquid wastes are
 
filtration, evaporation, and demineralization. Connections are provided to process liquid wastes with BVPS-1 facilities, when necessary. The system is described in Section 11.2.
Radioactive gaseous wastes are treated before release to the environment. Degasification and purification of the reactor coolant letdown reduces the in-containment radiation exposures and the in- plant consequences of any reactor coolant leakage. The degasification and purification processes produce gaseous streams, which, together with hydrogenated vents, are passed through  charcoal delay beds  to provide holdup time for the decay of noble gases and the removal of iodine. Air ejector
 
vents are selectively delayed in separate charcoal beds. Aerated streams, produced by other phases of plant operation, are passed through high efficiency particulate air (HEPA)
 
filters for particulate removal and charcoal adsorbers for iodine removal, as needed. Periodic batch disposal of degasifier effluent gases (primarily hydrogen) are sent to the BVPS-1 gaseous waste disposal system for discharge. Degasifier gases may be recycled back to the volume control tank. Sweep gases are filtered by a HEPA filter and, along with the containment vacuum pump discharge, are sent to BVPS-1 for final release to the environment. The plant is also equipped with seven gaseous waste storage tanks to provide the available storage space for hydrogen gas, prior to batch discharging for one unit going to cold shutdown. This system is described in Section 11.3.
 
BVPS-2 UFSAR Rev. 20 1.2-6 The radioactive solid waste system provides packaging and storage facilities for the eventual shipment offsite and ultimate disposal of solid radioactive waste material.
 
Available process operations include dewatering and pH adjustment of beaded resins, powdered resins, evaporator bottoms, and solidification of the waste with an in-drum cement system. Dry radioactive waste produced in the operation and  
 
maintenance of BVPS-2 may be baled or packaged, for shipment to an authorized offsite disposal location. Provisions for shielding during the processing and shipping preparations are included. As a backup, connections are provided to process  
 
beaded resin and evaporator bottoms with the BVPS-1 solidification facilities. This system is described in  
 
Section 11.4.  


1.2.7  Fuel Handling  
1.2.7  Fuel Handling  


The reactor is refueled by equipment which handles the spent fuel underwater from the time it leaves the reactor vessel until it is placed in a shipping cask for shipment from the site.
The reactor is refueled by equipment which handles the spent  
Underwater transfer of spent fuel provides an economic and transparent radiation shield, as well as a reliable coolant for removal of decay heat.


The fuel handling system is divided into two areas:  the reactor cavity area, which is flooded for refueling; and the fuel pool, which is external to the containment and is always accessible to plant personnel. The two areas are connected by a fuel transfer system which carries the fuel through a containment penetration.  
fuel underwater from the time it leaves the reactor vessel until it is placed in a shipping cask for shipment from the site.
Underwater transfer of spent fuel provides an economic and transparent radiation shield, as well as a reliable coolant for
 
removal of decay heat.
 
The fuel handling system is divided into two areas:  the reactor  
 
cavity area, which is flooded for refueling; and the fuel pool,  
 
which is external to the containment and is always accessible to plant personnel. The two areas are connected by a fuel transfer  
 
system which carries the fuel through a containment penetration.  


The design of the fuel transfer tube shielding inside the containment utilizes a labyrinth of steel and concrete shields.
The design of the fuel transfer tube shielding inside the containment utilizes a labyrinth of steel and concrete shields.
Outside of the containment, the shielding design utilizes a notched interlocking wall arrangement. Section 12.3.2.5 provides a detailed description of the fuel transfer tube shielding and arrangement.  
Outside of the containment, the shielding design utilizes a notched interlocking wall arrangement. Section 12.3.2.5 provides a detailed description of the fuel transfer tube  
 
shielding and arrangement.  
 
Spent fuel is removed from the reactor vessel by a refueling machine and placed in the fuel transfer system. In the fuel
 
pool, the fuel is removed from the transfer system and placed


Spent fuel is removed from the reactor vessel by a refueling machine and placed in the fuel transfer system. In the fuel pool, the fuel is removed from the transfer system and placed into storage racks. After a suitable decay period, and when offsite storage facilities or processing facilities are available, the fuel is removed from storage and loaded underwater into shipping casks for offsite transport. Storage is provided for no more than 1,690 spent fuel assemblies. Spent fuel storage is discussed in Section 9.1.2.  
into storage racks. After a suitable decay period, and when offsite storage facilities or processing facilities are available, the fuel is removed from storage and loaded underwater into shipping casks for offsite transport. Storage is provided for no more than 1,690 spent fuel assemblies. Spent fuel storage is discussed in Section 9.1.2.  


1.2.8  Turbine and Turbine Auxiliaries  
1.2.8  Turbine and Turbine Auxiliaries  
Line 93: Line 247:
1.2.8.1  Turbine Generator  
1.2.8.1  Turbine Generator  


The turbine is an 1,800 rpm, tandem-compound, four-flow, single-stage reheat unit with provision for six stages of feedwater heating. The turbine-generator is provided with an electro-hydraulic control system and with redundant emergency trip systems for turbine overspeed. The output of the turbine-generator is described in Section 10.2.  
The turbine is an 1,800 rpm, tandem-compound, four-flow, single-stage reheat unit with provision for six stages of feedwater  
 
heating. The turbine-generator is provided with an electro-
 
hydraulic control system and with redundant emergency trip systems for turbine overspeed. The output of the turbine-
 
generator is described in Section 10.2.  
 
BVPS-2 UFSAR Rev. 17 1.2-7  The generator is a direct driven, three-phase, 60 Hz, 22 kV, 1,800 rpm hydrogen inner-cooled, synchronous generator rated at 1,070 MVA at 0.92 power factor, and 0.61 short-circuit ratio at maximum hydrogen pressure of 75 psig.
1.2.8.2  Main Steam System
 
The main steam system delivers steam from the steam generators via three main steam lines to a 38 inch header which feeds four 28 inch lines to the turbine generator. The 38 inch header also supplies steam to the moisture separator reheaters, the auxiliary steam system, the gland seal steam system, and the
 
turbine bypass valves. Branches from each of three lines from the steam generators supply steam to the turbine driven auxiliary feed pump.
 
1.2.8.3  Main Condenser The main condenser condenses the turbine exhaust steam and maintains the turbine back pressure at 2 in Hg abs when
 
operating at turbine guarantee conditions with approximately
 
65F circulating water inlet temperature. The condenser includes provisions for accepting steam bypassed around the turbine-generator. Deaeration of condensate is accomplished in
 
the condenser.
1.2.8.4  Main Condenser Air Removal System
 
The main condenser air removal system uses steam jet air ejectors for normal operation and vacuum priming ejectors for start-up. The system evacuates noncondensible gases from the main turbine and condenser during plant start-up, and maintains the condenser essentially free of gases during operation. The system handles all inleakage of noncondensible gases through the turbine seals, condensate, feedwater, and steam systems, including the steam generators in the event of primary to secondary leakage.
 
1.2.8.5  Turbine Gland Sealing System
 
The turbine gland sealing system provides clean, relatively moisture- free steam to the seals of the turbine throttle valve stem glands and the turbine shaft glands. The sealing steam is normally provided from the 38-inch main steam header. Leakoff from the seals is directed to the gland steam condenser. The generator shaft seals are sealed with lubricating oil to prevent
 
hydrogen leakage.
 
BVPS-2 UFSAR Rev. 16 1.2-8 1.2.8.6  Steam Bypass System and Pressure Control System A turbine bypass system is provided to pass steam directly to the main condenser under the control of a pressure/temperature control regulator. Steam is bypassed to the condenser whenever the turbine trips or during start-up and cooldown. The turbine bypass system is capable of discharging steam flow directly to the main condenser. The capability of the turbine bypass system to mitigate a turbine and reactor trip upon loss of electrical load is discussed in Section 10.4.4.
 
1.2.8.7  Circulating Water System
 
The circulating water system provides the condenser with a continuous supply of cooling water. The circulating water system is a pumped, closed-loop system utilizing an air-cooled,
 
natural draft hyperbolic cooling tower as a heat sink. Four one-quarter capacity circulating water pumps are provided to pump cooling water from the discharge of the condenser to the


BVPS-2 UFSAR Rev. 17 1.2-7  The generator is a direct driven, three-phase, 60 Hz, 22 kV, 1,800 rpm hydrogen inner-cooled, synchronous generator rated at 1,070 MVA at 0.92 power factor, and 0.61 short-circuit ratio at maximum hydrogen pressure of 75 psig. 1.2.8.2  Main Steam System The main steam system delivers steam from the steam generators via three main steam lines to a 38 inch header which feeds four 28 inch lines to the turbine generator. The 38 inch header also supplies steam to the moisture separator reheaters, the auxiliary steam system, the gland seal steam system, and the turbine bypass valves. Branches from each of three lines from the steam generators supply steam to the turbine driven auxiliary feed pump.
tower. The cooling water is then gravity-fed back to the condenser. Makeup water is provided from the Ohio River by the service water system. Water quality is controlled by blowdown  
1.2.8.3  Main Condenser  The main condenser condenses the turbine exhaust steam and maintains the turbine back pressure at 2 in Hg abs when operating at turbine guarantee conditions with approximately 65F circulating water inlet temperature. The condenser includes provisions for accepting steam bypassed around the turbine-generator. Deaeration of condensate is accomplished in the condenser. 1.2.8.4  Main Condenser Air Removal System The main condenser air removal system uses steam jet air ejectors for normal operation and vacuum priming ejectors for start-up. The system evacuates noncondensible gases from the main turbine and condenser during plant start-up, and maintains the condenser essentially free of gases during operation. The system handles all inleakage of noncondensible gases through the turbine seals, condensate, feedwater, and steam systems, including the steam generators in the event of primary to secondary leakage.
1.2.8.5  Turbine Gland Sealing System The turbine gland sealing system provides clean, relatively moisture- free steam to the seals of the turbine throttle valve stem glands and the turbine shaft glands. The sealing steam is normally provided from the 38-inch main steam header. Leakoff from the seals is directed to the gland steam condenser. The generator shaft seals are sealed with lubricating oil to prevent hydrogen leakage.
BVPS-2 UFSAR Rev. 16 1.2-8 1.2.8.6  Steam Bypass System and Pressure Control System  A turbine bypass system is provided to pass steam directly to the main condenser under the control of a pressure/temperature control regulator. Steam is bypassed to the condenser whenever the turbine trips or during start-up and cooldown. The turbine bypass system is capable of discharging steam flow directly to the main condenser. The capability of the turbine bypass system to mitigate a turbine and reactor trip upon loss of electrical load is discussed in Section 10.4.4.
1.2.8.7  Circulating Water System The circulating water system provides the condenser with a continuous supply of cooling water. The circulating water system is a pumped, closed-loop system utilizing an air-cooled, natural draft hyperbolic cooling tower as a heat sink. Four one-quarter capacity circulating water pumps are provided to pump cooling water from the discharge of the condenser to the tower. The cooling water is then gravity-fed back to the condenser. Makeup water is provided from the Ohio River by the service water system. Water quality is controlled by blowdown to the Ohio River. 1.2.8.8  Condensate and Feedwater Systems The condensate and feedwater systems supply condensate from the condenser hotwell to the steam generators. The condensate is normally pumped by two of three 50-percent design capacity condensate pumps through the full flow condensate polishing system to the intercooler and aftercooler of the air ejector, and the gland seal condenser. The condensate then flows through drain coolers and five stages of low pressure heaters. The drain coolers and low pressure heaters are split into two one-half capacity parallel streams. The last low pressure heaters discharge to the suction of two parallel, motor-driven, steam generator feedwater pumps. The discharge of the steam generator feedwater pumps passes through two one-half capacity parallel heaters and into the steam generators. The feedwater flow to each steam generator is controlled by a feedwater flow control valve located downstream of the heaters. 1.2.8.9  Condensate Polishing System A powdered resin condensate polishing system with regeneration and dewatering facilities, instrumentation, and semiautomatic controls is provided to ensure a constant supply of high quality water to the steam generators.
The polishing system is capable of processing the full flow from the discharge of the condensate pumps. The demineralized water is returned to the condensate system upstream of the air ejectors.
BVPS-2 UFSAR Rev. 20  1.2-9 1.2.9  Electrical Systems The main generator is an 1,800 rpm, 22 kV, three-phase, 60 Hz, hydrogen inner-cooled unit rated at 1,070 MVA at 0.92 power factor. One 1020 MVA main step-up transformer is provided to deliver power to the 345 kV switchyard.


The station service system consists of auxiliary transformers, 4,160 V switchgear, 480 V unit substations, 480 V motor control centers, 120 V ac vital and essential buses, and 125 V dc batteries and equipment. The normal source of station service power is obtained from the main generator through the unit station service transformers. The preferred source is available from the 138 kV high voltage switchyard through the system station service transformers. The BVPS-2 one-line electrical diagram is shown on Figure 8.3-1.
to the Ohio River.
1.2.8.8  Condensate and Feedwater Systems


Two onsite, emergency diesel generators are provided to supply power in the event of complete loss of normal and preferred alternate station service power. Each emergency diesel generator supplies power to separate and redundant trains of the plant emergency station service system. Each emergency diesel generator has sufficient capacity for operation of all safety-related equipment which must be operated to mitigate the effects of a design basis accident (DBA) or to shut down the unit in a safe manner.
The condensate and feedwater systems supply condensate from the condenser hotwell to the steam generators. The condensate is normally pumped by two of three 50-percent design capacity condensate pumps through the full flow condensate polishing system to the intercooler and aftercooler of the air ejector,


In addition, a third onsite, nonsafety diesel generator is provided to supply power to significant but nonsafety electrical loads whose loss,  in the event of a complete loss of normal system ac power, would result in substantial equipment damage.  
and the gland seal condenser. The condensate then flows through drain coolers and five stages of low pressure heaters. The drain coolers and low pressure heaters are split into two one-half capacity parallel streams. The last low pressure heaters discharge to the suction of two parallel, motor-driven, steam generator feedwater pumps. The discharge of the steam generator feedwater pumps passes through two one-half capacity parallel heaters and into the steam generators. The feedwater flow to each steam generator is controlled by a feedwater flow control
 
valve located downstream of the heaters.
1.2.8.9  Condensate Polishing System
 
A powdered resin condensate polishing system with regeneration and dewatering facilities, instrumentation, and semiautomatic
 
controls is provided to ensure a constant supply of high quality water to the steam generators.
 
The polishing system is capable of processing the full flow from the discharge of the condensate pumps. The demineralized water is returned to the condensate system upstream of the air
 
ejectors.
 
BVPS-2 UFSAR Rev. 20  1.2-9 1.2.9  Electrical Systems
 
The main generator is an 1,800 rpm, 22 kV, three-phase, 60 Hz, hydrogen inner-cooled unit rated at 1,070 MVA at 0.92 power
 
factor. One 1020 MVA main step-up transformer is provided to deliver power to the 345 kV switchyard.
 
The station service system consists of auxiliary transformers,
 
4,160 V switchgear, 480 V unit substations, 480 V motor control centers, 120 V ac vital and essential buses, and 125 V dc batteries and equipment. The normal source of station service power is obtained from the main generator through the unit
 
station service transformers. The preferred source is available from the 138 kV high voltage switchyard through the system station service transformers. The BVPS-2 one-line electrical
 
diagram is shown on Figure 8.3-1.
 
Two onsite, emergency diesel generators are provided to supply
 
power in the event of complete loss of normal and preferred alternate station service power. Each emergency diesel generator supplies power to separate and redundant trains of the plant emergency station service system. Each emergency diesel generator has sufficient capacity for operation of all safety-related equipment which must be operated to mitigate the effects
 
of a design basis accident (DBA) or to shut down the unit in a
 
safe manner.
 
In addition, a third onsite, nonsafety diesel generator is  
 
provided to supply power to significant but nonsafety electrical  
 
loads whose loss,  in the event of a complete loss of normal  
 
system ac power, would result in substantial equipment damage.  


1.2.10  Engineered Safety Features Systems  
1.2.10  Engineered Safety Features Systems  


The engineered safety features systems have sufficient redundancy and independence of components and power sources such that, under DBA conditions, the systems can maintain the integrity of the containment and keep potential exposures to the public within the radiation dose criteria given in 10 CFR 50.67, as appropriate, even when operating with only partial effectiveness (Chapter 6). The following systems are provided:   
The engineered safety features systems have sufficient  
: 1. The steel-lined, reinforced concrete containment structure provides a highly reliable barrier against the escape of radioactivity. The structure and all penetrations, including access openings and ventilation ducts, are of proven design.
 
: 2. The emergency core cooling systems cool the core by injecting borated water into the reactor coolant loops from the accumulators, the high- and low-head safety injection pumps, and the recirculation spray pumps (during the recirculation phase following a loss-of-coolant accident (LOCA).
redundancy and independence of components and power sources such  
BVPS-2 UFSAR Rev. 18 1.2-10 3. The quench spray subsystem of the containment depressurization system provides a spray of borated water to the containment atmosphere. The recirculation spray system provides a spray of borated water buffered by the containment sump pH control system to the containment atmosphere. Following the DBA, the containment pressure is reduced by the containment depressurization system. The sodium tetraborate in the containment sump pH control system combined in the recirculation spray removes iodine from the containment atmosphere. Subsequent long-term cooldown and depressurization is accomplished by the recirculation spray system. 4. Radioactive leakage through containment penetrations to contiguous plant areas is removed by the supplementary leak collection and release system. The effluent is monitored for activity and discharged to the atmosphere at a release point above the containment structure.
 
: 5. The post-DBA hydrogen control system has the capability of purging a portion of the containment atmosphere to the atmosphere outside containment following a DBA. The containment spray system provides mixing of the containment atmosphere.  
that, under DBA conditions, the systems can maintain the integrity of the containment and keep potential exposures to the  
: 6. The containment isolation system isolates pipe lines which penetrate the containment boundary in accordance with Appendix A of 10 CFR 50, General Design Criteria 55 through 57, so that in the event of a LOCA, radioactivity is not released to the environment.
 
: 7. The habitability system for the main control room is provided to ensure that the control room operators are able to remain in the area and operate the nuclear power unit safely under all conditions, including during and following a postulated DBA.
public within the radiation dose criteria given in 10 CFR 50.67, as appropriate, even when operating with only partial  
 
effectiveness (Chapter 6). The following systems are provided:   
: 1. The steel-lined, reinforced concrete containment structure provides a highly reliable barrier against the escape of radioactivity. The structure and all penetrations, including access openings and  
 
ventilation ducts, are of proven design.  
: 2. The emergency core cooling systems cool the core by injecting borated water into the reactor coolant loops  
 
from the accumulators, the high- and low-head safety injection pumps, and the recirculation spray pumps (during the recirculation phase following a loss-of-
 
coolant accident (LOCA).  
 
BVPS-2 UFSAR Rev. 18 1.2-10 3. The quench spray subsystem of the containment depressurization system provides a spray of borated water to the containment atmosphere. The recirculation spray system provides a spray of borated water buffered by the containment sump pH control system to the containment atmosphere. Following the DBA, the containment pressure is reduced by the containment depressurization system. The sodium tetraborate in the containment sump pH control system combined in the recirculation spray removes iodine from the containment atmosphere. Subsequent long-term cooldown and depressurization is accomplished by the recirculation spray system.  
: 4. Radioactive leakage through containment penetrations to contiguous plant areas is removed by the supplementary leak collection and release system. The  
 
effluent is monitored for activity and discharged to the atmosphere at a release point above the  
 
containment structure.  
: 5. The post-DBA hydrogen control system has the capability of purging a portion of the containment  
 
atmosphere to the atmosphere outside containment following a DBA. The containment spray system  
 
provides mixing of the containment atmosphere.
: 6. The containment isolation system isolates pipe lines which penetrate the containment boundary in accordance with Appendix A of 10 CFR 50, General Design Criteria  
 
55 through 57, so that in the event of a LOCA,  
 
radioactivity is not released to the environment.  
: 7. The habitability system for the main control room is provided to ensure that the control room operators are able to remain in the area and operate the nuclear power unit safely under all conditions, including  
 
during and following a postulated DBA.  
 
1.2.11  Cooling Water and Other Auxiliary Systems  
1.2.11  Cooling Water and Other Auxiliary Systems  


Safety-related auxiliary systems are as follows:  
Safety-related auxiliary systems are as follows:  
: 1. The service water system transfers heat from the primary component cooling water system and other safety-related systems to the ultimate heat sink.
: 1. The service water system transfers heat from the primary component cooling water system and other safety-related systems to the ultimate heat sink.
This system operates during all normal, upset and faulted conditions.
This system operates during all normal, upset and  
BVPS-2 UFSAR Rev. 13 1.2-11 2. The primary component cooling water system is an intermediate cooling system provided to transfer heat from the reactor auxiliary systems and from systems containing potentially radioactive liquids. The primary component cooling water system provides cooling water for systems and components required for a safe shutdown. 3. The emergency diesel generator fuel oil storage and transfer system is designed to store and supply sufficient fuel oil for seven days of continuous operation of each diesel engine. Independent emergency diesel generator cooling water systems, redundant starting air systems, and lubrication systems, are provided for each diesel. 4. Air conditioning and ventilation systems for safety-related areas control ambient air temperature and provide a suitable environment for personnel and equipment, with features to provide protection against the spread of airborne radioactive contamination. Areas subject to radioactive release have provisions for particulate and gaseous radiation monitoring and filtration of the ventilation exhaust air. 5. The spent fuel pool cooling system removes residual and decay heat from the spent fuel stored in the fuel pool. 6. The functions of the chemical and volume control systems include the control of boron concentrations in the RCS, maintenance of the proper RCS inventory, removal of fission and corrosion products, water chemistry control and continuous supply of filtered water to the reactor coolant pump seals. Portions of the system also provide emergency core cooling following a postulated accident. 7. The auxiliary feedwater system serves as an emergency backup for supplying feedwater to the secondary side of the steam generators upon loss of normal feedwater. 8. The residual heat removal system removes residual and decay heat from the core during reactor cooldown at RCS temperatures of 350F and below. Auxiliary systems which are nonsafety-related are as follows: 1. The boron recovery system stores and processes borated radioactive water from the RCS. The system employs degasifiers, evaporators, filters, and demineralizers to produce primary grade water and concentrated boric acid BVPS-2 UFSAR Rev. 0 1.2-12 solution for reuse in plant or disposal. Some of the equipment is shared with BVPS-1.
 
: 2. The vent and drain system collects hydrogenated or aerated fluids from various systems and transfers them to either the boron recovery system or the appropriate waste system. 3. The compressed air systems supply service and instrument air required for normal operation (Section 9.3.1).   
faulted conditions.  
: 4. The fire protection system includes a water system shared with BVPS-1, a low pressure CO2 system, a Halon system, portable fire extinguishers, and a smoke detection system. 5. The fuel pool purification system clarifies and purifies the water in the fuel pool, the refueling cavity, the transfer canal, and the refueling water storage tank. 6. The sampling systems provide the capability to collect representative reactor and steam plant liquid and gaseous samples at the sampling sinks for laboratory analysis.
 
: 7. The demineralized water and cask washdown system is used during all modes of operation to supply high quality water to various reactor plant and turbine plant systems for makeup, sample sink flushing, hose stations for decontamination and other miscellaneous services requiring demineralized water. This system is connected to the BVPS-1 demineralized water system which provides all demineralized water for both units.
BVPS-2 UFSAR Rev. 13 1.2-11 2. The primary component cooling water system is an intermediate cooling system provided to transfer heat from the reactor auxiliary systems and from systems containing potentially radioactive liquids. The  
: 8. The primary grade water system is a storage and distribution system that supplies reactor plant auxiliary systems exclusively. It also supplies makeup water to the reactor plant. The storage tanks and pumps for this shared system are located in BVPS-1. 9. The chilled water system provides chilled water to the containment atmosphere recirculation coolers and to various building air cooling equipment. 10. The turbine plant component cooling water system is an intermediate cooling system provided to transfer heat from the turbine plant equipment to the service water system.
 
nmIt\)lr-@$i#tFI.l/w-'"-*-/"'\aa\....)81f,$lQIFN:ol,t.,7"'-'l Y'l\;\.--"4FIi*Es -5:FP-FE ZilHHJ=!3i6etlz-sni$r,'ffii:7\ i@"rdi4 -.,o.OFOO5oo-1FrJ0FFI1oi'JItDN)O(-flNJOld5b\oO5H BVPS-2 UFSAR Rev. 16  1.3-1 1.3 COMPARISON TABLES The comparisons with other stations provided herein reflects the status of Beaver Valley Power Station - Unit 2 at the time of the issuance of the Operating License. This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR. 1.3.1  Comparison with Similar Facility Designs Beaver Valley Power Station - Unit 2 (BVPS-2) utilizes proven mature designs. The nuclear steam supply system (NSSS) is of proven design and incorporates systems, equipment, and technology which have been successfully applied in more than 100 units designed by Westinghouse Electric Corporation. The balance of the unit, including the containment structure, was designed and constructed by the Applicant through its agent, Stone & Webster Engineering Corporation (SWEC). The SWEC design incorporated mature design concepts which had been utilized in nine operating nuclear power plants and seven nuclear plants which were in various stages of design, U.S. Nuclear Regulatory Commission (USNRC) review, and construction. In Table 1.3-1, the general design features of BVPS-2 are compared with those of Beaver Valley Power Station - Unit 1 (BVPS-1), Millstone Unit 3 (Northeast Utility Company), and North Anna Units 1 and 2 (Virginia Electric Power Company). The plant comparison follows the general outline of the Final Safety Analysis Report (FSAR) chapters and is based on a single unit of each design. The USNRC has reviewed these designs extensively; BVPS-2 design incorporates the experience gained in these applications.
primary component cooling water system provides cooling water for systems and components required for a safe shutdown.  
1.3.1.1  Comparison of Nuclear Steam Supply Systems The NSSS for BVPS-2 is similar to that of the other units, except for power level differences. In addition, Millstone Unit 3 has four reactor coolant loops while the other units each have three loops.
: 3. The emergency diesel generator fuel oil storage and transfer system is designed to store and supply sufficient fuel oil for seven days of continuous operation of each diesel engine. Independent emergency diesel generator cooling water systems,  
1.3.1.2  Comparison of Engineered Safety Features The engineered safety features (ESF) compared are the emergency core cooling system (ECCS), containment heat removal system, containment combustible gas control system, containment isolation system, control room habitability, and the emergency filtration system. The ESF are the same, except BVPS-2 and Millstone Unit 3 utilize two of the recirculation spray pumps to inject recirculated containment sump water as part of the ECCS. The BVPS-2 recirculation spray pumps also supply the high head safety injection pumps in the ECCS recirculation mode. Beaver Valley Power Station - Unit 1 and North Anna Units 1 and 2 utilize low head safety injection pumps to perform this function.  
 
redundant starting air systems, and lubrication systems, are provided for each diesel.  
: 4. Air conditioning and ventilation systems for safety-related areas control ambient air temperature and  
 
provide a suitable environment for personnel and  
 
equipment, with features to provide protection against the spread of airborne radioactive contamination. Areas subject to radioactive release have provisions for particulate and gaseous radiation monitoring and filtration of the ventilation exhaust air.  
: 5. The spent fuel pool cooling system removes residual and decay heat from the spent fuel stored in the fuel  
 
pool. 6. The functions of the chemical and volume control systems include the control of boron concentrations in the RCS, maintenance of the proper RCS inventory, removal of fission and corrosion products, water chemistry control and continuous supply of filtered water to the reactor coolant pump seals. Portions of the system also provide emergency core cooling following a postulated accident.  
: 7. The auxiliary feedwater system serves as an emergency backup for supplying feedwater to the secondary side of the steam generators upon loss of normal feedwater.  
: 8. The residual heat removal system removes residual and decay heat from the core during reactor cooldown at RCS temperatures of 350F and below.
Auxiliary systems which are nonsafety-related are as follows:  
: 1. The boron recovery system stores and processes borated radioactive water from the RCS. The system employs degasifiers, evaporators, filters, and demineralizers to produce primary grade water and concentrated boric  
 
acid BVPS-2 UFSAR Rev. 0 1.2-12 solution for reuse in plant or disposal. Some of the equipment is shared with BVPS-1.  
: 2. The vent and drain system collects hydrogenated or aerated fluids from various systems and transfers them to either the boron recovery system or the appropriate waste system.  
: 3. The compressed air systems supply service and instrument air required for normal operation (Section 9.3.1).   
: 4. The fire protection system includes a water system shared with BVPS-1, a low pressure CO 2 system, a Halon system, portable fire extinguishers, and a smoke  
 
detection system.  
: 5. The fuel pool purification system clarifies and purifies the water in the fuel pool, the refueling cavity, the transfer canal, and the refueling water storage tank.  
: 6. The sampling systems provide the capability to collect representative reactor and steam plant liquid and  
 
gaseous samples at the sampling sinks for laboratory  
 
analysis.  
: 7. The demineralized water and cask washdown system is used during all modes of operation to supply high quality water to various reactor plant and turbine plant systems for makeup, sample sink flushing, hose  
 
stations for decontamination and other miscellaneous services requiring demineralized water. This system is connected to the BVPS-1 demineralized water system  
 
which provides all demineralized water for both units.  
: 8. The primary grade water system is a storage and distribution system that supplies reactor plant auxiliary systems exclusively. It also supplies makeup water to the reactor plant. The storage tanks  
 
and pumps for this shared system are located in BVPS-
: 1. 9. The chilled water system provides chilled water to the containment atmosphere recirculation coolers and to
 
various building air cooling equipment.  
: 10. The turbine plant component cooling water system is an intermediate cooling system provided to transfer heat from the turbine plant equipment to the service water system.
nmIt\)lr-@$i#tFI.l/w-'"-*-/"'\
aa\....)81f,$lQIFN:ol,t.,7"'-'l Y'l\;\.--"4FIi*Es -5:FP-FE ZilHHJ=!3i6etlz-sni$r,'ffii:7\ i@"rdi4 -.,o.OFOO5oo-1FrJ0FFI1oi'JItDN)O(-flNJOld5b\oO5H BVPS-2 UFSAR Rev. 16  1.3-1 1.3 COMPARISON TABLES The comparisons with other stations provided herein reflects the status of Beaver Valley Power Station - Unit 2 at the time of the issuance of the Operating License. This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.
1.3.1  Comparison with Similar Facility Designs  
 
Beaver Valley Power Station - Unit 2 (BVPS-2) utilizes proven mature designs. The nuclear steam supply system (NSSS) is of  
 
proven design and incorporates systems, equipment, and technology which have been successfully applied in more than 100 units designed by Westinghouse Electric Corporation. The balance of the unit, including the containment structure, was designed and constructed by the Applicant through its agent, Stone & Webster Engineering Corporation (SWEC). The SWEC design incorporated mature design concepts which had been utilized in nine operating nuclear power plants and seven nuclear plants which were in various stages of design, U.S. Nuclear Regulatory  
 
Commission (USNRC) review, and construction.
In Table 1.3-1, the general design features of BVPS-2 are  
 
compared with those of Beaver Valley Power Station - Unit 1 (BVPS-1), Millstone Unit 3 (Northeast Utility Company), and North Anna Units 1 and 2 (Virginia Electric Power Company). The plant comparison follows the general outline of the Final Safety Analysis Report (FSAR) chapters and is based on a single unit of each design. The USNRC has reviewed these designs extensively; BVPS-2 design incorporates the experience gained in these applications.  
 
1.3.1.1  Comparison of Nuclear Steam Supply Systems The NSSS for BVPS-2 is similar to that of the other units, except for power level differences. In addition, Millstone Unit 3 has four reactor coolant loops while the other units each have three loops.  
 
1.3.1.2  Comparison of Engineered Safety Features  
 
The engineered safety features (ESF) compared are the emergency core cooling system (ECCS), containment heat removal system, containment combustible gas control system, containment isolation system, control room habitability, and the emergency filtration system. The ESF are the same, except BVPS-2 and Millstone Unit 3 utilize two of the recirculation spray pumps to inject recirculated containment sump water as part of the ECCS. The BVPS-2 recirculation spray pumps also supply the high head safety injection pumps in the ECCS recirculation mode. Beaver Valley Power Station - Unit 1 and North Anna Units 1 and 2 utilize low head safety injection pumps to perform this function.  
 
BVPS-2 UFSAR Rev. 16  1.3-2 1.3.1.3  Comparison of Containment Concepts The containment concept, as shown by the comparison of parameters in Table 1.3-1, is the same as that of the other
 
plants listed.
These plants have already been extensively reviewed and approved
 
by the USNRC for operation.
1.3.1.4  Comparison of Instrumentation Systems
 
Instrumentation and controls are functionally similar to those at the other plants. The term functionally similar is intended
 
to mean similar in the basic operating and safety functions of the compared systems to which this applies. The specific features of BVPS-2 design are shown in detail and described in
 
applicable sections of the FSAR.
1.3.1.5  Comparison of Electrical Systems
 
Sections 8.2 and 8.3 of Table 1.3-1 provide a summary comparison of the electrical systems and parameters. While the transmission systems and onsite power systems differ due to utility preference, the emergency power systems, ac vital bus systems, and 125 V dc systems are similar in design.
 
1.3.1.6  Comparison of Waste Management Systems
 
Sections 11.2, 11.3, and 11.4 of Table 1.3-1 provides a summary comparison of the waste management systems. The liquid systems are functionally similar for all units compared. The gaseous waste systems are functionally similar for all units compared except that North Anna Units 1 and 2 use recombiners for gaseous waste volume reduction and all other designs utilize the charcoal delay bed concept for radioactive gas management. Beaver Valley Power Station - Unit 2 utilizes a prefilled, cement-in-drum solid waste system, while BVPS-1 uses an in-line,
 
cement, solid waste system. The other plants use an urea-formaldehyde or Dow process binder solidification agent.
 
1.3.1.7  Comparison of Other Nuclear Plant Systems The auxiliary systems (fuel pool cooling, component cooling water, service water, and boron recovery systems) are functionally similar for all units compared. Some differences occur due to siting, plant arrangement, and system design; however, the design basis for the auxiliary systems is essentially the same. In addition, North Anna Units 1 and 2 share the same fuel pool cooling and purification system while BVPS-1 and BVPS-2 share tankage subsystems of the boron recovery system.
1.3.1.8  Comparison of Structural Design Characteristics Sections 2.1, 2.5, 3.3 and 3.8 of Table 1.3-1 compare the BVPS-2
 
structural design criteria with those of the other plants. Some differences occur due to different site conditions. However, the basic parameters that define structural loadings are essentially
 
the same.
BVPS-2 UFSAR Rev. 0  1.3-3 1.3.2  Comparison of Final and Preliminary Information The significant changes between the preliminary and final design of BVPS-2 are listed in Table 1.3-2. The sections that address these changes are identified by their FSAR and PSAR section numbers. These changes have occurred since the submission of the PSAR and prior to issuance of the operating license. They have been approved and controlled in accordance with administrative procedures and are within the scope of the principal design criteria. New systems and equipment that are
 
post-PSAR are also included in the listing.
1.3.3  References for Section 1.3
 
U.S. Nuclear Regulatory Commission (USNRC) 1981. Asymmetric Blowdown Loads on PWR Primary Systems; Resolution of Generic
 
Task Action Plan A-2. NUREG-0609.
USNRC 1981. Standard Review Plan For the Review of Safety
 
Analysis Reports for Nuclear Power Plants. NUREG-0800.
 
BVPS-2 UFSAR    Tables for Section 1.3
 
(Tables in Section 1.3 are historical)
 
BVPS-2 UFSAR Rev. 16  1 of 20 TABLE 1.3-1 DESIGN COMPARISON (HISTORICAL)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Introduction     
 
Reactor type  1.1 PWR Same* Same* Same*
Reactor manufacturer  1.1 Westinghouse Same* Same* Same*
Site Characteristics Exclusion area boundary (minimum) (ft) 2.1 1,500 2,000 1,795 4,432 Low population zone (mi)  2.1 3.6 3.6 2.4 6        Safe shutdown earthquake (horizontal) (g)  2.5 0.125 0.125 0.17 0.12        Operating basis earthquake (horizontal) (g) 2.5 0.06 0.06 0.09 0.06 Structural Design Category I            Normal wind (mph)  3.3 80 Same* 115 Same*        Tornado region  3.3 1 1 1 1        Foundation type  3.8 Sand and gravel Sand and gravel Bedrock Rock      Reactor     
 
Nominal core power (MWt)  4.1 2,689 2,689 3,411 2,775        Fuel  4.2 17 x 17 Same* Same* Same*
BVPS-2 UFSAR Rev. 0  2 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Reactivity control  4.2 Reactor control rods and boric acid shim Same* Same* Same*
Nuclear design  4.3 Slightly enriched U0 ceramic pellets in Zircaloy-4 tubing Same* Same* Same*
Reactor Coolant System and Connected Systems and Equipment 5.1            Reactor vessel  5.3 Cylindrical with welded hemispherical bottom
 
head and removable hemispherical top head Same* Same* Same*
Reactor coolant pumps  5.4.1 3 single-speed centrifugal units driven
 
by air-cooled 3-phase induction motors Same* Same* except that it has 4 RCPs due to four loop design Same*        Steam generators  5.4.2 Vertical U-tube Same* Same*, except 4 units Same*        Residual heat removal system  5.4.7            Number of pumps 2 Same* Same* Same*        Number of heat  exchangers  2 Same* Same* Same*
Pressurizer  5.4.10 Vertical cylindrical vessel using electric heaters for maintaining system
 
pressure Same* Same* Same*
 
BVPS-2 UFSAR Rev. 16  3 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Engineered Safety Features  6.2 Containment 6.2            Type  6.2 Subatmospheric (9-11 psia)
Same* Same* Same*
Design pressure (psig)  6.2 45 Same* Same*        Design leak rate (percent per day)  6.2 0.1 Same* 0.9 Same*        Containment heat removal systems  6.2.2 Quench spray system, recirculation spray system Same* Same* Same*
Containment isolation system  6.2.4 Complies with General Design Criteria 54,55,56, and 57 Same* Same* Same*
Emergency core cooling system  6.3 Injection of borated water by
 
accumulators, charging/HHSI pumps, and LHSI pumps during injection phase; recirculation of spilled
 
coolant from containment sump by recirculation and
 
charging/HHSI pumps Same* as BVPS-2, except LHSI pumps recirculate the containment sump
 
water Same* as BVPS-2, except
 
that the RHR pumps perform the same function
 
as the LHSI
 
pumps Same as BVPS-2, except LHSI
 
pumps recirculate the containment sump water
 
BVPS-2 UFSAR Rev. 0  4 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Control room habitability  6.4 Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, portable fire protection, personnel protective equipment and first aid, food and water storage, utility and sanitary facilities.
Some components and systems are shared with BVPS-1 Same* Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, portable fire
 
protection, personnel pro-tective equipment and first aid, food and water storage, utility and
 
sanitary facilities Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, fire protection, per-sonnel protective equipment and first aid, food and
 
water storage, utility and sanitary facilities, remote
 
air intakes Emergency filtration systems  6.5 Control room area pressurization filtration system and supplementary leak collection and release system used to mitigate the
 
consequence of an accident Same* Same* Same*
 
BVPS-2 UFSAR Rev. 0  5 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Instrumentation and Controls Reactor trip system  7.2 Process instrumentation and control system, nuclear instrumentation system, solid state logic protection system, reactor trip
 
switchgear, manual actuation circuit
** ** **
Engineered safety feature systems  7.3 Process instrumentation and control system, solid state logic protection system, engineered safety features test cabinet, automatic transfer from injection phase to recirculation
 
phase ** **, Same* except manual transfer from injection
 
phase to recirc-ulation phase
**        Systems required for safe shutdown  7.4 Monitoring indicators, controls, pumps, fans, diesel generators, valves, and heaters
** **, Same* except has the capability for a safety grade cold shutdown
 
from the auxiliary shutdown panel
**        Safety-related display instrumentation  7.5 Feedwater and steam systems parameters, containment pressure, RWST water level, pressurizer water level, containment
 
recir- ** ** **
BVPS-2 UFSAR Rev. 0  6 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2) culation sump level, nuclear instrumentation, reactor coolant system
 
parameters, reactor control system parameters Other safety systems  7.6 Instrumentation and control power supply system, ESF protection channels power supply, RCS loop isolation valve interlocks, residual heat removal isolation, accumulator motor-operated isolation valve, switchover from
 
injection to recirculation, refueling interlocks
** Instrumentation and control power
 
supply system, ESF protection channels power
 
supply, residual heat removal isolation, accumulator motor-operated isolation valve,
 
switchover from injection to recirculation,
 
refueling interlocks Instrumentation and control power
 
supply system, ESF protection channels power
 
supply, RCS loop isolation valve interlocks, residual heat removal isolation, accumulator motor-operated isolation valve, switchover from
 
injection to recirculation, refueling
 
interlocks Control systems not required for safety  7.7 Reactor control system, rod control system, plant control system interlocks,
 
pressurizer pressure control, pressurizer water level control,
 
steam generator water level control, turbine bypass control, incore
 
instrumentation. Designed for 85% loss of external electrical
** Same*, except 50% load rejection capability without
 
reactor trip
**
BVPS-2 UFSAR Rev. 0  7 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2) load without tripping the reactor and for turbine trip below 70%
power without reactor
 
trip          Electrical Power Transmission system to site  8.2.1 3 @ 345 kV lines 3 @ 138 kV lines Same* 3 345 kV lines 3 500 kV lines AC power system  8.3.1            Unit main transformer  1 @ 945 MVA Same* 2 @ 630 MVA 3 @ 330 MVA Unit station service transformer 2 @ 32 MVA Same* 1 @ 40 MVA 1 @ 50 MVA 3 @ 20 MVA System station service transformers (reserve) 2 @ 32 MVA Same* 1 @ 45 MVA 1 @ 50 MVA 3 @ 30 MVA Emergency power system  8.3.1            Emergency 4.16 kV buses  2 @ 1,200 amp Same* 2 @ 2,000 amp 2 @ 1,200 amp Diesel generator sets (2,000 hr rating) 2 @ 4,535 kW 2 @ 2,850 kW 2 @ 5,335 kW 2 @ 3,000 kW AC vital bus system  8.3.1 Inverters 4 @ 20 kVA Same* 4 @ 15 kW 3 @ 15 kVA 1 @ 20 kVA Dist. cabinets  4 Same* 4 4 BVPS-2 UFSAR Rev. 0  8 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2) 125 V dc power system  8.3.2 Unit batteries (125 V) 4 safety-related  2 @ 1,650 AH 2 @ 1,050 AH 2 nonsafety  2 @ 2,400 AH 2 @ 2,400 AH 4 safety-related 2 @ 1,800 AH 1 @ 1,650 AH  1 @ 1,680 AH 1 nonsafety 1 @ 2,400 AH 4 safety-related 2 @ 1,650 AH 2 @ 750 AH 2 nonsafety  2 @ 2,550 AH 4 safety-related 1 @ 1,500 AH 1 @ 800 AH Battery chargers 5 safety-related  4 @ 100 amp  1 spare @ 100 amp 2 nonsafety 1 @ 200 amp  1 @ 150 amp 4 safety related  4 @ 100 amp 1 nonsafety  1 @ 150 amp 6 safety-related 2 @ 200 amp  2 @ 50 amp  2 spare @ 200 amp 3 nonsafety 4 safety-related 4 @ 250 amp 2 spares  2 @ 250 amp 2 @ 200 amp  1 spare @ 200 amp        Auxiliary Systems Fuel storage and handling New fuel storage  9.1.1 Dry storage in steel and concrete structure within the fuel building for 1/3 of a core (53 fuel assemblies) plus 17 spare fuel assemblies Same* Same*,
but will use spent fuel area for storage of new fuel using the
 
dry storage area as an optional backup location Common area for
 
both units.
Storage the same as BVPS-2 for
 
each unit
 
BVPS-2 UFSAR Rev. 0  9 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section BVPS-2 BVPS-1 Millstone (Unit 3)  North Anna (Units 1 & 2)
Spent fuel storage  9.1.2 High density poison racks with storage for 1,088 spent fuel assemblies in a reinforced stainless steel-lined pool within
 
the fuel building High density racks with storage for 833 spent fuel
 
assemb-lies in a reinforced stainless steel-
 
lined pool within the fuel building Storage for 1,835
 
spent fuel assemblies with
 
room for 1 full core off-load Common area for
 
both units with storage for 966
 
spent fuel assemb-lies in a reinforced concrete pool within the fuel building  Spent fuel pool cooling and cleanup  9.1.3 2 pumps and 2 coolers; 2 pumps, 2 filters, and 1
 
demineralizer for purification Similar to BVPS-2 Similar to BVPS-2, except 2 additional filters in the purification system 2 pumps and 2 coolers; 3 pumps, 2 filters, and 1
 
demineralizer for purification  Fuel handling system  9.1.4 System has provisions to prevent fuel handling and cask drop accidents Similar to BVPS-2 Similar to BVPS-2 Similar to BVPS-2 Water Systems      Service water system  9.2.1 2 redundant flow paths supplied by three 50%
capacity service water pumps supplying cooling water to
 
primary and secondary component cooling systems,
 
control room cooling, charging pump cooling water system, and rod control area air-conditioning systems. For accident conditions, each SWS pump is a 100% capacity pump with all
 
systems isolated except containment recircula- 3 river water
 
pumps supplying cooling water to primary component cooling water system, control room cooling, charging pump cooling water system, and pump
 
and motor bearing cooling on river and raw water
 
pumps. For accident con-ditions the same as BVPS-2. Turbine plant component cooling water heat exchangers are cooled by a 2 redundant flow-paths, each con-taining two 100% capacity service water pumps,
 
sup-plying cooling to component cooling systems, charging pump cooling, con-trol buidling air-con-ditioning, SI pump cooler and rod con-trol area air-condi-tioning on loss of power. For acci-dent
 
conditions, service water sup-plies containment
 
recirculation spray 2 redundant flow-
 
paths supplied by four 50% capacity service water pumps (normal operation of both units) and two 50% capacity
 
auxiliary service water pumps supplying
 
component cooling systems, control room cooling, charging pump coolers, instrument air
 
compressors, and pipe penetra-tion cooling. For accident conditions, all systems isolated BVPS-2 UFSAR Rev. 0  10 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 


BVPS-2 UFSAR Rev. 16  1.3-2 1.3.1.3  Comparison of Containment Concepts  The containment concept, as shown by the comparison of parameters in Table 1.3-1, is the same as that of the other plants listed. These plants have already been extensively reviewed and approved by the USNRC for operation. 1.3.1.4  Comparison of Instrumentation Systems Instrumentation and controls are functionally similar to those at the other plants. The term functionally similar is intended to mean similar in the basic operating and safety functions of the compared systems to which this applies. The specific features of BVPS-2 design are shown in detail and described in applicable sections of the FSAR. 1.3.1.5  Comparison of Electrical Systems Sections 8.2 and 8.3 of Table 1.3-1 provide a summary comparison of the electrical systems and parameters. While the transmission systems and onsite power systems differ due to utility preference, the emergency power systems, ac vital bus systems, and 125 V dc systems are similar in design.
Millstone
1.3.1.6  Comparison of Waste Management Systems Sections 11.2, 11.3, and 11.4 of Table 1.3-1 provides a summary comparison of the waste management systems. The liquid systems are functionally similar for all units compared. The gaseous waste systems are functionally similar for all units compared except that North Anna Units 1 and 2 use recombiners for gaseous waste volume reduction and all other designs utilize the charcoal delay bed concept for radioactive gas management. Beaver Valley Power Station - Unit 2 utilizes a prefilled, cement-in-drum solid waste system, while BVPS-1 uses an in-line, cement, solid waste system. The other plants use an urea-formaldehyde or Dow process binder solidification agent.
1.3.1.7  Comparison of Other Nuclear Plant Systems  The auxiliary systems (fuel pool cooling, component cooling water, service water, and boron recovery systems) are functionally similar for all units compared. Some differences occur due to siting, plant arrangement, and system design; however, the design basis for the auxiliary systems is essentially the same. In addition, North Anna Units 1 and 2 share the same fuel pool cooling and purification system while BVPS-1 and BVPS-2 share tankage subsystems of the boron recovery system.
1.3.1.8  Comparison of Structural Design Characteristics  Sections 2.1, 2.5, 3.3 and 3.8 of Table 1.3-1 compare the BVPS-2 structural design criteria with those of the other plants. Some differences occur due to different site conditions. However, the basic parameters that define structural loadings are essentially the same.
BVPS-2 UFSAR Rev. 0  1.3-3 1.3.2  Comparison of Final and Preliminary Information  The significant changes between the preliminary and final design of BVPS-2 are listed in Table 1.3-2. The sections that address these changes are identified by their FSAR and PSAR section numbers. These changes have occurred since the submission of the PSAR and prior to issuance of the operating license. They have been approved and controlled in accordance with administrative procedures and are within the scope of the principal design criteria. New systems and equipment that are post-PSAR are also included in the listing. 1.3.3  References for Section 1.3 U.S. Nuclear Regulatory Commission (USNRC) 1981. Asymmetric Blowdown Loads on PWR Primary Systems; Resolution of Generic Task Action Plan A-2. NUREG-0609. USNRC 1981. Standard Review Plan For the Review of Safety Analysis Reports for Nuclear Power Plants. NUREG-0800.
BVPS-2 UFSAR    Tables for Section 1.3 


(Tables in Section 1.3 are historical)
(Unit 3)
BVPS-2 UFSAR Rev. 16  1 of 20 TABLE 1.3-1  DESIGN COMPARISON (HISTORICAL)  Section and Characteristics  Referenced in Section BVPS-2   
North Anna


BVPS-1    Millstone (Unit 3)
(Units 1 & 2) tion spray coolers, charging pump coolers, control room cooling, and  
North Anna (Units 1 & 2)       Introduction Reactor type  1.1 PWR Same* Same* Same*        Reactor manufacturer  1.1 Westinghouse Same* Same* Same*      Site Characteristics            Exclusion area boundary (minimum) (ft)  2.1 1,500 2,000 1,795 4,432        Low population zone (mi)  2.1 3.6 3.6 2.4 6        Safe shutdown earthquake (horizontal) (g)  2.5 0.125 0.125 0.17 0.12        Operating basis earthquake (horizontal) (g)  2.5 0.06 0.06 0.09 0.06      Structural Design  Category I            Normal wind (mph)  3.3 80 Same* 115 Same*        Tornado region  3.3 1 1 1 1        Foundation type  3.8 Sand and gravel Sand and gravel Bedrock Rock      Reactor Nominal core power (MWt)  4.1 2,689 2,689 3,411 2,775        Fuel  4.2 17 x 17 Same* Same* Same*
BVPS-2 UFSAR Rev. 0  2 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
emergency diesel generator cooling. A standby service water system, consisting of two 100% capacity pumps, takes suction
North Anna (Units 1 & 2)        Reactivity control  4.2 Reactor control rods and boric acid shim Same* Same* Same*        Nuclear design  4.3 Slightly enriched U0 ceramic pellets in Zircaloy-4 tubing Same* Same* Same*      Reactor Coolant System and Connected Systems and Equipment  5.1            Reactor vessel  5.3 Cylindrical with welded hemispherical bottom head and removable hemispherical top head Same* Same* Same*        Reactor coolant pumps  5.4.1 3 single-speed centrifugal units driven by air-cooled 3-phase induction motors Same* Same* except that it has 4 RCPs due to four loop design Same*        Steam generators  5.4.2 Vertical U-tube Same* Same*, except 4 units Same*        Residual heat removal system  5.4.7            Number of pumps 2 Same* Same* Same*        Number of heat  exchangers  2 Same* Same* Same*        Pressurizer  5.4.10 Vertical cylindrical vessel using electric heaters for maintaining system pressure Same* Same* Same*
BVPS-2 UFSAR Rev. 16  3 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
from an alternate intake structure and discharges to the  
North Anna (Units 1 & 2)      Engineered Safety Features  6.2            Containment  6.2            Type  6.2 Subatmospheric (9-11 psia) Same* Same* Same*        Design pressure (psig)  6.2 45 Same* Same*        Design leak rate (percent per day)  6.2 0.1 Same* 0.9 Same*        Containment heat removal systems  6.2.2 Quench spray system, recirculation spray system Same* Same* Same*        Containment isolation system  6.2.4 Complies with General Design Criteria 54,55,56, and 57 Same* Same* Same*      Emergency core cooling system  6.3 Injection of borated water by accumulators, charging/HHSI pumps, and LHSI pumps during injection phase; recirculation of spilled coolant from containment sump by recirculation and charging/HHSI pumps Same* as BVPS-2, except LHSI pumps recirculate the containment sump water Same* as BVPS-2, except that the RHR pumps perform the same function as the LHSI pumps Same as BVPS-2, except LHSI pumps recirculate the containment sump water BVPS-2 UFSAR Rev. 0  4 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
redundant service water headers, to provide cooling for unit
North Anna (Units 1 & 2)      Control room habitability  6.4 Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, portable fire protection, personnel protective equipment and first aid, food and water storage, utility and sanitary facilities.
Some components and systems are shared with BVPS-1 Same* Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, portable fire protection, personnel pro-tective equipment and first aid, food and water storage, utility and sanitary facilities Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, fire protection, per-sonnel protective equipment and first aid, food and water storage, utility and sanitary facilities, remote air intakes      Emergency filtration systems  6.5 Control room area pressurization filtration system and supplementary leak collection and release system used to mitigate the consequence of an accident Same* Same* Same*
BVPS-2 UFSAR Rev. 0  5 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
shutdown and cooldown after loss of the seismic Category I intake structure.
North Anna (Units 1 & 2)      Instrumentation and Controls            Reactor trip system  7.2 Process instrumentation and control system, nuclear instrumentation system, solid state logic protection system, reactor trip switchgear, manual actuation circuit ** ** **        Engineered safety feature systems  7.3 Process instrumentation and control system, solid state logic protection system, engineered safety features test cabinet, automatic transfer from injection phase to recirculation phase ** **, Same* except manual transfer from injection phase to recirc-ulation phase **        Systems required for safe shutdown  7.4 Monitoring indicators, controls, pumps, fans, diesel generators, valves, and heaters ** **, Same* except has the capability for a safety grade cold shutdown from the auxiliary shutdown panel **        Safety-related display instrumentation  7.5 Feedwater and steam systems parameters, containment pressure, RWST water level, pressurizer water level, containment recir- ** ** **
separate river water system  
BVPS-2 UFSAR Rev. 0  6 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   
: cooler, containment recirculation pump, ventilation units, SI and charging pump coolers, diesel  


BVPS-1 Millstone (Unit 3)
generators, control building air-conditioning
North Anna (Units 1 & 2)        culation sump level, nuclear instrumentation, reactor coolant system parameters, reactor control system parameters          Other safety systems  7.6 Instrumentation and control power supply system, ESF protection channels power supply, RCS loop isolation valve interlocks, residual heat removal isolation, accumulator motor-operated isolation valve, switchover from injection to recirculation, refueling interlocks ** Instrumentation and control power supply system, ESF protection channels power supply, residual heat removal isolation, accumulator motor-operated isolation valve, switchover from injection to recirculation, refueling interlocks Instrumentation and control power supply system, ESF protection channels power supply, RCS loop isolation valve interlocks, residual heat removal isolation, accumulator motor-operated isolation valve, switchover from injection to recirculation, refueling interlocks        Control systems not required for safety  7.7 Reactor control system, rod control system, plant control system interlocks, pressurizer pressure control, pressurizer water level control, steam generator water level control, turbine bypass control, incore instrumentation. Designed for 85% loss of external electrical ** Same*, except 50% load rejection capability without reactor trip **
BVPS-2 UFSAR Rev. 0  7 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
and post-accident sample cooler except containment recirculation spray cooling, charging
North Anna (Units 1 & 2)        load without tripping the reactor and for turbine trip below 70% power without reactor trip          Electrical Power            Transmission system to site  8.2.1 3 @ 345 kV lines 3 @ 138 kV lines Same* 3 345 kV lines 3 500 kV lines        AC power system  8.3.1            Unit main transformer  1 @ 945 MVA Same* 2 @ 630 MVA 3 @ 330 MVA        Unit station service transformer  2 @ 32 MVA Same* 1 @ 40 MVA 1 @ 50 MVA 3 @ 20 MVA        System station service transformers (reserve)  2 @ 32 MVA Same* 1 @ 45 MVA 1 @ 50 MVA 3 @ 30 MVA        Emergency power system  8.3.1            Emergency 4.16 kV buses  2 @ 1,200 amp Same* 2 @ 2,000 amp 2 @ 1,200 amp        Diesel generator sets (2,000 hr rating)  2 @ 4,535 kW 2 @ 2,850 kW 2 @ 5,335 kW 2 @ 3,000 kW        AC vital bus system  8.3.1            Inverters  4 @ 20 kVA Same* 4 @ 15 kW 3 @ 15 kVA 1 @ 20 kVA        Dist. cabinets  4 Same* 4 4 BVPS-2 UFSAR Rev. 0  8 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
pump coolers, control room  
North Anna (Units 1 & 2)        125 V dc power system  8.3.2            Unit batteries (125 V)  4 safety-related  2 @ 1,650 AH 2 @ 1,050 AH 2 nonsafety  2 @ 2,400 AH 2 @ 2,400 AH 4 safety-related 2 @ 1,800 AH 1 @ 1,650 AH  1 @ 1,680 AH 1 nonsafety 1 @ 2,400 AH 4 safety-related 2 @ 1,650 AH 2 @ 750 AH 2 nonsafety  2 @ 2,550 AH 4 safety-related 1 @ 1,500 AH 1 @ 800 AH        Battery chargers  5 safety-related  4 @ 100 amp  1 spare @ 100 amp 2 nonsafety 1 @ 200 amp  1 @ 150 amp 4 safety related  4 @ 100 amp 1 nonsafety  1 @ 150 amp 6 safety-related 2 @ 200 amp  2 @ 50 amp  2 spare @ 200 amp 3 nonsafety 4 safety-related 4 @ 250 amp 2 spares  2 @ 250 amp            2 @ 200 amp  1 spare @ 200 amp        Auxiliary Systems            Fuel storage and handling            New fuel storage  9.1.1 Dry storage in steel and concrete structure within the fuel building for 1/3 of a core (53 fuel assemblies) plus 17 spare fuel assemblies Same* Same*, but will use spent fuel area for storage of new fuel using the dry storage area as an optional backup location Common area for both units. Storage the same as BVPS-2 for each unit BVPS-2 UFSAR Rev. 0  9 of 20 TABLE 1.3-1 (Cont) Section and Characteristics  Referenced in Section      BVPS-2        BVPS-1    Millstone (Unit 3)  North Anna (Units 1 & 2)  Spent fuel storage  9.1.2 High density poison racks with storage for 1,088 spent fuel assemblies in a reinforced stainless steel-lined pool within the fuel building High density racks with storage for 833 spent fuel assemb-lies in a reinforced stainless steel-lined pool within the fuel building Storage for 1,835 spent fuel assemblies with room for 1 full core off-load Common area for both units with storage for 966 spent fuel assemb-lies in a reinforced concrete pool within the fuel building  Spent fuel pool cooling and cleanup  9.1.3 2 pumps and 2 coolers; 2 pumps, 2 filters, and 1 demineralizer for purification Similar to BVPS-2 Similar to BVPS-2, except 2 additional filters in the purification system 2 pumps and 2 coolers; 3 pumps, 2 filters, and 1 demineralizer for purification  Fuel handling system  9.1.4 System has provisions to prevent fuel handling and cask drop accidents Similar to BVPS-2 Similar to BVPS-2 Similar to BVPS-2 Water Systems      Service water system  9.2.1 2 redundant flow paths supplied by three 50%
: cooling,  
capacity service water pumps supplying cooling water to primary and secondary component cooling systems, control room cooling, charging pump cooling water system, and rod control area air-conditioning systems. For accident conditions, each SWS pump is a 100% capacity pump with all systems isolated except containment recircula- 3 river water pumps supplying cooling water to primary component cooling water system, control room cooling, charging pump cooling water system, and pump and motor bearing cooling on river and raw water pumps. For accident con-ditions the same as BVPS-2. Turbine plant component cooling water heat exchangers are cooled by a 2 redundant flow-paths, each con-taining two 100% capacity service water pumps, sup-plying cooling to component cooling systems, charging pump cooling, con-trol buidling air-con-ditioning, SI pump cooler and rod con-trol area air-condi-tioning on loss of power. For acci-dent conditions, service water sup-plies containment recirculation spray 2 redundant flow-paths supplied by four 50% capacity service water pumps (normal operation of both units) and two 50% capacity auxiliary service water pumps supplying component cooling systems, control room cooling, charging pump coolers, instrument air compressors, and pipe penetra-tion cooling. For accident conditions, all systems isolated BVPS-2 UFSAR Rev. 0  10 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
instrument air compressors, and pipe pene-tration  
North Anna (Units 1 & 2)        tion spray coolers, charging pump coolers, control room cooling, and emergency diesel generator cooling. A standby service water system, consisting of two 100% capacity pumps, takes suction from an alternate intake structure and discharges to the redundant service water headers, to provide cooling for unit shutdown and cooldown after loss of the seismic Category I intake structure. separate river water system cooler, containment recirculation pump, ventilation units, SI and charging pump coolers, diesel generators, control building air-conditioning and post-accident sample cooler except containment recirculation spray cooling, charging pump coolers, control room cooling, instrument air compressors, and pipe pene-tration cooling        Ultimate heat sink  9.2.5 Ohio River Same as BVPS-2 Long Island Sound (Atlantic Ocean) Service water reservoir with Lake Anna backup        Other water systems  9.2.2.1 9.2.2.2 9.2.3  9.2.4  9.2.6 Primary and secondary plant component cooling water systems, chilled water system, demineralized water makeup, potable and sanitary water systems, and condensate storage facilities. Same*
 
cooling        Ultimate heat sink  9.2.5 Ohio River Same as BVPS-2 Long Island Sound (Atlantic Ocean) Service water reservoir with Lake Anna backup        Other water systems  9.2.2.1 9.2.2.2  
 
9.2.3  9.2.4  9.2.6 Primary and  
 
secondary plant  
 
component cooling water systems, chilled water system,  
 
demineralized water makeup, potable and sanitary water  
 
systems, and condensate storage facilities.
Same*
Same* Same*
Same* Same*
Same* Same*
Same* Same*
Same*
Same*
BVPS-2 UFSAR Rev. 0  11 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2    
BVPS-2 UFSAR Rev. 0  11 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Process auxiliaries            Compressed air systems 9.3.1 2 redundant compressors supply air for instruments and service air system. 2 redundant
 
compressors supply containment instrument air system,
 
and 1 compressor supplies condensate polishing air. Same as BVPS-
 
2*, except there is
 
no condensate polishing air system and the
 
containment instrument air compressors are
 
inside the containment.
2 redundant compressors supply air for instruments. 1 compressor supplies service air and 2 redundant compressors supply containment
 
instrument air. Also, 2 additional compressors
 
supply air required for cold shutdown.
For both units, 2 compressors
 
supply service air and 2 compressors supply instrument air. For Unit 1, 2 com-pressors
 
supply containment instrument air. 
 
For Unit 2, 4 com-pressors supply containment
 
instrument air (2 operating, 2 back-up)        Process sampling system  9.3.2 Collects reactor plant and turbine plant gaseous and liquid samples for chemical and radiochemical
 
analysis Same* Same* Same*
Equipment and floor drainage system  9.3.3 Collects and treats potentially radioactive liquid drainage and associated entrained
 
gases Same* Same* Same*
Chemical and volume control system  9.3.4 Letdown and charging system is used for reactivity control, purification of reactor
 
coolant, RCS inventory control, and provides high pressure
 
flow to the ECCS Same* Same* Same*
BVPS-2 UFSAR Rev. 7  12 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2  
 
BVPS-1 Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Boron recovery system  9.3.4.6 Evaporative concentration of letdown boric acid and production of primary
 
grade water for recycle (shared tankage located on
 
BVPS-1) Same* Same*, except for shared portion of BVPS-2 Same*, except for shared portion of BVPS-2      Air-conditioning, heating, cooling, and ventilation systems            Control room and control building heating, ventilation, and air-conditioning system  9.4.1 Provides heating, ventilation, and air-conditioning to control room, computer room, process instrument room, equipment room, cable spreading
 
room, and the auxiliary building cable tunnel Same* Same*, excluding chiller room and cable spreading area Provides heating,
 
ventilation, and air-conditioning to control room,
 
office and computer room, process instrument room, relay room, and communications
 
room. Control room emergency bottled air supply system with subsequent filtered
 
emergency ventilation system Containment atmosphere recirculation system  9.4.7 Maintains controlled environment for personnel and
 
equipment during normal operation Same* Same* Same*
 
BVPS-2 UFSAR Rev. 0  13 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics
 
Referenced
 
in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Other heating, cooling, and ventilation systems 9.4.2 to  9.4.6  9.4.8 to  9.4.16 Fuel building, auxiliary building, turbine building, waste handling building,
 
emergency diesel generator building, condensate polishing
 
building Same*, except for
 
condensate polishing building Same* Same*
Other auxiliary systems  9.5 Fire protection system  9.5.1 Detects, extinguishes, and mitigates effects of fires that may occur Same* Same* Same*
Emergency diesel generator cooling water system  9.5.5 Maintains diesel generator jacket water within specified temperature limits by service water system Same* Same* Maintains diesel engine jacket water within specified
 
temperature limits by self-contained radiator cooling system        Additional auxiliary systems  9.5.2, 9.5.3, 9.5.4, 9.5.6, 9.5.7,  and 9.5.8 Communications
 
systems, lighting systems, redundant emergency diesel
 
generator support systems including:
1 nonsafety (black) diesel generator, fuel oil storage and transfer, starting, lubrication, and combustion air intake and exhaust systems. Same*, except for the nonsafety diesel generator Same*, except for the nonsafety diesel generator Same*, except for the nonsafety diesel generator
 
BVPS-2 UFSAR Rev. 0  14 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2  
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Steam and Power Conversion
 
System            Turbine generator  10.2 Westinghouse tandem-compound, 4-flow, 1,800 rpm steam reheat machine; 1
 
double-flow HP turbine and 2 double-flow LP turbines Same* Same*, except General Electric 6-flow turbine generators Same*        Main steam supply  10.3 797 psia, 11.61 x 10 lb/hr
 
steam flow, 518F Same* 960 psia, 15.05 x 10 lb/hr steam flow, 540F 850 psia, 12.2 x 10 lb/hr


BVPS-1 Millstone (Unit 3)
steam flow, 525F       Other features of steam and power conversion system             Main condensers 10.4.1 Double shell, single-pass, divided water box Same* Same* Same*
North Anna (Units 1 & 2)       Process auxiliaries             Compressed air systems 9.3.1 2 redundant compressors supply air for instruments and service air system. 2 redundant compressors supply containment instrument air system, and 1 compressor supplies condensate polishing air. Same as BVPS-2*, except there is no condensate polishing air system and the containment instrument air compressors are inside the containment. 2 redundant compressors supply air for instruments. 1 compressor supplies service air and 2 redundant compressors supply containment instrument air. Also, 2 additional compressors supply air required for cold shutdown. For both units, 2 compressors supply service air and 2 compressors supply instrument air. For Unit 1, 2 com-pressors supply containment instrument air.
Main condenser evacuation system  10.4.2 Steam jet air ejectors with auxiliary steam
For Unit 2, 4 com-pressors supply containment instrument air (2 operating, 2 back-up)        Process sampling system  9.3.2 Collects reactor plant and turbine plant gaseous and liquid samples for chemical and radiochemical analysis Same* Same* Same*       Equipment and floor drainage system  9.3.3 Collects and treats potentially radioactive liquid drainage and associated entrained gases Same* Same* Same*        Chemical and volume control system  9.3.4 Letdown and charging system is used for reactivity control, purification of reactor coolant, RCS inventory control, and provides high pressure flow to the ECCS Same* Same* Same*
BVPS-2 UFSAR Rev. 7  12 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2


BVPS-1 Millstone (Unit 3)
priming ejectors for initial evacuation Same* Steam jet air ejectors with vacuum pumps for initial evacuation Same*       Turbine bypass system  10.4.4 Passes up to 90% of full-load steam flow to allow 85% to 100% step load reduction without a reactor trip.   
North Anna (Units 1 & 2)        Boron recovery system  9.3.4.6 Evaporative concentration of letdown boric acid and production of primary grade water for recycle (shared tankage located on BVPS-1) Same* Same*, except for shared portion of BVPS-2 Same*, except for shared portion of BVPS-2      Air-conditioning, heating, cooling, and ventilation systems            Control room and control building heating, ventilation, and air-conditioning system  9.4.1 Provides heating, ventilation, and air-conditioning to control room, computer room, process instrument room, equipment room, cable spreading room, and the auxiliary building cable tunnel Same* Same*, excluding chiller room and cable spreading area Provides heating, ventilation, and air-conditioning to control room, office and computer room, process instrument room, relay room, and communications room. Control room emergency bottled air supply system with subsequent filtered emergency ventilation system        Containment atmosphere recirculation system  9.4.7 Maintains controlled environment for personnel and equipment during normal operation Same* Same* Same*
BVPS-2 UFSAR Rev. 0  13 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics Referenced in Section  


BVPS-2   
(See Section 10.4.4 for details.) Passes up to 90% of full-load steam


BVPS-1 Millstone (Unit 3)
flow to allow up to 100% step load reduction without
North Anna (Units 1 & 2)        Other heating, cooling, and ventilation systems  9.4.2 to 9.4.6  9.4.8 to 9.4.16 Fuel building, auxiliary building, turbine building, waste handling building, emergency diesel generator building, condensate polishing building Same*, except for condensate polishing building Same* Same*      Other auxiliary systems  9.5            Fire protection system  9.5.1 Detects, extinguishes, and mitigates effects of fires that may occur Same* Same* Same*        Emergency diesel generator cooling water system  9.5.5 Maintains diesel generator jacket water within specified temperature limits by service water system Same* Same* Maintains diesel engine jacket water within specified temperature limits by self-contained radiator cooling system        Additional auxiliary systems  9.5.2, 9.5.3, 9.5.4, 9.5.6, 9.5.7,  and 9.5.8 Communications systems, lighting systems, redundant emergency diesel generator support systems including: 1 nonsafety (black) diesel generator, fuel oil storage and transfer, starting, lubrication, and combustion air intake and exhaust systems. Same*, except for the nonsafety diesel generator Same*, except for the nonsafety diesel generator Same*, except for the nonsafety diesel generator BVPS-2 UFSAR Rev. 0  14 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
reactor trip Passes up to 40%
North Anna (Units 1 & 2)      Steam and Power Conversion System            Turbine generator  10.2 Westinghouse tandem-compound, 4-flow, 1,800 rpm steam reheat machine; 1 double-flow HP turbine and 2 double-flow LP turbines Same* Same*, except General Electric 6-flow turbine generators Same*        Main steam supply  10.3 797 psia, 11.61 x 10 lb/hr steam flow, 518F Same* 960 psia, 15.05 x 10 lb/hr steam flow, 540F 850 psia, 12.2 x 10 lb/hr steam flow, 525F      Other features of steam and power conversion system            Main condensers  10.4.1 Double shell, single-pass, divided water box Same* Same* Same*        Main condenser evacuation system  10.4.2 Steam jet air ejectors with auxiliary steam priming ejectors for initial evacuation Same* Steam jet air ejectors with vacuum pumps for initial evacuation Same*        Turbine bypass system  10.4.4 Passes up to 90% of full-load steam flow to allow 85% to 100% step load reduction without a reactor trip. 
of maximum  
(See Section 10.4.4 for details.) Passes up to 90% of full-load steam flow to allow up to 100% step load reduction without reactor trip Passes up to 40%
of maximum steam flow to allow up to 50% step load reduction without reactor or turbine trip Same*
BVPS-2 UFSAR Rev. 0  15 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
steam flow to allow up to 50%
North Anna (Units 1 & 2)        Circulating water system  10.4.5 Removes heat from the main condenser by circulating water through 1 natural draft cooling tower Same* Removes heat from the main condenser by circulating water from Long Island Sound Removes heat from the main condenser by circulating water from Lake Anna        Condensate cleanup system  10.4.6 Full flow condensate polishing demineralizers are provided at the discharge of the condensate pumps.
step load
Here powdered resin demineralizers are capable of maintaining a steam generator chemistry well below maximum requirements. None Same* Same*        Condensate and feedwater system  10.4.7 Returns condensed steam from condenser, and drains from regenerative feedwater heaters (6-stage heater cycle), to steam generators while maintaining water inventories throughout system Same* Same* Same*        Auxiliary feedwater system  10.4.9 Supplies necessary cooling water to steam generators for decay heat removal, feedwater line malfunction, or main steam line break Same* Same* Same*
BVPS-2 UFSAR Rev. 0  16 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
reduction without reactor or turbine trip Same*
North Anna (Units 1 & 2)        Auxiliary steam and condensate system  10.4.10 Supplies heating throughout the plant to various heating and processing equipment, and recovers the condensed steam from the equipment served. Normal source of auxiliary steam is main steam.
BVPS-2 UFSAR Rev. 0  15 of 20 TABLE 1.3-1 (Cont)
Auxiliary boiler used when reactor not at power Same* Same* Same*, except normal source of auxiliary steam is second point extraction.      Radioactive Waste Management            Liquid waste management system  11.2            Type of processing            Evaporation  Yes Yes Yes Yes        Demineralization  Yes Yes Yes Yes Filtration  Yes Yes Yes Yes Treatment of radioactive waste            High activity waste  11.2 All liquid waste can be evaporated or filtered depending on its activity. The distillate from the evaporator can be demineralized and filtered. There is no Evaporation and/or demineralization/
Section and Characteristics Referenced in Section
filtration Similar to BVPS-1 Similar to BVPS-1 BVPS-2 UFSAR Rev. 0  17 of 20 TABLE 1.3-1 (Cont) Section and Characteristics Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
BVPS-2  
North Anna (Units 1 & 2)        separation of high and low activity streams prior to liquid waste tanks          Low activity waste  11.2 See "High activity waste" Filtration (low activity waste can be routed to the high activity waste tanks and evaporated) Filtration (evaporation and subsequent operations are optional) Similar to Millstone Unit 3 with the addition of a clarifier before release to the environment        Steam generator blowdown  10.4.8 Blowdown piped to flash tank where steam is piped to 2nd point heater and liquid is piped to main condenser via 4th point heaters for processing through condensate polishing demineralizers, or liquid is piped to demineralizers for processing prior to routing to the condenser. Blowdown piped to flash tank and steam is then piped to the third point heaters and liquid is piped to demineralizers for processing prior to routing to the condenser Similar to BVPS-2 except steam piped to 4th point heater Blowdown piped to flash tank where steam is piped to roof vent and liquid processed by clarification.      Gaseous waste management systems  11.3            Type of treatment            Degasification  Yes (occurs in boron recovery system) Yes (occurs in boron recovery system) Yes Yes (called gas strippers in boron recovery system)        Decay of noble gases in high activity gas streams  Yes Yes Yes Yes BVPS-2 UFSAR Rev. 0  18 of 20 TABLE 1.3-1 (Cont) Section and Characteristics  Referenced in Section      BVPS-2        BVPS-1    Millstone (Unit 3)  North Anna (Units 1 & 2)        Filtration of low activity gas streams  Yes Yes No Yes        Recombiners  No No No Yes        Treatment of streams            Continuous degasification of reactor letdown capability  Yes Yes Yes Yes        Degasification of letdown to boron recovery system  Yes Yes Yes Yes        Degasification of reactor plant gaseous drains  Yes Yes Yes Yes        Decay method for gases stripped in degasifier  Adsorption on charcoal for minimun of 30 days and 2 days xenon and krypton decay, respectively, before recycle or release to atmosphere through BVPS-1 process vent on BVPS-1 cooling tower Same* Adsorption on charcoal for minimum of 60 days and 4 days xenon and krypton decay, respectively, before recycle or release to the environment Recombination of hydrogen in the gaseous waste stream to reduce storage requirements in waste gas decay tanks before release to the environment        Low activity air streams (nonventilation streams)  HEPA/charcoal filter assemblies in the process vent on BVPS-1 Same* Release through Millstone 1 stack Similar to BVPS-2        Solid waste management  11.4            Type of treatment            Solidification  In-drum In-line In-container In-line (1 waste disposal building for both units)
BVPS-2 UFSAR Rev. 0  19 of 20 TABLE 1.3-1 (Cont)  Section and Characteristics  Referenced in Section BVPS-2   


BVPS-1 Millstone (Unit 3)
BVPS-1  
North Anna (Units 1 & 2)       Solidification agent Cement Cement Dow process binder Urea-formaldehyde       Inputs (type) treated             Boron evaporator bottoms None; processed by BVPS-1 Yes Yes Yes       Waste evaporator bottoms Yes Yes Yes Yes        Spent beaded resins Yes Yes Yes Yes        Powdered resins  Yes No Yes Yes        Filtered elements  Yes Yes Yes Yes       Miscellaneous waste (contaminated clothing, tools, paper products, etc)  Yes Yes Yes Yes       Radiation Protection             Radiation Protection Design Features 12.3            Shielding  Shielding thickness and coverage determined for each area to assure maximum design dose rates are not exceeded and to prevent activation of components within containment Same* Same* Same*
 
BVPS-2 UFSAR Rev. 0  20 of 20 TABLE 1.3-1 (Cont) Section and Characteristics Referenced in Section BVPS-2    
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Circulating water system  10.4.5 Removes heat from the main condenser by circulating water through 1 natural draft cooling tower Same* Removes heat from the main condenser by circulating water
 
from Long Island Sound Removes heat from the main condenser by circulating water
 
from Lake Anna Condensate cleanup system  10.4.6 Full flow condensate polishing
 
demineralizers are
 
provided at the discharge of the condensate pumps.
Here powdered resin demineralizers are capable of maintaining
 
a steam generator chemistry well below maximum requirements. None Same* Same*
Condensate and feedwater system  10.4.7 Returns condensed steam from condenser, and drains from regenerative
 
feedwater heaters (6-stage heater cycle), to steam generators
 
while maintaining water inventories throughout system Same* Same* Same*
Auxiliary feedwater system  10.4.9 Supplies necessary cooling water to steam generators for decay heat removal, feedwater line malfunction, or main steam line break Same* Same* Same*
BVPS-2 UFSAR Rev. 0  16 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Auxiliary steam and condensate system  10.4.10 Supplies heating throughout the plant to various heating and processing equipment,
 
and recovers the condensed steam from the equipment
 
served. Normal source of auxiliary steam is main steam. 
 
Auxiliary boiler used when reactor not at power Same* Same* Same*, except normal source of auxiliary steam is second point
 
extraction.
Radioactive Waste Management            Liquid waste management system  11.2            Type of processing Evaporation  Yes Yes Yes Yes Demineralization  Yes Yes Yes Yes
 
Filtration  Yes Yes Yes Yes
 
Treatment of radioactive waste            High activity waste  11.2 All liquid waste can be evaporated or filtered depending on its
 
activity. The distillate from the evaporator can be demineralized and filtered. There is no Evaporation
 
and/or demineralization/
 
filtration Similar to BVPS-1 Similar to BVPS-1 BVPS-2 UFSAR Rev. 0  17 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone  
 
(Unit 3)
North Anna  
 
(Units 1 & 2) separation of high and low activity streams prior to liquid waste tanks          Low activity waste  11.2 See "High activity waste" Filtration (low
 
activity waste can be routed to the high activity waste tanks and
 
evaporated)
Filtration
 
(evaporation and
 
subsequent operations are optional)
Similar to
 
Millstone Unit 3
 
with the addition of a clarifier before release to
 
the environment Steam generator blowdown  10.4.8 Blowdown piped to flash tank where steam is piped to 2nd point heater and liquid is piped to main condenser via 4th point heaters for processing through condensate polishing demineralizers, or liquid is piped to demineralizers for processing prior to routing to the condenser. Blowdown piped to flash tank and steam is then piped to the third point heaters and liquid is piped to demineralizers for processing prior to routing to the condenser Similar to BVPS-2
 
except steam piped to 4th point heater Blowdown piped
 
to flash tank where steam is piped to roof vent
 
and liquid processed by clarification.
Gaseous waste management systems  11.3            Type of treatment Degasification Yes (occurs in boron recovery system) Yes (occurs in boron recovery system) Yes Yes (called gas strippers in boron recovery system)
Decay of noble gases in high activity gas streams  Yes Yes Yes Yes BVPS-2 UFSAR Rev. 0  18 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section BVPS-2 BVPS-1 Millstone (Unit 3)  North Anna (Units 1 & 2)
Filtration of low activity gas streams  Yes Yes No Yes Recombiners  No No No Yes Treatment of streams Continuous degasification of reactor letdown capability  Yes Yes Yes Yes Degasification of letdown to boron recovery system  Yes Yes Yes Yes Degasification of reactor plant gaseous drains  Yes Yes Yes Yes Decay method for gases stripped in degasifier Adsorption on charcoal for minimun of 30 days and 2 days
 
xenon and krypton decay, respectively, before recycle or release to atmosphere through BVPS-1 process vent on BVPS-1 cooling tower Same* Adsorption on charcoal for minimum of 60
 
days and 4 days xenon and krypton decay,
 
respectively, before recycle or release to the environment Recombination of hydrogen in the gaseous waste
 
stream to reduce storage requirements in waste gas decay tanks before release to the environment Low activity air streams (nonventilation streams)
HEPA/charcoal filter assemblies in the process vent on BVPS-1 Same* Release through Millstone 1 stack Similar to BVPS-2 Solid waste management 11.4            Type of treatment Solidification In-drum In-line In-container In-line (1 waste disposal building for both units)
BVPS-2 UFSAR Rev. 0  19 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Solidification agent Cement Cement Dow process binder Urea-formaldehyde Inputs (type) treated Boron evaporator bottoms None; processed by BVPS-1 Yes Yes Yes Waste evaporator bottoms Yes Yes Yes Yes        Spent beaded resins Yes Yes Yes Yes        Powdered resins  Yes No Yes Yes        Filtered elements  Yes Yes Yes Yes Miscellaneous waste (contaminated clothing, tools, paper products, etc)  Yes Yes Yes Yes Radiation Protection Radiation Protection Design Features 12.3            Shielding  Shielding thickness and coverage  
 
determined for each area to assure maximum design dose rates are not  
 
exceeded and to prevent activation of components within  
 
containment Same* Same* Same*  
 
BVPS-2 UFSAR Rev. 0  20 of 20 TABLE 1.3-1 (Cont)
Section and Characteristics Referenced in Section
 
BVPS-2 
 
BVPS-1 
 
Millstone
 
(Unit 3)
North Anna
 
(Units 1 & 2)
Ventilation Ventilation, filtration of ventilation streams, and atmospheric release of ventilation
 
streams to maintain comfortable environment and limit
 
airborne radioactivity below concentration limits of 10 CFR 20,
 
Appendix B Same* Same* Same*
NOTES:  *Where the word 'Same' appears, the design feature of the listed unit is the same as that of BVPS-2. **Instrumentation and Controls are functionally similar. The term functionally similar is intended to mean similar in the basic operating or safety functions of the compared systems to which this applies. The specific features of the BVPS-2 design are described in detail in applicable sections of the UFSAR.
 
BVPS-2 UFSAR Rev. 16  1 of 19 TABLE 1.3-2 COMPARISON OF FINAL AND PRELIMINARY INFORMATION (HISTORICAL)
FSAR Section
/PSAR Reference Significant Changes Since PSAR 2.2.3 /2.1 Addressed monitoring of main control room for accidental release of chlorine in accordance
 
with Regulatory Guide 1.95.


BVPS-1 Millstone (Unit 3)
North Anna (Units 1 & 2)        Ventilation  Ventilation, filtration of ventilation streams, and atmospheric release of ventilation streams to maintain comfortable environment and limit airborne radioactivity below concentration limits of 10 CFR 20, Appendix B Same* Same* Same*                                          NOTES:  *Where the word 'Same' appears, the design feature of the listed unit is the same as that of BVPS-2. **Instrumentation and Controls are functionally similar. The term functionally similar is intended to mean similar in the basic operating or safety functions of the compared systems to which this applies. The specific features of the BVPS-2 design are described in detail in applicable sections of the UFSAR.
BVPS-2 UFSAR Rev. 16  1 of 19 TABLE 1.3-2  COMPARISON OF FINAL AND PRELIMINARY INFORMATION (HISTORICAL)  FSAR Section /PSAR Reference  Significant Changes Since PSAR  2.2.3 /2.1 Addressed monitoring of main control room for accidental release of chlorine in accordance with Regulatory Guide 1.95.
2.5  
2.5  
/2.5 Discussion of subsurface conditions within main plant area revised due to discovery of zone of loose granular soil that required densification. 3.7B.3.1.2 /None Former selection of highest elevation curves of amplified response spectra (ARS) for piping analysis now envelopes all applicable ARS curves to assure more conservative analysis. Increased ARS peak broadening from 15% to +25% -20% to be comparable with equipment analysis.
/2.5 Discussion of subsurface conditions within main plant area revised due to discovery of zone of loose granular soil that required densification.
3.9B.3.2.1 /15.6.2.3 Seal leakage tests, previously addressed as being performed at the same pressure used in the hydrostatic tests, has been changed to read leakage tests performed at performance test pressures. 3.9N.4.4 /None The control rod drive mechanism (CRDM) seismic supports were upgraded because subsection NF requires that the component supports be the same code classification as the equipment they are supporting. Since the CRDM pressure housings are ASME Code Class 1, the supports must also be Class 1. 3.10B /15.5.3.1 Added Standard Review Plan (SRP) Section 3.10 statement dated 24 November 1975 (USNRC NUREG-75/087) in addition to existing IEEE Standard 344-1971 position.
3.7B.3.1.2  
/None Former selection of highest elevation curves of  
 
amplified response spectra (ARS) for piping analysis now envelopes all applicable ARS curves to assure more conservative analysis. Increased ARS peak broadening from 15% to +25% -20% to be comparable with equipment analysis.  
 
3.9B.3.2.1  
/15.6.2.3 Seal leakage tests, previously addressed as being performed at the same pressure used in the hydrostatic tests, has been changed to read leakage tests performed at performance test pressures.
3.9N.4.4  
/None The control rod drive mechanism (CRDM) seismic  
 
supports were upgraded because subsection NF  
 
requires that the component supports be the same code classification as the equipment they are supporting. Since the CRDM pressure housings are ASME Code Class 1, the supports must also be Class 1.
3.10B /15.5.3.1 Added Standard Review Plan (SRP) Section 3.10 statement dated 24 November 1975 (USNRC NUREG-75/087) in addition to existing IEEE Standard  
 
344-1971 position.  
 
3.10N  
3.10N  
/None The seismic and environmental requalification program has been necessitated by a change in licensing codes and regulations from IEEE Standards 323-1471 and 344-1971 to the methodology of IEEE Standard 344-1975 and the environmental test envelopes and analytical techniques associated with IEEE Standard 323-1974.
/None The seismic and environmental requalification program has been necessitated by a change in licensing codes and regulations from IEEE Standards 323-1471 and 344-1971 to the methodology of IEEE Standard 344-1975 and the environmental test envelopes and analytical techniques associated with IEEE Standard 323-
BVPS-2 UFSAR Rev. 0  2 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR Appendix 3A  
 
/None Piping analysis computer program changed from SHOCK 3, PIPESTRESS, STRESS COMBINER, AND NCCODE to current Stone & Webster Engineering Corporation (SWEC) computer program, NUPIPE-SW. 4.3.2.1 /None Hafnium conversion made to improve control rod design. 5.2.2.5 /None Addressed mounting, support, and reaction force capability of pressurizer relief valves. 5.2.3.4.6 /None Analysis of socket welded fittings made to show compliance of the socket weld, of the attached piping, and of the branch nozzle to the requirements of an ASME Section III fatigue evaluation. 5.2.5 /4.2.4 & 9.7 Provisions made for continuous monitoring of leakage from reactor containment pressure boundary into containment sumps with Class 1E narrow range level transmitters and programmable controllers. 5.3 /None Reactor vessel weld material program provides the information necessary to satisfy USNRC Bulletins 78-12 and 78-12A.
1974.
BVPS-2 UFSAR Rev. 0  2 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
Appendix 3A  
 
/None Piping analysis computer program changed from SHOCK 3, PIPESTRESS, STRESS COMBINER, AND NCCODE to current Stone & Webster Engineering Corporation (SWEC) computer program, NUPIPE-SW.
4.3.2.1 /None Hafnium conversion made to improve control rod  
 
design. 5.2.2.5 /None Addressed mounting, support, and reaction force capability of pressurizer relief valves.
5.2.3.4.6  
/None Analysis of socket welded fittings made to show compliance of the socket weld, of the attached piping, and of the branch nozzle to the requirements of an ASME Section III fatigue evaluation.
5.2.5 /4.2.4 & 9.7 Provisions made for continuous monitoring of leakage from reactor containment pressure boundary into containment sumps with Class 1E narrow range level transmitters and programmable controllers.
5.3 /None Reactor vessel weld material program provides  
 
the information necessary to satisfy USNRC  
 
Bulletins 78-12 and 78-12A.  
 
5.3.3.1  
5.3.3.1  
/4.4.2 The reactor pressure vessel insulation provides a thermal neutron shielding to reduce activation of the upper vessel, nozzles, and neutron shield tank. 5.4.1 /None As a result of the change to the surge and protection for the reactor coolant pump (RCP) motors, the RCP turn-to-turn insulation is rated to accept 4,160 V, indicating that surges 2.5 times higher than expected could be accommodated during pre-operational tests without harming the motors. 5.4.3.2 /None Thermal sleeves in the reactor coolant loop branch nozzles have been deleted to simplify the nozzle design and to show technical improvement.
/4.4.2 The reactor pressure vessel insulation provides a thermal neutron shielding to reduce activation of the upper vessel, nozzles, and neutron shield tank. 5.4.1 /None As a result of the change to the surge and protection for the reactor coolant pump (RCP) motors, the RCP turn-to-turn insulation is rated to accept 4,160 V, indicating that surges 2.5 times higher than expected could be accommodated  
BVPS-2 UFSAR Rev. 0  3 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 5.4.4.1  
 
/None Modifications to steam generators integral flow restrictor to provide significant design enhancement. Benefits include improved mass and energy calculation, reduced blowdown during a steam break, and reduced steam break size from 4.6 ft2 to 1.4 ft2. 5.4.7.2 /4.1.2.1 The change from a one train RHR system to a two train RHR system provides maximum operational flexibility concurrent with maintenance capabilities.
during pre-operational tests without harming the motors. 5.4.3.2 /None Thermal sleeves in the reactor coolant loop  
 
branch nozzles have been deleted to simplify the nozzle design and to show technical improvement.
BVPS-2 UFSAR Rev. 0  3 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
5.4.4.1  
/None Modifications to steam generators integral flow restrictor to provide significant design enhancement. Benefits include improved mass and energy calculation, reduced blowdown during a steam break, and reduced steam break size from 4.6 ft2 to 1.4 ft
: 2. 5.4.7.2 /4.1.2.1 The change from a one train RHR system to a two train RHR system provides maximum operational flexibility concurrent with maintenance  
 
capabilities.  
 
5.4.7.2.1  
5.4.7.2.1  
/4.1.2.1 The RHR interlocks have been revised to reflect an auto closure set point on increasing reactor coolant system (RCS) pressure >750 psig to allow full relief valve potential and preclude premature isolation of the RCS low pressure relief projection. 5.4.7.2.2 /None The residual heat removal (RHR) miniflow change from automatic to manual provides protection for the RHR pumps from deadheading against high discharge pressure.
 
/4.1.2.1 The RHR interlocks have been revised to reflect an auto closure set point on increasing reactor coolant system (RCS) pressure >750 psig to allow full relief valve potential and preclude premature isolation of the RCS low pressure relief projection.
5.4.7.2.2  
/None The residual heat removal (RHR) miniflow change from automatic to manual provides protection for the RHR pumps from deadheading against high  
 
discharge pressure.  
 
5.4.7.2.3  
5.4.7.2.3  
/None The reactor vessel head vent change is a part of the cold shutdown modification discussed in UFSAR Section/PSAR Reference 5.4.7.2.6, and provides venting capability from the reactor vessel head should this action become necessary.
 
/None The reactor vessel head vent change is a part of  
 
the cold shutdown modification discussed in UFSAR Section/PSAR Reference 5.4.7.2.6, and provides venting capability from the reactor  
 
vessel head should this action become necessary.  
 
5.4.7.2.6  
5.4.7.2.6  
/None The extensive change in the approach to safety grade cold shutdown provides a significant improvement in the ability to bring the plant to a cold shutdown condition in the event of an abnormal occurrence.
 
/None The extensive change in the approach to safety  
 
grade cold shutdown provides a significant improvement in the ability to bring the plant to a cold shutdown condition in the event of an  
 
abnormal occurrence.  
 
5.4.11.2.1  
5.4.11.2.1  
/None Pressurizer relief tank cooldown and drainage provide to protect against overfilling of tanks and introduction of water into the degassification system. Appendix 5A /None Same as for UFSAR Section/PSAR Reference 5.4.7.2.6.
 
BVPS-2 UFSAR Rev. 0  4 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 6.2.1.1.3.1  
/None Pressurizer relief tank cooldown and drainage provide to protect against overfilling of tanks and introduction of water into the degassification system.
/6.4 Refueling water storage tank (RWST) capacity increased because of containment depressurization calculation. 6.2.1.1.3.7 /10.3.5 Automatic closure of motor-operated discharge valves in auxiliary feedwater lines to each steam generator replaced with cavitating venturies to limit flow to the steam generator affected by a pipe break. 6.2.1.3 /None Same as for UFSAR Section/PSAR Reference 7.3.1.1. 6.2.2.2.1 /6.4 Quench spray system (QSS) header diameters and design of nozzles changed to provide more uniform delivery of smaller droplets spray for better thermal effectiveness.
Appendix 5A  
/None Same as for UFSAR Section/PSAR Reference  
 
5.4.7.2.6.
BVPS-2 UFSAR Rev. 0  4 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
6.2.1.1.3.1  
 
/6.4 Refueling water storage tank (RWST) capacity increased because of containment depressurization calculation.
6.2.1.1.3.7  
/10.3.5 Automatic closure of motor-operated discharge valves in auxiliary feedwater lines to each steam generator replaced with cavitating venturies to limit flow to the steam generator affected by a pipe break.
6.2.1.3 /None Same as for UFSAR Section/PSAR Reference 7.3.1.1.
6.2.2.2.1  
/6.4 Quench spray system (QSS) header diameters and design of nozzles changed to provide more uniform delivery of smaller droplets spray for better  
 
thermal effectiveness.  
 
6.2.4  
6.2.4  
/5.2 Changes to containment isolation system include:  
/5.2 Changes to containment isolation system include:  
: 1. Elimination of pressurizer dead weight calibrator.  
: 1. Elimination of pressurizer dead weight calibrator.  
: 2. Increased number of penetrations dedicated to containment leakage monitoring from one to two.   
: 2. Increased number of penetrations dedicated to containment leakage monitoring from one to two.   
: 3. Added new penetration for chemical addition line to QSS.
: 3. Added new penetration for chemical addition line to QSS.  
 
6.3.2  
6.3.2  
/6.3.2.1.2 To provide for reduced plant maintenance/radiation exposure, without compromise in plant safety, the boron injection tank was eliminated. 6.3.2.2 /6.3.2.2.2 The automatic transfer to recirculation design provides for those essential operations which establish a flow path from the containment sump to the RCS to continue reactor core cooling flowwithout operator action. The PSAR design required two manual operator actions. 6.3.3 /6.3.2.2.1 The coincidence of low pressurizer water level and pressure for the safety injection logic was deleted, and the existing safeguards actuation logic was converted to two-out-of-three low BVPS-2 UFSAR Rev. 0  5 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR pressurizer pressure signals. This modification meets the signal failure criterion.
/6.3.2.1.2 To provide for reduced plant maintenance/radiation exposure, without compromise in plant safety, the boron injection tank was eliminated.
6.3.2.2 /6.3.2.2.2 The automatic transfer to recirculation design  
 
provides for those essential operations which establish a flow path from the containment sump to the RCS to continue reactor core cooling flowwithout operator action. The PSAR design required two manual operator actions.
6.3.3 /6.3.2.2.1 The coincidence of low pressurizer water level and pressure for the safety injection logic was  
 
deleted, and the existing safeguards actuation logic was converted to two-out-of-three low  
 
BVPS-2 UFSAR Rev. 0  5 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
pressurizer pressure signals. This modification meets the signal failure criterion.  
 
6.4.2.3  
6.4.2.3  
/9.13.4 Added quick-acting chlorine detectors to outdoor air intakes of main control room envelope to enhance its habitability, as determined from toxic chemical analysis. Added redundant, Category 1 area radiation monitor to isolate the control room area environment to maintain control roomhabitability during design basis accident.
/9.13.4 Added quick-acting chlorine detectors to outdoor air intakes of main control room envelope to enhance its habitability, as determined from toxic chemical analysis. Added redundant,  
 
Category 1 area radiation monitor to isolate the control room area environment to maintain control roomhabitability during design basis  
 
accident.  
 
6.5.2  
6.5.2  
/6.4 Use of positive displacement pump to add sodium hydroxide solution to quench spray, instead of gravity feed system proposed earlier, to improve control of chemical addition. 6.5.3 /5.3.1 Changed elevated release point for fission product control from top of cooling tower to top of containment.
/6.4 Use of positive displacement pump to add sodium hydroxide solution to quench spray, instead of gravity feed system proposed earlier, to improve control of chemical addition.
6.5.3 /5.3.1 Changed elevated release point for fission product control from top of cooling tower to top  
 
of containment.  
 
7.2.1.1.2  
7.2.1.1.2  
/None Steam line break protection system changed to enhance plant safety and to increase plant availability by preventing spurious safety injection actuation. The analysis for the deletion of reactor trip following a turbine trip below 70 percent power is addressed in Section 15.2.3.
 
The deletion of coincidence of low pressurizer water level and pressure for the safety injection logic is addressed in FSAR Section/PSAR Reference 6.3.3. 7.2.2.2.3 /7.2.2.2.1 The deletion of the RCP breaker position allows the breaker open indication to be eliminated as a source of reactor trip when this indication is from a single relay source, without affecting plant safety. That is, this change can potentially eliminate nuisance trips.
/None Steam line break protection system changed to enhance plant safety and to increase plant availability by preventing spurious safety injection actuation.
The analysis for the deletion of reactor trip following a turbine trip below 70 percent power is addressed in Section 15.2.3.  
 
The deletion of coincidence of low pressurizer water level and pressure for the safety injection logic is addressed in FSAR Section/PSAR Reference 6.3.3.
7.2.2.2.3  
/7.2.2.2.1 The deletion of the RCP breaker position allows the breaker open indication to be eliminated as a source of reactor trip when this indication is from a single relay source, without affecting plant safety. That is, this change can  
 
potentially eliminate nuisance trips.  
 
7.3.1.1  
7.3.1.1  
/7.3.2.1.1 Implementation of N-1 loop steam line break protection system that actuates safety injection and steam line isolation on receiving two-out-of-three low steam line pressure signals from any one steam line. The protection logic will increase the BVPS-2 UFSAR Rev. 0  6 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR margins to the trip set points during the start up phase where problems are most likely to occur. The modification to the solid state protection system incorporates a manual initiation of steam line isolation at the system level. Amendment 12 of the PSAR, Question 7.5, committed this design modification to the USNRC. 7.4.1.2.1 /None A process equipment modification was made to nuclear steam supply system instrumentation signals to the emergency shutdown panel. 7.4.1.3 /None In the event of an exposure fire in the instrumentation and relay room, cable spreading room, west communication room, and the cable tunnel, an alternate shutdown panel is provided in the auxiliary building to provide a means of alternative shutdown capability that bypasses all equipment and electrical cables located in the fire areas. 7.5.3 /None Bypass inoperable status indication system added to monitor Beaver Valley Power Station - Unit 2 (BVPS-2) safety systems for operability prior to an accident condition. Safety parameter display system added to BVPS-2 to monitor specific plant parameters used in the emergency response facilities and nuclear data link.
/7.3.2.1.1 Implementation of N-1 loop steam line break  
 
protection system that actuates safety injection and steam line isolation on receiving two-out-of-three low steam line pressure signals from any one steam line. The protection logic will increase the  
 
BVPS-2 UFSAR Rev. 0  6 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
margins to the trip set points during the start up phase where problems are most likely to occur. The modification to the solid state protection system incorporates a manual initiation of steam line isolation at the system level. Amendment 12 of the PSAR, Question 7.5, committed this design modification to the USNRC.
7.4.1.2.1  
/None A process equipment modification was made to nuclear steam supply system instrumentation signals to the emergency shutdown panel.
7.4.1.3 /None In the event of an exposure fire in the  
 
instrumentation and relay room, cable spreading room, west communication room, and the cable tunnel, an alternate shutdown panel is provided in the auxiliary building to provide a means of alternative shutdown capability that bypasses all equipment and electrical cables located in the fire areas.
7.5.3 /None Bypass inoperable status indication system added to monitor Beaver Valley Power Station - Unit 2 (BVPS-2) safety systems for operability prior to an accident condition.
Safety parameter display system added to BVPS-2 to monitor specific plant parameters used in the  
 
emergency response facilities and nuclear data  
 
link.
7.6.5  
7.6.5  
/7.6.1 & 7.6.5 Transfer from emergency core cooling system injection mode to recirculation mode is automatic instead of manual, and depends on RWST level and a safety injection/CIB signal. Also see change for UFSAR Section/PSAR Reference 6.3.2.2. 7.6.2.1 /7.6.1 The suction valves of the RHR pumps can be powered from either Class 1E bus. This ensures that after an isolation that the valves can be opened for RHR pump operation. Interlocks are provided to prevent paralleling of the two Class 1E power sources.
/7.6.1 & 7.6.5 Transfer from emergency core cooling system  
BVPS-2 UFSAR Rev. 0  6a of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 7.6.7.2  
 
/4.2.2 Incorporation of RCS cold overpressurization mitigation to provide for potential transients by utilizing the existing power-operated relief valves with modifications to their actuation logic.   
injection mode to recirculation mode is automatic instead of manual, and depends on RWST level and a safety injection/CIB signal. Also  
 
see change for UFSAR Section/PSAR Reference 6.3.2.2.
7.6.2.1 /7.6.1 The suction valves of the RHR pumps can be powered from either Class 1E bus. This ensures that after an isolation that the valves can be opened for RHR pump operation. Interlocks are provided to prevent paralleling of the two Class 1E power sources.  
 
BVPS-2 UFSAR Rev. 0  6a of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
7.6.7.2  
/4.2.2 Incorporation of RCS cold overpressurization  
 
mitigation to provide for potential transients by utilizing the existing power-operated relief valves with modifications to their actuation  
 
logic.   
 
BVPS-2 UFSAR Rev. 0  7 of 19 TABLE 1.3-2 (Cont)
FSAR Section
/PSAR Reference Significant Changes Since PSAR
 
7.7.1.2
/3.3.2.5.3 Deletion of part length control rods made to comply with regulatory restrictions on use of part length rods.
9.1.1 /9.12 Capacity of hoist for handling new fuel
 
assemblies increased from 5 tons to 10 tons.
9.1.2 /9.12 Changes to storage and handling of spent fuel
 
include:
: 1. Capacity of spent fuel pool increased from 274 spent fuel assemblies to 1,059
 
assemblies.
: 2. Assurance of an effective multiplication factor, K effof 0.90, formerly accomplished by center-to-center spacing of spent fuel assemblies,is now attained by use of neutron absorbing material, where K effwill be less than 0.95.
: 3. Fuel building hoists changed from two hoists of 2 tons and 5 tons capacities to two hoists, each of 10 tons capacity.
: 4. Failed fuel containers are not being provided now; however, provisions have been made for
 
future installation.
9.1.4.2.3.4
/None Fuel transfer system upgraded to help ensure trouble-free operation during initial refueling and core loading operations. The replacement enhances the reliabilityand maintainability of the fuel transfer system.
9.1.5 /None Provided description of new system, overhead heavy load handling system, that is used
 
throughout plant.


BVPS-2 UFSAR Rev. 0  7 of 19 TABLE 1.3-2 (Cont)  FSAR Section /PSAR Reference  Significant Changes Since PSAR 7.7.1.2
/3.3.2.5.3 Deletion of part length control rods made to comply with regulatory restrictions on use of part length rods. 9.1.1 /9.12 Capacity of hoist for handling new fuel assemblies increased from 5 tons to 10 tons. 9.1.2 /9.12 Changes to storage and handling of spent fuel include: 
: 1. Capacity of spent fuel pool increased from 274 spent fuel assemblies to 1,059 assemblies. 2. Assurance of an effective multiplication factor, Keffof 0.90, formerly accomplished by center-to-center spacing of spent fuel assemblies,is now attained by use of neutron absorbing material, where Keffwill be less than 0.95. 
: 3. Fuel building hoists changed from two hoists of 2 tons and 5 tons capacities to two hoists, each of 10 tons capacity. 4. Failed fuel containers are not being provided now; however, provisions have been made for future installation. 9.1.4.2.3.4 /None Fuel transfer system upgraded to help ensure trouble-free operation during initial refueling and core loading operations. The replacement enhances the reliabilityand maintainability of the fuel transfer system. 9.1.5 /None Provided description of new system, overhead heavy load handling system, that is used throughout plant.
9.2.1  
9.2.1  
/9.9 Station service water system changes include:  
/9.9 Station service water system changes include:  
: 1. Service water system load changes for normal operation include:
: 1. Service water system load changes for normal operation include:  
: a. Component cooling water heat exchangers increased from one to two, BVPS-2 UFSAR Rev. 0  8 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR  
: a. Component cooling water heat exchangers increased from one to two,  
 
BVPS-2 UFSAR Rev. 0  8 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
: b. Added air-conditioning unit to safeguards area,   
: b. Added air-conditioning unit to safeguards area,   
: c. Added one set of cooling coils to main steam valve house,
: c. Added one set of cooling coils to main steam valve house,  
: d. Charging pump lube oil coolers decreased from two to one per pump, and  
: d. Charging pump lube oil coolers decreased from two to one per pump, and
: e. Added motor control center cooling coils. 2. Service water system load changes for post-DBA operation are:
: e. Added motor control center cooling coils.  
: a. Added a set of cooling coils for motor control center,
: 2. Service water system load changes for post-DBA operation are:  
: a. Added a set of cooling coils for motor control center,  
: b. Added rod control area air-conditioning unit,   
: b. Added rod control area air-conditioning unit,   
: c. Added safeguards area air-conditioning unit, and
: c. Added safeguards area air-conditioning unit, and  
: d. Added main steam valve house cooling coils.   
: d. Added main steam valve house cooling coils.   
: 3. The former provisions for chemical addition to recirculation coolers for corrosion control are deleted.  
: 3. The former provisions for chemical addition to recirculation coolers for corrosion control are deleted.  
: 4. All equipment with safety-related function and not located above probable maximum flood level is now flood-protected. 5. Primary component cooling water temperature is notcontrolled by flow of service water through recirculation coolers. Water temperature now a function of service water flow. 6. Portion of flow from cooling tower makeup diverted to service water discharge for reasons of avoiding sediment buildup in discharge lines.
: 4. All equipment with safety-related function and not located above probable maximum flood level is now flood-protected.  
BVPS-2 UFSAR Rev. 0  9 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 9.2.2.1  
: 5. Primary component cooling water temperature is notcontrolled by flow of service water through recirculation coolers. Water temperature now a function of service water flow. 6. Portion of flow from cooling tower makeup diverted to service water discharge for  
/9.4 Primary component cooling water system has these criteria and equipment changes: 1. Cooling water pumps are now environmentally qualifiedfor normal, abnormal, and accident conditions operation, as addressed in Section 3.11. 2. Additional equipment that utilizes the cooling water of this system include: primary drains coolers, auxiliary steam degasifier coolers, radiation monitors, overhead gas compressors, and containment instrument air compressors.
 
: 3. The containment air recirculation cooling coils have been deleted from Figure 9.4-4.
reasons of avoiding sediment buildup in  
 
discharge lines.  
 
BVPS-2 UFSAR Rev. 0  9 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
9.2.2.1  
/9.4 Primary component cooling water system has these  
 
criteria and equipment changes:  
: 1. Cooling water pumps are now environmentally qualifiedfor normal, abnormal, and accident conditions operation, as addressed in Section 3.11. 2. Additional equipment that utilizes the cooling water of this system include: primary drains coolers, auxiliary steam degasifier coolers, radiation monitors, overhead gas compressors, and containment  
 
instrument air compressors.  
: 3. The containment air recirculation cooling coils have been deleted from Figure 9.4-4.  
 
9.2.4  
9.2.4  
/9.11 Potable water will originate from wells instead of from Beaver Valley Power Station - Unit 1 (BVPS-1) treated river water supply, with head pressure provided by an elevated storage tank. 9.2.7 /10.3.9 Turbine plant component cooling water system changes are:  
/9.11 Potable water will originate from wells instead of from Beaver Valley Power Station - Unit 1 (BVPS-1) treated river water supply, with head pressure provided by an elevated storage tank.
: 1. Control valve added to discharge of each heat exchanger.
9.2.7 /10.3.9 Turbine plant component cooling water system  
: 2. Makeup water tosystem is from demineralized water system instead of condensate system.
 
: 3. Surge tank capacity increased from 2,900 gallons to 3,173 gallons.
changes are:  
: 4. Total dynamic head rating of dual volume horizontal pumps changed from 120 feet to 160 feet, with same capacity of 11,000 gpm.
: 1. Control valve added to discharge of each heat exchanger.  
: 5. Additional equipment served by this system include:  tank drain cooler, condensate polishing air compressor, evaporator reboiler drain coolers, and condensate polishing sample sink cooler.
: 2. Makeup water tosystem is from demineralized water system instead of condensate system.  
: 3. Surge tank capacity increased from 2,900 gallons to 3,173 gallons.  
: 4. Total dynamic head rating of dual volume horizontal pumps changed from 120 feet to 160 feet, with same capacity of 11,000 gpm.  
: 5. Additional equipment served by this system include:  tank drain cooler, condensate polishing air compressor, evaporator reboiler drain coolers, and condensate polishing  
 
sample sink cooler.  
 
9.2.8  
9.2.8  
/9.11 Primary grade water storage tank addressed earlier no longer in present design.
/9.11 Primary grade water storage tank addressed  
BVPS-2 UFSAR Rev. 0  10 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 9.3.1  
 
earlier no longer in present design.  
 
BVPS-2 UFSAR Rev. 0  10 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
9.3.1  
/9.8 Changes to compressed air system include:  
/9.8 Changes to compressed air system include:  
: 1. Containment instrument air compressors, air dryer, and airreceiver tanks (including new one of 25 ft3capacity) now located in main steam line valve area instead of within containment, although suction is still taken from within containment.
: 1. Containment instrument air compressors, air dryer, and airreceiver tanks (including new one of 25 ft 3capacity) now located in main steam line valve area instead of within  
: 2. Containment instrument air compressors rating changed from 110 psigat 50 scfm discharge to 120 psig at 30 scfm. Station air compressors rating increased from 110 psig at 358 scfm to 120 psig at 728 scfm.
 
: 3. Addition of refrigerant-type air dryer with desiccant filter bypass arrangement to containment instrument air system. 4. Addition of desiccant-type filter bypass arrangement to station instrument air dryer.
containment, although suction is still taken  
: 5. Both station air and containment instrument air compressors now have capability of operating with power from the onsite nonsafety diesel generator.
 
: 6. Addition of third system, condensate polishing air system.
from within containment.  
: 2. Containment instrument air compressors rating changed from 110 psigat 50 scfm discharge to 120 psig at 30 scfm. Station air compressors rating increased from 110 psig at 358 scfm to  
 
120 psig at 728 scfm.  
: 3. Addition of refrigerant-type air dryer with desiccant filter bypass arrangement to containment instrument air system.  
: 4. Addition of desiccant-type filter bypass arrangement to station instrument air dryer.  
: 5. Both station air and containment instrument air compressors now have capability of  
 
operating with power from the onsite  
 
nonsafety diesel generator.  
: 6. Addition of third system, condensate polishing air system.  
 
9.3.2.1  
9.3.2.1  
/9.6 Reactor plant and process sampling system changes include: 1. Addition of conditioning rack for blowdown grab samples.
/9.6 Reactor plant and process sampling system  
: 2. Addition of on-line pH and Na conductivity monitors for each steam generator.
 
: 3. Addition of sampling capabilities for: gaseous waste storage tanks, primary drains transfer tanks, primary grade water, gaseous waste surge tank, letdown flow, fuel pool, cesium removal ion exchangers, and RHR system liquids.
changes include:  
BVPS-2 UFSAR Rev. 0  11 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR  
: 1. Addition of conditioning rack for blowdown grab samples.  
: 4. Local sampling capabilities provided for RWST, boric acid tank, and QSS chemical addition tank. 5. Provisions made for exhausting potentially radioactive sample panel gases to supplementary leak collection and release system.
: 2. Addition of on-line pH and Na conductivity monitors for each steam generator.  
: 3. Addition of sampling capabilities for:
gaseous waste storage tanks, primary drains transfer tanks, primary grade water, gaseous waste surge tank, letdown flow, fuel pool, cesium removal ion exchangers, and RHR system liquids.  
 
BVPS-2 UFSAR Rev. 0  11 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
: 4. Local sampling capabilities provided for RWST, boric acid tank, and QSS chemical addition tank.  
: 5. Provisions made for exhausting potentially radioactive sample panel gases to supplementary leak collection and release  
 
system.
9.3.2.3  
9.3.2.3  
/None Addressed new post-accident sampling system.
/None Addressed new post-accident sampling system.  
 
9.3.3  
9.3.3  
/9.7 & 4.2.4 Changes to equipment and floor drainage system are:  1. Reactor coolant system loop drains formerly directed to both primary drains transfer and pressurizer relief tanks now directed to primary drains transfer tank only. 2. Valve stem leakoffs now go directly to primary drains transfer tank in containment instead of to pressurizer relief tank.
/9.7 & 4.2.4 Changes to equipment and floor drainage system  
: 3. Addressed containment sump monitoring with Class 1E level transmitters and programmable controller. 9.3.4 /None The chemical and volume control system continuous degasification allows for admittance of hydrogen whenever a low pressure alarm condition exists.
 
are:  1. Reactor coolant system loop drains formerly directed to both primary drains transfer and pressurizer relief tanks now directed to primary drains transfer tank only.  
: 2. Valve stem leakoffs now go directly to primary drains transfer tank in containment instead of to pressurizer relief tank.  
: 3. Addressed containment sump monitoring with Class 1E level transmitters and programmable controller.
9.3.4 /None The chemical and volume control system continuous degasification allows for admittance of hydrogen whenever a low pressure alarm  
 
condition exists.  
 
9.3.4.6  
9.3.4.6  
/9.2 Classification of that portion of boron recovery system from degasifiers and downstream piping to gaseous waste system downgraded from Safety Class 3 to non-nuclear safety (NNS) class. 9.4.1 /9.13.4 Same as for UFSAR Section/PSAR Reference 6.4.2.3. 9.4.3 /9.13.2 Changes to auxiliary and radwaste area ventilation system include:  
/9.2 Classification of that portion of boron recovery system from degasifiers and downstream piping to gaseous waste system downgraded from Safety Class 3 to non-nuclear safety (NNS) class.
9.4.1 /9.13.4 Same as for UFSAR Section/PSAR Reference  
 
6.4.2.3.
9.4.3 /9.13.2 Changes to auxiliary and radwaste area  
 
ventilation system include:  
: 1. Ambient air temperature lower limit for ventilation equipment area and general areas increased from 60F to 65F.
: 1. Ambient air temperature lower limit for ventilation equipment area and general areas increased from 60F to 65F.
BVPS-2 UFSAR Rev. 0  12 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR  
BVPS-2 UFSAR Rev. 0  12 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
: 2. Air temperature limits for shielded cubicles at all levels (except those in radwaste area) changed from between 65F and 104F to between 65F and 120F. For radwaste area cubicles, the limits are between 65F and 104F.   
: 2. Air temperature limits for shielded cubicles at all levels (except those in radwaste area) changed from between 65F and 104F to between 65F and 120F. For radwaste area cubicles, the limits are between 65F and 104F.   
: 3. Upper temperature limit during a DBA for component cooling water pump area and charging pump cubicles increased from 104F to 120F. 9.4.6 /9.13.7 Design temperature of the emergency diesel generator building ventilation system is 122F. Secondary supply fans have been added in order to meet environmental qualification requirements. 9.4.9 /None Upgraded main steam and feedwater valve area ventilation system to safety-related Safety Class 3 to maintain environmental qualification temperatures. 9.4.11 /6.2.4 Area design temperatures for safeguards area ventilation system following a DBA reduced from 140F for first hour and dropping to 120F after shutdown of quench spray and low head safety injection pumps, to 120F maximum at beginning of DBA and below 120F after 3 hours when aforementioned pumps are shut down.
: 3. Upper temperature limit during a DBA for component cooling water pump area and charging pump cubicles increased from 104F to 120F. 9.4.6 /9.13.7 Design temperature of the emergency diesel generator building ventilation system is 122F. Secondary supply fans have been added in order to meet environmental qualification requirements.
9.4.9 /None Upgraded main steam and feedwater valve area ventilation system to safety-related Safety  
 
Class 3 to maintain environmental qualification temperatures.
9.4.11 /6.2.4 Area design temperatures for safeguards area ventilation system following a DBA reduced from 140F for first hour and dropping to 120F after shutdown of quench spray and low head safety injection pumps, to 120F maximum at beginning of DBA and below 120F after 3 hours when aforementioned pumps are shut down.  
 
9.4.13  
9.4.13  
/9.15 Added filtration and exhaust subsystem for new gaseous waste storage tank and cask washdown areas to decontamination building ventilation system. 9.4.15 /10.3.3.1 Addressed gland seal steam exhaust ventilation system that filters and monitors noncondensable gases before being discharged to environment, previously discharged directly to atmosphere. 9.4.16 /None Addressed new condensate polishing building ventilation system, a NNS class system. 9.5.4 /9.14 Changes to emergency diesel generator fuel oil storage and transfer system include:
/9.15 Added filtration and exhaust subsystem for new gaseous waste storage tank and cask washdown areas to decontamination building ventilation system. 9.4.15 /10.3.3.1 Addressed gland seal steam exhaust ventilation system that filters and monitors noncondensable  
: 1. Total  capacity  of  two  fuel  oil  storage  tanks  increased  from  40,000  gallons  to BVPS-2 UFSAR Rev. 0  13 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 58,000 gallons to provide for 7 days full load operation of each diesel generator.
 
: 2. Cross-connection piping between fuel oil storage tanks now eliminated.
gases before being discharged to environment, previously discharged directly to atmosphere.
: 3. Fuel oil transfer pumps, formerly positive displacement type, mounted outside of storage tanks, and with capacity of 10 gpm, are now vertical centrifugal type, mounted inside of tanks, and with capacity of 40 gpm.
9.4.16 /None Addressed new condensate polishing building
: 4. Discharge line relief valves replaced with recirculation orifices.
 
: 5. Fuel strainers, formerly located in common fuel lines to diesel generators, now located in discharge of each oil transfer pump. 6. Engine-mounted fuel oil tank and day tank, each of 550-gallon capacity, replaced with single 1,100-gallon floor-mounted day tank for each diesel generator.
ventilation system, a NNS class system.
: 7. All storage tanks and associated piping are either indoors or encased in concrete, with no components in direct contact with soil. 9.5.6 /8.5.2 Changes to emergency diesel generator starting system include:
9.5.4 /9.14 Changes to emergency diesel generator fuel oil  
: 1. Both air compressors for each diesel generator now motor-driven, as opposed to formerly one motor-driven and one diesel/electric-driven.
 
: 2. Two air receivers now provided for each diesel generator instead of former six air bottles. 10.2.1 /10.3.3.2 Turbine-generator exciter maximum output rating at 1,800 rpm increased from 3,300 kWe and 500 V dc to 3,900 kWe and 525 V dc. 10.3.1 /10.3.1 The residual heat release and atmospheric dump piping and equipment have increased in size and capacity, and the Category I boundary extended to BVPS-2 UFSAR Rev. 0  14 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR accommodate cold shutdown. 10.3.2 /10.3.1.2 Main steam supply system changes include:  
storage and transfer system include:  
: 1. Replaced nonreturn valves with main steam isolation valves to prevent reverse flow of steam in event of accidental pressure reduction.
: 1. Total  capacity  of  two  fuel  oil  storage  tanks  increased  from  40,000  gallons  to  
: 2. Main steam line trip valves changed from swing disk-type to hydraulically-operated ball type, held open by solenoid-operated mechanical latch. 3. Parallel trip valve configuration for turbine-driven auxiliary feedwater pump steam supply changed. Presently, three pairs of series solenoid-operated trip valves are provided, one pair in each of the three 3-inch lines between the 32-inch main steam line and the 3-inch turbine drive common header. 4. Main steam line trip valves changed from hydraulically operated ball-type to pneumatically operated wye pattern globe valve. 10.4.4 /10.3.1 Added cooling tower pumps and low-low Tavgpermissive interlocks to turbine bypass control valves capabilities. 10.4.5 /10.3.4 Circulating water system changes include:  
 
: 1. Total dynamic head of cooling tower pumps reduced from 96.4 feet to 73 feet through use of natural draft counter-flow cooling tower with its lesser static lift requirements.
BVPS-2 UFSAR Rev. 0  13 of 19 TABLE 1.3-2 (Cont)
: 2. Addition of flood indicators to:  valve pits on suction side of cooling tower pumps, inlet and outlet sides of condenser, and turbine building retention pit, all with flood alarms to main control room.
FSAR Section  
BVPS-2 UFSAR Rev. 0  14a of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 10.4.6  
/PSAR Reference Significant Changes Since PSAR
/None Addressed new condensate cleanup system, a NNS class system, consisting of two subsystems, condensate polishing system and powdered resin dewatering system. 10.4.7.2 /10.3.5 Changes to condensate and feedwater systems include:
 
BVPS-2 UFSAR Rev. 0  15 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR  
58,000 gallons to provide for 7 days full load operation of each diesel generator.  
: 1. Reduction of two half-size motor-driven steam generator feedwater pumps total dynamic head rating from 1,900feet to 1,694 feet for same 15,200 gpm flow. 2. Addition of motor-driven start-up feedwater pump to minimize operation of main feedwater pumps at start-up and low loads. Pump can also be paralleled with a main feedwater pump when either one is out of service. 3. Addition of two separation drain pumps to supplement heater drain pumps during peak plant operation.
: 2. Cross-connection piping between fuel oil storage tanks now eliminated.  
: 4. Addition of full flow condensate polishing system downstream of condensate pumps.
: 3. Fuel oil transfer pumps, formerly positive displacement type, mounted outside of storage tanks, and with capacity of 10 gpm, are now vertical centrifugal type, mounted inside of  
: 5. Feedwater system containment isolation valve changed from a single motor-operated stop check valve outside containment per supply line to a check valve inside containment with an electro hydraulic-operated isolation valve outside containment. 10.4.8 /11.2.5 Steam generator blowdown system changes include:  
 
: 1. Blowdown liquids formerly processed by evaporator facilities now are normally processed by the condensate polishing system after they have been routed to the condenser.
tanks, and with capacity of 40 gpm.  
Processing by evaporator facilities as a backup has been retained. 2. Former discussion on providing common collection facility for blowdown from both BVPS-1 and BVPS-2 is no longer applicable.
: 4. Discharge line relief valves replaced with recirculation orifices.  
Each plant now has an independent processing system for return of blowdown to the condensers. 10.4.9 /10.3.5 Changes to auxiliary feedwater system include:  
: 5. Fuel strainers, formerly located in common fuel lines to diesel generators, now located in discharge of each oil transfer pump.  
: 1. Former two turbine-driven auxiliary feedwater pumps with motor-drive backup replaced with three pumps, two half-size motor-driven and one full capacity turbine-driven.
: 6. Engine-mounted fuel oil tank and day tank, each of 550-gallon capacity, replaced with single 1,100-gallon floor-mounted day tank  
BVPS-2 UFSAR Rev. 0  16 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR  
 
: 2. Output rating of former two turbine-driven auxiliary feedwater pumps was 700 gpm each. Output ratings of present three pumps are 375 gpm each for two motor-driven ones and 750 gpm for turbine-driven one.
for each diesel generator.  
: 3. Former continuous recirculation flow to primary plant demineralized water storage tank (PPDWST) now controlled automatically by recirculation control valve on discharge piping of auxiliary feedwater pumps to maintain minimum flow requirements. 4. Added cross-connection piping between 140,000 gallon PPDWST and 600,000 gallon demineralized water storage tank (DWST) to provide another source of backup water supply. 5. Hand-wheel type motor-operated control valves in auxiliary feedwater supply lines replaced with hand-pump hydraulic type electro-hydraulic-operated control valves for more positive control in event of loss of power. 6. Component cooling water to feedwater pump lube oil coolers, formerly in external piping, now in internal lines that are part of pump design.
: 7. All storage tanks and associated piping are either indoors or encased in concrete, with no components in direct contact with soil.
: 7. Added check valves downstream of control valves in auxiliary feedwater lines outside containment to prevent loss of auxiliary feedwater in event of auxiliary feedwater header rupture. Also added check valve in each auxiliary feedwater line inside containment for containment isolation purposes.
9.5.6 /8.5.2 Changes to emergency diesel generator starting  
: 8. Added cavitating venturi flow elements in common auxiliary feedwater supply lines to limit flow in event of main steam or main feedwater line rupture. 9. Provided redundant safety-related flow transmitters for each auxiliary feedwater line outside containment.
 
BVPS-2 UFSAR Rev. 0  17 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR  
system include:  
: 10. Added separate chemical feed connection on individual auxiliary feedwater supply lines.
: 1. Both air compressors for each diesel generator now motor-driven, as opposed to formerly one motor-driven and one  
: 11. Chemical addition to PPDWST, formerly supplied from chemical feed tank, now provided by injection of chemicals into suction piping. 12. Each motor-driven feedwater pump delivers water to separate header while turbine-driven pump can be manually aligned for water delivery to either header. 10.4.10 /10.3.2 Additional equipment served by auxiliary steam and condensate system include:
 
: 1. Degasifier steam heaters, 2. Evaporator reboilers,  
diesel/electric-driven.  
: 3. Boric acid batch tank,
: 2. Two air receivers now provided for each diesel generator instead of former six air bottles.
: 4. Carbon dioxide vaporizer, and 5. Cask washdown area. 11.2 /11.2.4 Liquid waste management systems have these changes:  
10.2.1 /10.3.3.2 Turbine-generator exciter maximum output rating at 1,800 rpm increased from 3,300 kWe and 500 V dc to 3,900 kWe and 525 V dc.
: 1. Added piping connection from evaporator bottoms cooler to liquid waste drain tanks.
10.3.1 /10.3.1 The residual heat release and atmospheric dump piping and equipment have increased in size and capacity, and the Category I boundary extended to BVPS-2 UFSAR Rev. 0  14 of 19 TABLE 1.3-2 (Cont)
: 2. Provided additional discharge points for liquid waste tanks that include steam generator blowdown (SGB) hold tanks, to cleanup filter, and then to cooling tower blowdown. 3. Expanded capability to process liquid waste by use of SGB evaporators and hold tanks as primary means of processing prior to utilizing other facilities of BVPS-1 and BVPS-2.
FSAR Section  
BVPS-2 UFSAR Rev. 0  18 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 11.3  
/PSAR Reference Significant Changes Since PSAR
/11.2.3 Gaseous waste management systems changes include: 1. Downgraded gaseous waste disposal (GWD) system from Safety Class 3 to NNS class.
 
: 2. Added seven gaseous waste storage tanks. 11.4 /11.2.6 Changes to solid waste management systems include:  
accommodate cold shutdown.
: 1. Formerly, spent resin was flushed to BVPS-1 (without solidification) directly to shipping casks, dewatered, and sealed. Evaporator bottoms were packaged in casks with cement-vermiculite mixture. Both casks were stored at BVPS-1. Now spent resin sludge and evaporator bottoms are normally packaged in 55-gallon drums preloaded with dry cement, with drums stored in condensate polishing building of BVPS-2. Option of disposal via BVPS-1 dewatering facility is still retained, however.
10.3.2 /10.3.1.2 Main steam supply system changes include:  
: 2. Formerly, used cartridge filter elements were mixed with other solid waste in same drum. Now filter elements are packaged by themselves in drums. 11.5 /11.2.7.2 Additional area, effluent, and process monitors added to process and effluent radiological monitoring system to improve system monitoring capabilities. 12.3.2.1 /11.3.2.1 Changes made to configuration design of supplementary neutron streaming shield to facilitate refueling operations. 12.3.2.5 /11.3.2.2 Modified fuel transfer tube shield design to prevent direct line streaming of radiation from spent fuel through seismic gap.
: 1. Replaced nonreturn valves with main steam isolation valves to prevent reverse flow of  
BVPS-2 UFSAR Rev. 0  19 of 19 TABLE 1.3-2 (Cont)   FSAR Section /PSAR Reference Significant Changes Since PSAR 12.3.4  
 
/11.3 Expanded radiation monitoring system with additional area, effluent, and process monitors to improve system monitoring capabilities and to provide post-accident detection. 15.2.3 /None The analysis for the deletion of reactor trip following a turbine trip below 70 percent power is required in order to demonstrate reactor safety should the fast bus transfer to offsite power fail following the generator motoring delay on turbine trip.
steam in event of accidental pressure  
 
reduction.  
: 2. Main steam line trip valves changed from swing disk-type to hydraulically-operated ball type, held open by solenoid-operated mechanical latch.  
: 3. Parallel trip valve configuration for turbine-driven auxiliary feedwater pump steam supply changed. Presently, three pairs of series solenoid-operated trip valves are provided, one pair in each of the three 3-inch lines between the 32-inch main steam line and the 3-inch turbine drive common header. 4. Main steam line trip valves changed from hydraulically operated ball-type to pneumatically operated wye pattern globe valve. 10.4.4 /10.3.1 Added cooling tower pumps and low-low Tavgpermissive interlocks to turbine bypass control valves capabilities.
10.4.5 /10.3.4 Circulating water system changes include:  
: 1. Total dynamic head of cooling tower pumps reduced from 96.4 feet to 73 feet through use  
 
of natural draft counter-flow cooling tower  
 
with its lesser static lift requirements.  
: 2. Addition of flood indicators to:  valve pits on suction side of cooling tower pumps, inlet and outlet sides of condenser, and turbine building retention pit, all with flood alarms  
 
to main control room.
BVPS-2 UFSAR Rev. 0  14a of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
10.4.6  
/None Addressed new condensate cleanup system, a NNS class system, consisting of two subsystems, condensate polishing system and powdered resin dewatering system.
10.4.7.2  
/10.3.5 Changes to condensate and feedwater systems  
 
include:
BVPS-2 UFSAR Rev. 0  15 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
: 1. Reduction of two half-size motor-driven steam generator feedwater pumps total dynamic head rating from 1,900feet to 1,694 feet for same 15,200 gpm flow.  
: 2. Addition of motor-driven start-up feedwater pump to minimize operation of main feedwater pumps at start-up and low loads. Pump can also be paralleled with a main feedwater pump when either one is out of service.  
: 3. Addition of two separation drain pumps to supplement heater drain pumps during peak plant operation.  
: 4. Addition of full flow condensate polishing system downstream of condensate pumps.  
: 5. Feedwater system containment isolation valve changed from a single motor-operated stop check valve outside containment per supply line to a check valve inside containment with an electro hydraulic-operated isolation valve outside containment.
10.4.8 /11.2.5 Steam generator blowdown system changes include:  
: 1. Blowdown liquids formerly processed by evaporator facilities now are normally processed by the condensate polishing system after they have been routed to the condenser.  
 
Processing by evaporator facilities as a backup has been retained.  
: 2. Former discussion on providing common collection facility for blowdown from both BVPS-1 and BVPS-2 is no longer applicable.
Each plant now has an independent processing system for return of blowdown to the condensers.
10.4.9 /10.3.5 Changes to auxiliary feedwater system include:  
: 1. Former two turbine-driven auxiliary feedwater pumps with motor-drive backup replaced with  
 
three pumps, two half-size motor-driven and  
 
one full capacity turbine-driven.
BVPS-2 UFSAR Rev. 0  16 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
: 2. Output rating of former two turbine-driven auxiliary feedwater pumps was 700 gpm each. Output ratings of present three pumps are 375 gpm each for two motor-driven ones and 750  
 
gpm for turbine-driven one.  
: 3. Former continuous recirculation flow to primary plant demineralized water storage tank (PPDWST) now controlled automatically by recirculation control valve on discharge  
 
piping of auxiliary feedwater pumps to maintain minimum flow requirements.  
: 4. Added cross-connection piping between 140,000 gallon PPDWST and 600,000 gallon  
 
demineralized water storage tank (DWST) to  
 
provide another source of backup water supply. 5. Hand-wheel type motor-operated control valves in auxiliary feedwater supply lines replaced  
 
with hand-pump hydraulic type electro-hydraulic-operated control valves for more positive control in event of loss of power.  
: 6. Component cooling water to feedwater pump lube oil coolers, formerly in external piping, now in internal lines that are part  
 
of pump design.  
: 7. Added check valves downstream of control valves in auxiliary feedwater lines outside containment to prevent loss of auxiliary feedwater in event of auxiliary feedwater header rupture. Also added check valve in each auxiliary feedwater line inside containment for containment isolation  
 
purposes.  
: 8. Added cavitating venturi flow elements in common auxiliary feedwater supply lines to limit flow in event of main steam or main feedwater line rupture.  
: 9. Provided redundant safety-related flow transmitters for each auxiliary feedwater line outside containment.
BVPS-2 UFSAR Rev. 0  17 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
: 10. Added separate chemical feed connection on individual auxiliary feedwater supply lines.  
: 11. Chemical addition to PPDWST, formerly  
 
supplied from chemical feed tank, now provided by injection of chemicals into suction piping.  
: 12. Each motor-driven feedwater pump delivers water to separate header while turbine-driven pump can be manually aligned for water delivery to either header.
10.4.10 /10.3.2 Additional equipment served by auxiliary steam and condensate system include:  
: 1. Degasifier steam heaters,  
: 2. Evaporator reboilers,  
: 3. Boric acid batch tank,  
: 4. Carbon dioxide vaporizer, and  
: 5. Cask washdown area.
11.2 /11.2.4 Liquid waste management systems have these  
 
changes:  
: 1. Added piping connection from evaporator bottoms cooler to liquid waste drain tanks.  
: 2. Provided additional discharge points for liquid waste tanks that include steam generator blowdown (SGB) hold tanks, to cleanup filter, and then to cooling tower blowdown.  
: 3. Expanded capability to process liquid waste by use of SGB evaporators and hold tanks as primary means of processing prior to utilizing other facilities of BVPS-1 and BVPS-2.
BVPS-2 UFSAR Rev. 0  18 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
11.3  
/11.2.3 Gaseous waste management systems changes  
 
include:  
: 1. Downgraded gaseous waste disposal (GWD) system from Safety Class 3 to NNS class.  
: 2. Added seven gaseous waste storage tanks.
11.4 /11.2.6 Changes to solid waste management systems  
 
include:  
: 1. Formerly, spent resin was flushed to BVPS-1 (without solidification) directly to shipping casks, dewatered, and sealed. Evaporator bottoms were packaged in casks with cement-vermiculite mixture. Both casks were stored at BVPS-1. Now spent resin sludge and evaporator bottoms are normally packaged in 55-gallon drums preloaded with dry cement,  
 
with drums stored in condensate polishing building of BVPS-2. Option of disposal via BVPS-1 dewatering facility is still retained,  
 
however.  
: 2. Formerly, used cartridge filter elements were mixed with other solid waste in same drum.
Now filter elements are packaged by themselves in drums.
11.5 /11.2.7.2 Additional area, effluent, and process monitors  
 
added to process and effluent radiological  
 
monitoring system to improve system monitoring capabilities.
12.3.2.1  
/11.3.2.1 Changes made to configuration design of supplementary neutron streaming shield to facilitate refueling operations.
12.3.2.5  
/11.3.2.2 Modified fuel transfer tube shield design to prevent direct line streaming of radiation from  
 
spent fuel through seismic gap.
BVPS-2 UFSAR Rev. 0  19 of 19 TABLE 1.3-2 (Cont)
FSAR Section  
/PSAR Reference Significant Changes Since PSAR
 
12.3.4  
/11.3 Expanded radiation monitoring system with  
 
additional area, effluent, and process monitors to improve system monitoring capabilities and to provide post-accident detection.
15.2.3 /None The analysis for the deletion of reactor trip following a turbine trip below 70 percent power is required in order to demonstrate reactor safety should the fast bus transfer to offsite power fail following the generator motoring  
 
delay on turbine trip.  
 
15.6.5  
15.6.5  
/None The loss-of-coolant accident analysis of N-1 loop operation is a prerequisite to plant operation with one loop out of service. The analysis must demonstrate acceptable results for accidents initiated from the steady state N-1 loop mode of operation.
/None The loss-of-coolant accident analysis of N-1 loop operation is a prerequisite to plant operation with one loop out of service. The analysis must demonstrate acceptable results for accidents initiated from the steady state N-1 loop mode of operation.  
Baffle to barrel region configuration changed from downflow to upflow to reduce baffle plate and baffle bolt loading, and to minimize the potential for excessive baffle joint jetting.
 
BVPS-2 UFSAR Rev. 16 1.4-1 1.4  IDENTIFICATION OF AGENT AND CONTRACTORS This section identifies the prime agents and contractors for the design, construction, and operation of the Beaver Valley Power Station - Unit 2 (BVPS-2). This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.
Baffle to barrel region configuration changed from downflow to upflow to reduce baffle plate and baffle bolt loading, and to minimize the  
1.4.1  Applicant The Central Area Power Coordinating Group (CAPCO), which is comprised of Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company, and Duquesne Light Company (DLC), was the Applicant for BVPS-2. The Applicant engaged the contractors identified in Sections 1.4.2 through 1.4.5 to perform engineering, procurements, and construction services for the plant. However, DLC retained overall project responsibility which included engineering; construction; testing; and from the time of initial fuel loading, operation and maintenance of BVPS-2. DLC maintained a technically competent and  safety-oriented staff with the proper qualifications, training, and licenses. Most of the senior personnel in the DLC Engineering and Construction Division and Operations Division were active participants in the design, construction, and operation of the Shippingport Atomic Power Station (SAPS). During the BVPS evaluation, engineering design, construction, testing, and operations phases, the same successful managerial techniques that were developed over the years were employed.
 
In March 1981, DLC established the Nuclear Division to meet the needs of the company's nuclear power goals and objectives. The support functions of the Quality Assurance Department remained with the Nuclear Construction Division.
potential for excessive baffle joint jetting.  
Duquesne Light Company was engaged principally in the production, purchase, transmission, distribution, and sale of electric energy. Duquesne Light Company served an area of approximately 800 square miles in Allegheny and Beaver Counties. This area, which includes the city of Pittsburgh, is located in southwestern Pennsylvania and has a population of approximately 1,500,000. A summary of previous experience in the field of power generation shows that DLC was technically qualified to engage in the proposed activities. Duquesne Light Company had been involved in various nuclear projects for over 30 years. They include the following: 1. A study of the feasibility and economics of constructing a nuclear reactor for the use of atomic energy and its possible implementation in the commercial power industry - 1952. 2. Establishment of the Atomic Power Development Department - 1953.
 
BVPS-2 UFSAR Rev. 0 1.4-2 3. An agreement with the U.S. Atomic Energy Commission (USAEC) to operate and maintain SAPS and to conduct an extensive testing program prescribed by the USAEC - 1954. 4. Participation in nuclear research and development programs such as the Westinghouse Electric Corporation Liquid Metal Fast Breeder Reactor project, reactor vessel inspection study, and the plutonium recycle fuel fabrication. 5. The design, construction, and operation of Beaver Valley Power Station - Unit 1 (BVPS-1) - 1976. 1.4.2  Architect Engineer Stone & Webster Engineering Corporation (SWEC) provided engineering design and construction management services for BVPS-2. The Corporation maintained offices in Boston, Massachusetts, Cherry Hill, New Jersey, Denver, Colorado, New York, New York, and Houston, Texas, with a total manpower resource pool of over 12,000 employees. Approximately 700 engineers, designers, construction specialists, and clerical and administrative personnel were assigned to the BVPS-2 project during its peak level of activity. In addition to its project-dedicated staff, SWEC utilized specialists in various engineering disciplines to ensure that BVPS-2 was designed in accordance with industry codes and standards and met the requirements of the applicable federal, state, and local regulations for commercial nuclear power plants.
BVPS-2 UFSAR Rev. 16 1.4-1 1.4  IDENTIFICATION OF AGENT AND CONTRACTORS This section identifies the prime agents and contractors for the design, construction, and operation of the Beaver Valley Power Station - Unit 2 (BVPS-2). This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.  
SWEC has been associated with the installation of over 77,000 MW of hydroelectric, nuclear, and fossil-fired electric generating facilities for the electric utility industry. The Corporation's experience in the field of nuclear energy dates from 1942 when it participated in initiating the first self-sustaining nuclear chain reaction at the University of Chicago. Since 1954, SWEC has designed and/or constructed the following nuclear power stations which are either presently operating or have operated successfully:  
 
: 1. Shippingport Atomic Power Plant of Duquesne Light Company and ERDA 2. Army Package Power Reactor (APPR, also known as Al)
1.4.1  Applicant  
 
The Central Area Power Coordinating Group (CAPCO), which is comprised of Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company, and Duquesne Light Company (DLC), was the Applicant for BVPS-2. The Applicant engaged the contractors identified in Sections 1.4.2 through 1.4.5 to perform engineering, procurements, and construction services for the plant. However, DLC retained overall project responsibility which included engineering;  
 
construction; testing; and from the time of initial fuel loading, operation and maintenance of BVPS-2. DLC maintained a technically competent and  safety-oriented staff with the proper  
 
qualifications, training, and licenses.
Most of the senior personnel in the DLC Engineering and  
 
Construction Division and Operations Division were active participants in the design, construction, and operation of the Shippingport Atomic Power Station (SAPS). During the BVPS  
 
evaluation, engineering design, construction, testing, and operations phases, the same successful managerial techniques that were developed over the years were employed.  
 
In March 1981, DLC established the Nuclear Division to meet the needs of the company's nuclear power goals and objectives. The support functions of the Quality Assurance Department remained with the Nuclear Construction Division.  
 
Duquesne Light Company was engaged principally in the production, purchase, transmission, distribution, and sale of electric energy. Duquesne Light Company served an area of approximately 800 square miles in Allegheny and Beaver Counties.
This area, which includes the city of Pittsburgh, is located in southwestern Pennsylvania and has a population of approximately  
 
1,500,000.
A summary of previous experience in the field of power generation shows that DLC was technically qualified to engage in the proposed activities. Duquesne Light Company had been involved in various nuclear projects for over 30 years. They  
 
include the following:  
: 1. A study of the feasibility and economics of constructing a nuclear reactor for the use of atomic  
 
energy and its possible implementation in the commercial power industry - 1952.  
: 2. Establishment of the Atomic Power Development Department - 1953.  
 
BVPS-2 UFSAR Rev. 0 1.4-2 3. An agreement with the U.S. Atomic Energy Commission (USAEC) to operate and maintain SAPS and to conduct an extensive testing program prescribed by the USAEC -
1954. 4. Participation in nuclear research and development programs such as the Westinghouse Electric Corporation Liquid Metal Fast Breeder Reactor project, reactor vessel inspection study, and the plutonium recycle fuel fabrication.  
: 5. The design, construction, and operation of Beaver Valley Power Station - Unit 1 (BVPS-1) - 1976.
1.4.2  Architect Engineer  
 
Stone & Webster Engineering Corporation (SWEC) provided engineering design and construction management services for BVPS-2. The Corporation maintained offices in Boston, Massachusetts, Cherry Hill, New Jersey, Denver, Colorado, New York, New York, and Houston, Texas, with a total manpower resource pool of over 12,000 employees. Approximately 700 engineers, designers, construction specialists, and clerical and administrative personnel were assigned to the BVPS-2 project during its peak level of activity. In addition to its project-dedicated staff, SWEC utilized specialists in various engineering disciplines to ensure that BVPS-2 was designed in accordance with industry codes and standards and met the requirements of the applicable federal, state, and local regulations for commercial nuclear power plants.  
 
SWEC has been associated with the installation of over 77,000 MW of hydroelectric, nuclear, and fossil-fired electric generating facilities for the electric utility industry. The Corporation's  
 
experience in the field of nuclear energy dates from 1942 when it participated in initiating the first self-sustaining nuclear chain reaction at the University of Chicago. Since 1954, SWEC has designed and/or constructed the following nuclear power stations which are either presently operating or have operated successfully:  
: 1. Shippingport Atomic Power Plant of Duquesne Light Company and ERDA  
: 2. Army Package Power Reactor (APPR, also known as Al)  
: 3. Yankee Nuclear Power Station of Yankee Atomic Power Company   
: 3. Yankee Nuclear Power Station of Yankee Atomic Power Company   
: 4. Carolinas-Virginia Tube Reactor of the Carolinas-Virginia Nuclear Power Associates, Inc.
: 4. Carolinas-Virginia Tube Reactor of the Carolinas-Virginia Nuclear Power Associates, Inc.  
: 5. Haddam Neck Plant of Connecticut Yankee Atomic Power Company   
: 5. Haddam Neck Plant of Connecticut Yankee Atomic Power Company   
: 6. Nine Mile Point Nuclear Station Unit 1 of Niagara Mohawk Power Corporation BVPS-2 UFSAR Rev. 0 1.4-3 7. Maine Yankee Atomic Power Station of Maine Yankee Atomic Power Company 8. Surry  Power  Station Units 1 and 2 of Virginia Electric and Power Company
: 6. Nine Mile Point Nuclear Station Unit 1 of Niagara Mohawk Power Corporation BVPS-2 UFSAR Rev. 0 1.4-3 7. Maine Yankee Atomic Power Station of Maine Yankee Atomic Power Company  
: 9. James A. Fitzpatrick Nuclear Power Plant - Unit 1 of the Power Authority of the State of New York
: 8. Surry  Power  Station Units 1 and 2 of Virginia Electric and Power Company  
: 10. North Anna Power Station - Units 1 and 2 of Virginia Electric and Power Company
: 9. James A. Fitzpatrick Nuclear Power Plant - Unit 1 of the Power Authority of the State of New York  
: 11. Beaver Valley Power Station - Unit 1 of Duquesne Light Company  In addition, SWEC had under design and construction at that time the following nuclear power stations: 1. North Anna Power Station - Unit 3 of Virginia Electric and Power Company 2. Millstone Nuclear Power Station - Unit 3 of Northeast Utilities Service Company
: 10. North Anna Power Station - Units 1 and 2 of Virginia Electric and Power Company  
: 3. Shoreham Nuclear Power Station - Unit 1 of Long Island Lighting Company
: 11. Beaver Valley Power Station - Unit 1 of Duquesne Light Company  In addition, SWEC had under design and construction at that time  
: 4. Nine Mile Point - Unit 2 of Niagara Mohawk Power Corporation
 
: 5. River Bend Power Station - Units 1 and 2 of Gulf States Utilities. Also, SWEC provided construction management services for the Demonstration Liquid Metal Fast Breeder Reactor Plant (Clinch River Project) and the Department of Energy's Gas Centrifuge Uranium Enrichment Plant.
the following nuclear power stations:  
1.4.3  Nuclear Steam Supply System Manufacturer Westinghouse Electric Corporation (Westinghouse) was responsible for supplying the NSSS and fuel for BVPS-2.
: 1. North Anna Power Station - Unit 3 of Virginia Electric and Power Company  
: 2. Millstone Nuclear Power Station - Unit 3 of Northeast Utilities Service Company  
: 3. Shoreham Nuclear Power Station - Unit 1 of Long Island Lighting Company  
: 4. Nine Mile Point - Unit 2 of Niagara Mohawk Power Corporation  
: 5. River Bend Power Station - Units 1 and 2 of Gulf States Utilities.
Also, SWEC provided construction management services for the Demonstration Liquid Metal Fast Breeder Reactor Plant (Clinch River Project) and the Department of Energy's Gas Centrifuge Uranium Enrichment Plant.  
 
1.4.3  Nuclear Steam Supply System Manufacturer  
 
Westinghouse Electric Corporation (Westinghouse) was responsible for supplying the NSSS and fuel for BVPS-2.  
 
Westinghouse has designed, developed, and manufactured nuclear power facilities since the 1950s, beginning with the world's first large central station nuclear power plant (Shippingport),
Westinghouse has designed, developed, and manufactured nuclear power facilities since the 1950s, beginning with the world's first large central station nuclear power plant (Shippingport),
which has produced power since 1957. Completed or contracted commercial nuclear capacity totals were in excess of 97,000 MW. Westinghouse pioneered new nuclear design concepts, such as chemical shim control of reactivity and the rod cluster control concept, throughout the last two decades. Westinghouse manufacturing facilities include the largest commercial nuclear fuel fabrication facility in the world, and the world's most modern heat transfer equipment production facility, as well as other facilities producing nuclear steam supply system (NSSS)  
which has produced power since 1957. Completed or contracted commercial nuclear capacity totals were in excess of 97,000 MW. Westinghouse pioneered new nuclear design concepts, such as chemical shim control of reactivity and the rod cluster control concept, throughout the last two decades. Westinghouse manufacturing facilities include the largest commercial nuclear fuel fabrication facility in the world, and the world's most modern heat transfer equipment production facility, as well as other facilities producing nuclear steam supply system (NSSS)  


BVPS-2 UFSAR Rev. 14 1.4-4 components. Table 1.4-1 lists all Westinghouse pressurized water reactor (PWR) plants to date, including those plants under construction or on order, at the time of BVPS-2 license application.
BVPS-2 UFSAR Rev. 14 1.4-4 components. Table 1.4-1 lists all Westinghouse pressurized water reactor (PWR) plants to date, including those plants under construction or on order, at the time of BVPS-2 license application.  
The U.S. Nuclear Regulatory Commission (USNRC) and the Electric Power Research Institute have contracted with Westinghouse for research into NSSS related activities. Westinghouse experience was also utilized by the USNRC and Metropolitan Edison immediately following the Three Mile Island Unit 2 accident. At the time of license application, the corporation continued to participate with the Westinghouse Owner's Group of utilities in addressing the USNRC'S action plan for corrective actions.
 
1.4.3.1  Plants in Operation Westinghouse PWR plants in operation were as follows: 1. Shippingport Shippingport was the world's first large central station nuclear power plant. The reactor plant was designed by the Bettis Atomic Power Laboratory, which is operated by Westinghouse under a USNRC contract. Shippingport's PWR has produced power for DLC since December 1957. 2. Yankee-Rowe Singled out by the USNRC as a "Nuclear Success Story" Yankee-Rowe went on-line in November 1960. Owned and operated by the Yankee Atomic Electric Company, Yankee-Rowe has progressed from an initial rating of 120 MWe to its present 175 MWe rating. Westinghouse supplied the NSSS and the turbine generator. 3. Trino Vercellese (Enrico Fermi) The Trino Vercellese nuclear plant was one of the first Westinghouse designed plants to incorporate chemical shim control of reactivity. Chemical shim has since become a standard feature of Westinghouse PWR control. Trino Vercellese achieved initial criticality in June 1964 and began power operation in October 1964. The plant is rated at 260 MWe. 4. Chooz (Ardennes) The Chooz plant is unique in that the Westinghouse PWR and its auxiliaries are housed in man-made caverns. Ardennes, a joint Franco-Belgian undertaking, owned and operated by the Societe d'Energie Nucleaire Franco-Belge des Ardennes (SENA), is located in France near the French-Belgian border. Chooz achieved initial criticality in October 1966 and began power operation in 1967.
The U.S. Nuclear Regulatory Commission (USNRC) and the Electric Power Research Institute have contracted with Westinghouse for research into NSSS related activities. Westinghouse experience was also utilized by the USNRC and Metropolitan Edison immediately following the Three Mile Island Unit 2 accident. At the time of license application, the corporation continued to participate with the Westinghouse Owner's Group of utilities in  
BVPS-2 UFSAR Rev. 0 1.4-5 5. San Onofre Unit 1 San Onofre Unit 1 employs the Westinghouse developed rod cluster control concept which has since become a standard feature on the Westinghouse PWR. Owned by the Southern California Edison Company and the San Diego Gas and Electric Company, the 430 MWe plant is located near San Clemente, California. Westinghouse supplied the NSSS and the turbine generator. Initial criticality was achieved in June 1967, and power operation began in January 1968. 6. Haddam Neck (Connecticut Yankee) Owned and operated by the Connecticut Yankee Atomic Power Company, this plant went critical in July 1967 and attained full power operation in December 1967. Like San Onofre Unit 1, the plant employs rod cluster control in conjunction with chemical shim control.
 
Westinghouse supplied the NSSS and the turbine generator. The plant has been uprated to 575 MWe. 7. Jose Cabrera - Zorita The Jose Cabrera Station is located near Zorita, Spain. The 153 MWe plant employs rod cluster control, chemical shim control and a Zircaloy-clad core. Construction began in mid-1965 and power operation began in 1968. Jose Cabrera is owned and operated by the Union Electrica, S. A., a Spanish utility. 8. Beznau Unit 1 and Unit 2 Beznau Unit 1, Switzerland's first commercial nuclear power plant, achieved initial criticality in June 1969 and supplied power to the system in July 1969. The 350 MWe plant was designed and constructed by the Westinghouse-Brown Boveri Consortium for the owner/operator utility, Nordostschweizerische Kraftwerke AG. The plant started producing power less than 4 years after award of the plant contract. Beznau Unit 2 achieved criticality in October 1971 and began commercial operation in early 1972.  
addressing the USNRC'S action plan for corrective actions.  
: 9. Robert Emmett Ginna The Robert Emmett Ginna Plant, owned and operated by Rochester Gas and Electric Corporation, is located in New York on the south shore of Lake Ontario.
 
1.4.3.1  Plants in Operation  
 
Westinghouse PWR plants in operation were as follows:  
: 1. Shippingport Shippingport was the world's first large central station nuclear power plant. The reactor plant was designed by the Bettis Atomic Power Laboratory, which is operated by Westinghouse under a USNRC contract. Shippingport's PWR has produced power for DLC since  
 
December 1957.  
: 2. Yankee-Rowe Singled out by the USNRC as a "Nuclear Success Story" Yankee-Rowe went on-line in November 1960. Owned and operated by the Yankee Atomic Electric Company, Yankee-Rowe has progressed from an initial rating of 120 MWe to its present 175 MWe rating. Westinghouse  
 
supplied the NSSS and the turbine generator.  
: 3. Trino Vercellese (Enrico Fermi)
The Trino Vercellese nuclear plant was one of the  
 
first Westinghouse designed plants to incorporate chemical shim control of reactivity. Chemical shim has since become a standard feature of Westinghouse PWR control. Trino Vercellese achieved initial criticality in June 1964 and began power operation in October 1964. The plant is rated at 260 MWe.  
: 4. Chooz (Ardennes)
The Chooz plant is unique in that the Westinghouse PWR and its auxiliaries are housed in man-made caverns.
Ardennes, a joint Franco-Belgian undertaking, owned and operated by the Societe d'Energie Nucleaire Franco-Belge des Ardennes (SENA), is located in France near the French-Belgian border. Chooz achieved initial criticality in October 1966 and began power  
 
operation in 1967.  
 
BVPS-2 UFSAR Rev. 0 1.4-5 5. San Onofre Unit 1 San Onofre Unit 1 employs the Westinghouse developed  
 
rod cluster control concept which has since become a standard feature on the Westinghouse PWR. Owned by the Southern California Edison Company and the San Diego Gas and Electric Company, the 430 MWe plant is located near San Clemente, California. Westinghouse supplied the NSSS and the turbine generator. Initial criticality was achieved in June 1967, and power  
 
operation began in January 1968.  
: 6. Haddam Neck (Connecticut Yankee)
Owned and operated by the Connecticut Yankee Atomic Power Company, this plant went critical in July 1967 and attained full power operation in December 1967. Like San Onofre Unit 1, the plant employs rod cluster control in conjunction with chemical shim control.
Westinghouse supplied the NSSS and the turbine generator. The plant has been uprated to 575 MWe.  
: 7. Jose Cabrera - Zorita  
 
The Jose Cabrera Station is located near Zorita, Spain. The 153 MWe plant employs rod cluster control, chemical shim control and a Zircaloy-clad core. Construction began in mid-1965 and power operation  
 
began in 1968. Jose Cabrera is owned and operated by the Union Electrica, S. A., a Spanish utility.  
: 8. Beznau Unit 1 and Unit 2 Beznau Unit 1, Switzerland's first commercial nuclear power plant, achieved initial criticality in June 1969 and supplied power to the system in July 1969. The 350 MWe plant was designed and constructed by the  
 
Westinghouse-Brown Boveri Consortium for the owner/operator utility, Nordostschweizerische Kraftwerke AG. The plant started producing power less than 4 years after award of the plant contract. Beznau Unit 2 achieved criticality in October 1971 and began commercial operation in early 1972.  
: 9. Robert Emmett Ginna  
 
The Robert Emmett Ginna Plant, owned and operated by Rochester Gas and Electric Corporation, is located in New York on the south shore of Lake Ontario.
 
Westinghouse supplied the 490 MWe plant on a turnkey basis. Construction began in April 1966 with initial criticality being achieved in November 1969 (just 42 months after start of construction). Power was supplied to the system in December 1969.
Westinghouse supplied the 490 MWe plant on a turnkey basis. Construction began in April 1966 with initial criticality being achieved in November 1969 (just 42 months after start of construction). Power was supplied to the system in December 1969.
BVPS-2 UFSAR Rev. 0 1.4-6 10. Mihama Unit 1 and Takahama Unit 1 These plants are owned by the Kansai Electric Power Company, Inc. Mihama Unit 1 is a two-loop, 320 MWe unit and marks the beginning of a line of Westinghouse PWRS supplying the generation needs of the Far East. Westinghouse International Company was the prime contractor for the Mihama project, supplying the NSSS engineering, nuclear fuel, and some major system components. Mihama Unit 1 required only 44 months from the start of site construction to first power production in August 1970. Takahama Unit 1 is a three-loop, 780 MWe unit. Initial criticality was achieved in March 1974. 11. H. B. Robinson Unit 2 This plant is a three-loop, 707 MWe unit which was built on a turnkey basis for the Carolina Power and Light Company. The plant is located at a site near Hartsville, South Carolina, on a man-made cooling lake. The construction permit was granted in April 1967. The plant achieved criticality in August 1970 and first power to system in October 1970. 12. Point Beach Unit 1 and Unit 2 The Point Beach Project consists of two 497 MWe units, which were built on a turnkey basis for the Wisconsin Michigan Power Company and the Wisconsin Electric Power Company. The plants are located near Two Creeks, Wisconsin, 90 miles north of Milwaukee on Lake Michigan. This was the first two-unit station to utilize many common facilities and shared auxiliary systems. The construction permit for Point Beach Unit 1 was granted in July 1967 with initial criticality and first power to the system in November 1970. Point Beach Unit 2 went critical in May 1972 and was available for commercial operation in October 1972. 13. Surry Unit 1 and Unit 2 The Surry Power Station, two three-loop 822 MWe units, is owned by the Virginia Electric and Power Company. The James River Station is about 30 miles from Norfolk, Virginia. First criticality on Surry Unit 1 was achieved in July 1972. Commercial operation began in September 1972. Initial criticality on Surry Unit 2 was achieved in March 1973.  
BVPS-2 UFSAR Rev. 0 1.4-6 10. Mihama Unit 1 and Takahama Unit 1 These plants are owned by the Kansai Electric Power  
: 14. Turkey Point Unit 3 and Unit 4 Florida Power and Light Company is the owner of a four-unit station on Biscayne Bay, Florida. Turkey Point Units 3 and 4 of the station are three-loop, 745 MWe BVPS-2 UFSAR Rev. 0 1.4-7 plants. Commercial status for Turkey Point Unit 3 was achieved in December 1972. Initial criticality for Turkey Point Unit 4 was achieved in June 1973. 15. Indian Point Unit 2 and Unit 3 Consolidated Edison Company of New York operates three nuclear units located in Buchanan, New York; two (Units 1 and 2) are owned by the Company and one (Unit 3) is owned by the Power Authority of the State of New York. Units 2 and 3 are Westinghouse PWRS rated at 873 MWe and 965 MWe, respectively. Indian Point Unit 2 achieved initial criticality in May 1973 and Indian Point Unit 3 achieved initial criticality in April 1976. 16. Prairie Island Unit 1 Northern States Power Company, is the owner of these two-loop, 530 MWe units located in Welch, Minnesota. Initial criticality was achieved in December 1973 for Prairie Island Unit 1, and in December 1974 for Prairie Island Unit 2. 17. Zion Unit 1 and Unit 2 Commonwealth Edison Company is the owner of these two four-loop, 1,050 MWe units. The units are located on Lake Michigan near Zion, Illinois. Initial criticality was  achieved in  June 1973 for Zion Unit 1 and in December 1973 for Zion Unit 2.  
 
: 18. Kewaunee Wisconsin Public Service Corporation, Wisconsin Power and Light Company, and Madison Gas and Electric Company are the owners of this two-loop, 541 MWe plant located in Kewaunee, Wisconsin. Initial criticality was achieved in March 1974. 19. Ringhals Unit 2 Statens Vattenfallsverk (SSPB) is the owner of this three-loop, 822 MWe unit located in Sweden. Initial criticality was achieved in June 1974. 20. Donald C. Cook Unit 1 and Unit 2 Indiana and Michigan Electric Company is the owner of these four-loop 1,090 MWe plants located in Bridgman, Michigan. These plants are the first to use the Westinghouse Ice Condenser Containment design.
Company, Inc. Mihama Unit 1 is a two-loop, 320 MWe unit and marks the beginning of a line of Westinghouse PWRS supplying the generation needs of the Far East.
Westinghouse International Company was the prime contractor for the Mihama project, supplying the NSSS engineering, nuclear fuel, and some major system components. Mihama Unit 1 required only 44 months from the start of site construction to first power production in August 1970. Takahama Unit 1 is a three-loop, 780 MWe unit. Initial criticality was  
 
achieved in March 1974.  
: 11. H. B. Robinson Unit 2 This plant is a three-loop, 707 MWe unit which was built on a turnkey basis for the Carolina Power and Light Company. The plant is located at a site near Hartsville, South Carolina, on a man-made cooling lake. The construction permit was granted in April  
 
1967. The plant achieved criticality in August 1970 and first power to system in October 1970.  
: 12. Point Beach Unit 1 and Unit 2 The Point Beach Project consists of two 497 MWe units, which were built on a turnkey basis for the Wisconsin Michigan Power Company and the Wisconsin Electric Power Company. The plants are located near Two Creeks, Wisconsin, 90 miles north of Milwaukee on Lake Michigan. This was the first two-unit station to utilize many common facilities and shared auxiliary systems. The construction permit for Point Beach Unit 1 was granted in July 1967 with initial criticality and first power to the system in November 1970. Point Beach Unit 2 went critical in May 1972 and was available for commercial operation in October 1972.  
: 13. Surry Unit 1 and Unit 2 The Surry Power Station, two three-loop 822 MWe units, is owned by the Virginia Electric and Power Company. The James River Station is about 30 miles from Norfolk, Virginia. First criticality on Surry Unit 1 was achieved in July 1972. Commercial operation began in September 1972. Initial criticality on Surry Unit 2 was achieved in March 1973.  
: 14. Turkey Point Unit 3 and Unit 4  
 
Florida Power and Light Company is the owner of a four-unit station on Biscayne Bay, Florida. Turkey Point Units 3 and 4 of the station are three-loop, 745  
 
MWe BVPS-2 UFSAR Rev. 0 1.4-7 plants. Commercial status for Turkey Point Unit 3 was achieved in December 1972. Initial criticality for Turkey Point Unit 4 was achieved in June 1973.  
: 15. Indian Point Unit 2 and Unit 3 Consolidated Edison Company of New York operates three nuclear units located in Buchanan, New York; two (Units 1 and 2) are owned by the Company and one (Unit 3) is owned by the Power Authority of the State of New  
 
York. Units 2 and 3 are Westinghouse PWRS rated at 873 MWe and 965 MWe, respectively. Indian Point Unit 2 achieved initial criticality in May 1973 and Indian Point Unit 3 achieved initial criticality in April 1976. 16. Prairie Island Unit 1 Northern States Power Company, is the owner of these two-loop, 530 MWe units located in Welch, Minnesota. Initial criticality was achieved in December 1973 for Prairie Island Unit 1, and in December 1974 for  
 
Prairie Island Unit 2.  
: 17. Zion Unit 1 and Unit 2 Commonwealth Edison Company is the owner of these two four-loop, 1,050 MWe units. The units are located on Lake Michigan near Zion, Illinois. Initial criticality was  achieved in  June 1973 for Zion Unit 1 and in December 1973 for Zion Unit 2.  
: 18. Kewaunee  
 
Wisconsin Public Service Corporation, Wisconsin Power and Light Company, and Madison Gas and Electric Company are the owners of this two-loop, 541 MWe plant located in Kewaunee, Wisconsin. Initial criticality was achieved in March 1974.  
: 19. Ringhals Unit 2 Statens Vattenfallsverk (SSPB) is the owner of this three-loop, 822 MWe unit located in Sweden. Initial criticality was achieved in June 1974.  
: 20. Donald C. Cook Unit 1 and Unit 2 Indiana and Michigan Electric Company is the owner of these four-loop 1,090 MWe plants located in Bridgman, Michigan. These plants are the first to use the Westinghouse Ice Condenser Containment design.
 
Initial criticality was achieved in January 1975 for Unit 1 and March 1978 for Unit 2.
Initial criticality was achieved in January 1975 for Unit 1 and March 1978 for Unit 2.
BVPS-2 UFSAR Rev. 0 1.4-8 21. Trojan This four-loop, 1,130 MWe plant is jointly owned by Portland General Electric Company, Eugene Water and Electric Board, and Pacific Power and Light Company. In addition to being the first commercial nuclear plant to operate in the Pacific Northwest (located on the Oregon shore of the Columbia River near Rainier, Oregon), Trojan is the first 17 x 17 fuel-rod-per-assembly plant to achieve criticality. Initial criticality was achieved in December 1975. 22. Beaver Valley Unit 1 This three-loop, 852 MWe plant is jointly owned by Duquesne Light Company, Ohio Edison Company, and Pennsylvania Power Company, Beaver Valley Unit 1 is located on the Ohio River, 22 miles northwest of Pittsburgh, Pemsylvania. Commercial operation began in early 1976. 23. Salem Unit 1 and Unit 2 Salem Units 1 and 2, owned jointly by the Public Service Electric and Gas Company, Philadelphia Electric Company, Atlantic Electric Company, and Delmarva Power and Light Company, are located on Artificial Island, a man-made peninsula in Salem County, New Jersey. The 1,090 MWe, four-loop plant achieved initial criticality for Unit 1 in late 1976 and Unit 2 achieved criticality in August 1980.  
BVPS-2 UFSAR Rev. 0 1.4-8 21. Trojan This four-loop, 1,130 MWe plant is jointly owned by  
: 24. North Anna Unit 1 and Unit 2 Virginia Electric and Power Company owns the two approximately 907 MWe (net) plants located 40 miles north of Richmond, Virginia, on Lake Anna. Unit 1 achieved criticality in June 1980. 25. Joseph M. Farley Unit 1 and Unit 2 The two 899 MWe (net) Alabama Power Company units are located at Dothan, Alabama which is approximately 180 miles south-southwest of Atlanta, Georgia. Unit 1 achieved criticality in August 1977 and Unit 2 achieved criticality in February 1981.  
 
: 26. Sequoyah Unit 1 and Unit 2 The two 1,148 MWe (net) units are located on the Tennessee River near Chattanooga, Tennessee. These units are owned by Tennessee Valley Authority.
Portland General Electric Company, Eugene Water and Electric Board, and Pacific Power and Light Company. In addition to being the first commercial nuclear plant to operate in the Pacific Northwest (located on  
Sequoyah Unit 1 received a full power license in September 1980.
 
BVPS-2 UFSAR Rev. 0 1.4-9 1.4.3.2  Westinghouse Facilities Westinghouse, in its effort to plan for the future, developed a broad range of facilities to satisfy the needs of the nuclear industry. The following paragraphs briefly describe these facilities: 1. Columbia Plant, Nuclear Fuel Division The Columbia Plant was capable of performing all operations necessary to manufacture finished nuclear fuel assemblies. These operations include conversion of uranium hexafluoride to uranium dioxide powder, fabrication of fuel assembly grids, complete pellet loading, and final fabrication of assemblies. The plant, located at Columbia, South Carolina, began full production in early 1970. The Columbia Plant was the largest commercial nuclear fuel fabrication facility in the world.  
the Oregon shore of the Columbia River near Rainier, Oregon), Trojan is the first 17 x 17 fuel-rod-per-assembly plant to achieve criticality. Initial  
: 2. Tampa Division The Tampa Division Plant was the world's most modern heat transfer equipment production facility. The plant has 236,000 square feet of working space with two manufacturing aisles for the production of steam generators and pressurizers. Transportation facilities include four railroad spurs and a complete barge slip and dock facility for water shipment to all parts of the world. The Tampa Division Plant made its first steam generator and pressurizer shipment in September 1969.  
 
: 3. Pensacola Division The Pensacola Division Plant, located on Escambia Bay on the northwest coast of Florida, was a new 140,000 square foot manufacturing plant for producing precision reactor vessel internals. Contributing to the precision manufacturing capability was an environmental control system which minimized year round temperature changes throughout the shop area. Transportation facilities of the plant include a railroad spur for loading and unloading inside the shop, and access to barge loading facilities on Escambia Bay. Pensacola shipped its first package of reactor internals in July 1970. 4. Cheswick Plant, Electro-Mechanical Division The Electro-Mechanical Division was established in Cheswick, Pennsylvania in 1953 to manufacture canned motor primary coolant pumps for nuclear reactors. The product line expanded to include shaft seal pumps (reactor coolant pumps), valves from 4 inches to 31 inches, and control rod drive mechanisms, essential components of the Westinghouse PWR. The facility  
criticality was achieved in December 1975.  
: 22. Beaver Valley Unit 1 This three-loop, 852 MWe plant is jointly owned by  
 
Duquesne Light Company, Ohio Edison Company, and Pennsylvania Power Company, Beaver Valley Unit 1 is located on the Ohio River, 22 miles northwest of Pittsburgh, Pemsylvania. Commercial operation began  
 
in early 1976.  
: 23. Salem Unit 1 and Unit 2 Salem Units 1 and 2, owned jointly by the Public  
 
Service Electric and Gas Company, Philadelphia  
 
Electric Company, Atlantic Electric Company, and Delmarva Power and Light Company, are located on Artificial Island, a man-made peninsula in Salem County, New Jersey. The 1,090 MWe, four-loop plant achieved initial criticality for Unit 1 in late 1976 and Unit 2 achieved criticality in August 1980.  
: 24. North Anna Unit 1 and Unit 2  
 
Virginia Electric and Power Company owns the two approximately 907 MWe (net) plants located 40 miles north of Richmond, Virginia, on Lake Anna. Unit 1  
 
achieved criticality in June 1980.  
: 25. Joseph M. Farley Unit 1 and Unit 2 The two 899 MWe (net) Alabama Power Company units are located at Dothan, Alabama which is approximately 180 miles south-southwest of Atlanta, Georgia. Unit 1 achieved criticality in August 1977 and Unit 2 achieved criticality in February 1981.  
: 26. Sequoyah Unit 1 and Unit 2  
 
The two 1,148 MWe (net) units are located on the Tennessee River near Chattanooga, Tennessee. These units are owned by Tennessee Valley Authority.
 
Sequoyah Unit 1 received a full power license in September 1980.  
 
BVPS-2 UFSAR Rev. 0 1.4-9 1.4.3.2  Westinghouse Facilities Westinghouse, in its effort to plan for the future, developed a broad range of facilities to satisfy the needs of the nuclear industry. The following paragraphs briefly describe these facilities:  
: 1. Columbia Plant, Nuclear Fuel Division The Columbia Plant was capable of performing all operations necessary to manufacture finished nuclear fuel assemblies. These operations include conversion of uranium hexafluoride to uranium dioxide powder,  
 
fabrication of fuel assembly grids, complete pellet loading, and final fabrication of assemblies. The plant, located at Columbia, South Carolina, began full production in early 1970. The Columbia Plant was the largest commercial nuclear fuel fabrication facility in the world.  
: 2. Tampa Division  
 
The Tampa Division Plant was the world's most modern heat transfer equipment production facility. The plant has 236,000 square feet of working space with two  
 
manufacturing aisles for the production of steam generators and pressurizers. Transportation facilities include four railroad spurs and a complete barge slip  
 
and dock facility for water shipment to all parts of the world. The Tampa Division Plant made its first steam generator and pressurizer shipment in September 1969.  
: 3. Pensacola Division  
 
The Pensacola Division Plant, located on Escambia Bay on the northwest coast of Florida, was a new 140,000 square foot manufacturing plant for producing precision reactor  
 
vessel internals. Contributing to the precision manufacturing capability was an environmental control system which minimized year round temperature changes throughout the shop area. Transportation facilities of the plant include a railroad spur for loading and unloading inside the shop, and access to barge loading  
 
facilities on Escambia Bay. Pensacola shipped its first package of reactor internals in July 1970.  
: 4. Cheswick Plant, Electro-Mechanical Division The Electro-Mechanical Division was established in Cheswick, Pennsylvania in 1953 to manufacture canned motor primary coolant pumps for nuclear reactors. The product line expanded to include shaft seal pumps (reactor coolant pumps), valves from 4 inches to 31 inches, and control rod drive mechanisms, essential components of the Westinghouse PWR. The facility  
 
BVPS-2 UFSAR Rev. 0 1.4-10 occupied 250,000 square feet and contained the most modern facilities available for the production and testing of nuclear plant components.
: 5. Specialty Metals Division The Specialty Metals Division located in Blairsville, Pennsylvania, was completed in late 1967. Several essential PWR component processes were accomplished at Blairsville, including the precision manufacture of inconel tubing for steam generators, and the complete processing of Zircaloy seamless tubing for nuclear fuel cladding. At Blairsville, complete quality
 
control facilities were utilized for the evaluation and analysis of all specialty metal products used in Westinghouse nuclear systems.
: 6. Westinghouse Nuclear Center
 
The headquarters of Westinghouse Nuclear Energy Systems was located just east of Pittsburgh in Monroeville, Pennsylvania. Operating primarily as a
 
headquarters and engineering facility, the complex housed many of the divisions which encompassed Westinghouse's nuclear activities associated with the
 
electric utility industry.
: 7. Zion Nuclear Training Center The Westinghouse Electric Corporation and the
 
Commonwealth Edison Company of Chicago built and operated a nuclear training center at Zion, Illinois.
The 28,000 square foot training center contained classrooms, a training reactor, training material
 
center, video recording facilities, and multi-plant nuclear power plant simulators. Westinghouse staffed and operated the center, supplied all the equipment required, and was responsible for the development and presentation of all training programs. Commonwealth Edison provided the building, access to the Zion
 
nuclear units for conducting in-plant observation training, and advised and assisted Westinghouse in developing training programs.
 
BVPS-2 UFSAR Rev. 0 1.4-11 1.4.4  Power Conversion System Supplier Westinghouse was awarded the contracts to design, fabricate, deliver, and erect the turbine generator for BVPS-2.
Westinghouse achieved an excellent operating record in the nuclear turbine generator industry by incorporating product improvements based on operating experience as well as
 
knowledge gained from research and development programs and the capabilities of modern manufacturing facilities. This nuclear operating performance record made Westinghouse one of
 
the leaders in total power produced as well as in reliability and availability.
 
Continuing Westinghouse commitment to this kind of product evaluation produced modern and reliable nuclear turbine-generator units around the world. The Westinghouse nuclear
 
turbine-generator operating record was as follows:
: a. The first Westinghouse nuclear turbine generator was placed in commercial operation in
 
1957. b. Forty-five Westinghouse nuclear turbine generators were in service, totaling over
 
36,000 MW.
: c. An additional forty-five Westinghouse nuclear turbine generators were on order, in storage, or being erected.
1.4.5  Consultants
 
Duquesne Light Company directly or through the architect engineer, SWEC, engaged the service of various consultants to perform work relating to the design, construction, operation, and maintenance of BVPS-2. These consultants included, but were not limited to, the following companies:
: 1. Hansen, Holley, and Biggs


BVPS-2 UFSAR Rev. 0 1.4-10 occupied 250,000 square feet and contained the most modern facilities available for the production and testing of nuclear plant components. 5. Specialty Metals Division  The Specialty Metals Division located in Blairsville, Pennsylvania, was completed in late 1967. Several essential PWR component processes were accomplished at Blairsville, including the precision manufacture of inconel tubing for steam generators, and the complete processing of Zircaloy seamless tubing for nuclear fuel cladding. At Blairsville, complete quality control facilities were utilized for the evaluation and analysis of all specialty metal products used in Westinghouse nuclear systems.  
This firm provided consultation services on structural design and analyses for SWEC as well as others. The firm included Professors R. J. Hanson; M. J. Holley, Jr.; and J. M. Biggs - all of whom were actively associated with the Massachusetts Institute of Technology (MIT). The firm provided services to SWEC in support of efforts for Yankee Atomic, Connecticut Yankee, Malibu, and Shoreham Nuclear Power Plants.  
: 6. Westinghouse Nuclear Center The headquarters of Westinghouse Nuclear Energy Systems was located just east of Pittsburgh in Monroeville, Pennsylvania. Operating primarily as a headquarters and engineering facility, the complex housed many of the divisions which encompassed Westinghouse's nuclear activities associated with the electric utility industry. 7. Zion Nuclear Training Center  The Westinghouse Electric Corporation and the Commonwealth Edison Company of Chicago built and operated a nuclear training center at Zion, Illinois. The 28,000 square foot training center contained classrooms, a training reactor, training material center, video recording facilities, and multi-plant nuclear power plant simulators. Westinghouse staffed and operated the center, supplied all the equipment required, and was responsible for the development and presentation of all training programs. Commonwealth Edison provided the building, access to the Zion nuclear units for conducting in-plant observation training, and advised and assisted Westinghouse in developing training programs.  
: 2. NUS Corporation


BVPS-2 UFSAR Rev. 0 1.4-11 1.4.4  Power Conversion System Supplier  Westinghouse was awarded the contracts to design, fabricate, deliver, and erect the turbine generator for BVPS-2.
NUS Corporation was retained to provide general consulting services. This corporation was a consulting engineering firm headquartered in Rockville, Maryland, that served utilities, industry, and the government in the fields of nuclear engineering, environmental engineering,  
Westinghouse achieved an excellent operating record in the nuclear turbine generator industry by incorporating product improvements based on operating experience as well as knowledge gained from research and development programs and the capabilities of modern manufacturing facilities. This nuclear operating performance record made Westinghouse one of the leaders in total power produced as well as in reliability and availability.
Continuing Westinghouse commitment to this kind of product evaluation produced modern and reliable nuclear turbine-generator units around the world. The Westinghouse nuclear turbine-generator operating record was as follows:  a. The first Westinghouse nuclear turbine generator was placed in commercial operation in 1957. b. Forty-five Westinghouse nuclear turbine generators were in service, totaling over 36,000 MW. c. An additional forty-five Westinghouse nuclear turbine generators were on order, in storage, or being erected. 1.4.5  Consultants Duquesne Light Company directly or through the architect engineer, SWEC, engaged the service of various consultants to perform work relating to the design, construction, operation, and maintenance of BVPS-2. These consultants included, but were not limited to, the following companies:
: 1. Hansen, Holley, and Biggs This firm provided consultation services on structural design and analyses for SWEC as well as others. The firm included Professors R. J. Hanson; M. J. Holley, Jr.; and J. M. Biggs - all of whom were actively associated with the Massachusetts Institute of Technology (MIT). The firm provided services to SWEC in support of efforts for Yankee Atomic, Connecticut Yankee, Malibu, and Shoreham Nuclear Power Plants.
: 2. NUS Corporation NUS Corporation was retained to provide general consulting services. This corporation was a consulting engineering firm headquartered in Rockville, Maryland, that served utilities, industry, and the government in the fields of nuclear engineering, environmental engineering, systems analysis and operations research, plant water technology, nuclear personnel training, and BVPS-2 UFSAR Rev. 0 1.4-12 manpower planning services. It numbered over eighty utilities among its clients and provided these clients with a broad spectrum of nuclear-related services including reactor safeguards analysis, reactor siting, and reactor design services. 3. Weston Geophysical Research, Inc. Weston Geophysical Research, Inc., was retained by the BVPS-2 project to provide consulting services on seismicity. The Reverend Daniel Linehan, Director of Weston Observatory, was a consultant to Weston Geophysical Research, Inc., and participated in these studies. Father Linehan was also a consultant to the U. S. Coast and Geodetic Survey and to numerous reactor projects, including those of Northeast Utilities Service Company, Connecticut Yankee Atomic Power Company, Virginia Electric and Power Company, and Boston Edison Company.
Weston Geophysical engineers were pioneers in the development of shallow refraction survey techniques, especially shear wave velocity determinations, which were necessary for establishing dynamic soil moduli for use in analysis of structural response to earthquakes. 4. Whitman and Rand This firm provided consulting services in the area of soil dynamics, geology, and hydrology. Doctor R. V.
Whitman, who was associated with MIT, was an outstanding authority in the field of soil dynamics and published many papers on the subject. His studies have included significant work on amplification of earthquake motion within the overburden. Mr. J. R. Rand, formerly Chief State Geologist for the State of Maine, assisted in geology and ground-water hydrology studies.
BVPS-2 UFSAR  Tables for Section 1.4 


  (Tables in Section 1.4 are historical)
systems analysis and operations research, plant water technology, nuclear personnel training, and  
BVPS-2 UFSAR Rev. 16  1 of 9 TABLE 1.4-1  WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS (HISTORICAL)
Plant            Owner Utility  Location Scheduled Commercial Operation  MWe Net  Number of Loops  Shippingport Duquesne Light Company; Energy Research & Development Administration (ERDA)  Pennsylvania 1957 90 4 Yankee-Rowe Yankee Atomic Electric Company  Massachusetts 1961 175 4 Trino Vercellese (Enrico Fermi) Ente Nazionale per I'Energia Elettrica (ENEL)
Italy 1965 260 4 Chooz Ardennes Societe D'Energie Nucleaire Franco-Belge des Ardennes (SENA)
France 1967 305 4 San Onofre No. 1 Southern California Edison Co.; San Diego Gas and Electric Co.
California 1968 430 3 Haddam Neck (Connecticut Yankee) Connecticut Yankee Atomic Power Company Connecticut 1968 575 4 Jose Cabrera - Zorita Union Electrica, S. A. Spain 1969 153 1 Beznau No. 1 Nordostschweizerische Kraftwerke AG (NOK)
Switzerland 1969 350 2 Robert Emmett Ginna Rochester Gas and Electric Corporation New York 1970 490 2 Mihama No. 1 The Kansai Electric Power  Company, Inc.
Japan 1970 320 2 Point Beach No. 1 Wisconsin Electric Power Co.; Wisconsin Michigan Power Co.
Wisconsin 1970 497 2 H. B. Robinson No. 2 Carolina Power and Light Co. South Carolina 1971 712 3 Beznau No. 2 Nordostschweizerische Kraftwerke AG (NOK) Switzerland 1972 350 2 BVPS-2 UFSAR Rev. 14  2 of 9 TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Point Beach No. 2 Wisconsin Electric Power Co.; Wisconsin Michigan Power Co. Wisconsin 1972 497 2 Surry No. 1 Virginia Electric and Power Co. Virginia 1972 822 3 Turkey Point No. 3 Florida Power and Light Co. Florida 1972 693 3 Indian Point No. 2 Consolidated Edison Company  of New York, Inc.
New York 1973 873 4 Prairie Island No. 1 Northern States Power Company  Minnesota 1973 530 2 Turkey Point No. 4 Florida Power and Light Co. Florida 1973 693 3 Surry No. 2 Virginia Electric and Power Co. Virginia 1973 822 3 Zion No. 1 Commonwealth Edison Company  Illinois 1973 1040 4 Kewaunee Wisconsin Public Service Corp.; Wisconsin Power and Light Co.;
Madison Gas and Electric Co.
Wisconsin 1974 535 2 Prairie Island No. 2 Northern States Power Company  Minnesota 1974 530 2 Takahama No. 1 The Kansai Electric Power Company, Inc.
Japan 1974 781 3 Zion No. 2 Commonwealth Edison Company  Illinois 1974 1040 4 Doel No. 1 Indivision Doel  Belgium 1975 390 2 Doel No. 2 Indivision Doel  Belgium 1975 390 2 Donald C. Cook No. 1 Indiana and Michigan Electric Company (AEP)
Michigan 1975 1054 4 Ringhals No. 2 Statens Vattenfallsverk (SSPB)  Sweden 1975 822 3 BVPS-2 UFSAR Rev. 14  3 of 9 TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Indian Point No. 3 Power Authority of the State of New York (PASNY)  New York 1976 873 4 Salem No. 1 Public Service Electric and Gas Company; Philadelphia Electric Co.;
Atlantic Electric Co.; Delmarva Power and Light Co. New Jersey 1976 1090 4 Trogan Portland General Electric Co.; Eugene Water and Electric Board; Pacific Power and Light Company Oregon 1976 1130 4 Beaver Valley No. 1 Duquesne Light Company; Ohio Edison Company; Pennsylvania Power Company  Pennsylvania 1977 852 3 Almaraz No. 1 Union Electrica, S.A.; Compania Sevillana de Electricicdad, S. A.; Hidroelectrica Espanola, S. A.
Spain 1978 902 3 Angra dos Reis No. 1 Furnas-Centrais Electricas, S. A. Brazil 1978 626 2 Diablo Canyon No. 1 Pacific Gas and Electric Co. California 1978 1084 4 Donald C. Cook No. 2 Indiana and Michigan Electric Company (AEP)  Michigan 1978 1060 4 Joseph M. Farley No. 1 Alabama Power Company  Alabama 1978 829 3 Ko-Ri No. 1 Korea Electric Company  Korea 1978 564 2 North Anna No. 1 Virginia Electric and Power Co. Virginia 1978 907 3 Ringhals No. 3 Statens Vattenfallsvert (SSPB)  Sweden 1978 912 3 Ohi No. 1 The Kansai Electric Power Co., Inc. Japan 1978 1122 4 BVPS-2 UFSAR Rev. 14  4 of 9 TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Ohi No. 2 The Kansai Electric Power Co., Inc. Japan 1978 1122 4 Sequoyah No. 1 Tennessee Valley Authority  Tennessee 1978 1148 4 Almaraz No. 2 Union Electrica, S.A.; Compania Sevillana de Electricidad, S.A.; Hidroelectrica Espanola, S.A. Spain 1979 902 3 Asco No. 1 Fuerzas Electricas deCataluna, S.A. (FECSA)
Spain 1979 902 3 Asco No. 2 Fuerzas Electricas deCataluna, S.A. (FECSA); Empresa Nacional Hidroelec-trica del Riborganzana, S.S. (ENHER); Fuerzas Hidroelectricas del Segre, S.A.; Hidroelectroca deCataluna, S.A.
Spain 1979 902 3 Diablo Canyon No. 2 Pacific Gas and Electric Co. California 1979 1106 4 Lemoniz No. 1 Iberduero, S.A. Spain 1979 902 3 Sequoyah No. 2 Tennessee Valley Authority  Tennessee 1979 1148 4 Watts Bar No. 1 Tennessee Valley Authority  Tennessee 1979 1177 4 William B. McGuire No. 1 Duke Power Company North Carolina 1979 1180 4 Joseph M. Farley No. 2 Alabama Power Company  Alabama 1979 829 3 Krsko Savske Elektrarne, Ljubljana, Slovenia; Elektroprivreda, Zagreb, Croatia  Yugoslavia 1979 615 2 Ringhals No. 4 Statens Vattenfallsvert (SSPB)  Sweden 1979 912 3 BVPS-2 UFSAR Rev. 14  5 of 9 TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Salem No. 2 Public Service Electric and Gas Company; Philadelphia Electric Co.;
Atlantic Electric Co.; Delmarva Power and Light Co. New Jersey 1979 1115 4 Lemonis No. 2 Iberduero, S.A. Spain 1980 902 3 North Anna No. 2 Virginia Electric and Power Co. Virginia 1979 907 3 Virgil C. Summer South Carolina Electric and Gas Company South Carolina 1980 900 3 Watts Bar No. 2 Tennessee Valley Authority  Tennessee 1980 1177 4 South Texas Project Unit No. 1 Houston Lighting and Power Co.;
Central Power and Light Co.; City Public Service of San Antonio; City of Austin, Texas  Texas 1980 1250 4 William B. McGuire No. 2 Duke Power Company North Carolina 1981 1180 4 Comanche Peak No. 1 Texas Utilities Generating Co. Texas 1981 1150 4 Byron No. 1 Commonwealth Edison Company  Illinois 1981 1120 4 Vandellos No. 2 Fuerzas Electricas de Cataluna, S.A. (FECSA); Empresa Nacional Hidroelectrica del Ribagorzana, S.A. (ENHER);
Fuerzas Hidroelectricas del Segre S.A.; Hidroelectrica de Cataluna, S.A.
Spain 1981 920 3 Seabrook No. 1 Public Service Company of New Hampshire; United Illuminating Company  New Hampshire 1982 1200 4 Braidwood No. 1 Commonwealth Edison Company Illinois 1982 1120 4 BVPS-2 UFSAR Rev. 14  6 of 9 TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Catawba No. 1 Duke Power Company  South Carolina 1982 1145 4 Callaway No. 1 SNUPPS - Union Electric Co. Missouri 1982 1150 4 Ko-Ri No. 2 Korea Electric Company  Korea 1982 605 2 Comanche Peak No. 2 Texas Utilities Generating Co. Texas 1982 1150 4 Marble Hill No. 1 Public Service Company of Indiana, Inc.,;
Wabash Valley Power Association  Indiana 1982 1130 4 Millstone No. 3 Northeast Nuclear Energy Co. Connecticut 1982 1156 4 South Texas Project Unit 2 Houston Lighting and Power Co.;
Central Power and Light Co. City Public Service of San Antonio; City of Austin, Texas Texas 1982 1250 4 Napot Point No. 1 National Power Corporation  Philippines 1982 620 2 Sayago No. 1 Iberduero, S.A. Spain 1982 1000 3 Braidwood No. 2 Commonwealth Edison Company  Illinois 1983 1120 4 Byron No. 2 Commonwealth Edison Company  Illinois 1983 1120 4 Catawba No. 2  Duke Power Company South Carolina 1983 1145 4 Maanshan No. 1  Taiwan Power Company Taiwan 1983 907 3 Alvin W. Vogtle No. 1 Georgia Power Company; Oglethorpe Electric Membership Corp.; Municipal Electric Authority of Georgia; City of Dalton, Georgia Georgia 1983 1113 4 BVPS-2 UFSAR Rev. 14  7 of 9 TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Wolf Creek Unit No. 1 SNUPPS - Kansas Gas and Electric  Company; Kansas City Power and Light Company  Kansas 1984 1150 4 Seabrook No. 2 Public Service Company of New Hampshire; United Illuminating Company  New Hampshire 1984 1200 4 Jamesport No. 1 Long Island Lighting Company; New York State Electric and Gas Corp.
New York 1984 1150 4 Maanshan No. 2 Taiwan Power Company  Taiwan 1984 907 3 Alvin W. Vogtle No. 2 Georgia Power Company; Oglethorpe Electric Membership Corp.;
Municipal Electric Authority of Georgia; City of Dalton, Georgia Georgia 1984 1113 4 Marble Hill No. 2 Public Service Company of Indiana, Inc.;
Wabash Valley Power Association  Indiana 1984 1130 4 Shearon Harris No. 1 Carolina Power and Light Co. North Carolina 1984 900 3 Sterling SNUPPS - Rochester Gas and Electric Corporation; Central Hudson Gas and Electric  Corporation; Niagara Mohawk Power Corporation; Orange and Rockland Utilities, Inc. New York 1984 1150 4 Tyrone No. 1 SNUPPS - Northern States Power Company Wisconsin 1984 1150 4 BVPS-2 UFSAR Rev. 14  8 of 9  TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Atlantic No. 1 (O.P.S) Public Service Electric and Gas Company; Atlantic Electric Co.; Jersey Central Power and Light Company New Jersey - 1150 4 Jamesport No. 2 Long Island Lighting Company; New York State Electric and Gas Corp. New York 1986 1150 4 Shearon Harris No. 2 Carolina Power and Light Co. North Carolina 1986 900 3 Callaway No. 2 SNUPPS - Union Electric Company  Missouri 1987 1150 4 Haven No. 1 Wisconsin Electric Power Co.; Wisconsin Power and Light Co.; Wisconsin Public Service Corp.
Wisconsin 1987 900 3 Atlantic No. 2 (O.P.S) Public Service Electric and Gas Company; Atlantic Electric Co.; Jersey Central Power and  Light Company New Jersey - 1150 4 Shearon Harris No. 4 Carolina Power and Light Co. North Carolina 1988 900 3 Haven Wisconsin Electric Power Co.; Wisconsin Power and Light Co.;
Wisconsin Public Service Corp.
Wisconsin 1989 900 3 Unit No. 4 Iberduero, S.A. Spain 1980's 1000 3 Shearon Harris No. 3 Carolina Power and Light Co. North Carolina 1990 900 3 BVPS-2 UFSAR Rev. 14  9 of 9 TABLE 1.4-1 (Cont)    Plant Owner Utility  Location Scheduled Commercial Operation  MWE Net  Number of Loops  Unassigned No. 1 (O.P.S) Public Service Electric and Gas Company; Atlantic Electric Company New Jersey 1990 1150 4 Unassigned No. 2 Public Service Electric and Gas Company; Atlantic Electric Company  New Jersey 1992 1150 4 BVPS-2 UFSAR Rev. 16 1.5-1 1.5  REQUIREMENTS FOR FURTHER TECHNICAL INFORMATION  The requirements for further technical information provided herein reflects the status of Beaver Valley Power Station - Unit 2 (BVPS-2) at the time of the issuance of the Operating License. This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR. The Westinghouse Electric Corporation (Westinghouse) report WCAP-8768 (Eggleston 1978) presents descriptions of the safety-related research and development programs which are being carried out for, by, or in conjunction with Westinghouse Nuclear Energy Systems and which are applicable to Westinghouse pressurized water reactors (PWRS).
For each program still in progress, the safety-related program is first introduced and is followed where appropriate by background information. A description of the program follows, which relates the program objectives to the problem and presents pertinent recent results. Finally, a backup position may be given for programs (generally experimental rather than analytical) that have not yet reached a stage at which it is reasonably certain that the results confirm the expectation.
The backup position is one that might be used if the results were to be unfavorable; it is not necessarily the only course that might be taken in the ultimate solution of the problem.
The term "research and development" as used in this report is the same as that used by the U.S. Nuclear Regulatory Commission (USNRC) in 10 CFR 50.2, and means:  1. Theoretical analysis, exploration, or experimentation, or  2. The extension of investigative findings and theories of a scientific or technical nature into practical application for experimental and demonstration purposes including the experimental production and testing of models, devices, equipment, material, and processes. The technical information generated by these research and development programs will be used either to demonstrate the safety of the design and more sharply define margins of conservatism, or could lead to design improvements. Included in the overall research and development effort are the programs described as follows which are applicable to this plant, but are not required for issuance of either a Construction Permit or Operating License.
1.5.1  Blowdown Heat Transfer Testing 1.5.1.1  Introduction  The USNRC acceptance criteria for emergency core cooling systems (ECCSs) for light-water power reactors were issued in Section 50.46 of 10 CFR 50 on December 28, 1973. They define the basis BVPS-2 UFSAR Rev. 16 1.5-2 and conservative assumptions to be used in the evaluation of the performance of ECCSs. Westinghouse believes that some of the conservatism of the criteria is associated with the manner in which transient departure from nucleate boiling (DNB) phenomena are treated in the evaluation models. Transient critical heat flux data presented at the 1972 specialists meeting of the Committee on Reactor Safety Technology indicated that the time to DNB can be delayed under transient conditions. To demonstrate the conservatism of the ECCS evaluation models, Westinghouse has initiated a program to experimentally simulate the blowdown phase of a loss-of-coolant accident (LOCA). This testing is part of the Electric Power Research Institute (EPRI) sponsored Blowdown Heat Transfer Program, which was started in early 1976. Testing was completed in 1979. A DNB correlation developed by Westinghouse from these test results will be used in the ECCS analyses.
1.5.1.2  Objective The objective of the Blowdown Heat Transfer Test was to determine the time that DNB occurs under LOCA conditions. This information was used to confirm the existing, or develop a new Westinghouse transient DNB correlation. The steady state DNB data obtained from 15 by 15 and 17 by 17 test programs can be used to assure that the geometrical differences between the two fuel arrays can be correctly treated in the transient correlations.
1.5.1.3  Program  The program was divided into two phases. Phase I tests started from steady state conditions, with sufficient power to maintain nucleate boiling throughout the bundle, controlled ramps of decreasing test section pressure, or flow initiated DNB. By applying a series of controlled conditions, investigation of the DNB was studied over a range of qualities, flows, and pressures relevant to a PWR blowdown.
Phase I provided separate-effects data to permit heat transfer correlation development.
Typical parameters used for Phase I testing are presented in Table 1.5-1. Phase II simulated PWR behavior during a LOCA to permit definition of the time delay associated with onset of DNB. Tests in Phase II covered the large double-ended guillotine cold leg break. All tests in Phase II were started after establishment of typical steady state operating conditions. The fluid transient was then initiated, and the rod power decay was programmed in such a manner as to simulate the actual heat input of fuel rods. The test was terminated when the heater rod temperatures reached a predetermined limit. Typical parameters used for Phase II testing are shown in Table 1.5-2.
BVPS-2 UFSAR Rev. 0 1.5-3 1.5.1.4  Test Description  The experimental program was conducted in the J-Loop at the Westinghouse Forest Hills Facility with a full length 5 by 5 rod bundle simulating a section of a 15 by 15 assembly to determine DNB occurrence under LOCA conditions.
The heater rod bundles used in this program were internally heated rods, capable of a maximum power of 18.8 kW/ft, with a total power of 135 kW (for extended periods) over the 12-foot heated length of the rod. Heat was generated internally by means of a varying cross-sectional resistor which approximates a chopped cosine power distribution. Each rod was adequately instrumented with a total of 12 clad thermocouples. 1.5.1.5  Results The experiments in the delayed departure from nucleate boiling facility resulted in cladding temperature and inlet fluid properties measured as a function of time throughout the blowdown range from 0 to 20 seconds.
Facility modifications and installation of the initial test bundle were completed. A series of shakedown tests in the J-Loop were performed. These tests provided data for instrumentation calibration and check-out, and provided information regarding facility control and performance. Initial program tests were performed during the first half of 1975.
Under the sponsorship of EPRI, testing was reinitiated during 1976 on the same test bundle. The testing was terminated in November 1976 and plans were made for a new test bundle and further testing during 1978-1979. A DNB correlation developed from these results are used in the Westinghouse ECCS analyses for Beaver Valley Power Station - Unit 2.
1.5.2  Reference for Section 1.5 Eggleston, F.T. 1978. Safety-Related Research and Development for Westinghouse Pressurized Water Reactors, Program Summaries - Winter 1977, Summer 1978. WCAP-8768, Revision 2.
BVPS-2 UFSAR  Tables for Section 1.5   


  (Tables in Section 1.5 are historical) 
BVPS-2 UFSAR Rev. 0 1.4-12 manpower planning services. It numbered over eighty utilities among its clients and provided these clients with a broad spectrum of nuclear-related services including reactor safeguards analysis, reactor siting,


BVPS-2 UFSAR Rev. 16 1 of 1 TABLE 1.5-1  DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE I TEST PARAMETERS (HISTORICAL)
and reactor design services.  
Parameters  Nominal Value Initial Steady State Conditions Pressure (psia) 1,250 to 2,250  Test section mass velocity (lb/hr-ft2)  1.12 to 2.5 x 106  Core inlet temperature (F)  550 to 600  Maximum heat flux (Btu/hr-ft2)  306,000 to 531,000 Transient Ramp Conditions Pressure decrease  0 to 350 psi/sec and subcooled depressurization from 2,250 psia  Flow decrease (%/sec)  0 to 100  Inlet enthalpy constant BVPS-2 UFSAR Rev. 16 1 of 1 TABLE 1.5-2  DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE II TEST PARAMETERS (HISTORICAL)
: 3. Weston Geophysical Research, Inc.
Parameters  Nominal Value Initial Steady State Conditions Pressure (psia) 2,250  Test section mass velocity (lb/hr-ft2)  2.5 X 106  Inlet coolant temperature (F)  545  Maximum heat flux (Btu/hr-ft2)  531,000 Transient Conditions    Simulated break  Double-ended cold leg guillotine breaks BVPS-2 UFSAR Rev. 16 1.6-1 1.6  MATERIAL INCORPORATED BY REFERENCE  Table 1.6-1 lists topical reports which, prior to issuance of the operating license, provided information in addition to that provided in this Final Safety Analysis Report and which were filed separately with the U.S. Nuclear Regulatory Commission (USNRC) in support of this and similar applications. Therefore, this section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.
Weston Geophysical Research, Inc., was retained by the  
The legend for the review status code letter follows:
A - U.S. Nuclear Regulatory Commission review complete; USNRC acceptance letter issued.
AE - U. S. Nuclear Regulatory Commission accepted as part of the Westinghouse emergency core cooling system (ECCS) evaluation model only; does not constitute acceptance for any purpose other than for ECCS analyses. B - Submitted to USNRC as background information; not undergoing formal USNRC review.
O - On file with USNRC; older generation report with current validity; not actively under formal USNRC review.
N - Not applicable; that is, open literature, etc.
U - Actively under formal USNRC review.
BVPS-2 UFSAR  Tables for Section 1.6   


  (Tables in Section 1.6 are historical) 
BVPS-2 project to provide consulting services on seismicity. The Reverend Daniel Linehan, Director of Weston Observatory, was a consultant to Weston Geophysical Research, Inc., and participated in these studies. Father Linehan was also a consultant to the U. S. Coast and Geodetic Survey and to numerous reactor projects, including those of Northeast


BVPS-2 UFSAR Rev. 16  1 of 15 TABLE 1.6-1  MATERIAL INCORPORATED BY REFERENCE (HISTORICAL)  REPORT NO.
Utilities Service Company, Connecticut Yankee Atomic Power Company, Virginia Electric and Power Company, and Boston Edison Company.
TITLE USNRC SUBMITTAL REFERENCE SECTION(S) REVIEW STATUS WCAP-2048 The Doppler Effect for a Non-Uniform  Temperature Distribution in
 
Weston Geophysical engineers were pioneers in the development of shallow refraction survey techniques,
 
especially shear wave velocity determinations, which were necessary for establishing dynamic soil moduli for use in analysis of structural response to
 
earthquakes.
: 4. Whitman and Rand
 
This firm provided consulting services in the area of
 
soil dynamics, geology, and hydrology. Doctor R. V.
Whitman, who was associated with MIT, was an outstanding authority in the field of soil dynamics and published many papers on the subject. His studies have included significant work on amplification of earthquake motion within the overburden. Mr. J. R. Rand, formerly Chief State Geologist for the State of Maine, assisted in geology and ground-water hydrology studies.
 
BVPS-2 UFSAR  Tables for Section 1.4
 
  (Tables in Section 1.4 are historical)
 
BVPS-2 UFSAR Rev. 16  1 of 9 TABLE 1.4-1 WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS (HISTORICAL)
 
Plant            Owner Utility Location Scheduled Commercial Operation MWe Net  Number of Loops  Shippingport Duquesne Light Company; Energy Research & Development
 
Administration (ERDA)
Pennsylvania 1957 90 4 Yankee-Rowe Yankee Atomic Electric Company Massachusetts 1961 175 4 Trino Vercellese (Enrico Fermi) Ente Nazionale per I'Energia Elettrica (ENEL)
 
Italy 1965 260 4 Chooz Ardennes Societe D'Energie Nucleaire
 
Franco-Belge des Ardennes (SENA)
 
France 1967 305 4 San Onofre No. 1 Southern California Edison Co.;
San Diego Gas and Electric Co.
 
California 1968 430 3 Haddam Neck (Connecticut Yankee) Connecticut Yankee Atomic Power Company
 
Connecticut 1968 575 4 Jose Cabrera - Zorita Union Electrica, S. A.
Spain 1969 153 1 Beznau No. 1 Nordostschweizerische Kraftwerke AG (NOK)
 
Switzerland 1969 350 2 Robert Emmett Ginna Rochester Gas and Electric Corporation
 
New York 1970 490 2 Mihama No. 1 The Kansai Electric Power  Company, Inc.
 
Japan 1970 320 2 Point Beach No. 1 Wisconsin Electric Power Co.; Wisconsin Michigan Power Co.
 
Wisconsin 1970 497 2 H. B. Robinson No. 2 Carolina Power and Light Co.
South Carolina 1971 712 3 Beznau No. 2 Nordostschweizerische Kraftwerke AG (NOK) Switzerland 1972 350 2 BVPS-2 UFSAR Rev. 14  2 of 9 TABLE 1.4-1 (Cont)
Plant Owner Utility Location Scheduled Commercial Operation MWE Net  Number of Loops  Point Beach No. 2 Wisconsin Electric Power Co.; Wisconsin Michigan Power Co.
Wisconsin 1972 497 2 Surry No. 1 Virginia Electric and Power Co.
Virginia 1972 822 3 Turkey Point No. 3 Florida Power and Light Co.
Florida 1972 693 3 Indian Point No. 2 Consolidated Edison Company of New York, Inc.
 
New York 1973 873 4 Prairie Island No. 1 Northern States Power Company Minnesota 1973 530 2 Turkey Point No. 4 Florida Power and Light Co.
Florida 1973 693 3 Surry No. 2 Virginia Electric and Power Co.
Virginia 1973 822 3 Zion No. 1 Commonwealth Edison Company Illinois 1973 1040 4 Kewaunee Wisconsin Public Service Corp.;
Wisconsin Power and Light Co.;
 
Madison Gas and Electric Co.
 
Wisconsin 1974 535 2 Prairie Island No. 2 Northern States Power Company Minnesota 1974 530 2 Takahama No. 1 The Kansai Electric Power Company, Inc.
 
Japan 1974 781 3 Zion No. 2 Commonwealth Edison Company Illinois 1974 1040 4 Doel No. 1 Indivision Doel Belgium 1975 390 2 Doel No. 2 Indivision Doel Belgium 1975 390 2 Donald C. Cook No. 1 Indiana and Michigan Electric Company (AEP)
 
Michigan 1975 1054 4 Ringhals No. 2 Statens Vattenfallsverk (SSPB)
Sweden 1975 822 3
 
BVPS-2 UFSAR Rev. 14  3 of 9 TABLE 1.4-1 (Cont)
Plant Owner Utility Location Scheduled Commercial Operation MWE Net  Number of Loops  Indian Point No.
: n. Detailed Control Room Design Review - Supplemental Report   
: n. Detailed Control Room Design Review - Supplemental Report   
: o. Fire Protection Safe Shutdown Report 3. Programs reviewed at BVPS-2  
: o. Fire Protection Safe Shutdown Report  
: 3. Programs reviewed at BVPS-2  
: a. Equipment Qualification Documentation (EQD)  
: a. Equipment Qualification Documentation (EQD)  
: b. Seismic and Dynamic Qualification Program for Safety-Related Equipment D N I REV. 12 RECIPROCATING COMPRESSOR AIR HEATING COIL 6 S P R A Y Z Z L E COCJI lNG COIL MOVABLE LOUVER [ LIQUID TANK K(55) ROTARY COMPRESSOR X PROPELLER FAN n "---------' II A GAS CYLINDER n ld u D (Q? ION EXCHANGER // FIXED LOUVER CENTRIFUGAL COMPRESSOR CENTRIFUGAL FAN / / 0 [b:::::::J GAS INJECTOR 111 [Q!J rAN COIL UNIT AIR GAS RECEIVER RESTRICTING ORIFICE [] TRAP 1/1 [lJ t! RELIEF VALVE MOISTURE SEPARATOR FLOW INSTRUMENT MANUAL DAMPER m bJd RCJLL iLl t_R 0 [2J SELF-ACTUATING. [:::::1 CHECK VALVE 521 FILTER BACKFLOW OR RUPTURE DISK GRAVITY DAMPER c=J ENGINE 0 FOUR WAY VALVE G PUMP FIRE DAMPER c=J GENERATOR C><J MANUAL VALVE EJ 0 SKIMMER RADIATION MONITOR D ClfJ THREE WAY VALVE SINGLE STAGE TURBINE n r:-1 u PROPORTIONING MOTOR OPERATOR 0 STRAINER PUMP MULTISTAGE TURBINE u (8) ROTARY PUMP r AIR OPERATOR J DISCHARGE NOZZLE CONDENSER Cfl SOLENOID OPERATOR a g EVAPORATOR (9 COOLER ACCUMULATOR 0 LOOP HEAT EXCHANGER u HYDRAULIC OPERATOR PART[CULATE FILTER ABBREVIATIONS DEMINERALIZER TXV-THERMAL EXPANSION VALVE OOJJ TCV-TEMPERATURE CONTROL VALVE REGENERATIVE ELECTRO-HYDRAULIC il PCV-PRESSURE CONTROL VALVE HEAT EXCHANGER OPERATOR HCV-HAND CONTROL VALVE n CHARCOAL FILTER sv -SAFETY VALVE 0 STEAM GENERATOR TV -THROTTLE VALVE THRU HEAT EXCHANGER "\ I 0 SPECIAL VALVE GV GOVERNOR VALVE u -NRV-NON-RETURN VALVE U TUBE HEAT EXCHANGER 0 PRESSURIZER [fJ LOUVER W/SCREEN BLENDER @ FIGURE 1
: b. Seismic and Dynamic Qualification Program for Safety-Related Equipment  
* 7-1 DEHYDRATOR AIR DRYER SYMBOLS FOR FIGURES BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT BVPS-2 UFSAR Rev. 0 1.8-1 1.8  CONFORMANCE TO NRC REGULATORY GUIDES Table 1.8-1 provides an evaluation of the degree of Beaver Valley Power Station-Unit 2 (BVPS) conformance to NRC Division 1 Regulatory Guides. The revisions of the regulatory guides against which BVPS-2 is evaluated are indicated. Any alternatives to the provisions of the regulatory guides are identified and justification is provided where appropriate. FSAR sections applicable to the subject regulatory guide are referenced.  
 
D N I REV. 12 RECIPROCATING COMPRESSOR AIR HEATING COIL 6 S P R A Y Z Z L E COCJI lNG COIL MOVABLE LOUVER [ LIQUID TANK K(55) ROTARY COMPRESSOR X PROPELLER FAN n "---------'
II A GAS CYLINDER n ld u D (Q? ION EXCHANGER  
// FIXED LOUVER CENTRIFUGAL COMPRESSOR CENTRIFUGAL FAN / / 0 [b:::::::J GAS INJECTOR 111 [Q!J rAN COIL UNIT AIR GAS RECEIVER RESTRICTING ORIFICE [] TRAP 1/1 [lJ t! RELIEF VALVE MOISTURE SEPARATOR FLOW INSTRUMENT MANUAL DAMPER m bJd RCJLL iLl t_R 0 [2J SELF-ACTUATING.  
[:::::1 CHECK VALVE 521 FILTER BACKFLOW OR RUPTURE DISK GRAVITY DAMPER c=J ENGINE 0 FOUR WAY VALVE G PUMP FIRE DAMPER c=J GENERATOR C><J MANUAL VALVE EJ 0 SKIMMER RADIATION MONITOR D ClfJ THREE WAY VALVE SINGLE STAGE TURBINE n r:-1 u PROPORTIONING MOTOR OPERATOR 0 STRAINER PUMP MULTISTAGE TURBINE u (8) ROTARY PUMP r AIR OPERATOR J DISCHARGE NOZZLE CONDENSER Cfl SOLENOID OPERATOR a g EVAPORATOR (9 COOLER ACCUMULATOR 0 LOOP HEAT EXCHANGER u HYDRAULIC OPERATOR PART[CULATE FILTER ABBREVIATIONS DEMINERALIZER TXV-THERMAL EXPANSION VALVE OOJJ TCV-TEMPERATURE CONTROL VALVE REGENERATIVE ELECTRO-HYDRAULIC il PCV-PRESSURE CONTROL VALVE HEAT EXCHANGER OPERATOR HCV-HAND CONTROL VALVE n CHARCOAL FILTER sv -SAFETY VALVE 0 STEAM GENERATOR TV -THROTTLE VALVE THRU HEAT EXCHANGER  
"\ I 0 SPECIAL VALVE GV GOVERNOR VALVE u -NRV-NON-RETURN VALVE U TUBE HEAT EXCHANGER 0 PRESSURIZER  
[fJ LOUVER W/SCREEN BLENDER @ FIGURE 1
* 7-1 DEHYDRATOR AIR DRYER SYMBOLS FOR FIGURES BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT BVPS-2 UFSAR Rev. 0 1.8-1 1.8  CONFORMANCE TO NRC REGULATORY GUIDES Table 1.8-1 provides an evaluation of the degree of Beaver Valley Power Station-Unit 2 (BVPS) conformance to NRC Division 1 Regulatory Guides. The revisions of the regulatory guides against which BVPS-2 is evaluated are indicated. Any alternatives to the provisions of the regulatory guides are identified and justification is provided where appropriate.
FSAR sections applicable to the subject regulatory guide are referenced.  
 
BVPS-2 UFSAR  Tables for Section 1.8
 
BVPS-2 UFSAR Rev. 18  1 of 91 TABLE 1.8-1 USNRC REGULATORY GUIDES


BVPS-2 UFSAR  Tables for Section 1.8 BVPS-2 UFSAR Rev. 18  1 of 91 TABLE 1.8-1  USNRC REGULATORY GUIDES RG No. 1.1, Rev. 0 UFSAR Reference Section 6.2.2, 6.3  
RG No. 1.1, Rev. 0 UFSAR Reference Section 6.2.2, 6.3  


NET POSITIVE SUCTION HEAD FOR EMERGENCY CORE COOLING AND CONTAINMENT HEAT REMOVAL SYSTEM PUMPS (NOVEMBER 2, 1970)
NET POSITIVE SUCTION HEAD FOR EMERGENCY CORE COOLING AND CONTAINMENT HEAT REMOVAL SYSTEM PUMPS (NOVEMBER 2, 1970)
Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.1 for providing adequate net positive suction head (NPSH) for emergency core cooling and containment heat removal systems pumps with the following alternatives:
 
The containment pressure and sump vapor pressure are calculated explicitly on a transient basis and used to calculate the available NPSH for the Recirculation Spray pumps as described in Section 6.2.2.3.2.
Beaver Valley Power Station - Unit 2 meets the intent of  
 
Regulatory Guide 1.1 for providing adequate net positive suction head (NPSH) for emergency core cooling and containment heat  
 
removal systems pumps with the following alternatives:  
 
The containment pressure and sump vapor pressure are calculated explicitly on a transient basis and used to calculate the available NPSH for the Recirculation Spray pumps as described in Section 6.2.2.3.2.  
 
RG No. 1.2, Rev. 0 UFSAR Reference Section 5.3  
RG No. 1.2, Rev. 0 UFSAR Reference Section 5.3  


THERMAL SHOCK TO REACTOR PRESSURE VESSELS (NOVEMBER 2, 1970)
THERMAL SHOCK TO REACTOR PRESSURE VESSELS (NOVEMBER 2, 1970)
The guidance provided by this regulatory guide regarding Section 5.3 thermal shock to the reactor pressure vessel is followed for Beaver Valley Power Station - Unit 2 with the following clarification:
Paragraph C.3  The vessel design does not preclude the use of an engineering solution to assure adequate recovery of the fracture toughness properties of the vessel material. If additional margin is needed, the reactor vessel can be annealed. This solution was shown to be feasible by EPRI program RP1021-1, "Feasibility and Methodology for Thermal Annealing an Embrittled Reactor Vessel."


RG No. 1.3, Rev. 2  ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A LOSS-OF-COOLANT ACCIDENT FOR BOILING WATER REACTORS (JUNE 1974)  This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
The guidance provided by this regulatory guide regarding Section
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont)  2 of 91 RG No. 1.4, Rev. 2 UFSAR Reference Sections 4.2, 6.2.1, 6.2.4, 6.5.1, 15.1.5, 15.6.3, 15.6.5  ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A LOSS-OF-COOLANT ACCIDENT FOR PRESSURIZED WATER REACTORS (JUNE 1974)
 
The assumptions used for evaluating the potential radiological consequences of a loss-of-coolant accident at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183. Refer to the position on Regulatory Guide 1.183, later in this table.
5.3 thermal shock to the reactor pressure vessel is followed for Beaver Valley Power Station - Unit 2 with the following
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2. RG No. 1.5, Rev. 0  ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A STEAM LINE BREAK ACCIDENT FOR BOILING WATER REACTORS (MARCH 10, 1971)  This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2. RG No. 1.6, Rev. 0 UFSAR Reference Sections 7.6, 8.3.1.4, 8.3.2, 7.6.1  INDEPENDENCE BETWEEN REDUNDANT STANDBY (ONSITE) POWER SOURCES AND BETWEEN THEIR DISTRIBUTION SYSTEMS (MARCH 10, 1971)
 
Methods for establishing the degree of independence between redundant standby (onsite) power sources and between their distribution systems at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide. RG No. 1.7, Rev. 2 UFSAR Reference Section 6.2.5 CONTROL OF COMBUSTIBLE GAS CONCENTRATIONS IN CONTAINMENT FOLLOWING A LOSS-OF-COOLANT ACCIDENT (NOVEMBER 1978)
clarification:  
The hydrogen control system was originally designed following the guidance of Regulatory Guide 1.7, but with the subsequent 10 CFR 50.44 rule change, the hydrogen recombiners are not required; therefore, the hydrogen recombiners may be maintained, modified or eliminated. RG No. 1.8 UFSAR Reference Sections 12.5, 13.1, 13.2 PERSONNEL SELECTION AND TRAINING  Application of Regulatory Guide 1.8 to the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  3 of 91 RG No. 1.9, Rev. 2 UFSAR Reference Sections 8.3.1.1.15, 14.2.12.54, 14.2.12.55 SELECTION, DESIGN, AND QUALIFICATION OF DIESEL-GENERATOR UNITS USED AS STANDBY (ONSITE) ELECTRIC POWER SYSTEMS AT NUCLEAR POWER PLANTS (DECEMBER 1979)  Diesel-generator units used as onsite electric power systems at BVPS-2 have been selected, designed, and qualified following the guidance of this Regulatory Guide with the following alternative and clarifications:  The Class lE diesel generator units were designed and procured following the guidance of Regulatory Guide 1.9, Rev. 0 (March 1971) and IEEE Standard 387-1972.  (Revision status at time of design/procurement)  However, the Class lE diesel generators were manufactured to IEEE Standard 387-1977 with the following clarifications:
Paragraph C.3 The vessel design does not preclude the use of an engineering solution to assure adequate recovery of the fracture toughness properties of the vessel material. If additional margin is needed, the reactor vessel can be  
: 1. Section 4.1[8]:  The BVPS-2 Class lE diesels are qualified utilizing the mild environment concept acknowledged by 10 CFR 50.49(c). 2. Section 4.1[12]:  The BVPS-2 Class lE diesels are seismically qualified in accordance with IEEE Standard 344-1971. 
 
: 3. Section 5.4:  The BVPS-2 Class lE diesels are qualified utilizing the mild environment concept acknowledged by 10 CFR 50.49(c). 4. Section 6.3.1:  All required tests or analyses have been performed by the manufacturer with the exception of the2-hour short-time/22-hour continuous rating test. This test will be performed at the site in accordance with Section 6.3.1 and the loading sequence specified in Paragraph C.14 of Regulatory Guide 1.9. RG No. 1.10, Rev. 1 UFSAR Reference Section 3.8.1.6.2 MECHANICAL (CADWELD) SPLICES IN REINFORCING BARS OF CATEGORY I CONCRETE STRUCTURES (JANUARY 2, 1973)
annealed. This solution was shown to be feasible by EPRI program RP1021-1, "Feasibility and Methodology for Thermal
Regulatory Guide 1.10 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136 ("Materials, Construction, and Testing of Concrete Containments (Articles CC-1OOO, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containment)"). However, since a significant portion of Beaver Valley Power Station - Unit 2 design and construction was completed prior to the withdrawal of this regulatory guide, mechanical (Cadweld) splices in reinforcing bars of Category I concrete structures meet the intent of Regulatory Guide 1.10 with the following alternative:
BVPS-2 UFSAR Rev. 15  TABLE 1.8-1 (Cont)  4 of 91 Reinforcing bars with a radius of curvature 60 feet-0 inches or greater will be tested at the sampling frequency specified in Paragraphs C.4a and C.4b. Reinforcing bars with a radius of curvature of less than 60 feet-0 inches will be tested using only sister splices with the following frequency for each splicing crew:
: 1. One sister splice representing the first 10 production splices,  2. Four sister splices representing the next 90 production splices, and 
: 3. One sister splice representing the next and every subsequent 33 production splices. Testing of the sister splices is in accordance with Paragraphs C.3 and C.5.
The acceptability of this alternative is based on the following:  The second paragraph of Section 3 of Regulatory Guide 1.10 states that production mechanical splice samples for tensile testing should not be used from curved reinforcing sections, and then refers to Paragraph 4b for sampling frequency. Paragraph 4b provides for a combination of production and sister splices, which appears to be an inconsistency. The regulatory guide assumes that the cadwelders perform splices in the horizontal, vertical, and diagonal directions on the same day. Thus, there would be occasional splices on straight vertical bars which could be alternated with the curve bar splicing to permit the frequency of testing in Paragraph 4b of Regulatory Guide 1.10, which requires both production and sister splices.
However, construction is apt to perform splices in one position only for more splices than those requiring another set of tests. The 60-foot radius was established because satisfactory test results have been obtained for splices on bars of this or greater radii. During the operations phase, splicing reinforcing bars shall be performed in accordance with individual project specifications. Project Specifications shall include or reference manufacturer's instructions and comply with the applicable requirements of ANSI N45.2.5-1974. FENOC Quality Assurance Program Manual (QAPM) identifies specific subarticles of ASME Section III Division 2-1995 edition that will be used in lieu of the corresponding requirements in ANSI N45.2.5-1974. 


BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont)  5 of 91 RG No. 1.11, Rev. 0 UFSAR Reference Section 6.2.4 INSTRUMENT LINES PENETRATING PRIMARY REACTOR CONTAINMENT (MARCH 10, 1971)
Annealing an Embrittled Reactor Vessel."
The guidance of this regulatory guide is followed for instrument lines penetrating primary reactor containment at Beaver Valley Power Station - Unit 2.
 
RG No. 1.12, Rev. 1 UFSAR Reference Section 3.7B.4. INSTRUMENTATION FOR EARTHQUAKES (APRIL 1974) Earthquake instrumentation at Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide with the following exceptions based on industry experience: 1) No triaxial accelerograph unit listed in Section 3.7B.4.2 is located on equipment, piping or supports since experience has shown that data obtained at these locations are obscured by the vibratory motion associated with normal plant operations. 2) There is no immediate indication that the zero period acceleration at the containment mat has been exceeded via a switch. The system will determine within minutes whether actual conditions have exceeded a pre-determined building response spectra and provide indication if the 1/2-SSE has been exceeded. 3) All instruments are oriented to the same azimuths, except one remote accelerograph sensor which is mounted to the containment cranewall. It is oriented such that it will respond to horizontal motion in the radial and tangential directions of the containment.
RG No. 1.3, Rev. 2 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A LOSS-OF-COOLANT ACCIDENT FOR BOILING WATER REACTORS (JUNE 1974)
RG No. 1.13, Rev. 1 UFSAR Reference Sections 9.1.2, 9.1.3, 9.1.4, 9.1.5 SPENT FUEL STORAGE FACILITY DESIGN BASIS (DECEMBER 1975) The design of spent fuel storage facilities follows the guidance of this regulatory guide with the following alternative: Local spent fuel pool level alarms are not provided. A fuel pool level alarm is provided in the control room.
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
The motor-driven platform crane, which is the only crane that is operable over the spent fuel pool, has hoists that are each provided with an adjustable interlock which will stop hoist motion if a preset weight is exceeded. The setpoint is based upon the weight of a single fuel assembly. Accordingly, the interlock must be overridden in order to use the hoist for maintenance operations.
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 6 of 91 Administrative procedures require that maintenance operations be carried out along a safe path away from the spent fuel pool. When the motor-driven crane is not in use, administrative procedures require that it be positioned away from the spent fuel pool.
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 2 of 91 RG No. 1.4, Rev. 2 UFSAR Reference Sections 4.2, 6.2.1, 6.2.4, 6.5.1, 15.1.5, 15.6.3, 15.6.5  ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A LOSS-OF-COOLANT ACCIDENT FOR PRESSURIZED WATER REACTORS (JUNE 1974)
RG No. 1.14, Rev. 1 UFSAR Reference Section 5.4.1.5 REACTOR COOLANT PUMP FLYWHEEL INTEGRITY (AUGUST 1975) Reactor coolant pump flywheel integrity at Beaver Valley Power Station - Unit 2 is assured by meeting the intent of this regulatory guide as specified in WCAP-8163, September 1973,  
 
("Reactor Coolant Pump Integrity in LOCA") and with the following alternative: No post-spin test inspections are performed and pre-spin test inspections are considered adequate because flaw growth attributable to the spin tests (that is, from a single reversal of stress, up to speed and back), under the most adverse conditions, is about three orders of magnitude smaller than that which nondestructive inspection techniques are capable of detecting.
The assumptions used for evaluating the potential radiological consequences of a loss-of-coolant accident at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183. Refer to the position on Regulatory Guide 1.183, later in this table.
 
This regulatory guide is not applicable to Beaver Valley Power Station
- Unit 2.
RG No. 1.5, Rev. 0 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A STEAM LINE BREAK ACCIDENT FOR BOILING WATER REACTORS (MARCH 10, 1971)
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
RG No. 1.6, Rev. 0 UFSAR Reference Sections 7.6, 8.3.1.4, 8.3.2, 7.6.1 INDEPENDENCE BETWEEN REDUNDANT STANDBY (ONSITE) POWER SOURCES AND BETWEEN THEIR DISTRIBUTION SYSTEMS (MARCH 10, 1971)
 
Methods for establishing the degree of independence between redundant standby (onsite) power sources and between their distribution systems at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.
RG No. 1.7, Rev. 2 UFSAR Reference Section 6.2.5
 
CONTROL OF COMBUSTIBLE GAS CONCENTRATIONS IN CONTAINMENT FOLLOWING A LOSS-OF-COOLANT ACCIDENT (NOVEMBER 1978)
 
The hydrogen control system was originally designed following the guidance of Regulatory Guide 1.7, but with the subsequent 10 CFR 50.44 rule change, the hydrogen recombiners are not required; therefore, the hydrogen recombiners may be maintained, modified or eliminated.
RG No. 1.8 UFSAR Reference Sections 12.5, 13.1, 13.2
 
PERSONNEL SELECTION AND TRAINING Application of Regulatory Guide 1.8 to the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 3 of 91 RG No. 1.9, Rev. 2 UFSAR Reference Sections 8.3.1.1.15, 14.2.12.54, 14.2.12.55
 
SELECTION, DESIGN, AND QUALIFICATION OF DIESEL-GENERATOR UNITS USED AS STANDBY (ONSITE) ELECTRIC POWER SYSTEMS AT NUCLEAR POWER PLANTS (DECEMBER 1979)
Diesel-generator units used as onsite electric power systems at BVPS-2 have been selected, designed, and qualified following the
 
guidance of this Regulatory Guide with the following alternative and clarifications:
The Class lE diesel generator units were designed and procured following the guidance of Regulatory Guide 1.9, Rev. 0 (March 1971) and IEEE Standard 387-1972.  (Revision
 
status at time of design/procurement)
However, the Class lE diesel generators were manufactured to IEEE Standard 387-1977 with the following clarifications:
: 1. Section 4.1[8]:  The BVPS-2 Class lE diesels are qualified utilizing the mild environment concept
 
acknowledged by 10 CFR 50.49(c).
: 2. Section 4.1[12]:  The BVPS-2 Class lE diesels are seismically qualified in accordance with IEEE Standard 344-1971.
: 3. Section 5.4:  The BVPS-2 Class lE diesels are qualified utilizing the mild environment concept acknowledged by 10 CFR 50.49(c).
: 4. Section 6.3.1:  All required tests or analyses have been performed by the manufacturer with the exception of the2-hour short-time/22-hour continuous rating
 
test. This test will be performed at the site in accordance with Section 6.3.1 and the loading sequence specified in Paragraph C.14 of Regulatory Guide 1.9.
RG No. 1.10, Rev. 1 UFSAR Reference Section 3.8.1.6.2
 
MECHANICAL (CADWELD) SPLICES IN REINFORCING BARS OF CATEGORY I CONCRETE STRUCTURES (JANUARY 2, 1973)
 
Regulatory Guide 1.10 was withdrawn (June 1981) and has been
 
superseded by Regulatory Guide 1.136 ("Materials, Construction, and Testing of Concrete Containments (Articles CC-1OOO, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containment)"). However, since a significant portion of Beaver Valley Power Station - Unit 2 design and construction was completed prior to the withdrawal of this regulatory guide, mechanical (Cadweld) splices in reinforcing bars of Category I concrete structures meet the intent of Regulatory Guide 1.10 with the following alternative:
 
BVPS-2 UFSAR Rev. 15  TABLE 1.8-1 (Cont) 4 of 91 Reinforcing bars with a radius of curvature 60 feet-0 inches or greater will be tested at the sampling frequency specified in Paragraphs C.4a and C.4b. Reinforcing bars with a radius of
 
curvature of less than 60 feet-0 inches will be tested using only sister splices with the following frequency for each splicing crew:
: 1. One sister splice representing the first 10 production
: splices,
: 2. Four sister splices representing the next 90 production splices, and
: 3. One sister splice representing the next and every subsequent 33 production splices.
Testing of the sister splices is in accordance with Paragraphs C.3 and C.5.
 
The acceptability of this alternative is based on the following:
The second paragraph of Section 3 of Regulatory Guide 1.10 states that production mechanical splice samples for tensile testing should not be used from curved reinforcing sections, and then refers to Paragraph 4b for sampling frequency. Paragraph 4b provides for a combination of production and sister splices, which appears to be an
 
inconsistency.
The regulatory guide assumes that the cadwelders perform splices in the horizontal, vertical, and diagonal directions on the same day. Thus, there would be occasional splices on straight vertical bars which could be alternated with the curve bar splicing to permit the frequency of testing in Paragraph 4b of Regulatory Guide 1.10, which requires both production and sister splices.  
 
However, construction is apt to perform splices in one position only for more splices than those requiring another set of tests. The 60-foot radius was established because satisfactory test results have been obtained for splices on bars of this or greater radii.
During the operations phase, splicing reinforcing bars shall be performed in accordance with individual project specifications. Project Specifications shall include or reference manufacturer's instructions and comply with the applicable requirements of ANSI N45.2.5-1974.
FENOC Quality Assurance Program Manual (QAPM) identifies specific subarticles of ASME Section III Division 2-1995 edition that will be used in lieu of the corresponding requirements in ANSI N45.2.5-1974.
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 5 of 91 RG No. 1.11, Rev. 0 UFSAR Reference Section 6.2.4  
 
INSTRUMENT LINES PENETRATING PRIMARY REACTOR CONTAINMENT (MARCH 10, 1971)
 
The guidance of this regulatory guide is followed for instrument lines penetrating primary reactor containment at Beaver Valley Power Station - Unit 2.  
 
RG No. 1.12, Rev. 1 UFSAR Reference Section 3.7B.4.
INSTRUMENTATION FOR EARTHQUAKES (APRIL 1974)
Earthquake instrumentation at Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide with the following exceptions based on industry experience:  
: 1) No triaxial accelerograph unit listed in Section 3.7B.4.2 is located on equipment, piping or supports since experience has shown that data obtained at these locations are obscured by the vibratory motion associated with normal plant operations.  
: 2) There is no immediate indication that the zero period acceleration at the containment mat has been exceeded via a switch. The system will determine within minutes whether actual conditions have exceeded a pre-determined building response spectra and provide indication if the 1/2-SSE has been exceeded.  
: 3) All instruments are oriented to the same azimuths, except one remote accelerograph sensor which is mounted to the containment cranewall. It is oriented such that it will respond to horizontal motion in the radial and tangential directions of the containment.  
 
RG No. 1.13, Rev. 1 UFSAR Reference Sections 9.1.2, 9.1.3, 9.1.4, 9.1.5 SPENT FUEL STORAGE FACILITY DESIGN BASIS (DECEMBER 1975)
The design of spent fuel storage facilities follows the guidance of this regulatory guide with the following alternative:
Local spent fuel pool level alarms are not provided. A fuel pool level alarm is provided in the control room.  
 
The motor-driven platform crane, which is the only crane that is operable over the spent fuel pool, has hoists that are each provided with an adjustable interlock which will  
 
stop hoist motion if a preset weight is exceeded. The setpoint is based upon the weight of a single fuel assembly. Accordingly, the interlock must be overridden  
 
in order to use the hoist for maintenance operations.  
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 6 of 91 Administrative procedures require that maintenance operations be carried out along a safe path away from the spent fuel pool. When the motor-driven crane is not in use, administrative procedures require that it be positioned away from the spent fuel pool.  
 
RG No. 1.14, Rev. 1 UFSAR Reference Section 5.4.1.5  
 
REACTOR COOLANT PUMP FLYWHEEL INTEGRITY (AUGUST 1975)
Reactor coolant pump flywheel integrity at Beaver Valley Power Station - Unit 2 is assured by meeting the intent of this regulatory guide as specified in WCAP-8163, September 1973,  
("Reactor Coolant Pump Integrity in LOCA") and with the following alternative:
No post-spin test inspections are performed and pre-spin test inspections are considered adequate because flaw growth attributable to the spin tests (that is, from a single reversal of stress, up to speed and back), under the most adverse conditions, is about three orders of magnitude smaller than that which nondestructive  
 
inspection techniques are capable of detecting.  


RG No. 1.15, Rev. 1 UFSAR Reference Section 3.8.1.6.2  
RG No. 1.15, Rev. 1 UFSAR Reference Section 3.8.1.6.2  


TESTING OF REINFORCING BARS FOR CATEGORY I CONCRETE STRUCTURES (DECEMBER 28, 1972)
TESTING OF REINFORCING BARS FOR CATEGORY I CONCRETE STRUCTURES (DECEMBER 28, 1972)
Regulatory Guide 1.15 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981 (Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, - 2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station -
Regulatory Guide 1.15 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981 (Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, - 2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station -
Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, testing of reinforcing bars for Category I concrete structures at BVPS-2 follows the guidance of this Regulatory Guide 1.15, Rev. 1. During the operations phase, splicing reinforcing bars shall be performed in accordance with individual project specifications. Project Specifications shall include or reference manufacturer's instructions and comply with the applicable requirements of ANSI N45.2.5-1974. FENOC Quality Assurance Program Manual (QAPM) identifies specific subarticles of ASME Section III Division 2-1995 edition that will be used in lieu of the corresponding requirements in ANSI N45.2.5-1974.  
Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, testing of reinforcing bars for Category I concrete structures at BVPS-2 follows the  
 
guidance of this Regulatory Guide 1.15, Rev. 1.
During the operations phase, splicing reinforcing bars shall be performed in accordance with individual project specifications. Project Specifications shall include or reference manufacturer's instructions and comply with the applicable requirements of ANSI N45.2.5-1974.
FENOC Quality Assurance Program Manual (QAPM) identifies specific subarticles of ASME Section III  
 
Division 2-1995 edition that will be used in lieu of the  
 
corresponding requirements in ANSI N45.2.5-1974.  
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 7 of 91 RG No. 1.16, Rev. 4 UFSAR Reference Chapter 16
 
REPORTING OF OPERATING INFORMATION - APPENDIX A TECHNICAL SPECIFICATIONS (AUGUST 1975)


BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont)  7 of 91 RG No. 1.16, Rev. 4 UFSAR Reference Chapter 16 REPORTING OF OPERATING INFORMATION - APPENDIX A TECHNICAL SPECIFICATIONS (AUGUST 1975)
Reporting of operating information for Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide, except for the Monthly Operating Report, which will follow the guidance provided in NRC Generic Letter 97-02, "Revised Contents of the Monthly Operating Report" dated May 15, 1997.
Reporting of operating information for Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide, except for the Monthly Operating Report, which will follow the guidance provided in NRC Generic Letter 97-02, "Revised Contents of the Monthly Operating Report" dated May 15, 1997.
RG No. 1.17, Rev. 1 UFSAR Reference Section 13.6 PROTECTION OF NUCLEAR POWER PLANTS AGAINST INDUSTRIAL SABOTAGE (JUNE 1973)
RG No. 1.17, Rev. 1 UFSAR Reference Section 13.6 PROTECTION OF NUCLEAR POWER PLANTS AGAINST INDUSTRIAL SABOTAGE (JUNE 1973)
The protection of Beaver Valley Power Station - Unit 2 against industrial sabotage is provided for by following the guidance of this regulatory guide.
 
The protection of Beaver Valley Power Station - Unit 2 against industrial sabotage is provided for by following the guidance of this regulatory guide.  
 
RG No. 1.18, Rev. 1 UFSAR Reference Section 3.8.1  
RG No. 1.18, Rev. 1 UFSAR Reference Section 3.8.1  


STRUCTURAL ACCEPTANCE TEST FOR CONCRETE PRIMARY REACTOR CONTAINMENTS (DECEMBER 28, 1972)
STRUCTURAL ACCEPTANCE TEST FOR CONCRETE PRIMARY REACTOR CONTAINMENTS (DECEMBER 28, 1972)
Regulatory Guide 1.18 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981 (Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station -
Regulatory Guide 1.18 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981 (Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station -
Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, the structural acceptance test for the containment structure at BVPS-2 follows the guidance of this regulatory guide with the following clarifications: As permitted by Paragraph C.3 of the Regulatory Guide, minor changes will be made in the selection of locations for deflection measurements around the access openings to account for the thickened ring beam. The containment structure is a nonprototype structure similar in design and construction to those referenced in UFSAR Section 3.8.1.1.1. Therefore, the regulatory positions for a nonprototype structure are followed.
Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, the structural acceptance test for the containment structure at BVPS-2 follows  
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 8 of 91 RG No. 1.19, Rev. 1 UFSAR Reference Sections 3.8.1.2.3, 3.8.1.7.2 NONDESTRUCTIVE EXAMINATION OF PRIMARY CONTAINMENT LINER WELDS (AUGUST 11, 1972)
 
Regulatory Guide 1.19 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981, ["Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")]. However, since a significant portion of BVPS-2 design and construction was completed prior to the withdrawal of this regulatory guide, nondestructive examination of primary containment liner welds at BVPS-2 meets the intent of Regulatory Guide 1.19 with the following alternatives: Paragraph C.1.d Where leak chase system channels are installed over liner seam welds, the nondestructive examination of these seam welds is to be done by either 1) use of a vacuum box test before application of the channel, or 2) application of soapsuds to the liner seam while the channel is air-pressurized to the calculated peak containment pressure. Necessary repairs are to be made up to completion of a successful leaktight test. After completion of this test, a test of the channel-to-liner welds is to be performed by either 1) evacuating the air from the channel, and then pressurizing with Freon 22 to calculated peak containment pressure and examining these welds with a Halogen detector, or 2) pressurizing the test channels to containment peak pressure with air; and, if any indicated loss of channel test pressure occurs, within 2 hours as evidenced by the test gage, the channel-to-liner welds should be soap bubble tested. Necessary repairs are to be made up to completion of a successful leaktight test. The Freon is to be purged after the test. Paragraphs C.2.a, C.7.a, C.7.b, and C.7.d Nondestructive test methods and acceptance standards are in accordance with ASME Section III, Subsection NE-5300, which corresponds to the referenced Subsection NE-5120. RG No. 1.20, Rev. 2 UFSAR Reference Section 3.9.2  
the guidance of this regulatory guide with the following clarifications:
As permitted by Paragraph C.3 of the Regulatory Guide, minor changes will be made in the selection of locations for deflection measurements around the access openings to  
 
account for the thickened ring beam.
The containment structure is a nonprototype structure similar in design and construction to those referenced in UFSAR Section 3.8.1.1.1. Therefore, the regulatory positions for a nonprototype structure are followed.  
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 8 of 91 RG No. 1.19, Rev. 1 UFSAR Reference Sections 3.8.1.2.3, 3.8.1.7.2  
 
NONDESTRUCTIVE EXAMINATION OF PRIMARY CONTAINMENT LINER WELDS (AUGUST 11, 1972)
 
Regulatory Guide 1.19 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981,  
["Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")]. However, since a significant portion of BVPS-2 design and construction was completed prior to the withdrawal of this regulatory guide, nondestructive examination of primary containment liner welds at BVPS-2 meets the intent of Regulatory Guide 1.19 with the  
 
following alternatives:
Paragraph C.1.d Where leak chase system channels are installed over liner seam welds, the nondestructive examination of these seam welds is to be done by either 1) use of a vacuum box test before application of the channel, or 2) application of soapsuds to the liner seam while the channel is air-pressurized to the calculated peak containment pressure.
Necessary repairs are to be made up to completion of a successful leaktight test.
After completion of this test, a test of the channel-to-
 
liner welds is to be performed by either 1) evacuating the air from the channel, and then pressurizing with Freon 22 to calculated peak containment pressure and examining these welds with a Halogen detector, or 2) pressurizing  
 
the test channels to containment peak pressure with air; and, if any indicated loss of channel test pressure occurs, within 2 hours as evidenced by the test gage, the channel-to-liner welds should be soap bubble tested.
Necessary repairs are to be made up to completion of a successful leaktight test. The Freon is to be purged  
 
after the test.
Paragraphs C.2.a, C.7.a, C.7.b, and C.7.d Nondestructive test methods and acceptance standards are in accordance with ASME Section III, Subsection NE-5300,  
 
which corresponds to the referenced Subsection NE-5120.
RG No. 1.20, Rev. 2 UFSAR Reference Section 3.9.2  


COMPREHENSIVE VIBRATION ASSESSMENT PROGRAM FOR REACTOR INTERNALS DURING PREOPERATIONAL AND INITIAL STARTUP TESTING (MAY 1976)
COMPREHENSIVE VIBRATION ASSESSMENT PROGRAM FOR REACTOR INTERNALS DURING PREOPERATIONAL AND INITIAL STARTUP TESTING (MAY 1976)
BVPS-2 follows the guidance of Regulatory Guide 1.20 for a comprehensive vibration assessment program which verifies the structural integrity of the reactor internals for flow-induced vibrations prior to commercial operation.
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 9 of 91 Briefly, this comprehensive program considers both the prototype reactor and subsequent reactors as follows: For each prototype reactor internals design, a program of vibration analysis, measurement, and inspection has been developed and reviewed by the USNRC. This is documented in WCAP-7879. The reactor internals similar to the prototype design are subjected during hot functional testing to the same system flow conditions imposed on the prototype design applicable, and for the same duration. Pre- and post-test inspections will be conducted to assure that the internals are well-behaved and that no excessive motion or wear are experienced. Refer to UFSAR Section 3.9N.2.4 for details on the testing and inspections.
BVPS-2 follows the guidance of Regulatory Guide 1.20 for a comprehensive vibration assessment program which verifies the structural integrity of the reactor internals for flow-induced  
RG No. 1.21, Rev. 1 UFSAR Reference Section 11.5.1 MEASURING, EVALUATING, AND REPORTING RADIOACTIVITY IN SOLID WASTES AND RELEASES OF RADIOACTIVE MATERIALS IN LIQUID AND GASEOUS EFFLUENTS FROM LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (JUNE 1974) The monitoring, evaluating and reporting of radioactivity in solid wastes and releases of radioactive materials in liquid and gaseous effluents at BVPS-2 will meet the intent of this regulatory guide with the following alternative: For the turbine building drains, grab sample systems are provided for each of the three transfer pump systems. Normally, grab samples will be taken on a weekly basis. However, in the event of a high activity alarm from the main steam discharge monitors or the steam generator blowdown sample monitor, grab samples from the turbine building drains will be taken on a hourly basis. If any of these samples exceeds a predetermined activity level, the isolation valve for that transfer system will be closed and the flow will be diverted to the liquid waste system.   
 
vibrations prior to commercial operation.  
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 9 of 91 Briefly, this comprehensive program considers both the prototype reactor and subsequent reactors as follows:
For each prototype reactor internals design, a program of vibration analysis, measurement, and inspection has been developed and reviewed by the USNRC. This is documented  
 
in WCAP-7879.
The reactor internals similar to the prototype design are subjected during hot functional testing to the same system flow conditions imposed on the prototype design applicable, and for the same duration. Pre- and post-test inspections will be conducted to assure that the internals are well-behaved and that no excessive motion or wear are experienced. Refer to UFSAR Section 3.9N.2.4 for details on the testing and inspections.  
 
RG No. 1.21, Rev. 1 UFSAR Reference Section 11.5.1 MEASURING, EVALUATING, AND REPORTING RADIOACTIVITY IN SOLID WASTES AND RELEASES OF RADIOACTIVE MATERIALS IN LIQUID AND GASEOUS EFFLUENTS FROM LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (JUNE 1974)
The monitoring, evaluating and reporting of radioactivity in solid wastes and releases of radioactive materials in liquid and gaseous effluents at BVPS-2 will meet the intent of this  
 
regulatory guide with the following alternative:
For the turbine building drains, grab sample systems are provided for each of the three transfer pump systems. Normally, grab samples will be taken on a weekly basis.
However, in the event of a high activity alarm from the main steam discharge monitors or the steam generator blowdown sample monitor, grab samples from the turbine building drains will be taken on a hourly basis. If any of these samples exceeds a predetermined activity level, the isolation valve for that transfer system will be closed and the flow will be diverted to the liquid waste  
 
system.   


RG No. 1.22, Rev. 0 UFSAR Reference Sections 7.1.2, 7.2, 7.3.2.2, 7.1.2.4  
RG No. 1.22, Rev. 0 UFSAR Reference Sections 7.1.2, 7.2, 7.3.2.2, 7.1.2.4  


PERIODIC TESTING OF PROTECTION SYSTEM ACTUATION FUNCTIONS (FEBRUARY 17, 1972)
PERIODIC TESTING OF PROTECTION SYSTEM ACTUATION FUNCTIONS (FEBRUARY 17, 1972)
Periodic testing of protection system actuation functions for Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide.  
Periodic testing of protection system actuation functions for Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide.  


BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 10 of 91 RG No. 1.23, Rev. 0 UFSAR Reference Section 2.3.3 ONSITE METEOROLOGICAL PROGRAMS (FEBRUARY 17, 1972)
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 10 of 91 RG No. 1.23, Rev. 0 UFSAR Reference Section 2.3.3  
Onsite meteorological programs for Beaver Valley Power Station -
 
Unit 2 will follow the guidance of this regulatory guide.
ONSITE METEOROLOGICAL PROGRAMS (FEBRUARY 17, 1972)
 
Onsite meteorological programs for Beaver Valley Power Station -  
 
Unit 2 will follow the guidance of this regulatory guide.  
 
RG No. 1.24, Rev. 0 UFSAR Reference Section 15.7.1.3  
RG No. 1.24, Rev. 0 UFSAR Reference Section 15.7.1.3  


ASSUMPTIONS USED FOR EVALUATING POTENTIAL RADIOLOGICAL CONSEQUENCES OF A PRESSURIZED WATER REACTOR RADIOACTIVE GAS STORAGE TANK FAILURE (MARCH 23, 1972) Beaver Valley Power Station - Unit 2 evaluation of the potential radiological consequences of a pressurized water reactor radioactive gas storage tank rupture meets the intent of this regulatory guide. The following alternatives were considered prudent:
ASSUMPTIONS USED FOR EVALUATING POTENTIAL RADIOLOGICAL CONSEQUENCES OF A PRESSURIZED WATER REACTOR RADIOACTIVE GAS STORAGE TANK FAILURE (MARCH 23, 1972)
Paragraph C.1.a In recognition of specific plant equipment arrangements for gaseous waste handling, the system component producing the worst environmental impact was identified and additional conservatism was appropriately applied. Paragraph C.2 Atmospheric diffusion (X/Q) values were calculated using the latest approved techniques which are provided in Regulatory Guide 1.145. BVPS takes some alternatives to Section C.3 dose calculation methodology.   
Beaver Valley Power Station - Unit 2 evaluation of the potential radiological consequences of a pressurized water reactor radioactive gas storage tank rupture meets the intent of this regulatory guide. The following alternatives were considered prudent:  
 
Paragraph C.1.a In recognition of specific plant equipment arrangements for gaseous waste handling, the system component producing the worst environmental impact was identified and  
 
additional conservatism was appropriately applied.
Paragraph C.2 Atmospheric diffusion (X/Q) values were calculated using the latest approved techniques which are provided in  
 
Regulatory Guide 1.145.
BVPS takes some alternatives to Section C.3 dose  
 
calculation methodology.  
 
RG No. 1.25, Rev. 0
 
ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A FUEL HANDLING ACCIDENT IN THE FUEL HANDLING AND STORAGE FACILITY FOR BOILING AND PRESSURIZED WATER REACTORS (MARCH 23, 1972)
The assumptions used for evaluating the potential radiological consequences of a fuel handling accident in the fuel handling and storage facility at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183. Refer to the position on Regulatory Guide 1.183, later in this table.
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
 
BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 11 of 91 RG NO. 1.26, Rev. 3 UFSAR Reference Section 3.2.2 QUALITY GROUP CLASSIFICATIONS AND STANDARDS FOR WATER-, STEAM-,
AND RADIOACTIVE-WASTE-CONTAINING COMPONENTS OF NUCLEAR POWER PLANTS (FEBRUARY 1976)
Quality group classifications and standards for water-, steam-,


RG No. 1.25, Rev. 0 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A FUEL HANDLING ACCIDENT IN THE FUEL HANDLING AND STORAGE FACILITY FOR BOILING AND PRESSURIZED WATER REACTORS (MARCH 23, 1972)  The assumptions used for evaluating the potential radiological consequences of a fuel handling accident in the fuel handling and storage facility at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183. Refer to the position on Regulatory Guide 1.183, later in this table.
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  11 of 91  RG NO. 1.26, Rev. 3 UFSAR Reference Section 3.2.2  QUALITY GROUP CLASSIFICATIONS AND STANDARDS FOR WATER-, STEAM-, AND RADIOACTIVE-WASTE-CONTAINING COMPONENTS OF NUCLEAR POWER PLANTS (FEBRUARY 1976)  Quality group classifications and standards for water-, steam-,
and radioactive-waste-containing components of Beaver Valley Power Station - Unit 2 meet the intent of Regulatory Guide 1.26 with the following alternatives:  
and radioactive-waste-containing components of Beaver Valley Power Station - Unit 2 meet the intent of Regulatory Guide 1.26 with the following alternatives:  
: 1. The safety class terminology of ANSI N18.2-1973 and ANSI N18.2a-1975 is used instead of the quality group terminology. Thus, the terms Safety Class 1, Safety Class 2, Safety Class 3, and Non-nuclear Safety (NNS) Class are used instead of Quality Groups A, B, C, and D, respectively, and are consistent with present nuclear industry practice. 2. Paragraph NB-7153 of the ASME Section III Code requires that there be no valves between a code safety valve and its relief point unless special interlocks prevent shutoff without other protection capacity. Therefore, as an alternative to Paragraphs C.1.e and C.2.c, a single safety valve designed, manufactured, and tested in accordance with ASME III Division 1 is considered acceptable as the boundary between the reactor coolant pressure boundary and a lower safety class or NNS class line.
: 1. The safety class terminology of ANSI N18.2-1973 and ANSI N18.2a-1975 is used instead of the quality group terminology. Thus, the terms Safety Class 1, Safety Class 2, Safety Class 3, and Non-nuclear Safety (NNS)
: 3. Portions of the emergency diesel generator cooling water system, considered by the vendor to be parts of the engine (as distinguished from auxiliary support systems), were built to the manufacturer's standards rather than ASME III. These are identified in Table 3.2-1 and Section 9.5.5. The components used are of high quality, proven by experience, and were designed, fabricated, erected, and tested under the vendor's Quality Assurance Program which meets the requirements of 10CFR5O, Appendix B. Similar equipment has been accepted by the NRC for other nuclear power plant applications. 4. Regarding Regulatory Positions C.1 and C.2, all instrument tubing, classified as Safety Class 2 or 3, are designed to ASME Section III rules and installed in accordance with the BVPS-2 quality assurance program for safety-related equipment.
Class are used instead of Quality Groups A, B, C, and  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 12 of 91 RG NO. 1.27, Rev. 2 UFSAR Reference Sections 2.4.11.6, 9.2.5 ULTIMATE HEAT SINK FOR NUCLEAR POWER PLANTS (JANUARY 1976)
 
The ultimate heat sink for Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide.
D, respectively, and are consistent with present nuclear industry practice.  
: 2. Paragraph NB-7153 of the ASME Section III Code requires that there be no valves between a code safety  
 
valve and its relief point unless special interlocks prevent shutoff without other protection capacity.
Therefore, as an alternative to Paragraphs C.1.e and C.2.c, a single safety valve designed, manufactured, and tested in accordance with ASME III Division 1 is considered acceptable as the boundary between the reactor coolant pressure boundary and a lower safety  
 
class or NNS class line.  
: 3. Portions of the emergency diesel generator cooling water system, considered by the vendor to be parts of the engine (as distinguished from auxiliary support systems), were built to the manufacturer's standards rather than ASME III. These are identified in Table 3.2-1 and Section 9.5.5. The components used are of high quality, proven by experience, and were designed, fabricated, erected, and tested under the vendor's Quality Assurance Program which meets the requirements of 10CFR5O, Appendix B. Similar equipment has been accepted by the NRC for other nuclear power plant applications.  
: 4. Regarding Regulatory Positions C.1 and C.2, all instrument tubing, classified as Safety Class 2 or 3,  
 
are designed to ASME Section III rules and installed in accordance with the BVPS-2 quality assurance program for safety-related equipment.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 12 of 91 RG NO. 1.27, Rev. 2 UFSAR Reference Sections 2.4.11.6, 9.2.5  
 
ULTIMATE HEAT SINK FOR NUCLEAR POWER PLANTS (JANUARY 1976)
 
The ultimate heat sink for Beaver Valley Power Station - Unit 2  
 
follows the guidance of this regulatory guide.  
 
RG No. 1.28, Rev. 2 UFSAR Reference Sections 17.1.2, 17.2  
RG No. 1.28, Rev. 2 UFSAR Reference Sections 17.1.2, 17.2  


QUALITY ASSURANCE PROGRAM REQUIREMENTS (DESIGN AND CONSTRUCTION) (FEBRUARY 1979)
QUALITY ASSURANCE PROGRAM REQUIREMENTS (DESIGN AND CONSTRUCTION)  
(FEBRUARY 1979)
 
This regulatory guide does not apply to the Beaver Valley Power Station - Unit 2 (BVPS-2) Quality Assurance Program since it is applicable to construction permit applicants docketed after October 1979. BVPS-2, docketed October 20, 1972, meets the requirements of Appendix B to 10 CFR 50 with the BVPS-2 Design and Construction Quality Assurance Program submitted and approved through Appendix A of the BVPS-2 PSAR. Regulatory Guide 1.28 does not apply to the BVPS-2 quality assurance program for plant operations since it is applicable only to the plant design and construction phase.  
This regulatory guide does not apply to the Beaver Valley Power Station - Unit 2 (BVPS-2) Quality Assurance Program since it is applicable to construction permit applicants docketed after October 1979. BVPS-2, docketed October 20, 1972, meets the requirements of Appendix B to 10 CFR 50 with the BVPS-2 Design and Construction Quality Assurance Program submitted and approved through Appendix A of the BVPS-2 PSAR. Regulatory Guide 1.28 does not apply to the BVPS-2 quality assurance program for plant operations since it is applicable only to the plant design and construction phase.  


Line 625: Line 2,992:


SEISMIC DESIGN CLASSIFICATION (SEPTEMBER 1978)
SEISMIC DESIGN CLASSIFICATION (SEPTEMBER 1978)
The seismic design classification of structures, systems, and components at Beaver Valley Power Station Unit 2 follows the guidance of Regulatory Guide 1.29 with the following clarification:
Components within the NSSS vendor scope of supply which are placed in Safety Class 3 per ANSI N18.2, Paragraphs 2.2.3 (l), (3), or (4) may be classified Seismic Category II if failure during or following an ANS Condition II event would result in consequences no more severe than allowed for an ANS Condition III event. For the Balance of Plant, each component which is required to mitigate the consequences of an accident, as defined in ANSI N18.2, shall be classified Seismic Category I. In addition, all components classified as Safety Class 1, 2, or 3 shall be designated Seismic Category I. Seismic Category I components, structures, and systems shall be designed to remain functional in the event of the safe shutdown earthquake (SSE). All Seismic Category I components are designed and constructed to Quality Assurance (QA) Category I requirements.


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 13 of 91 Portions of structures, systems, or components whose continued function after an SSE are not required, but whose failure could reduce the functioning of other safety-related structures, systems, or components shall be designated Seismic Category II. These structures, systems, or components shall either be seismically designed, located to preclude interactions, further restrained, structurally upgraded, or proven incapable of affecting safety.
The seismic design classification of structures, systems, and components at Beaver Valley Power Station Unit 2 follows the guidance of Regulatory Guide 1.29 with the following clarification:
Seismic Category I design requirements shall extend to the first seismic restraint beyond the seismic boundary and shall include the interface portion of the boundary itself (that is, for piping systems, the isolation valve at a boundary between Seismic Category I and nonseismic portions shall be designated Seismic Category I. The piping up to and including the first seismic restraint beyond the valve shall be designed to Seismic Category I requirements but, since the piping is not required to be ASME III Class 1, 2, or 3, shall not be designated Seismic Category I). By this means, the Seismic Category I boundary is defined with respect to safety-related function, and the interfacing portions meet the seismic design requirements in order to ensure the integrity of the boundary. Structures, systems, and components designed in accordance with Paragraphs C.2 and C.3 of the regulatory guide are designated Seismic Category II and are constructed to QA Category II or III requirements.
 
RG No. 1.30, Rev. 0 UFSAR Reference Sections 17.1, 17.2 QUALITY ASSURANCE REQUIREMENTS FOR THE INSTALLATION, INSPECTION, AND TESTING OF INSTRUMENTATION AND ELECTRIC EQUIPMENT (AUGUST 11, 1972)
Components within the NSSS vendor scope of supply which are placed in Safety Class 3 per ANSI N18.2, Paragraphs 2.2.3 (l), (3), or (4) may be classified Seismic Category II if failure during or following an ANS Condition II event would result in consequences no more severe than
The guidance provided by this regulatory guide for quality assurance requirements for the installation, inspection, and testing of instrumentation and electric equipment was followed during the construction phase of Beaver Valley Power Station Unit 2. Application of Regulatory Guide 1.30 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 14 of 91 RG No. 1.31, Rev. 3 UFSAR Reference Sections 4.5.2.4, 5.2.3.4.6, 5.3.1.4, 6.1.1.1, 10.3.6.2 CONTROL OF FERRITE CONTENT IN STAINLESS STEEL WELD METAL (APRIL 1978)
allowed for an ANS Condition III event.
For nuclear steam supply system fabrication, Beaver Valley Power Station -  Unit  2 (BVPS-2) meets the intent of Regulatory Guide 1.31 for control of ferrite content in stainless steel weld metal by following acceptable alternative criteria. Westinghouse submitted a delta ferrite verification program for austenitic stainless steel weldments in WCAP-8324-A, June 1974, which the staff subsequently approved as a valid approach in a letter on December 30, 1974.
For the Balance of Plant, each component which is required to mitigate the consequences of an accident, as defined in ANSI N18.2, shall be classified Seismic Category I. In addition, all components classified as Safety Class 1, 2, or 3 shall be designated Seismic Category I. Seismic Category I components, structures, and systems shall be designed to remain functional in the event of the safe
For balance of plant fabrication, BVPS-2 meets the intent of Regulatory Guide 1.31 by following the guidance of either Safety Guide 31, Regulatory Guide 1.31, Revision 1, Materials Engineering Branch Technical Position MTEB 5-1, or Regulatory Guide 1.31, Revision 3.
 
Following the guidance of any of the preceding document revisions was based primarily on the revision in effect on the date of the last specification revision wherein the regulatory guide was invoked. Since each revision of the regulatory guide is less restrictive than the foregoing, following the guidance of any of the revisions is considered acceptable.
shutdown earthquake (SSE). All Seismic Category I components are designed and constructed to Quality Assurance (QA) Category I requirements.
RG No. 1.32, Rev. 2 UFSAR Reference Sections 7.5, 8.1.5, 8.2, 8.3.1, 8.3.2, 7.5.2.3.1.3 CRITERIA FOR SAFETY-RELATED ELECTRIC POWER SYSTEMS FOR NUCLEAR POWER PLANTS (FEBRUARY 1977)
 
The design of the safety-related electric power systems for Beaver Valley Power Station - Unit 2 (BVPS-2) follows IEEE Standard 308-1974, and the guidance of Regulatory Guide 1.32, with the following clarifications: Two immediate access offsite power circuits are provided. Each circuit is designed to be immediately available following a loss of onsite alternating current power supplies so that sufficient power capacity remains for an orderly shutdown and to supply all train related engineered safety feature loads:
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 13 of 91 Portions of structures, systems, or components whose continued function after an SSE are not required, but whose failure could reduce the functioning of other safety-related structures, systems, or components shall be designated Seismic Category II. These structures, systems, or components shall either be seismically  
Each battery charger that supplies Class IE 125 V dc systems is designed with full capacity and capability to supply the largest combined demands of the various steady state loads while simultaneously providing sufficient power for adequate charging capacity to restore the battery from the design minimum charged state to the charged state irrespective of the BVPS-2 status during which these demands occur.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 15 of 91 For test methods, procedures, and intervals for all Class IE battery performance discharge and service tests, refer to the position on Regulatory Guide 1.129. RG No. 1.33 UFSAR Reference Sections 13.4, 13.5, 17.2  
designed, located to preclude interactions, further restrained, structurally upgraded, or proven incapable of affecting safety.  
 
Seismic Category I design requirements shall extend to the first seismic restraint beyond the seismic boundary and shall include the interface portion of the boundary itself (that is, for piping systems, the isolation valve at a boundary between Seismic Category I and nonseismic portions shall be designated Seismic Category I. The piping up to and including the first seismic restraint beyond the valve shall be designed to Seismic Category I requirements but, since the piping is not required to be ASME III Class 1, 2, or 3, shall not be designated Seismic Category I). By this means, the Seismic Category I boundary is defined with respect to safety-related function, and the interfacing portions meet the seismic design requirements in order to ensure the integrity of  
 
the boundary.
Structures, systems, and components designed in accordance with Paragraphs C.2 and C.3 of the regulatory guide are designated Seismic Category II and are constructed to QA Category II or III requirements.  
 
RG No. 1.30, Rev. 0 UFSAR Reference Sections 17.1, 17.2  
 
QUALITY ASSURANCE REQUIREMENTS FOR THE INSTALLATION, INSPECTION, AND TESTING OF INSTRUMENTATION AND ELECTRIC EQUIPMENT (AUGUST 11, 1972)
 
The guidance provided by this regulatory guide for quality assurance requirements for the installation, inspection, and testing of instrumentation and electric equipment was followed  
 
during the construction phase of Beaver Valley Power Station Unit 2. Application of Regulatory Guide 1.30 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual
.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 14 of 91 RG No. 1.31, Rev. 3 UFSAR Reference Sections 4.5.2.4, 5.2.3.4.6, 5.3.1.4, 6.1.1.1, 10.3.6.2  
 
CONTROL OF FERRITE CONTENT IN STAINLESS STEEL WELD METAL (APRIL 1978)
 
For nuclear steam supply system fabrication, Beaver Valley Power Station -  Unit  2 (BVPS-2) meets the intent of Regulatory Guide 1.31 for control of ferrite content in stainless steel weld metal by following acceptable alternative criteria. Westinghouse submitted a delta ferrite verification program for austenitic stainless steel weldments in WCAP-8324-A, June 1974, which the staff subsequently approved as a valid approach in a letter on December 30, 1974.  
 
For balance of plant fabrication, BVPS-2 meets the intent of Regulatory Guide 1.31 by following the guidance of either Safety Guide 31, Regulatory Guide 1.31, Revision 1, Materials Engineering Branch Technical Position MTEB 5-1, or Regulatory Guide 1.31, Revision 3.  
 
Following the guidance of any of the preceding document revisions was based primarily on the revision in effect on the date of the last specification revision wherein the regulatory guide was invoked. Since each revision of the regulatory guide is less restrictive than the foregoing, following the guidance  
 
of any of the revisions is considered acceptable.  
 
RG No. 1.32, Rev. 2 UFSAR Reference Sections 7.5, 8.1.5, 8.2, 8.3.1, 8.3.2,  
 
7.5.2.3.1.3  
 
CRITERIA FOR SAFETY-RELATED ELECTRIC POWER SYSTEMS FOR NUCLEAR POWER PLANTS (FEBRUARY 1977)
 
The design of the safety-related electric power systems for Beaver Valley Power Station - Unit 2 (BVPS-2) follows IEEE Standard 308-1974, and the guidance of Regulatory Guide 1.32, with the following clarifications:
Two immediate access offsite power circuits are provided. Each circuit is designed to be immediately available following a loss of onsite alternating current power supplies so that sufficient power capacity remains for an orderly shutdown and to supply all train related engineered safety feature loads:  
 
Each battery charger that supplies Class IE 125 V dc systems is designed with full capacity and capability to supply the largest combined demands of the various steady state loads while simultaneously providing sufficient power for adequate charging capacity to restore the  
 
battery from the design minimum charged state to the charged state irrespective of the BVPS-2 status during which these demands occur.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 15 of 91 For test methods, procedures, and intervals for all Class IE battery performance discharge and service tests, refer  
 
to the position on Regulatory Guide 1.129.
RG No. 1.33 UFSAR Reference Sections 13.4, 13.5, 17.2  


QUALITY ASSURANCE PROGRAM REQUIREMENTS (OPERATION)
QUALITY ASSURANCE PROGRAM REQUIREMENTS (OPERATION)
Application of Regulatory Guide 1.33 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
Application of Regulatory Guide 1.33 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.34, Rev. 0 UFSAR Reference Section 5.2.3 CONTROL OF ELECTROSLAG WELD PROPERTIES (DECEMBER 28, 1972) The guidance provided by this regulatory guide regarding control of electroslag weld properties was followed for fabrication of applicable components for Beaver Valley Power Station - Unit 2.
RG No. 1.34, Rev. 0 UFSAR Reference Section 5.2.3  
RG NO. 1.35, Rev. 2 INSERVICE INSPECTION OF UNGROUTED TENDONS IN PRESTRESSED CONCRETE CONTAINMENT STRUCTURES (JANUARY 1976)
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
CONTROL OF ELECTROSLAG WELD PROPERTIES (DECEMBER 28, 1972)
RG No. 1.36, Rev. 0 UFSAR Reference Sections 5.2.3, 6.1.1 NONMETALLIC THERMAL INSULATION FOR AUSTENITIC STAINLESS STEEL (FEBRUARY 23, 1973)
The guidance provided by this regulatory guide regarding control of electroslag weld properties was followed for fabrication of applicable components for Beaver Valley Power Station - Unit 2.  
Nonmetallic thermal insulation for austenitic stainless steel used at Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide. As an alternative to controlled packaging and shipping described in Paragraph C.1, receipt inspection and tests are required by specification. This testing and inspection consists of visual inspection for physical or water damage to all cartons. Damaged cartons are segregated. Potentially contaminated insulation is not accepted, unless randomly selected samples from each carton are shown to be acceptable after being resubjected to the production test outlined in this regulatory guide.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 16 of 91 RG NO. 1.37, Rev. 0 UFSAR Reference Sections 6.1.1.1, 17.2, 5.2.3.4.1 QUALITY ASSURANCE REQUIREMENTS FOR CLEANING OF FLUID SYSTEMS AND ASSOCIATED COMPONENTS OF WATER-COOLED NUCLEAR POWER PLANTS (MARCH 16, 1973) During the construction phase, quality assurance requirements for cleaning of fluid systems and associated components at Beaver Valley Power Station - Unit 2 met the intent of this regulatory guide with the following alternatives:
RG NO. 1.35, Rev. 2 INSERVICE INSPECTION OF UNGROUTED TENDONS IN PRESTRESSED CONCRETE CONTAINMENT STRUCTURES (JANUARY 1976)
Paragraph C.3 The water quality for final flushes of fluid systems and associated components is at least equivalent to the quality of the operating system water, except for the oxygen content.
 
Dissolved oxygen content of water cannot be maintained at reactor quality during flushing of open systems.
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.  
The maximum particle size criteria for class B cleanness is consistent with Section 3.1.2 except in  the Recirculation Spray System (RSS). Particles of a maximum size of 1/8 inch in any dimension are allowed in the RSS. This particle size limit was chosen since it is smaller than the openings in the recirculation spray system nozzles and the smallest coolant flow channel in the reactor core. Therefore, this exception will have no effect on the recirculation spray systems ability to perform its intended safety function. Paragraph C.4 Expendable materials, that is, inks and related products, temperature indicating sticks, tapes, gummed labels, wrapping materials (other than polyethylene), water soluble dam materials, lubricants, nondestructive testing penetrant materials and couplants which contact stainless steel or nickel alloy surfaces are in accordance with the following: 1. They do not contain the following as basic and essential chemical constituents:  lead, zinc, copper, mercury, cadmium and other low melting point metals, their alloys and/or compounds. 2. Prescribed maximum levels of water leachable chlorides, total halogens, and sulfur and its compounds are imposed on expendable products.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 17 of 91 Contamination levels in expendable products are based upon safe practices and industrial availability. Contaminant levels are controlled such that subsequent removal by standard cleaning methods will result in the achievement of final acceptable levels which are not detrimental to the materials.
RG No. 1.36, Rev. 0 UFSAR Reference Sections 5.2.3, 6.1.1 NONMETALLIC THERMAL INSULATION FOR AUSTENITIC STAINLESS STEEL (FEBRUARY 23, 1973)
 
Nonmetallic thermal insulation for austenitic stainless steel used at Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide. As an alternative to controlled packaging and shipping described in Paragraph C.1, receipt inspection and tests are required by specification. This testing and inspection consists of visual inspection for physical or water damage to all cartons. Damaged cartons are segregated. Potentially contaminated insulation is not accepted, unless randomly selected samples from each carton are shown to be acceptable after being resubjected to the production  
 
test outlined in this regulatory guide.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 16 of 91 RG NO. 1.37, Rev. 0 UFSAR Reference Sections 6.1.1.1, 17.2, 5.2.3.4.1  
 
QUALITY ASSURANCE REQUIREMENTS FOR CLEANING OF FLUID SYSTEMS AND ASSOCIATED COMPONENTS OF WATER-COOLED NUCLEAR POWER PLANTS (MARCH 16, 1973)
During the construction phase, quality assurance requirements for cleaning of fluid systems and associated components at Beaver Valley Power Station - Unit 2 met the intent of this regulatory guide with the following alternatives:  
 
Paragraph C.3 The water quality for final flushes of fluid systems and associated components is at least equivalent to the quality of the operating system water, except for the oxygen content.  
 
Dissolved oxygen content of water cannot be maintained at reactor quality during flushing of open systems.  
 
The maximum particle size criteria for class B cleanness is consistent with Section 3.1.2 except in  the  
 
Recirculation Spray System (RSS).
Particles of a maximum size of 1/8 inch in any dimension  
 
are allowed in the RSS. This particle size limit was chosen since it is smaller than the openings in the recirculation spray system nozzles and the smallest coolant flow channel in the reactor core. Therefore, this exception will have no effect on the recirculation spray systems ability to perform its intended safety function.
Paragraph C.4 Expendable materials, that is, inks and related products, temperature indicating sticks, tapes, gummed labels, wrapping materials (other than polyethylene), water  
 
soluble dam materials, lubricants, nondestructive testing penetrant materials and couplants which contact stainless steel or nickel alloy surfaces are in accordance with the  
 
following:  
: 1. They do not contain the following as basic and essential chemical constituents:  lead, zinc, copper, mercury, cadmium and other low melting point metals, their alloys and/or compounds.  
: 2. Prescribed maximum levels of water leachable chlorides, total halogens, and sulfur and its compounds are imposed on expendable products.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 17 of 91 Contamination levels in expendable products are based upon safe practices and industrial availability. Contaminant levels are controlled such that subsequent removal by standard cleaning methods will result in the achievement of final acceptable levels which are not detrimental to the materials.  
 
Application of Regulatory Guide 1.37 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.   
Application of Regulatory Guide 1.37 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.   


RG No. 1.38 UFSAR Reference Section 17.2  
RG No. 1.38 UFSAR Reference Section 17.2  


QUALITY ASSURANCE REQUIREMENTS FOR PACKAGING, SHIPPING, RECEIVING, STORAGE, AND HANDLING OF ITEMS FOR WATER-COOLED NUCLEAR POWER PLANTS Application of Regulatory Guide 1.38 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
QUALITY ASSURANCE REQUIREMENTS FOR PACKAGING, SHIPPING, RECEIVING, STORAGE, AND HANDLING OF ITEMS FOR WATER-COOLED NUCLEAR POWER PLANTS Application of Regulatory Guide 1.38 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.39, UFSAR Reference Sections 12.5.3, 17.2 HOUSEKEEPING REQUIREMENTS FOR WATER-COOLED NUCLEAR POWER PLANTS Application of Regulatory Guide 1.39 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.39, UFSAR Reference Sections 12.5.3, 17.2
 
HOUSEKEEPING REQUIREMENTS FOR WATER-COOLED NUCLEAR POWER PLANTS Application of Regulatory Guide 1.39 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.40, Rev. 0 UFSAR Reference Sections 3.11, 8.3  
RG No. 1.40, Rev. 0 UFSAR Reference Sections 3.11, 8.3  


QUALIFICATION TESTS OF CONTINUOUS-DUTY MOTORS INSTALLED INSIDE THE CONTAINMENT OF WATER-COOLED NUCLEAR POWER PLANTS (MARCH 16, 1973)  This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2 since there are no continuous-duty Class IE motors installed inside the containment.
QUALIFICATION TESTS OF CONTINUOUS-DUTY MOTORS INSTALLED INSIDE THE CONTAINMENT OF WATER-COOLED NUCLEAR POWER PLANTS (MARCH 16, 1973)  This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2 since there are no continuous-duty Class IE  
 
motors installed inside the containment.  
 
RG No. 1.41, Rev. 0 UFSAR Reference Sections 8.1, 8.3, 14.2.12.54  
RG No. 1.41, Rev. 0 UFSAR Reference Sections 8.1, 8.3, 14.2.12.54  


PREOPERATIONAL TESTING OF REDUNDANT ONSITE ELECTRIC POWER SYSTEMS TO VERIFY PROPER LOAD GROUP ASSIGNMENTS (MARCH 16, 1973)
PREOPERATIONAL TESTING OF REDUNDANT ONSITE ELECTRIC POWER SYSTEMS TO VERIFY PROPER LOAD GROUP ASSIGNMENTS (MARCH 16, 1973)
Onsite electric power systems at Beaver Valley Power Station - Unit 2 designed in accordance with Regulatory Guides 1.6 and 1.32 will be tested in accordance with the intent of Regulatory Guide 1.41 during preoperational testing. Following major modifications or repairs appropriate testing will be performed to demonstrate operability and functional capability as required.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 18 of 91 RG No. 1.42, Rev. 1 INTERIM LICENSING POLICY ON AS LOW AS PRACTICABLE FOR GASEOUS RADIOIODINE RELEASES FROM LIGHT-WATER COOLED NUCLEAR POWER REACTORS (MARCH 1976)
Onsite electric power systems at Beaver Valley Power Station - Unit 2 designed in accordance with Regulatory Guides 1.6 and 1.32 will be tested in accordance with the intent of Regulatory  
This regulatory guide was withdrawn March 1976.
 
Guide 1.41 during preoperational testing. Following major modifications or repairs appropriate testing will be performed to demonstrate operability and functional capability as  
 
required.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 18 of 91 RG No. 1.42, Rev. 1 INTERIM LICENSING POLICY ON AS LOW AS PRACTICABLE FOR GASEOUS RADIOIODINE RELEASES FROM LIGHT-WATER COOLED NUCLEAR POWER REACTORS (MARCH 1976)
 
This regulatory guide was withdrawn March 1976.  
 
RG No. 1.43, Rev. 0 UFSAR Reference Section 5.3.1.4, 5.2.3.3.2  
RG No. 1.43, Rev. 0 UFSAR Reference Section 5.3.1.4, 5.2.3.3.2  


CONTROL OF STAINLESS STEEL WELD CLADDING OF LOW-ALLOY STEEL COMPONENTS (MAY 1973)
CONTROL OF STAINLESS STEEL WELD CLADDING OF LOW-ALLOY STEEL COMPONENTS (MAY 1973)
For balance-of-plant components, Regulatory Guide 1.43 is not applicable, since stainless steel weld cladding of low-alloy steel is not used in fabrication of such components.
For NSSS components, Beaver Valley Power Station - Unit 2 follows the guidance of Regulatory Guide 1.43 with the exception of Paragaph C.1.a. For Paragraph C.1.a, Westinghouse practices are considered to achieve the same purpose as Regulatory Guide 1.43 by requiring qualification of any high heat input process used on ASME SA-508 Class 2 material by following the recommendations of Paragraph C.2 of the regulatory guide.
RG No. 1.44, Rev. 0 UFSAR Reference Sections 4.5.1, 4.5.2.4, 5.2.3.4, 5.3.1.4, 6.1.1.1, 10.3.6.2  CONTROL OF THE USE OF SENSITIZED STAINLESS STEEL (MAY 1973)  Control of the use of stainless steels subject to sensitization at BVPS-2 meets the intent of Regulatory Guide 1.44 with the following clarifications and alternatives:  The following applies to NSSS fabrication with respect to Regulatory Position C.3:  The Westinghouse practice is that austenitic stainless steel materials of product forms with simple shapes need not be corrosion tested provided that the solution heat treatment is followed by water quenching. Simple shapes are defined as all plates, sheets, bars, pipe, and tubes, as well as forgings, fittings, and other shaped products which do not have inaccessible cavities or chambers that would preclude rapid cooling when water quenched. Stainless steel cast metal and weld deposits (including weld deposited safe ends), which contain a minimum of 5 percent ferrite, are not considered to be susceptible to sensitization, and therefore, are not corrosion tested. When testing is required, the tests are performed in accordance with ASTM A262-70, BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  19 of 91 Practice A or E, as amended by Westinghouse Process Specification 84201MW. This process specification supplements the A262 specification since the latter does not define specimen removal location and does not adequately define bend testing criteria for thick and complex stainless steel raw material. The Westinghouse specification requires that 1) specimens be removed from the same location from which mechanical test specimens are removed, and 2) the bend test diameter must be 4X material thickness instead of 1X (Paragraph 36.1, ASTM A262-70). This second modification is based on the fact that almost all stainless steel materials procured by Westinghouse are eventually welded, and the 4X thickness bend test diameter is required for weldments.
The following applies to balance of plant fabrication with respect to Regulatory Position C.6:  1. The ASTM A708-74 standard is used to perform the intergranular corrosion testing for field fabrication and erection of ASME III piping. The radius of the bend specimen is as specified in ASME IX with the weld metal-base metal interface located at the centerline of the bend. 2. Shop fabrication of ASME III piping and field fabrication of ASME III tanks require control of heat input during welding so as to avoid severe sensitization of the weld zone. The heat input during shop fabrication of  ASME III piping is based on procedure qualifications in accordance with Regulatory Guide 1.31, Rev. 1, and, during field fabrication of ASME III tanks, is 50,000 (maximum) joules per inch. In addition, the maximum interpass temperature is limited to 350F. While no testing for intergranular corrosion during weld procedure qualification is required, the above controls ensure that base material will not be severely sensitized during welding. 3. Fabrication of ASME III components other than those identified in Items 1 and 2 above is performed in fabrication shops and requires a maximum interpass temperature of 350F. While no testing for intergranular corrosion during weld procedure qualification is required, this specific control reduces the possibility of a severely sensitized heat-affected zone during welding. In addition, the need for the shop fabricator to provide unsensitized components is specifically identified in all procurement specifications by requiring supplied material to be capable of meeting ASTM A262, Practice A or E. Shop practice generally recognizes the need to limit heat input during welding through good fit-up, adequate welder accessibility, proper positioning, BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  20 of 91 and close supervision. Finally, most of the pressure retaining components of the reactor coolant pressure boundary piping system are castings and, because of their delta ferrite content, are highly resistant to stress corrosion cracking. The following applies to the operational phase of BVPS-2.
Stainless wrought products of the AISI Type 304 and 316 will be obtained in the solution heat treatment condition with a sufficiently rapid cooling through the 800F to 1500F range by water quench. Materials not meeting this condition (oil or air quench) will be tested for sensitization in accordance with ASTM A262-70, Practice A or E, or with ASTM A708, and bent for examination in accordance with weld test bending requirements of ASME Section IX.
Qualification of AISI Type 304 and 316 welding procedures will be in accordance with the requirements of ASME Section IX except that the maximum amperage (heat input) specified in weld technique sheets shall not exceed that qualified by the controlling Weld Procedure Qualification Report. Materials used for qualification will be commercially available AISI Type 304 and 316. ASTM A708 shall be used as the corrosion test on bend specimens to demonstrate that the welding procedure has not caused the base metal heat affected zone to become excessively sensitized. Corrosion test bend specimens shall consist of two side bends or one face bend and one root bend as required by ASME Section IX taken from the qualification test plate thickness. Corrosion test bend specimens shall be bent over the appropriate radius specified in  ASME IX for bend specimens with the weld metal-base metal interface located at the centerline of the bend. The specimens shall be evaluated as stated in ASTM A708 and shall indicate the absence of intergranular attack.
Corrosion tests shall be incorporated as part of the weld procedure qualification test record. RG No. 1.45, Rev. 0 UFSAR Reference Section 5.2.5  REACTOR COOLANT PRESSURE BOUNDARY LEAKAGE DETECTION SYSTEMS (MAY 1973)
The leakage detection systems provided to detect leakage from the reactor coolant pressure boundary (RCPB) meet the intent of Regulatory Guide 1.45 with the following clarification of Paragraph C.5 and alternative to Paragraph C.6:
BVPS-2 UFSAR Rev. 15  TABLE 1.8-1 (Cont)  21 of 91 Paragraph C.5  The sensitivity and response time of each leakage detection system employed to collect unidentified leakage are as  shown in the following table:  SYSTEM SENSITIVITY AND RESPONSE TIME Sump levels 1 gpm in less than 1 hour Air cooler condensate  Drain flow rate 1 gpm in less than 1 hour Air cooler outlet Water temperature increase 


5 gpm in 1 hour Containment atmosphere humidity, temperature, and pressure   
For balance-of-plant components, Regulatory Guide 1.43 is not applicable, since stainless steel weld cladding of low-alloy steel is not used in fabrication of such components.
 
For NSSS components, Beaver Valley Power Station - Unit 2 follows the guidance of Regulatory Guide 1.43 with the exception of Paragaph C.1.a. For Paragraph C.1.a, Westinghouse practices are considered to achieve the same purpose as Regulatory Guide 1.43 by requiring qualification of any high heat input process used on ASME SA-508 Class 2 material by following the recommendations of Paragraph C.2 of the regulatory guide.
 
RG No. 1.44, Rev. 0 UFSAR Reference Sections 4.5.1, 4.5.2.4, 5.2.3.4, 5.3.1.4, 6.1.1.1, 10.3.6.2 CONTROL OF THE USE OF SENSITIZED STAINLESS STEEL (MAY 1973)
Control of the use of stainless steels subject to sensitization at BVPS-2 meets the intent of Regulatory Guide 1.44 with the
 
following clarifications and alternatives:
The following applies to NSSS fabrication with respect to Regulatory Position C.3:
The Westinghouse practice is that austenitic stainless steel materials of product forms with simple shapes need not be corrosion tested provided that the solution heat treatment is followed by water
 
quenching. Simple shapes are defined as all plates, sheets, bars, pipe, and tubes, as well as forgings, fittings, and other shaped products which do not have inaccessible cavities or chambers that would preclude rapid cooling when water quenched. Stainless steel cast metal and weld deposits (including weld deposited safe ends), which contain a minimum of 5 percent ferrite, are not considered to be susceptible to sensitization, and therefore, are not corrosion tested. When testing is required, the tests are performed in accordance with ASTM A262-70, BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 19 of 91 Practice A or E, as amended by Westinghouse Process Specification 84201MW. This process specification supplements the A262 specification since the latter does not define specimen removal location and does not adequately define bend testing criteria for thick and complex stainless steel raw material. The
 
Westinghouse specification requires that 1) specimens be removed from the same location from which mechanical test specimens are removed, and 2) the bend test diameter must be 4X material thickness instead of 1X (Paragraph 36.1, ASTM A262-70). This second modification is based on the fact that almost
 
all stainless steel materials procured by Westinghouse are eventually welded, and the 4X thickness bend test diameter is required for
 
weldments.
 
The following applies to balance of plant fabrication with
 
respect to Regulatory Position C.6:
: 1. The ASTM A708-74 standard is used to perform the intergranular corrosion testing for field fabrication
 
and erection of ASME III piping. The radius of the bend specimen is as specified in ASME IX with the weld metal-base metal interface located at the centerline of the bend.
: 2. Shop fabrication of ASME III piping and field fabrication of ASME III tanks require control of heat input during welding so as to avoid severe sensitization of the weld zone. The heat input during shop fabrication of  ASME III piping is based on procedure qualifications in accordance with Regulatory
 
Guide 1.31, Rev. 1, and, during field fabrication of ASME III tanks, is 50,000 (maximum) joules per inch. In addition, the maximum interpass temperature is limited to 350F. While no testing for intergranular corrosion during weld procedure qualification is required, the above controls ensure that base material will not be severely sensitized during welding.
: 3. Fabrication of ASME III components other than those identified in Items 1 and 2 above is performed in fabrication shops and requires a maximum interpass temperature of 350F. While no testing for intergranular corrosion during weld procedure qualification is required, this specific control reduces the possibility of a severely sensitized heat-affected zone during welding. In addition, the need for the shop fabricator to provide unsensitized
 
components is specifically identified in all procurement specifications by requiring supplied material to be capable of meeting ASTM A262, Practice A or E. Shop practice generally recognizes the need to limit heat input during welding through good fit-up, adequate welder accessibility, proper positioning, BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 20 of 91 and close supervision. Finally, most of the pressure retaining components of the reactor coolant pressure boundary piping system are castings and, because of their delta ferrite content, are highly resistant to stress corrosion cracking.
The following applies to the operational phase of BVPS-2.
 
Stainless wrought products of the AISI Type 304 and 316 will be obtained in the solution heat treatment condition
 
with a sufficiently rapid cooling through the 800F to 1500F range by water quench. Materials not meeting this
 
condition (oil or air quench) will be tested for
 
sensitization in accordance with ASTM A262-70, Practice A
 
or E, or with ASTM A708, and bent for examination in accordance with weld test bending requirements of ASME
 
Section IX.
 
Qualification of AISI Type 304 and 316 welding procedures will be in accordance with the requirements of ASME Section IX except that the maximum amperage (heat input) specified in weld technique sheets shall not exceed that
 
qualified by the controlling Weld Procedure Qualification Report. Materials used for qualification will be commercially available AISI Type 304 and 316. ASTM A708
 
shall be used as the corrosion test on bend specimens to demonstrate that the welding procedure has not caused the base metal heat affected zone to become excessively sensitized. Corrosion test bend specimens shall consist of two side bends or one face bend and one root bend as required by ASME Section IX taken from the qualification test plate thickness. Corrosion test bend specimens shall be bent over the appropriate radius specified in  ASME IX for bend specimens with the weld metal-base metal interface located at the centerline of the bend. The specimens shall be evaluated as stated in ASTM A708 and shall indicate the absence of intergranular attack.
Corrosion tests shall be incorporated as part of the weld procedure qualification test record.
RG No. 1.45, Rev. 0 UFSAR Reference Section 5.2.5 REACTOR COOLANT PRESSURE BOUNDARY LEAKAGE DETECTION SYSTEMS (MAY 1973)
The leakage detection systems provided to detect leakage from the reactor coolant pressure boundary (RCPB) meet the intent of Regulatory Guide 1.45 with the following clarification of Paragraph C.5 and alternative to Paragraph C.6:
 
BVPS-2 UFSAR Rev. 15  TABLE 1.8-1 (Cont) 21 of 91 Paragraph C.5 The sensitivity and response time of each leakage detection system employed to collect unidentified leakage are as  shown in the following table:
SYSTEM SENSITIVITY AND RESPONSE TIME Sump levels 1 gpm in less than 1 hour Air cooler condensate Drain flow rate
 
1 gpm in less than 1 hour Air cooler outlet
 
Water temperature
 
increase
 
5 gpm in 1 hour Containment atmosphere  
 
humidity, temperature,  
 
and pressure  
 
5 gpm in 1 hour Containment atmosphere
 
radioactivity monitor
 
1 gpm in less than 1 hour assuming primary coolant radioactivity concentrations stated in the environmental report. For other conditions the equilibrium activity of the reactor coolant must be sufficiently high and the equilibrium activity of the containment atmosphere must be below a level that would mask the change in activity corresponding to this leak
 
rate. Paragraph C.6 BVPS-2 does not fully follow the guidance of Paragraph C.6 in that the containment sump level detection systems which meet the detection sensitivity requirements of normal plant operation (that is, 1 gpm in 1 hour) are not designed to meet seismic requirements. However, a
 
seismically qualified, less sensitive, additional sump level instrumentation system, powered from Class IE electrical buses, is provided with remote displays in the control room to monitor for excessive leakage following seismic events. This instrumentation is qualified for seismic loads up to safe shutdown earthquake loads.
 
The SWEC interpretation of the RCPB leakage detection system requirements and Paragraph C.5 of Regulatory Guide 1.45 agrees with the USNRC staff interpretation given in Section 5.2.5 of Regulatory Guide 1.70, "Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants," Rev. 2, dated September 1975, and the corresponding USNRC Standard Review Plan, NUREG-75/087, dated November 1975. In addition, the USNRC staff has agreed to this position by accepting the leakage detection systems that have been described in safety analysis reports for SWEC plants (SWESSAR P-1, Section 5.2.7).
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 22 of 91 RG No. 1.46, Rev. 0 UFSAR Reference Section 3.6
 
PROTECTION AGAINST PIPE WHIP INSIDE CONTAINMENT (MAY 1973)
 
Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.46 for the protection against pipe whip inside containment with the following clarifications and alternatives:
 
Paragraph C.1.b The piping breaks are postulated to occur at any intermediate locations where the maximum stress exceeds 3.0 S as calculated by equation (10) and by either equation (12) or equation (13) in Paragraph NB-3653 of the ASME Code Section III.
Paragraph C.2.b The piping breaks are postulated to occur at any intermediate locations where either the circumferential or the longitudinal stresses derived on an elastically calculated basis under the loadings associated with
 
specified seismic events and operational plant conditions exceeds 0.8 (1.8 S h + SA) as calculated with equations (9) and (10) in Paragraph NC-3652 of the ASME Code, Section III (Section 3.6B.2).
Paragraph C.3.a Longitudinal breaks are not postulated at terminal points nor at locations where the criterion for a minimum number
 
of break locations must be satisfied.
Paragraph C.3.b Circumferential breaks are not postulated where detailed stress analysis shows that circumferential stress is at least 1.5 times that in the axial direction. Longitudinal breaks are not postulated where axial stress is at least 1.5 times the circumferential stress.
 
RG No. 1.47, Rev. 0 UFSAR Reference Section 7.1.2
 
BYPASSED AND INOPERABLE STATUS INDICATION FOR NUCLEAR POWER PLANT SAFETY SYSTEMS (MAY 1973)
 
The bypass and inoperable status indication system for Beaver
 
Valley Power Station - Unit 2 follows the guidance provided by this regulatory guide.
 
Automatic bypass indication is provided in the control room for each safety-related system train and is at the system level.
 
BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 23 of 91 RG No. 1.48, Rev. 0 UFSAR Reference Sections 3.9N.1, 3.9N.3, 3.9B.3
 
DESIGN LIMITS AND LOADING COMBINATIONS FOR SEISMIC CATEGORY I FLUID SYSTEM COMPONENTS (MAY 1973)
 
The criteria and procedures used in the design of Beaver Valley Power Station - Unit 2 concerning design limits and loading combinations for Seismic Category 1 fluid system components,
 
satisfy the requirements of General Design Criterion 2 and thereby meet the intent of Regulatory Guide 1.48 in an alternate acceptable manner.


5 gpm in 1 hour Containment atmosphere radioactivity monitor 1 gpm in less than 1 hour assuming primary coolant radioactivity concentrations stated in the environmental report. For other conditions the equilibrium activity of the reactor coolant must be sufficiently high and the equilibrium activity of the containment atmosphere must be below a level that would mask the change in activity corresponding to this leak rate. Paragraph C.6  BVPS-2 does not fully follow the guidance of Paragraph C.6 in that the containment sump level detection systems which meet the detection sensitivity requirements of normal plant operation (that is, 1 gpm in 1 hour) are not designed to meet seismic requirements. However, a seismically qualified, less sensitive, additional sump level instrumentation system, powered from Class IE electrical buses, is provided with remote displays in the control room to monitor for excessive leakage following seismic events. This instrumentation is qualified for seismic loads up to safe shutdown earthquake loads.
To ensure the structural integrity of fluid systems components, the limits given in Section 3.9N.1 will be used in the design and analysis of ASME Code Class 1 components within the Westinghouse scope of supply. For ASME Code Class 2 and 3 components within the Westinghouse scope of supply, the limits  
The SWEC interpretation of the RCPB leakage detection system requirements and Paragraph C.5 of Regulatory Guide 1.45 agrees with the USNRC staff interpretation given in Section 5.2.5 of Regulatory Guide 1.70, "Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants," Rev. 2, dated September 1975, and the corresponding USNRC Standard Review Plan, NUREG-75/087, dated November 1975. In addition, the USNRC staff has agreed to this position by accepting the leakage detection systems that have been described in safety analysis reports for SWEC plants (SWESSAR P-1, Section 5.2.7).
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont)  22 of 91 RG No. 1.46, Rev. 0 UFSAR Reference Section 3.6 PROTECTION AGAINST PIPE WHIP INSIDE CONTAINMENT (MAY 1973)
given in Section 3.9N.3 are used.
Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.46 for the protection against pipe whip inside containment with the following clarifications and alternatives:
Criteria outlined in Section 3.9B.3 are applicable to balance of plant ASME Code Class 1, 2, and 3 components and are consistent with the applicable provisions of Section III of the ASME Boiler and Pressure Vessel Code. Supplemental criteria relating to assurance of component operability are drawn from developing industry code activities, including the efforts of the ANSI N45 Committees.  
Paragraph C.1.b  The piping breaks are postulated to occur at any intermediate locations where the maximum stress exceeds 3.0 S as calculated by equation (10) and by either equation (12) or equation (13) in Paragraph NB-3653 of the ASME Code Section III. Paragraph C.2.b  The piping breaks are postulated to occur at any intermediate locations where either the circumferential or the longitudinal stresses derived on an elastically calculated basis under the loadings associated with specified seismic events and operational plant conditions exceeds 0.8 (1.8 Sh + SA) as calculated with equations (9) and (10) in Paragraph NC-3652 of the ASME Code, Section III (Section 3.6B.2). Paragraph C.3.a  Longitudinal breaks are not postulated at terminal points nor at locations where the criterion for a minimum number of break locations must be satisfied. Paragraph C.3.b  Circumferential breaks are not postulated where detailed stress analysis shows that circumferential stress is at least 1.5 times that in the axial direction. Longitudinal breaks are not postulated where axial stress is at least 1.5 times the circumferential stress.
 
RG No. 1.47, Rev. 0 UFSAR Reference Section 7.1.2 BYPASSED AND INOPERABLE STATUS INDICATION FOR NUCLEAR POWER PLANT SAFETY SYSTEMS (MAY 1973)
RG No. 1.49, Rev. 1 UFSAR Reference Section 1.1 POWER LEVELS OF NUCLEAR POWER PLANTS (DECEMBER 1973)
The bypass and inoperable status indication system for Beaver Valley Power Station - Unit 2 follows the guidance provided by this regulatory guide.
Beaver Valley Power Station - Unit 2 design and analysis involving power level follows the guidance of this regulatory  
Automatic bypass indication is provided in the control room for each safety-related system train and is at the system level.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  23 of 91 RG No. 1.48, Rev. 0 UFSAR Reference Sections 3.9N.1, 3.9N.3, 3.9B.3 DESIGN LIMITS AND LOADING COMBINATIONS FOR SEISMIC CATEGORY I FLUID SYSTEM COMPONENTS (MAY 1973)
guide.
The criteria and procedures used in the design of Beaver Valley Power Station - Unit 2 concerning design limits and loading combinations for Seismic Category 1 fluid system components, satisfy the requirements of General Design Criterion 2 and thereby meet the intent of Regulatory Guide 1.48 in an alternate acceptable manner.
To ensure the structural integrity of fluid systems components, the limits given in Section 3.9N.1 will be used in the design and analysis of ASME Code Class 1 components within the Westinghouse scope of supply. For ASME Code Class 2 and 3 components within the Westinghouse scope of supply, the limits given in Section 3.9N.3 are used. Criteria outlined in Section 3.9B.3 are applicable to balance of plant ASME Code Class 1, 2, and 3 components and are consistent with the applicable provisions of Section III of the ASME Boiler and Pressure Vessel Code. Supplemental criteria relating to assurance of component operability are drawn from developing industry code activities, including the efforts of the ANSI N45 Committees.
RG No. 1.49, Rev. 1 UFSAR Reference Section 1.1 POWER LEVELS OF NUCLEAR POWER PLANTS (DECEMBER 1973) Beaver Valley Power Station - Unit 2 design and analysis involving power level follows the guidance of this regulatory guide.
RG No. 1.50, Rev. 0 UFSAR Reference Section 5.2.3.3, 5.3.1.4  
RG No. 1.50, Rev. 0 UFSAR Reference Section 5.2.3.3, 5.3.1.4  


CONTROL OF PREHEAT TEMPERATURE FOR WELDING OF LOW-ALLOY STEEL (MAY 1973)
CONTROL OF PREHEAT TEMPERATURE FOR WELDING OF LOW-ALLOY STEEL (MAY 1973)
Beaver Valley Power Station - Unit 2 (BVPS-2) meets the intent of Regulatory Guide 1.50 for the control of preheat temperature for welding of low-alloy steel with the following clarifications and alternatives:
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 24 of 91 Westinghouse considers that Regulatory Guide 1.50 applies only to ASME Code, Section III, Class 1 components. The Westinghouse practice for Class 1 components follows welding procedures which meet the criteria in Section IX of the ASME Code and WCAP-8577, February 1976, "The Application of Preheat Temperatures after Welding Pressure Vessel Steels," in lieu of Paragraphs C.1.b and C.2 of Regulatory Guide 1.50. Westinghouse experience has shown high quality and integrity for welds using these procedures which have been found acceptable by the USNRC. For the remainder of BVPS-2 welds, in cases when it is impractical to maintain the preheat temperature until a post- weld heat treatment has been performed (Paragraph C.2), a minimum temperature of 300F is maintained for two hours per inch of thickness. This practice of maintaining the completed weld at an elevated temperature for the prescribed period of time allows hydrogen to effuse from the weld zone, reducing the tendency to form cracks in the weldment. RG No. 1.51, Rev. 0 INSERVICE INSPECTION OF ASME CODE CLASS 2 AND 3 NUCLEAR POWER PLANT COMPONENTS (MAY 1973)
Beaver Valley Power Station - Unit 2 (BVPS-2) meets the intent of Regulatory Guide 1.50 for the control of preheat temperature for welding of low-alloy steel with the following clarifications  
This regulatory guide was withdrawn July 1975.
 
RG No. 1.52, Rev. 2 UFSAR Reference Section 6.5.1.2 DESIGN, TESTING, AND MAINTENANCE CRITERIA FOR POST ACCIDENT ENGINEERED-SAFETY-FEATURE ATMOSPHERE CLEANUP SYSTEM AIR FILTRATION AND ADSORPTION UNITS OF LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (MARCH 1978) The design, testing, and maintenance criteria for the post-accident engineered safety feature (ESF) atmosphere cleanup system at BVPS-2 meets the intent of this regulatory guide with the following alternatives:
and alternatives:  
Paragraph C.2.b Tornado protection is not considered necessary for the ESF atmosphere cleanup systems because of the low probability of a joint occurrence of a tornado and those DBAs that would require operation of the ESF atmospheric cleanup systems (
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 24 of 91 Westinghouse considers that Regulatory Guide 1.50 applies only to ASME Code, Section III, Class 1 components. The Westinghouse practice for Class 1 components follows  
 
welding procedures which meet the criteria in Section IX of the ASME Code and WCAP-8577, February 1976, "The Application of Preheat Temperatures after Welding Pressure  
 
Vessel Steels," in lieu of Paragraphs C.1.b and C.2 of Regulatory Guide 1.50. Westinghouse experience has shown high quality and integrity for welds using these  
 
procedures which have been found acceptable by the USNRC.
For the remainder of BVPS-2 welds, in cases when it is impractical to maintain the preheat temperature until a post- weld heat treatment has been performed (Paragraph C.2), a minimum temperature of 300F is maintained for two hours per inch of thickness. This practice of maintaining the completed weld at an elevated temperature for the  
 
prescribed period of time allows hydrogen to effuse from the weld zone, reducing the tendency to form cracks in the weldment.
RG No. 1.51, Rev. 0 INSERVICE INSPECTION OF ASME CODE CLASS 2 AND 3 NUCLEAR POWER PLANT COMPONENTS (MAY 1973)
 
This regulatory guide was withdrawn July 1975.  
 
RG No. 1.52, Rev. 2 UFSAR Reference Section 6.5.1.2 DESIGN, TESTING, AND MAINTENANCE CRITERIA FOR POST ACCIDENT ENGINEERED-SAFETY-FEATURE ATMOSPHERE CLEANUP SYSTEM AIR FILTRATION AND ADSORPTION UNITS OF LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (MARCH 1978)
The design, testing, and maintenance criteria for the post-accident engineered safety feature (ESF) atmosphere cleanup system at BVPS-2 meets the intent of this regulatory guide with  
 
the following alternatives:  
 
Paragraph C.2.b Tornado protection is not considered necessary for the ESF  
 
atmosphere cleanup systems because of the low probability  
 
of a joint occurrence of a tornado and those DBAs that would require operation of the ESF atmospheric cleanup systems (


==References:==
==References:==
SRP 6.5.1 and Regulatory Guide 1.117). Paragraph C.2.f Filter component layouts consist of a maximum of four high efficiency particulate air (HEPA) filters high and five HEPA filters wide.
SRP 6.5.1 and Regulatory Guide  
BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont) 25 of 91 Paragraph C.2.g Pressure drop is indicated at each airstream HEPA filter and annunciated in the main control room. Paragraph C.2.h Annunciator functions are incorporated in the overall system design. Annunciators are not safety-related; therefore, they are not designed in accordance with IEEE Standard 279-1971.
 
Paragraph C.2.j The trains of the ESF atmosphere cleanup systems are designed to be removed as intact units or as a minimum number of segmented sections. Individual filter components will be removed prior to cutting the housing into segmented sections. Paragraph C.2.l 1. The ductwork leak tests are performed in accordance with ANSI N510-1975 with the alternative that ASME performance test code 19.5-1971 will be used in lieu of paragraph 6.3.1. The equipment and equipment arrangement based on the above ASME performance test code will provide test results equivalent to results obtained by equipment specified in paragraph 6.3.1 of ANSI N510-1975.
1.117). Paragraph C.2.f Filter component layouts consist of a maximum of four high efficiency particulate air (HEPA) filters high and five  
: 2. The air leakage rate for ductwork will be established based on the air cleaning effectiveness provisions defined in Paragraph 4.12.1 of ANSI N509-1976.
 
Because the ductwork carrying contaminated air upstream of the filters is under negative pressure and there is no leakage from the ductwork to surrounding space, and because any air leak from the ductwork under positive pressure is on the downstream side of the filters (filtered air), the leakage for ductwork upstream of the filters and downstream of the fans is limited to 1 percent of rated flow at internal design pressure.
HEPA filters wide.
: 3. For ductwork between the outlet of filters and the inlet of fans, the leakage is limited to 0.5 percent of rated flow at internal design pressure.
BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont) 25 of 91 Paragraph C.2.g Pressure drop is indicated at each airstream HEPA filter and annunciated in the main control room.
: 4. The duct leakage for the control room emergency ventilation system is limited to 5 percent of rated flow. This rate of leakage will not adversely affect the system capability to pressurize the control room envelope. All components of the system carrying unfiltered outside air are under negative pressure, precluding any leakage of unfiltered air to the control room envelope.
Paragraph C.2.h Annunciator functions are incorporated in the overall system design. Annunciators are not safety-related;  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 26 of 91 5. The filter housing leak tests will be performed in accordance with paragraph 4.12 of ANSI N509-1976 with the alternative that the housing maximum allowable leakage will be as specified in Table 4-3 of ANSI N509-1980. The leakage test procedure will be developed based on Section 6 of ANSI N510-1980. Paragraph C.3.a Demisters meet Underwriters Laboratories (UL) Class 2 requirements. Paragraph C.3.e Filter and adsorber mounting frames are constructed and designed in accordance with the recommendations of Section 4.3 of ORNL-NSIC-65, except for the frame tolerance guidelines in Table 4.2. The tolerances for HEPA filter and adsorber mountings are sufficient to satisfy the bank leak test criteria of paragraphs C.5.c and C.5.d of this Regulatory Guide. Paragraph C.3.f Filter component layouts consist of a maximum of four HEPA filters high and five HEPA filters wide. Paragraph C.3.g 1. Stainless steel materials for filter housings are procured to ASTM material specification A167 Type 304 in addition to those listed in paragraph 4.3 of NSIC-65/ERDA 76-21. 2. Welding is performed in accordance with AWS D1.1 or ASME IX; therefore, the workmanship samples recommended in paragraph 7.3 of ANSI N509-1976 are not used to demonstrate welders' qualifications to perform production work. Paragraph C.3.l The qualification of unused impregnated carbon will be in accordance with Table 5-1 of ANSI N509-1980. Paragraph C.3.g 1. The type and application of protective coatings on internal surfaces is controlled in accordance with the designer's specifications, which specify high quality materials and application methods in accordance with the coating manufacturer's instructions. These practices are used in lieu of the recommendations in paragraphs 5.7.1 and 5.6.4 of ANSI N509-1976.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 27 of 91 2. An alternative is taken to paragraph 5.7.2 of ANSI N509-1976. Copies of fan ratings or test reports are not provided. However, certified fan performance curves are furnished.
therefore, they are not designed in accordance with IEEE  
: 3. The balancing techniques defined in paragraph 5.7.3 of ANSI N509-1976 will be used except that normal industrial practice will be used to determine the maximum permissible vibration velocity criteria. 4. The fan drawings follow the recommendations of paragraph 5.7.4 of ANSI N509-1976 with the alternative that all information about lubricants and lubrication is contained in operation and instruction manuals. 5. Where AMCA certified ratings are submitted, documentation developed in conjunction with the certification of fans is not furnished in accordance with paragraph 5.7.5 of ANSI N509-1976. Paragraph C.3.n 1. Welding procedures, welders, and welding operators are qualified in accordance with designer's welding specifications. These specifications are in general conformance with AWS D1.1 and ASME Section IX, which are recommended in paragraph 7.3 of ANSI N509-1976.
 
Production weld visual acceptance criteria, which are based on AWS D1.1, are used in lieu of workmanship samples recommended in ANSI N509-1976, paragraph 7.3. 2. Materials for ductwork are procured to ASTM material specifications, such as A276 Type 304, A500 Gr B, A575 Gr N1020, and A576 Gr 1020, in addition to those listed in paragraph 5.10.6 of ANSI N509-1976. 3. An alternative is taken to paragraph 5.10.3.5 of ANSI N509-1976. While ductwork, as a structure, has a resonant frequency above 25 Hz, this may not be true for the unsupported plate or sheet sections. ANSI  N509-1980, which has been issued since the issuance of this regulatory guide, has deleted this provision.
Standard 279-1971.  
Tympanic vibration modes of the duct are not considered in the design because the loads will be small and minimum thickness of duct material is 20 gauge. This is more conservative than SMACNA provisions.
 
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont) 28 of 91 Paragraph C.3.p The following alternatives are taken to paragraph 5.9 of ANSI N509-1976: 1. Isolation dampers used in the supplementary leak collection and release system are neither designed nor constructed to the recommendations of ANSI B31.1. The system is designed to ensure that the leakage through the dampers is from the noncontaminated to the contaminated portion of the system and the flow is exhausted through the filters before being released to the atmosphere. Therefore, the uncontrolled release of radioactivity is precluded and the intent of Section 5.9 of ANSI N509-1976 is satisfied. 2. Butterfly valves used for control room isolation are in accordance with the ASME III code. 3. One Class B damper of each size will be tested for leakage rate instead of testing every damper.
Paragraph C.2.j The trains of the ESF atmosphere cleanup systems are  
: 4. Welding is controlled in accordance with the designers' specifications using visual acceptance criteria, which are based on AWS D1.1 in lieu of the standards recommended in paragraphs 5.9 and 7.3 of ANSI N509-1976. 5. The minimum diameter of damper shafts that are 24 inches and under in length shall be 1/2 inch. The minimum diameter of damper shafts that are greater than 24 inches in length through 48 inches in length shall be 3/4 inch. Paragraph C.4.a Alternatives are taken to Section 2.3.8 of ERDA 76-21: 1. The control room filtration assembly, due to its size, does not require entry to the housing interior. The SLCRS filtration assembly is of gasketless type, therefore handling of the charcoal adsorber trays inside the housing is eliminated. During replacement of HEPA filters, voice communication is sufficient.
 
designed to be removed as intact units or as a minimum  
 
number of segmented sections. Individual filter components will be removed prior to cutting the housing  
 
into segmented sections.
Paragraph C.2.l
: 1. The ductwork leak tests are performed in accordance with ANSI N510-1975 with the alternative that ASME performance test code 19.5-1971 will be used in lieu of paragraph 6.3.1. The equipment and equipment  
 
arrangement based on the above ASME performance test  
 
code will provide test results equivalent to results obtained by equipment specified in paragraph 6.3.1 of  
 
ANSI N510-1975.  
: 2. The air leakage rate for ductwork will be established based on the air cleaning effectiveness provisions defined in Paragraph 4.12.1 of ANSI N509-1976.
 
Because the ductwork carrying contaminated air upstream of the filters is under negative pressure and  
 
there is no leakage from the ductwork to surrounding space, and because any air leak from the ductwork  
 
under positive pressure is on the downstream side of  
 
the filters (filtered air), the leakage for ductwork upstream of the filters and downstream of the fans is limited to 1 percent of rated flow at internal design  
 
pressure.  
: 3. For ductwork between the outlet of filters and the inlet of fans, the leakage is limited to 0.5 percent  
 
of rated flow at internal design pressure.  
: 4. The duct leakage for the control room emergency ventilation system is limited to 5 percent of rated flow. This rate of leakage will not adversely affect  
 
the system capability to pressurize the control room  
 
envelope.
All components of the system carrying unfiltered  
 
outside air are under negative pressure, precluding  
 
any leakage of unfiltered air to the control room  
 
envelope.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 26 of 91 5. The filter housing leak tests will be performed in accordance with paragraph 4.12 of ANSI N509-1976 with the alternative that the housing maximum allowable leakage will be as specified in Table 4-3 of ANSI N509-1980. The leakage test procedure will be developed based on Section 6 of ANSI N510-1980.
Paragraph C.3.a Demisters meet Underwriters Laboratories (UL) Class 2 requirements.
Paragraph C.3.e Filter and adsorber mounting frames are constructed and designed in accordance with the recommendations of Section 4.3 of ORNL-NSIC-65, except for the frame tolerance guidelines in Table 4.2. The tolerances for HEPA filter and adsorber mountings are sufficient to satisfy the bank leak test criteria of paragraphs C.5.c and C.5.d of this Regulatory Guide.
Paragraph C.3.f Filter component layouts consist of a maximum of four HEPA filters high and five HEPA filters wide.
Paragraph C.3.g
: 1. Stainless steel materials for filter housings are procured to ASTM material specification A167 Type 304 in addition to those listed in paragraph 4.3 of NSIC-65/ERDA 76-21.  
: 2. Welding is performed in accordance with AWS D1.1 or ASME IX; therefore, the workmanship samples recommended in paragraph 7.3 of ANSI N509-1976 are not used to demonstrate welders' qualifications to perform production work.
Paragraph C.3.l The qualification of unused impregnated carbon will be in accordance with Table 5-1 of ANSI N509-1980.
Paragraph C.3.g
: 1. The type and application of protective coatings on internal surfaces is controlled in accordance with the  
 
designer's specifications, which specify high quality materials and application methods in accordance with  
 
the coating manufacturer's instructions. These practices are used in lieu of the recommendations in paragraphs 5.7.1 and 5.6.4 of ANSI N509-1976.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 27 of 91 2. An alternative is taken to paragraph 5.7.2 of ANSI N509-1976. Copies of fan ratings or test reports are not provided. However, certified fan performance  
 
curves are furnished.  
: 3. The balancing techniques defined in paragraph 5.7.3 of ANSI N509-1976 will be used except that normal industrial practice will be used to determine the maximum permissible vibration velocity criteria.  
: 4. The fan drawings follow the recommendations of paragraph 5.7.4 of ANSI N509-1976 with the alternative that all information about lubricants and lubrication is contained in operation and instruction manuals.  
: 5. Where AMCA certified ratings are submitted, documentation developed in conjunction with the  
 
certification of fans is not furnished in accordance  
 
with paragraph 5.7.5 of ANSI N509-1976.
Paragraph C.3.n
: 1. Welding procedures, welders, and welding operators are qualified in accordance with designer's welding specifications. These specifications are in general conformance with AWS D1.1 and ASME Section IX, which are recommended in paragraph 7.3 of ANSI N509-1976.
Production weld visual acceptance criteria, which are based on AWS D1.1, are used in lieu of workmanship samples recommended in ANSI N509-1976, paragraph 7.3.  
: 2. Materials for ductwork are procured to ASTM material specifications, such as A276 Type 304, A500 Gr B, A575 Gr N1020, and A576 Gr 1020, in addition to those listed in paragraph 5.10.6 of ANSI N509-1976.  
: 3. An alternative is taken to paragraph 5.10.3.5 of ANSI N509-1976. While ductwork, as a structure, has a resonant frequency above 25 Hz, this may not be true for the unsupported plate or sheet sections. ANSI  N509-1980, which has been issued since the issuance of this regulatory guide, has deleted this provision.
Tympanic vibration modes of the duct are not considered in the design because the loads will be small and minimum thickness of duct material is 20  
 
gauge. This is more conservative than SMACNA provisions.  
 
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont) 28 of 91 Paragraph C.3.p The following alternatives are taken to paragraph 5.9 of ANSI N509-1976:  
: 1. Isolation dampers used in the supplementary leak collection and release system are neither designed nor constructed to the recommendations of ANSI B31.1. The system is designed to ensure that the leakage through the dampers is from the noncontaminated to the contaminated portion of the system and the flow is exhausted through the filters before being released to the atmosphere. Therefore, the uncontrolled release of radioactivity is precluded and the intent of Section 5.9 of ANSI N509-1976 is satisfied.  
: 2. Butterfly valves used for control room isolation are in accordance with the ASME III code.  
: 3. One Class B damper of each size will be tested for leakage rate instead of testing every damper.  
: 4. Welding is controlled in accordance with the designers' specifications using visual acceptance criteria, which are based on AWS D1.1 in lieu of the standards recommended in paragraphs 5.9 and 7.3 of ANSI N509-1976.  
: 5. The minimum diameter of damper shafts that are 24 inches and under in length shall be 1/2 inch. The minimum diameter of damper shafts that are greater than 24 inches in length through 48 inches in length shall be 3/4 inch.
Paragraph C.4.a Alternatives are taken to Section 2.3.8 of ERDA 76-21:  
: 1. The control room filtration assembly, due to its size, does not require entry to the housing interior.
The SLCRS filtration assembly is of gasketless type, therefore handling of the charcoal adsorber trays inside the housing is eliminated. During replacement of HEPA filters, voice communication is sufficient.
The filter housing is provided with large doors allowing visual and voice communication between personnel inside and outside of the housing.
The filter housing is provided with large doors allowing visual and voice communication between personnel inside and outside of the housing.
Therefore, no special communication system need be provided. 2. Decontamination, clothing change, and shower facilities for personnel involved in the filter service are incorporated into the overall plant radiation protection program.
Therefore, no special communication system need be provided.  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 29 of 91 3. Due to the large number of duct inlets (registers), it is not feasible to provide prefilters at each register. It should be noted that areas exhausted by filtration systems are not expected to contain significant amounts of dust. Inspection doors are provided at all dampers, reheat coils, and other similar items requiring inspection or maintenance. These doors can serve the functions specified in Section 2.3.8 of ERDA. Paragraph C.4.d The ESF atmosphere cleanup systems are operated a minimum of 15 minutes per month. Paragraph C.5.a A visual inspection of the ESF atmosphere cleanup system and all associated components is not planned to be made before each in-place airflow distribution test, DOP test, or activated carbon adsorber section leak test, but will be performed after initial installation and on an as-needed basis in accordance with the provisions of Section 5 of ANSI N510-1975.
: 2. Decontamination, clothing change, and shower facilities for personnel involved in the filter service are incorporated into the overall plant  
Paragraph C.5.b The acceptance testing airflow capacity and distribution test procedure will be developed based on Section 8 of ANSI N510-1980 except for the following alternatives:  
 
: 1. To avoid damage to system components an artificial resistance will be used in lieu of the recommendations of Paragraph 8.3.1.1.
radiation protection program.  
: 2. Airflow measurements for the airflow capacity test will be performed in accordance with AABC National Standards for Total System Balance, Fourth Edition, 1982, instead of Section 9 of ACGIH, Industrial Ventilation, as recommended in Paragraph 8.3.1.3 and 8.3.1.4 of ANSI N510-1980. The above alternative will provide consistency with the airflow measurement method for balancing of the plant ventilation systems.
 
: 3. The airflow test specified in Paragraph 8.3.1.6 will be performed with the filter bank at 100 percent of design dirty filter pressure drop. The system and equipment instrumentation and surveillance preclude inadvertent operation of the filter banks with the pressure or flow outside of the allowable limits. 4. The test specified in Paragraph 8.3.1.7 of ANSI N510-1980 cannot be performed because the system cannot operate at the flow associated with the pressure drop below clean component pressure drop. The pressure drop of about 50% of the design dirty filters is about equal to the pressure drop of clean components.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 29 of 91 3. Due to the large number of duct inlets (registers), it is not feasible to provide prefilters at each register. It should be noted that areas exhausted by filtration systems are not expected to contain significant amounts of dust. Inspection doors are provided at all dampers, reheat coils, and other similar items requiring inspection or maintenance. These doors can serve the functions specified in Section 2.3.8 of ERDA.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 30 of 91 5. Airflow distribution through prefilters and moisture separator banks is not specified. Therefore, the provisions of Paragraph 8.3.2.3 do not apply. The surveillance test airflow measurements will be taken following maintenance when required by Technical Specifications using installed instrumentation, when available, or the pitot tube velocity traverse method in accordance with an approved surveillance test procedure.
Paragraph C.4.d The ESF atmosphere cleanup systems are operated a minimum of 15 minutes per month.
Paragraph C.5.c The in-place DOP test of HEPA filters will be performed in accordance with Section 10 of ANSI N510-1980 with the air-aerosol mixing uniformity test in accordance with Section 9 of the above code. Paragraph C.5.d The in-place test of the carbon adsorber will be performed in accordance with Section 12 of ANSI N510-1980. Paragraph C.6.b Laboratory testing frequency for the activated carbon will meet the recommended minimum test frequency indicated in Table 1 of ANSI N510-1980.
Paragraph C.5.a A visual inspection of the ESF atmosphere cleanup system and all associated components is not planned to be made before each in-place airflow distribution test, DOP test, or activated carbon adsorber section leak test, but will be performed after initial installation and on an as-needed basis in accordance with the provisions of Section 5 of ANSI N510-1975.  
The carbon samples not obtained from test canisters will be obtained with slotted-tube sampler in accordance with ANSI N509-1980. Table 2  Laboratory tests for methyl iodide penetration for the representative sample will allow a maximum penetration of 3 percent as stipulated in Table 5-1 of ANSI N509-1980. RG No. 1.53, Rev. 0 UFSAR Reference Section 3.1.1, 7.1.2.6, 15.0.8  
 
Paragraph C.5.b The acceptance testing airflow capacity and distribution test procedure will be developed based on Section 8 of ANSI N510-1980 except for the following alternatives:  
: 1. To avoid damage to system components an artificial resistance will be used in lieu of the recommendations of Paragraph 8.3.1.1.  
: 2. Airflow measurements for the airflow capacity test will be performed in accordance with AABC National Standards for Total System Balance, Fourth Edition, 1982, instead of Section 9 of ACGIH, Industrial Ventilation, as recommended in Paragraph 8.3.1.3 and 8.3.1.4 of ANSI N510-1980. The above alternative will provide consistency with the airflow measurement  
 
method for balancing of the plant ventilation systems.  
: 3. The airflow test specified in Paragraph 8.3.1.6 will be performed with the filter bank at 100 percent of design dirty filter pressure drop. The system and equipment instrumentation and surveillance preclude inadvertent operation of the filter banks with the pressure or flow outside of the allowable limits.  
: 4. The test specified in Paragraph 8.3.1.7 of ANSI N510-1980 cannot be performed because the system cannot operate at the flow associated with the pressure drop below clean component pressure drop. The pressure drop of about 50% of the design dirty filters is about equal to the pressure drop of clean components.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 30 of 91 5. Airflow distribution through prefilters and moisture separator banks is not specified. Therefore, the provisions of Paragraph 8.3.2.3 do not apply.
The surveillance test airflow measurements will be taken following maintenance when required by Technical  
 
Specifications using installed instrumentation, when available, or the pitot tube velocity traverse method in accordance with an approved surveillance test procedure.  
 
Paragraph C.5.c The in-place DOP test of HEPA filters will be performed in accordance with Section 10 of ANSI N510-1980 with the air-aerosol mixing uniformity test in accordance with  
 
Section 9 of the above code.
Paragraph C.5.d The in-place test of the carbon adsorber will be performed in accordance with Section 12 of ANSI N510-1980.
Paragraph C.6.b Laboratory testing frequency for the activated carbon will meet the recommended minimum test frequency indicated in Table 1 of ANSI N510-1980.  
 
The carbon samples not obtained from test canisters will be obtained with slotted-tube sampler in accordance with  
 
ANSI N509-1980.
Table 2  Laboratory tests for methyl iodide penetration for the representative sample will allow a maximum penetration of  
 
3 percent as stipulated in Table 5-1 of ANSI N509-1980.
RG No. 1.53, Rev. 0 UFSAR Reference Section 3.1.1, 7.1.2.6, 15.0.8  


APPLICATION OF THE SINGLE-FAILURE CRITERION TO NUCLEAR POWER PLANT PROTECTION SYSTEMS (JUNE 1973)
APPLICATION OF THE SINGLE-FAILURE CRITERION TO NUCLEAR POWER PLANT PROTECTION SYSTEMS (JUNE 1973)
Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.53 for application of the single failure criterion to protection systems with the following alternatives:  
Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.53 for application of the single failure criterion to protection systems with the following alternatives:  
: 1. As stated in Paragraph C.1, departure from certain provisions may occur. 2. For certain Westinghouse supplied equipment, a fault tree analysis, rather than a failure mode and effects analysis, has been used.
: 1. As stated in Paragraph C.1, departure from certain provisions may occur.  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 31 of 91 3. Final actuation devices are generally capable of periodic in-service testing. However, some devices by necessity can only be tested partially with the unit on line and completely with the unit off line.
: 2. For certain Westinghouse supplied equipment, a fault tree analysis, rather than a failure mode and effects analysis, has been used.  
: 4. With regard to Paragraph C.3, single switches supplying signals to redundant channels will have a separation of at least 6 inches or a suitable barrier will be supplied. 5. Compliance with single failure criteria will be verified based on a collective analysis of both the protective system and the final actuation devices or actuators. RG No. 1.54, Rev. 0 UFSAR Reference Sections 6.1.2, 17.1 QUALITY ASSURANCE REQUIREMENTS FOR PROTECTIVE COATINGS APPLIED TO WATER-COOLED NUCLEAR POWER PLANTS (JUNE 1973)
 
Quality assurance requirements for protective coatings at BVPS-2 meet the intent of this regulatory guide with the following clarification and alternatives: For the balance-of-plant, ANSI N101.4-1972 requirements for documentation are applied as follows to equipment located in the containment.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 31 of 91 3. Final actuation devices are generally capable of periodic in-service testing. However, some devices by necessity can only be tested partially with the unit  
For large surface area components, the documents are submitted by the vendors as required by ANSI N101.4-1972. These components include such items as the polar crane, structural steel, concrete, ductwork, uninsulated pipe, neutron shield tank, exteriors of uninsulated tanks and vessels, major equipment supports, and the containment liner. For manufactured equipment such as pumps, motors, pipe hangers, and supports, the documentation required by ANSI N101.4-1972 is maintained in the seller's files for the complete duration of the contract warranty-guarantee period. A certificate of compliance signed by responsible management personnel is furnished by the seller.
 
For balance of plant, in lieu of the inspection defined in Section 6.2.4 of ANSI 101.4-1972, inspection is performed in accordance with ANSI N5.12-1974, Section 10, "Inspection for Shop and Field Work." For nuclear steam supply equipment located in the containment, the following acceptable alternate method is employed.
on line and completely with the unit off line.  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 32 of 91 For large surface area components, Westinghouse specifies stringent requirements through the use of a painting specification which includes the use of specific coating systems qualified to ANSI N101.2 and certifications of compliance from the vendors. The vendor's implementation of the specification requirements is monitored during the quality assurance surveillance activities. These components include the reactor coolant system supports, reactor coolant pumps, accumulator tanks, and the manipulator crane. For intermediate surface area components, Westinghouse employs another specification which also includes the use of coating systems which are qualified to ANSI N101.2. The vendor's compliance with the requirements is also checked during quality assurance surveillance activities. These components include the seismic platform and tie rods, reactor internals lifting rig, head lifting rig, and electrical cabinets. For both the nuclear steam supply system and the balance-of-plant, Regulatory Guide 1.54 guidelines are not invoked for items such as valve bodies, handwheels, certain electrical cabinets and control panels, loudspeakers, emergency light cases, and small instruments. The total surface area of these items is very small in comparison with the total surface area for which the guidelines are imposed. The guidelines of this regulatory guide are not applied to routine touch-up work. No special QA requirements are imposed for the painting of surfaces that will be insulated. In general, stainless steel and corrosion-resistant alloys are not painted. RG No. 1.55, Rev. 0 UFSAR Reference Section 3.8.1.6.1  
: 4. With regard to Paragraph C.3, single switches supplying signals to redundant channels will have a separation of at least 6 inches or a suitable barrier will be supplied.  
: 5. Compliance with single failure criteria will be verified based on a collective analysis of both the protective system and the final actuation devices or actuators.
RG No. 1.54, Rev. 0 UFSAR Reference Sections 6.1.2, 17.1  
 
QUALITY ASSURANCE REQUIREMENTS FOR PROTECTIVE COATINGS APPLIED TO WATER-COOLED NUCLEAR POWER PLANTS (JUNE 1973)
 
Quality assurance requirements for protective coatings at BVPS-2 meet the intent of this regulatory guide with the following  
 
clarification and alternatives:
For the balance-of-plant, ANSI N101.4-1972 requirements for documentation are applied as follows to equipment located in the containment.  
 
For large surface area components, the documents are submitted by the vendors as required by ANSI N101.4-1972. These components include such items as the polar crane,  
 
structural steel, concrete, ductwork, uninsulated pipe, neutron shield tank, exteriors of uninsulated tanks and vessels, major equipment supports, and the containment  
 
liner. For manufactured equipment such as pumps, motors, pipe  
 
hangers, and supports, the documentation required by ANSI N101.4-1972 is maintained in the seller's files for the complete duration of the contract warranty-guarantee period. A certificate of compliance signed by responsible management personnel is furnished by the seller.  
 
For balance of plant, in lieu of the inspection defined in Section 6.2.4 of ANSI 101.4-1972, inspection is performed in accordance with ANSI N5.12-1974, Section 10,  
 
"Inspection for Shop and Field Work."
For nuclear steam supply equipment located in the  
 
containment, the following acceptable alternate method is employed.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 32 of 91 For large surface area components, Westinghouse specifies stringent requirements through the use of a painting specification which includes the use of specific coating systems qualified to ANSI N101.2 and certifications of compliance from the vendors. The vendor's implementation of the specification requirements is monitored during the  
 
quality assurance surveillance activities. These components include the reactor coolant system supports, reactor coolant pumps, accumulator tanks, and the  
 
manipulator crane.
For intermediate surface area components, Westinghouse  
 
employs another specification which also includes the use of coating systems which are qualified to ANSI N101.2. The vendor's compliance with the requirements is also checked during quality assurance surveillance activities. These components include the seismic platform and tie rods, reactor internals lifting rig, head lifting rig, and  
 
electrical cabinets.
For both the nuclear steam supply system and the balance-of-plant, Regulatory Guide 1.54 guidelines are not invoked for items such as valve bodies, handwheels, certain electrical cabinets and control panels, loudspeakers,  
 
emergency light cases, and small instruments. The total surface area of these items is very small in comparison with the total surface area for which the guidelines are  
 
imposed.
The guidelines of this regulatory guide are not applied to  
 
routine touch-up work.
No special QA requirements are imposed for the painting of  
 
surfaces that will be insulated.
In general, stainless steel and corrosion-resistant alloys  
 
are not painted.
RG No. 1.55, Rev. 0 UFSAR Reference Section 3.8.1.6.1  


CONCRETE PLACEMENT IN CATEGORY I STRUCTURES (JUNE 1973)
CONCRETE PLACEMENT IN CATEGORY I STRUCTURES (JUNE 1973)
Regulatory Guide 1.55 was, withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981, (Materials, Construction and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station - Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, concrete placement in Category I structures at BVPS-2 meets or exceeds the intent of Regulatory Guide 1.55 with the following alternatives:


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 33 of 91 1. Shop detail drawings for the reactor containment mat, shell, dome, and internals are checked by the designer. All other reinforcing shop details are checked by engineers at the job site.
Regulatory Guide 1.55 was, withdrawn (June 1981) and has been
: 2. Constituents and proportions for design mixes to be used for mass concrete are selected to minimize the effects of shrinkage and heat of hydration. The slump used for mass concrete is 3 inches, the slump used in normal concrete is 4 inches, and a slump of 5 inches is allowed in congested areas of heavily reinforced structures and electrical duct lines to permit placing concrete.
 
: 3. Curing and protection of freshly deposited concrete conforms to ACI-301, Chapter 12, except that curing compounds are not used on surfaces to which additional concrete is to be bonded, and where wood and/or metal forms are used and remain in place for curing, the forms are kept wet as required to prevent their opening at the joints and drying out of the concrete. 4. The ACI and ASTM specifications are supplemented as necessary with mandatory requirements relating to types and strengths of concrete, minimum concrete densities, proportioning of ingredients, reinforcing steel requirements, joint treatments, and testing agency requirements.
superseded by Regulatory Guide 1.136, Rev. 2, June 1981, (Materials, Construction and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station - Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, concrete placement in Category I structures at BVPS-2 meets or exceeds the intent of Regulatory Guide 1.55 with the following alternatives:
RG No. 1.56, Rev. 1 MAINTENANCE OF WATER PURITY IN BOILING WATER REACTORS (JULY 1978)
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 33 of 91 1. Shop detail drawings for the reactor containment mat, shell, dome, and internals are checked by the designer. All other reinforcing shop details are  
 
checked by engineers at the job site.  
: 2. Constituents and proportions for design mixes to be used for mass concrete are selected to minimize the effects of shrinkage and heat of hydration. The slump used for mass concrete is 3 inches, the slump used in  
 
normal concrete is 4 inches, and a slump of 5 inches is allowed in congested areas of heavily reinforced structures and electrical duct lines to permit placing  
 
concrete.  
: 3. Curing and protection of freshly deposited concrete conforms to ACI-301, Chapter 12, except that curing compounds are not used on surfaces to which additional concrete is to be bonded, and where wood and/or metal forms are used and remain in place for curing, the forms are kept wet as required to prevent their opening at the joints and drying out of the concrete.  
: 4. The ACI and ASTM specifications are supplemented as necessary with mandatory requirements relating to types and strengths of concrete, minimum concrete densities, proportioning of ingredients, reinforcing steel requirements, joint treatments, and testing  
 
agency requirements.  
 
RG No. 1.56, Rev. 1
 
MAINTENANCE OF WATER PURITY IN BOILING WATER REACTORS (JULY 1978)
This regulatory guide is not applicable to Beaver Valley Power  
 
Station - Unit 2.  
 
RG No. 1.57, Rev. 0 UFSAR Reference Section 3.8.2  
RG No. 1.57, Rev. 0 UFSAR Reference Section 3.8.2  


DESIGN LIMITS AND LOADING COMBINATIONS FOR METAL PRIMARY REACTOR CONTAINMENT SYSTEM COMPONENTS (JUNE 1973)
DESIGN LIMITS AND LOADING COMBINATIONS FOR METAL PRIMARY REACTOR CONTAINMENT SYSTEM COMPONENTS (JUNE 1973)
The design limits and loading combinations for the Beaver Valley Power Station - Unit 2 metal primary reactor containment system components meet the intent of Regulatory Guide 1.57 with the following alternatives which apply only to those portions not backed by concrete:  1. The applicable edition of the ASME Boiler and Pressure Vessel Code for affected ASME III components is identified in the ASME Code Baseline Document.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  34 of 91 2. The primary stresses, based on elastic analysis, meet the following limits in lieu of the limits specified in paragraph C.1.b(2):  General membrane...1.5 Sm  Local membrane...the greater of 1.8Sm or 1.5Sm Bending plus local membrane...the greater of 1.8Sm or 1.5Sm. 3. The bellows assemblies were designed, fabricated, tested, and installed to the following criteria in lieu of the requirements of paragraphs C.2.a and b. The fuel transfer tube expansion bellows shall be in accordance with Code Case 1330-3 (special ruling) Special Equipment Requirements Section III. An N-2 form in accordance with Code Case 1177 shall be furnished by the bellows vendor. A duplicate bellows shall be required for pressure and fatigue testing by the Contractor in accordance with ASME III, Winter 1974 Addendum, paragraph NE-3365.2(e)(2). The 15-percent maximum convolution pitch in accordance with paragraph NE-3365.2(c) for unreinforced bellows may be exceeded provided the bellows remain within the elastic range. RG No. 1.58 UFSAR Reference Sections 17.1, 17.2  QUALIFICATION OF NUCLEAR POWER PLANT INSPECTION, EXAMINATION, AND TESTING PERSONNEL  Application of Regulatory Guide 1.58 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual. RG No. 1.59, Rev. 2 UFSAR Reference Section 2.4.2.2  DESIGN BASIS FLOODS FOR NUCLEAR POWER PLANTS (AUGUST 1977)  The determination of the design basis flood and the design of Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  35 of 91 RG No. 1.60, Rev. 1 UFSAR Reference Section 3.7B.1.1 DESIGN RESPONSE SPECTRA FOR SEISMIC DESIGN OF NUCLEAR POWER PLANTS (DECEMBER 1973)
The design limits and loading combinations for the Beaver Valley Power Station - Unit 2 metal primary reactor containment system components meet the intent of Regulatory Guide 1.57 with the following alternatives which apply only to those portions not backed by concrete:
The design response spectra for the seismic design of Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.60 with the following alternatives:
: 1. The applicable edition of the ASME Boiler and Pressure Vessel Code for affected ASME III components is
The horizontal design response spectra used for seismic analyses are shown on Figures 3.7B-1 and 3.7B-2. The spectra shown for the safe shutdown earthquake (SSE) correspond to a maximum ground acceleration of 0.125g and the spectra shown for the operating basis earthquake (OBE) correspond to a maximum ground acceleration of 0.06g. The vertical design response spectra are taken to be two-thirds of the horizontal design response spectra. These response spectra are based upon the response spectra used for Beaver Valley Power Station - Unit 1 (Figures 2.5-1 and 2.5-2, BVPS-1 UFSAR, October 27, 1972 Docket 5O-33A) and as revised in response to USAEC Regulatory Position 3 of May 25, 1973 (Question 3.15, BVPS-2 PSAR, Amendment 7, July 9, 1973).
 
identified in the ASME Code Baseline Document.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 34 of 91 2. The primary stresses, based on elastic analysis, meet the following limits in lieu of the limits specified in paragraph C.1.b(2):
General membrane...1.5 S m  Local membrane...the greater of 1.8S m or 1.5Sm Bending plus local membrane...the greater of 1.8S m or 1.5Sm. 3. The bellows assemblies were designed, fabricated, tested, and installed to the following criteria in lieu of the requirements of paragraphs C.2.a and b.
The fuel transfer tube expansion bellows shall be in accordance with Code Case 1330-3 (special ruling) Special Equipment Requirements Section III. An N-2 form in accordance with Code Case 1177 shall be furnished by the bellows vendor. A duplicate bellows shall be required for pressure and fatigue testing by the Contractor in accordance with ASME III, Winter 1974 Addendum, paragraph NE-3365.2(e)(2). The 15-percent maximum convolution pitch in accordance with paragraph NE-3365.2(c) for unreinforced bellows may be exceeded provided the bellows remain within the elastic range.
RG No. 1.58
 
UFSAR Reference Sections 17.1, 17.2 QUALIFICATION OF NUCLEAR POWER PLANT INSPECTION, EXAMINATION, AND TESTING PERSONNEL Application of Regulatory Guide 1.58 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual. RG No. 1.59, Rev. 2 UFSAR Reference Section 2.4.2.2 DESIGN BASIS FLOODS FOR NUCLEAR POWER PLANTS (AUGUST 1977)
The determination of the design basis flood and the design of Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.
 
BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 35 of 91 RG No. 1.60, Rev. 1 UFSAR Reference Section 3.7B.1.1  
 
DESIGN RESPONSE SPECTRA FOR SEISMIC DESIGN OF NUCLEAR POWER PLANTS (DECEMBER 1973)
 
The design response spectra for the seismic design of Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.60 with the following alternatives:  
 
The horizontal design response spectra used for seismic  
 
analyses are shown on Figures 3.7B-1 and 3.7B-2. The spectra shown for the safe shutdown earthquake (SSE) correspond to a maximum ground acceleration of 0.125g and the spectra shown for the operating basis earthquake (OBE) correspond to a maximum ground acceleration of 0.06g. The vertical design response spectra are taken to be two-thirds of the horizontal design response spectra.
These response spectra are based upon the response spectra used for Beaver Valley Power Station - Unit 1 (Figures
 
2.5-1 and 2.5-2, BVPS-1 UFSAR, October 27, 1972 Docket 5O-33A) and as revised in response to USAEC Regulatory Position 3 of May 25, 1973 (Question 3.15, BVPS-2 PSAR,  
 
Amendment 7, July 9, 1973).  


RG No. 1.61, Rev. 0 UFSAR Reference Section 3.7.1  
RG No. 1.61, Rev. 0 UFSAR Reference Section 3.7.1  


DAMPING VALUES FOR SEISMIC DESIGN OF NUCLEAR POWER PLANTS (OCTOBER 1973)
DAMPING VALUES FOR SEISMIC DESIGN OF NUCLEAR POWER PLANTS (OCTOBER 1973)
The determination of the damping values used for the design of Seismic Category I structures, systems, and components at Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide with the following clarifications: A value of 4 percent of critical is employed for the primary coolant loop system components for the safe shutdown earthquake (SSE). For discussion and justification of this value, refer to WCAP-7921-AR and WCAP-8288. Values of 1/2 percent and 1 percent of critical are used for the design basis of piping and piping components for the l/2-SSE and SSE, respectively, except as indicated below. In addition; a value of 2 percent of critical is used for reinforced concrete structures for the l/2-SSE. These values are less than the values given in Table 1 of the regulatory guide and are therefore more conservative.
 
The higher, frequency dependent damping values provided in ASME III Code Case N-411 may be used for stress reconciliation of piping systems and for support optimization.
The determination of the damping values used for the design of Seismic Category I structures, systems, and components at Beaver Valley Power Station - Unit 2 follows the guidance of this  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 36 of 91 Values of 4 percent and 8 percent of critical are used for cable tray and conduit systems for 1/2 SSE and SSE, respectively. Existing analysis and testing of strut-supported cable tray and conduit systems constructed similar to the support configurations used at BVPS-2 demonstrate that damping values increase with increasing system response. Levels of damping have been measured in excess of 20 percent of critical. Use of 4 percent and 8 percent of critical for cable tray and conduit systems at BVPS-2 is therefore conservative. For discussion of the analysis and testing, refer to:
 
Elsabee, F., Anagnostis, S., and Djordjevic, W., 1983. Seismic Evaluation of Electrical Raceway Systems. American Society of Mechanical Engineers, Paper 83-PVP-18.
regulatory guide with the following clarifications:
Koss, P., 1979. Seismic Testing of Electrical Cable Support Systems. 48th Annual Convention of Structural Engineers Association of California, Paper. RG No. 1.62, Rev. 0 UFSAR Reference Section 7.2.2.2, 7.3.2.2.7, 7.2.2.2.3  
A value of 4 percent of critical is employed for the primary coolant loop system components for the safe shutdown earthquake (SSE). For discussion and justification of this value, refer to WCAP-7921-AR and  
 
WCAP-8288.
Values of 1/2 percent and 1 percent of critical are used for the design basis of piping and piping components for the l/2-SSE and SSE, respectively, except as indicated below. In addition; a value of 2 percent of critical is used for reinforced concrete structures for the l/2-SSE. These values are less than the values given in Table 1 of the regulatory guide and are therefore more conservative.  
 
The higher, frequency dependent damping values provided in ASME III Code Case N-411 may be used for stress  
 
reconciliation of piping systems and for support optimization.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 36 of 91 Values of 4 percent and 8 percent of critical are used for cable tray and conduit systems for 1/2 SSE and SSE, respectively. Existing analysis and testing of strut-supported cable tray and conduit systems constructed similar to the support configurations used at BVPS-2 demonstrate that damping values increase with increasing system response. Levels of damping have been measured in excess of 20 percent of critical. Use of 4 percent and 8 percent of critical for cable tray and conduit systems at  
 
BVPS-2 is therefore conservative. For discussion of the analysis and testing, refer to:  
 
Elsabee, F., Anagnostis, S., and Djordjevic, W., 1983. Seismic Evaluation of Electrical Raceway Systems.
American Society of Mechanical Engineers, Paper 83-PVP-18.  
 
Koss, P., 1979. Seismic Testing of Electrical Cable Support Systems. 48th Annual Convention of Structural  
 
Engineers Association of California, Paper.
RG No. 1.62, Rev. 0 UFSAR Reference Section 7.2.2.2, 7.3.2.2.7, 7.2.2.2.3  


MANUAL INITIATION OF PROTECTIVE ACTIONS (OCTOBER 1973)
MANUAL INITIATION OF PROTECTIVE ACTIONS (OCTOBER 1973)
The design of manual initiation of protective actions at Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide with the following clarification: Manual initiation of the semi-automatic switchover to recirculation following a LOCA is in general compliance with IEEE 279-1971. However, once safety injection is initiated manually, all automatic functions follow except for the opening of the containment sump isolation valves. These valves remain closed until receipt of a low level signal from the refueling water storage tank level instrumentation. RG No. 1.63, Rev. 2 UFSAR Reference Section 8.3 ELECTRIC PENETRATION ASSEMBLIES IN CONTAINMENT STRUCTURES FOR LIGHT-WATER COOLED NUCLEAR POWER PLANTS (JULY 1978)
 
Since Beaver Valley Power Station - Unit 2 (BVPS-2) was docketed before August 31, 1978, the methods described in Regulatory Guide 1.63 were not required to be used in the evaluation of the BVPS-2 Construction Permit application. However, the design and construction of the electric penetration assemblies on BVPS-2 follow the guidance of this regulatory guide, except that a ASME Code data report, (ANI) third party inspection and ASME Code stamping of the penetrations are not required as the penetrations are an extension of the containment liner boundary which is not code stamped as discussed in Section 3.8.1.2.1.2.
The design of manual initiation of protective actions at Beaver  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 37 of 91 RG No. 1.64, Rev. 2 UFSAR Reference Section 17.2 QUALITY ASSURANCE REQUIREMENTS FOR THE DESIGN OF NUCLEAR POWER PLANTS (JUNE 1976)
 
Quality Assurance Programs in effect at the time of systems design were followed in the design of BVPS-2 and meet the intent of Regulatory Guide 1.64 with the following clarifications and alternative: Duquesne Light Company has developed a Quality Assurance Program which conforms to 10 CFR 50, Appendix B. The DLC Quality Assurance Department verifies, through the audit process, that Stone & Webster Engineering Corporation (SWEC) and Westinghouse Electric Corporation are regularly reviewing the status and adequacy of their own QA programs. The original BVPS-2 Quality Assurance Program was described in Appendix A of the PSAR. This QA Program was initially implemented in accordance with Regulatory Guide 1.64, Rev. 0, dated October 1973. Subsequent Revisions 1 and 2 of the guide required upgrading of the design process, with the most significant changes being independent design verification by individuals not having immediate supervisory responsibility for the individual performing the design. Accordingly, SWEC Engineering Assurance Division issued a change to Engineering Assurance Procedure (EAP) 3.1, "Verification of Nuclear Plant Designs," which requires the following: All initial issues of key design documents issued after February 8, 1977, shall be subject to independent objective review.
Valley Power Station - Unit 2 follows the guidance of this regulatory guide with the following clarification:
Subsequent revisions to all key design documents, other than calculations, which contain a change in design concept shall be subject to independent objective review.
Manual initiation of the semi-automatic switchover to recirculation following a LOCA is in general compliance with IEEE 279-1971. However, once safety injection is  
This review shall be limited to that portion of design being changed. Revisions that do not involve a change in design concept shall be reviewed, approved, and issued in accordance with applicable EAPs. For calculations, the applicable portions of this EAP and independent objective review requirements contained in EAP 5.3 shall be applied to initial issues and all subsequent revisions.
 
Westinghouse has also updated their Quality Assurance Program to reflect changes in the regulatory process and, in particular, Regulatory Guide 1.64. Changes are described in Westinghouse Topical Reports WCAP-8370, "Westinghouse Quality Assurance Program," and WCAP-7800, BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 38 of 91 "Nuclear Fuel Division Quality Assurance Program."  WCAP-8370 revisions applicable to activities for specific time periods are Rev. 7A (June 1, 1975 - Sept. 30, 1977), Rev.
initiated manually, all automatic functions follow except for the opening of the containment sump isolation valves. These valves remain closed until receipt of a low level  
8A (Oct. 1, 1977 - Oct. 31, 1979), and Rev. 9A (Nov. 1, 1979 - present). WCAP-7800, Rev. 5, is applicable to the activities for the entire time period.
 
Westinghouse has followed the alternative to Regulatory Guide 1.64 that the designer's immediate supervisor may perform design verification in exceptional cases when the supervisor is the only qualified engineer available. For such a case, justification is documented and approved in advance by the supervisor's management.
signal from the refueling water storage tank level instrumentation.
RG No. 1.63, Rev. 2 UFSAR Reference Section 8.3 ELECTRIC PENETRATION ASSEMBLIES IN CONTAINMENT STRUCTURES FOR LIGHT-WATER COOLED NUCLEAR POWER PLANTS (JULY 1978)
 
Since Beaver Valley Power Station - Unit 2 (BVPS-2) was docketed before August 31, 1978, the methods described in Regulatory Guide 1.63 were not required to be used in the evaluation of the BVPS-2 Construction Permit application. However, the design and construction of the electric penetration assemblies on BVPS-2  
 
follow the guidance of this regulatory guide, except that a ASME Code data report, (ANI) third party inspection and ASME Code stamping of the penetrations are not required as the penetrations are an extension of the containment liner boundary which is not code stamped as discussed in Section 3.8.1.2.1.2.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 37 of 91 RG No. 1.64, Rev. 2 UFSAR Reference Section 17.2  
 
QUALITY ASSURANCE REQUIREMENTS FOR THE DESIGN OF NUCLEAR POWER PLANTS (JUNE 1976)
 
Quality Assurance Programs in effect at the time of systems design were followed in the design of BVPS-2 and meet the intent of Regulatory Guide 1.64 with the following clarifications and  
 
alternative:
Duquesne Light Company has developed a Quality Assurance Program which conforms to 10 CFR 50, Appendix B. The DLC Quality Assurance Department verifies, through the audit process, that Stone & Webster Engineering Corporation (SWEC) and Westinghouse Electric Corporation are regularly reviewing the status and adequacy of their own QA programs.
The original BVPS-2 Quality Assurance Program was described in Appendix A of the PSAR. This QA Program was  
 
initially implemented in accordance with Regulatory Guide 1.64, Rev. 0, dated October 1973. Subsequent Revisions 1 and 2 of the guide required upgrading of the design  
 
process, with the most significant changes being independent design verification by individuals not having immediate supervisory responsibility for the individual performing the design. Accordingly, SWEC Engineering Assurance Division issued a change to Engineering Assurance Procedure (EAP) 3.1, "Verification of Nuclear  
 
Plant Designs," which requires the following:
All initial issues of key design documents issued after February 8, 1977, shall be subject to independent objective review.  
 
Subsequent revisions to all key design documents, other than calculations, which contain a change in design concept shall be subject to independent objective review.
 
This review shall be limited to that portion of design being changed. Revisions that do not involve a change in design concept shall be reviewed, approved, and issued in  
 
accordance with applicable EAPs.
For calculations, the applicable portions of this EAP and independent objective review requirements contained in EAP 5.3 shall be applied to initial issues and all subsequent revisions.  
 
Westinghouse has also updated their Quality Assurance Program to reflect changes in the regulatory process and,  
 
in particular, Regulatory Guide 1.64. Changes are described in Westinghouse Topical Reports WCAP-8370, "Westinghouse Quality Assurance Program," and WCAP-7800, BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 38 of 91 "Nuclear Fuel Division Quality Assurance Program."  WCAP-8370 revisions applicable to activities for specific time periods are Rev. 7A (June 1, 1975 - Sept. 30, 1977), Rev.
8A (Oct. 1, 1977 - Oct. 31, 1979), and Rev. 9A (Nov. 1, 1979 - present). WCAP-7800, Rev. 5, is applicable to the activities for the entire time period.  
 
Westinghouse has followed the alternative to Regulatory Guide 1.64 that the designer's immediate supervisor may  
 
perform design verification in exceptional cases when the supervisor is the only qualified engineer available. For such a case, justification is documented and approved in  
 
advance by the supervisor's management.  
 
Application of Regulatory Guide 1.64 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
Application of Regulatory Guide 1.64 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.65, Rev. 0 UFSAR Reference Section 5.3.1.7 MATERIALS AND INSPECTIONS FOR REACTOR VESSEL CLOSURE STUDS (OCTOBER 1973)
RG No. 1.65, Rev. 0 UFSAR Reference Section 5.3.1.7 MATERIALS AND INSPECTIONS FOR REACTOR VESSEL CLOSURE STUDS (OCTOBER 1973)
Materials and inspection for reactor vessel closure studs meet the intent of Regulatory Guide 1.65 with the following alternatives: 1. The use of modified SA-540, Grade B24, as specified in the ASME Code (Code Case 1605) is permitted by Westinghouse but is not listed in this regulatory guide. This alternative is based on ASME Code Case 1605 which has been found acceptable to the NRC for application in the construction of components for water-cooled nuclear power plants within the limitation discussed in Regulatory Guide 1.85, which are followed by the Westinghouse practice and one use of Code Case 1605 for reactor vessel closure stud materials is not precluded by this regulatory guide. 2. A maximum ultimate tensile strength of 170,000 psi is not specified by Westinghouse, as recommended by this regulatory guide. The ASME Code requirement for toughness for reactor vessel bolting has precluded the regulatory guide's additional recommendation for tensile strength limitation, since to obtain the required toughness levels, the tensile levels are reduced.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 39 of 91 Westinghouse has specified both 45 ft-lb and 25 mils lateral expansion for control of fracture toughness determined by Charpy-V testing, required by the ASME Code, Section III, and 10 CFR 50, Appendix G, "Fracture Toughness Requirements," (Paragraph IV.A.4). These toughness requirements ensure optimization of the stud bolt material tempering operation with the accompanying reduction of the tensile strength level when compared with previous ASME Code requirements. The specification of both impact and maximum tensile strength, as stated in the regulatory guide, results in unnecessary hardship in procurement of material without any additional improvement in quality. The closure stud bolting material is procured to a minimum yield strength of 130,000 psi and a minimum tensile strength of 145,000 psi. This strength level is compatible with the fracture toughness requirement of 10 CFR 50, Appendix G (Paragraph I.C) although higher strength level bolting materials are permitted by the ASME Code. The primary concern of paragraph C.1.b(l) concerning a maximum tensile strength is to minimize the susceptibility of the bolting material to stress corrosion cracking. Stress corrosion has not been observed in reactor vessel closure stud bolting manufactured from material of this strength level. Accelerated stress corrosion test data do exist for materials of 170,000 psi minimum yield strength exposed to marine water environment stressed to 75 percent of the yield strength (given in Reference 2 of the regulatory guide). These data are not considered applicable to Westinghouse reactor vessel closure stud bolting because of the specified yield strength differences and a less severe environment; this has been demonstrated by years of satisfactory service experience. Additional protection against the possibility of incurring corrosion effects is ensured by: a. Decrease in level of tensile strength compatible with the requirement of fracture toughness as described previously.
Materials and inspection for reactor vessel closure studs meet the intent of Regulatory Guide 1.65 with the following  
: b. Design of the reactor vessel studs, nuts, and washers, allowing them to be completely removed during each refueling permitting visual and/or nondestructive inspection in parallel with refueling operations to assess protection against corrosion, as part of the inservice inspection described in Section 5.2.4.
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 40 of 91 c. Design of the reactor vessel studs, nuts, and washers, providing protection against corrosion by allowing them to be completely removed during each refueling and placed in storage racks on the containment operating deck, as required by Westinghouse refueling procedures. The stud holes in the reactor vessel flange are sealed with special plugs before removing the reactor closure. Thus, the bolting materials and stud holes are never exposed to the borated refueling cavity water. 3. Some studs cannot be removed from the vessel for surface examination per paragraph C.4.a. For these studs, it has been determined that a volumetric examination (refer to Section 5.3.3.7) is sufficient.
alternatives:  
: 4. The supplemental surface examination specified in paragraph C.4.a is not required. Improved volumetric (UT) techniques (per Appendix VIII of ASME XI) have rendered surface examinations on the studs unnecessary.
: 1. The use of modified SA-540, Grade B24, as specified in the ASME Code (Code Case 1605) is permitted by Westinghouse but is not listed in this regulatory guide. This alternative is based on ASME Code Case 1605 which has been found acceptable to the NRC for application in the construction of components for water-cooled nuclear power plants within the limitation discussed in Regulatory Guide 1.85, which are followed by the Westinghouse practice and one use of Code Case 1605 for reactor vessel closure stud materials is not precluded by this regulatory guide.  
RG No. 1.66, Rev. 0 NONDESTRUCTIVE EXAMINATION OF TUBULAR PRODUCTS (OCTOBER 1973) This regulatory guide was withdrawn October 1977.
: 2. A maximum ultimate tensile strength of 170,000 psi is not specified by Westinghouse, as recommended by this regulatory guide.
RG No. 1.67, Rev. 0 INSTALLATION OF OVERPRESSURE PROTECTION DEVICES (OCTOBER 1973)
The ASME Code requirement for toughness for reactor vessel bolting has precluded the regulatory guide's additional recommendation for tensile strength limitation, since to obtain the required toughness  
The design of piping for safety valve and relief valve stations, which have open discharge systems with limited discharge pipes and which have inlet piping that neither contains a water seal nor is subject to slug flow of water upon discharge of the valves, follows the guidance of this regulatory guide.
 
levels, the tensile levels are reduced.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 39 of 91 Westinghouse has specified both 45 ft-lb and 25 mils lateral expansion for control of fracture toughness determined by Charpy-V testing, required by the ASME Code, Section III, and 10 CFR 50, Appendix G, "Fracture Toughness Requirements," (Paragraph IV.A.4).
These toughness requirements ensure optimization of the stud bolt material tempering operation with the accompanying reduction of the tensile strength level when compared with previous ASME Code requirements.
The specification of both impact and maximum tensile strength, as stated in the regulatory guide, results in unnecessary hardship in procurement of material without any additional improvement in quality.
The closure stud bolting material is procured to a minimum yield strength of 130,000 psi and a minimum tensile strength of 145,000 psi. This strength level is compatible with the fracture toughness requirement of 10 CFR 50, Appendix G (Paragraph I.C) although higher strength level bolting materials are permitted  
 
by the ASME Code.
The primary concern of paragraph C.1.b(l) concerning a maximum tensile strength is to minimize the susceptibility of the bolting material to stress corrosion cracking. Stress corrosion has not been observed in reactor vessel closure stud bolting manufactured from material of this strength level. Accelerated stress corrosion test data do exist for materials of 170,000 psi minimum yield strength exposed to marine water environment stressed to 75 percent of the yield strength (given in Reference 2 of the regulatory guide). These data are not considered applicable to Westinghouse reactor vessel closure stud bolting because of the specified yield strength differences and a less severe environment; this has been demonstrated by years of satisfactory service experience.
Additional protection against the possibility of incurring corrosion effects is ensured by:  
: a. Decrease in level of tensile strength compatible with the requirement of fracture toughness as described previously.  
: b. Design of the reactor vessel studs, nuts, and washers, allowing them to be completely removed during each refueling permitting visual and/or nondestructive inspection in parallel with  
 
refueling operations to assess protection against corrosion, as part of the inservice inspection described in Section 5.2.4.  
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 40 of 91 c. Design of the reactor vessel studs, nuts, and washers, providing protection against corrosion by allowing them to be completely removed during each refueling and placed in storage racks on the containment operating deck, as required by Westinghouse refueling procedures. The stud holes in the reactor vessel flange are sealed with special plugs before removing the reactor closure. Thus, the bolting materials and stud holes are  
 
never exposed to the borated refueling cavity water. 3. Some studs cannot be removed from the vessel for surface examination per paragraph C.4.a. For these studs, it has been determined that a volumetric  
 
examination (refer to Section 5.3.3.7) is sufficient.  
: 4. The supplemental surface examination specified in paragraph C.4.a is not required. Improved volumetric (UT) techniques (per Appendix VIII of ASME XI) have rendered surface examinations on the studs unnecessary.  
 
RG No. 1.66, Rev. 0
 
NONDESTRUCTIVE EXAMINATION OF TUBULAR PRODUCTS (OCTOBER 1973)
This regulatory guide was withdrawn October 1977.  
 
RG No. 1.67, Rev. 0 INSTALLATION OF OVERPRESSURE PROTECTION DEVICES (OCTOBER 1973)
 
The design of piping for safety valve and relief valve stations,  
 
which have open discharge systems with limited discharge pipes and which have inlet piping that neither contains a water seal nor is subject to slug flow of water upon discharge of the  
 
valves, follows the guidance of this regulatory guide.  
 
RG No. 1.68, Rev. 2 UFSAR Reference Section 14.2  
RG No. 1.68, Rev. 2 UFSAR Reference Section 14.2  


INITIAL TEST PROGRAMS FOR WATER-COOLED NUCLEAR POWER PLANTS (AUGUST 1978)
INITIAL TEST PROGRAMS FOR WATER-COOLED NUCLEAR POWER PLANTS (AUGUST 1978)
Initial test program testing for BVPS-2 will be conducted in accordance with the intent of Regulatory Guide 1.68 for those structures, systems, and components designated by the General Design Criteria as discussed in UFSAR Section 3.1 and consistent with the extent of compliance noted in UFSAR Section 14.2.12. Compliance with the various referenced regulatory guides is discussed in UFSAR Section 1.8.
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont)  41 of 91 Initial test program testing for structures, systems, and components that are unrelated to functions designated in the General Design Criteria will be accomplished consistent with their importance to plant reliability and/or safety. For example, the condenser hotwell level control system at BVPS-2 serves no safety-related function, is not power dependent, and is clearly not governed by the regulatory bases cited in Regulatory Guide 1.68 (10CFR50 Appendices A and B). Testing performed on this system will be reasonable and prudent as determined by DLC, but is not appropriate for discussion or commitment in the UFSAR. Other examples of tests which fall into this category include the Normal AC Power Distribution System Test, Containment Instrument Air System Design Verification Test, Computer Input and Printout Data Test, Seismic Instrumentation Test, Computer Operability Test, Extraction Steam System Test, and Rod Cluster Control Assembly Bank and Boron Worth Measurement Test. Also, the plant performance following MSIV closure at power test will now be performed at 30 percent power rather than at 100 percent power. Performance of this test at 100 percent power is unacceptable because of the potential for damage to the plant with an MSIV closure at this power level. A graded approach to testing will be implemented to provide adequate assurance, considering the importance to safety of the item, that the item will perform satisfactorily while, at the same time, assuring the testing is accomplished in a cost effective manner.
RG No. 1.68.1, Rev. 1 PREOPERATIONAL AND INITIAL STARTUP TESTING OF FEEDWATER AND CONDENSATE SYSTEMS FOR BOILING WATER REACTOR POWER PLANTS (JANUARY 1977)
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
RG No. 1.68.2, Rev. 1 UFSAR Reference Section 14.2  INITIAL STARTUP TEST PROGRAM TO DEMONSTRATE REMOTE SHUTDOWN CAPABILITY FOR WATER-COOLED NUCLEAR POWER PLANTS (JULY 1978)
The initial start-up test program to demonstrate remote shutdown capability for BVPS-2 follows the guidance of Regulatory Guide 1.68.2 with the following clarification:  Paragraph C.3  The test does not require the turbine generator to be in operation since it would produce an unnecessary perturbation on the electrical distribution system. Steam can be bypassed to the main condenser with the reactor at a moderate power level.


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 42 of 91 During the test, the only action necessary with regard to the turbine is the reactor trip which is initiated at the switchgear and results in a turbine trip signal. Under actual conditions, the trip would occur prior to evacuating the control room and no further actions regarding the turbine are necessary. Therefore, the purposes specified in the Regulatory Guide (demonstration of design, procedures, procedural familiarity and sufficient numbers of personnel) are in no way dependent on actual operation of the turbine. RG No. 1.68.3, Rev. 0 UFSAR Reference Section 14.2  
Initial test program testing for BVPS-2 will be conducted in accordance with the intent of Regulatory Guide 1.68 for those structures, systems, and components designated by the General Design Criteria as discussed in UFSAR Section 3.1 and consistent with the extent of compliance noted in UFSAR Section 14.2.12. Compliance with the various referenced regulatory guides is
 
discussed in UFSAR Section 1.8.
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 41 of 91 Initial test program testing for structures, systems, and components that are unrelated to functions designated in the General Design Criteria will be accomplished consistent with their importance to plant reliability and/or safety. For example, the condenser hotwell level control system at BVPS-2 serves no safety-related function, is not power dependent, and is clearly not governed by the regulatory bases cited in Regulatory Guide 1.68 (10CFR50 Appendices A and B). Testing performed on this system will be reasonable and prudent as determined by DLC, but is not appropriate for discussion or commitment in the UFSAR. Other examples of tests which fall into this category include the Normal AC Power Distribution System Test, Containment Instrument Air System Design Verification Test, Computer Input and Printout Data Test, Seismic Instrumentation Test, Computer Operability Test, Extraction Steam System Test, and Rod Cluster Control Assembly Bank and Boron Worth Measurement Test. Also, the plant performance following MSIV closure at power test will now be performed at 30 percent power rather than at 100 percent power. Performance of this test at 100 percent power is unacceptable because of the potential for damage to the plant with an MSIV
 
closure at this power level.
A graded approach to testing will be implemented to provide adequate assurance, considering the importance to safety of the item, that the item will perform satisfactorily while, at the same time, assuring the testing is accomplished in a cost
 
effective manner.
 
RG No. 1.68.1, Rev. 1
 
PREOPERATIONAL AND INITIAL STARTUP TESTING OF FEEDWATER AND CONDENSATE SYSTEMS FOR BOILING WATER REACTOR POWER PLANTS (JANUARY 1977)
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
 
RG No. 1.68.2, Rev. 1 UFSAR Reference Section 14.2 INITIAL STARTUP TEST PROGRAM TO DEMONSTRATE REMOTE SHUTDOWN CAPABILITY FOR WATER-COOLED NUCLEAR POWER PLANTS (JULY 1978)
 
The initial start-up test program to demonstrate remote shutdown capability for BVPS-2 follows the guidance of Regulatory Guide
 
1.68.2 with the following clarification:
Paragraph C.3 The test does not require the turbine generator to be in operation since it would produce an unnecessary perturbation on the electrical distribution system. Steam can be bypassed to the main condenser with the reactor at a moderate power level.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 42 of 91 During the test, the only action necessary with regard to the turbine is the reactor trip which is initiated at the switchgear and results in a turbine trip signal. Under actual conditions, the trip would occur prior to evacuating the control room and no further actions regarding the turbine are necessary. Therefore, the  
 
purposes specified in the Regulatory Guide (demonstration of design, procedures, procedural familiarity and sufficient numbers of personnel) are in no way dependent  
 
on actual operation of the turbine.
RG No. 1.68.3, Rev. 0 UFSAR Reference Section 14.2  


PREOPERATIONAL TESTING OF INSTRUMENT AND CONTROL AIR SYSTEMS (APRIL 1982)
PREOPERATIONAL TESTING OF INSTRUMENT AND CONTROL AIR SYSTEMS (APRIL 1982)
Preoperational testing of instrument and control air systems for BVPS-2 will meet the intent of Regulatory Guide 1.68.3 with the following alternatives and clarifications:
Paragraph C.2  As an alternative to verifying the system relief/safety valve settings, credit will be taken for the purchase of specified code valves with documented set-points. Test results were provided with the valves, as specified in the purchase documents. Paragraph C.3  A full regeneration cycle will be tested only on the station instrument air dryer since it is the only regenerative/desiccant-type dryer installed at BVPS-2. The refrigerant-type dryer installed in containment will be tested in accordance with the intended design attributes. The BVPS-2 position on testing the relief/safety valves is as stated above for Paragraph C.2. Paragraph C.6  Both station and containment air compressors are oil-free by design. The station air compressors are the dry screw-type, and the containment air compressors are the water ring-type, Therefore, oil content in the product air would be negligible. Regarding particulate matter in the product air, credit will be taken for vendor documented qualification of filter efficiency. Paragraph C.8  As an alternative to testing the backup air supplies (accumulators), credit will be taken for the fail-as-is and fail-safe design that precludes the necessity of an excess stored air supply to effect safe shutdown.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  43 of 91 Paragraph C.9  Normal valve lineups are a prerequisite to the activation of any system or equipment or the performance of tests. The valve lineup completion/signoff sheets are verified by on-shift supervision, and system interface valves are administratively controlled. This precludes the possibility of plant equipment designated by design to be supplied by the instrument and control air system being supplied by another compressed air system having less restrictive air quality requirements. Paragraph C.10  BVPS-2 has no installed equipment being supplied by the instrument and control air system and having large air requirements. The largest air requirements is less than 1 percent of the capacity of a single compressor.


RG No. 1.69, Rev. 0 UFSAR Reference Section 12.3.2 CONCRETE RADIATION SHIELDS FOR NUCLEAR POWER PLANTS (DECEMBER 1973)
Preoperational testing of instrument and control air systems for BVPS-2 will meet the intent of Regulatory Guide 1.68.3 with the following alternatives and clarifications:
Regulatory Guide 1.69 invokes the requirements and recommended practices contained in ANSI N101.6-1972, "Concrete Radiation Shields."  The design and construction procedures for Beaver Valley Power Station - Unit 2 (BVPS-2) will meet or exceed the guidance of Regulatory Guide 1.69, with the following alternatives: 1. ANSI N101.6-1972 requires that shop drawings be prepared showing details and dimensions of formwork, and then approved by the responsible engineer before fabrication of the formwork may begin. On BVPS-2, it is the responsibility of field personnel to visually check all formwork. Detail drawings are made only for special applications.
 
: 2. Finishing and patching of concrete surfaces after removal of forms will conform to Chapter 9 of ACI-301 rather than Section 8.7.5 of ANSI N101.6. It is not necessary to complete this work within 96 hours after the placing of concrete.
Paragraph C.2 As an alternative to verifying the system relief/safety valve settings, credit will be taken for the purchase of specified code valves with documented set-points. Test results were provided with the valves, as specified in the purchase documents.
: 3. Section 8.2.4 of ANSI N101.6 lists the maximum vertical drop of concrete as 5 feet. The maximum vertical drop of concrete during placement operations is 6 feet. Experience has indicated that suitable equipment and provisions are given to prevent segregation of the concrete.
Paragraph C.3 A full regeneration cycle will be tested only on the station instrument air dryer since it is the only regenerative/desiccant-type dryer installed at BVPS-2. The refrigerant-type dryer installed in containment will be tested in accordance with the intended design attributes. The BVPS-2 position on testing the relief/safety valves is as stated above for Paragraph C.2.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 44 of 91 RG No. 1.70, Rev. 3 UFSAR Reference Section 1.1 STANDARD FORMAT AND CONTENT OF SAFETY ANALYSIS REPORTS FOR NUCLEAR POWER PLANTS (NOVEMBER 1978)
Paragraph C.6 Both station and containment air compressors are oil-free by design. The station air compressors are the dry screw-type, and the containment air compressors are the water ring-type, Therefore, oil content in the product air would be negligible.
During construction of BVPS-2, Section 50.34 of 10 CFR Part 50 required that each application for a license to operate a nuclear reactor facility include a final safety analysis report (FSAR). Section 50.34 specified in general terms the information to be supplied in these safety analysis reports. The guidance of this regulatory guide was followed in identifying information to be included in the FSAR, on which the NRC could base its findings requisite to the issuance of the license.
Regarding particulate matter in the product air, credit will be taken for vendor documented qualification of filter efficiency.
RG No. 1.71, Rev. 0 UFSAR Reference Sections 5.2.3, 5.3.1.4, 10.3.6.2 WELDER QUALIFICATION FOR AREAS OF LIMITED ACCESSIBILITY (DECEMBER 1973)
Paragraph C.8 As an alternative to testing the backup air supplies (accumulators), credit will be taken for the fail-as-is and fail-safe design that precludes the necessity of an excess stored air supply to effect safe shutdown.
Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.71 with the following clarifications and alternatives: Neither the nuclear steam supply system nor the balance of plant supplier requires qualification of welders for areas of limited accessibility for shop fabrication. Current shop practices have produced high quality welds. In addition, the performance of required nondestructive evaluations provides further assurance of acceptable weld quality. Limited accessibility qualification or requalification, which is in excess of ASME Code, Section III and IX requirements, is believed to be an unduly restrictive requirement for component fabrication, where the welder's physical position relative to the welds is controlled and does not present any significant problems. In addition, shop welds of limited accessibility are repetitive due to multiple production of similar components, and such welding is closely supervised.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 43 of 91 Paragraph C.9 Normal valve lineups are a prerequisite to the activation of any system or equipment or the performance of tests. The valve lineup completion/signoff sheets are verified by on-shift supervision, and system interface valves are
For field fabrication and erection of ASME III piping, applicable welds are volumetrically inspected to the requirements and standards of ASME III, Class 1.
 
administratively controlled. This precludes the possibility of plant equipment designated by design to be supplied by the instrument and control air system being supplied by another compressed air system having less restrictive air quality requirements.
Paragraph C.10 BVPS-2 has no installed equipment being supplied by the instrument and control air system and having large air requirements. The largest air requirements is less than 1 percent of the capacity of a single compressor.
 
RG No. 1.69, Rev. 0 UFSAR Reference Section 12.3.2 CONCRETE RADIATION SHIELDS FOR NUCLEAR POWER PLANTS (DECEMBER 1973)
Regulatory Guide 1.69 invokes the requirements and recommended  
 
practices contained in ANSI N101.6-1972, "Concrete Radiation Shields."  The design and construction procedures for Beaver Valley Power Station - Unit 2 (BVPS-2) will meet or exceed the guidance of Regulatory Guide 1.69, with the following alternatives:  
: 1. ANSI N101.6-1972 requires that shop drawings be prepared showing details and dimensions of formwork,  
 
and then approved by the responsible engineer before fabrication of the formwork may begin. On BVPS-2, it is the responsibility of field personnel to visually check all formwork. Detail drawings are made only for  
 
special applications.  
: 2. Finishing and patching of concrete surfaces after removal of forms will conform to Chapter 9 of ACI-301 rather than Section 8.7.5 of ANSI N101.6. It is not necessary to complete this work within 96 hours after  
 
the placing of concrete.  
: 3. Section 8.2.4 of ANSI N101.6 lists the maximum vertical drop of concrete as 5 feet. The maximum vertical drop of concrete during placement operations is 6 feet. Experience has indicated that suitable  
 
equipment and provisions are given to prevent segregation of the concrete.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 44 of 91 RG No. 1.70, Rev. 3 UFSAR Reference Section 1.1  
 
STANDARD FORMAT AND CONTENT OF SAFETY ANALYSIS REPORTS FOR NUCLEAR POWER PLANTS (NOVEMBER 1978)
 
During construction of BVPS-2, Section 50.34 of 10 CFR Part 50 required that each application for a license to operate a nuclear reactor facility include a final safety analysis report (FSAR). Section 50.34 specified in general terms the information to be supplied in these safety analysis reports. The guidance of this regulatory guide was followed in  
 
identifying information to be included in the FSAR, on which the NRC could base its findings requisite to the issuance of the license.  
 
RG No. 1.71, Rev. 0 UFSAR Reference Sections 5.2.3, 5.3.1.4, 10.3.6.2 WELDER QUALIFICATION FOR AREAS OF LIMITED ACCESSIBILITY (DECEMBER 1973)
 
Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.71 with the following clarifications and alternatives:
Neither the nuclear steam supply system nor the balance of plant supplier requires qualification of welders for areas of limited accessibility for shop fabrication. Current  
 
shop practices have produced high quality welds. In addition, the performance of required nondestructive evaluations provides further assurance of acceptable weld  
 
quality.
Limited accessibility qualification or requalification,  
 
which is in excess of ASME Code, Section III and IX requirements, is believed to be an unduly restrictive requirement for component fabrication, where the welder's physical position relative to the welds is controlled and does not present any significant problems. In addition, shop welds of limited accessibility are repetitive due to  
 
multiple production of similar components, and such welding is closely supervised.  
 
For field fabrication and erection of ASME III piping, applicable welds are volumetrically inspected to the requirements and standards of ASME III, Class 1.
 
Volumetric nondestructive examination of the production welds made in areas of limited accessibility assures their acceptable quality.  
Volumetric nondestructive examination of the production welds made in areas of limited accessibility assures their acceptable quality.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 45 of 91 RG No. 1.72, Rev. 2 SPRAY POND PIPING MADE FROM FIBERGLASS-REINFORCED THERMOSETTING RESIN (NOVEMBER 1978)
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 45 of 91 RG No. 1.72, Rev. 2 SPRAY POND PIPING MADE FROM FIBERGLASS-REINFORCED THERMOSETTING RESIN (NOVEMBER 1978)
This guide is not applicable to Beaver Valley Power Station -
 
Unit 2 because fiberglass pipe is not used for Quality Assurance Category I applications.
This guide is not applicable to Beaver Valley Power Station -  
RG No. 1.73, Rev. 0 UFSAR Reference Section 3.11.2 QUALIFICATION TESTS OF ELECTRIC VALVE OPERATORS INSTALLED INSIDE THE CONTAINMENT OF NUCLEAR POWER PLANTS (JANUARY 1974)
 
Qualification tests of electric valve operators installed inside the containment at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.
Unit 2 because fiberglass pipe is not used for Quality Assurance Category I applications.  
 
RG No. 1.73, Rev. 0 UFSAR Reference Section 3.11.2 QUALIFICATION TESTS OF ELECTRIC VALVE OPERATORS INSTALLED INSIDE THE CONTAINMENT OF NUCLEAR POWER PLANTS (JANUARY 1974)
 
Qualification tests of electric valve operators installed inside the containment at Beaver Valley Power Station - Unit 2 follow  
 
the guidance of this regulatory guide.  
 
RG No. 1.74 UFSAR Reference Section 17.2  
RG No. 1.74 UFSAR Reference Section 17.2  


QUALITY ASSURANCE TERMS AND DEFINITIONS Application of Regulatory Guide 1.74 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
QUALITY ASSURANCE TERMS AND DEFINITIONS
RG No. 1.75, Rev. 2 UFSAR Reference Sections 7.1.2, 7.5.2, 8.3.1.4, 8.3.2.2 PHYSICAL INDEPENDENCE OF ELECTRIC SYSTEMS (SEPTEMBER 1978) Beaver Valley Power Station - Unit 2 (BVPS-2) follows the guidance of Regulatory Guide 1.75 for physical independence of electrical systems with the following clarifications:  
 
: 1. General For the purposes of electrical separation, equivalent protection is provided through enclosure by rigid aluminum conduit, rigid steel conduit, electro-metallic tubing (EMT), flexible aluminum conduit, and flexible steel conduit. Enclosures provided to meet the requirements of BTP CMEB 9.5-1 are considered equivalent to enclosures provided for electrical separation and will have 1 hour or longer fire rating.
Application of Regulatory Guide 1.74 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 46 of 91 Metal clad cable, type MC, utilized in low energy, 120 V ac and 125 V dc nominal circuits and in low density applications is considered adequately protected. As such, the minimum separation between these cables and other cables, or raceway (where required) is 1 in. These cables are further described as follows: a. Type MC cable is a factory assembly of conductors, each individually insulated, enclosed in a metallic sheath of interlocking type, or a smooth or corrugated tube. b. Largest conductor size is No. 10 AWG.
RG No. 1.75, Rev. 2 UFSAR Reference Sections 7.1.2, 7.5.2, 8.3.1.4, 8.3.2.2 PHYSICAL INDEPENDENCE OF ELECTRIC SYSTEMS (SEPTEMBER 1978)
: c. No more than six conductors. d. No more than three No. 10 AWG conductors with remaining conductors of smaller size.
Beaver Valley Power Station - Unit 2 (BVPS-2) follows the guidance of Regulatory Guide 1.75 for physical independence of electrical systems with the following clarifications:  
: e. Aluminum sheath cable (a Type MC cable in which the aluminum is continuously welded) and/or interlocked armor cable may have an overall jacket of neoprene or hypalon. Type SO or SJO cords for lighting drops to fixtures are size 12 AWG or smaller and supply low energy, 120 V ac or 125 V dc, in low density applications. Adequate protection is provided by 1 inch or greater distance to Class lE raceways.
: 1. General For the purposes of electrical separation, equivalent protection is provided through enclosure by rigid aluminum conduit, rigid steel conduit, electro-metallic tubing (EMT), flexible aluminum conduit, and flexible steel conduit. Enclosures provided to meet the requirements of BTP CMEB 9.5-1 are considered  
A raised floor panel can be used as a barrier. Panels are 1 in. thick particle board with 22 gauge steel top and bottom sheets, and are fire rated Class A. These panels are considered a barrier when used in a configuration as shown in IEEE Standard 384-1974, Figures 2, 3, or 4. The Cable Spreading Areas (CSA - Main Control Room, Cable Spreading room, and Computer Room) are protected areas and are not exposed to potential hazards such as high pressure piping, missiles, flammable material, flooding, or wiring that is not flame retardant. They do not contain high energy equipment such as switchgear, transformers, rotating equipment, or potential sources of missiles or pipe whip and are not used for storing flammable materials.
 
The General Plant Areas (GPA) have been analyzed for potential hazards and as such are categorized as areas where the damage potential is limited to failures of faults internal to the electrical equipment or circuits. 2. Paragraph C.6 Analyses of potential hazards in Section 5.1.1.1.1 of IEEE Standard 384-1974 are accomplished as follows: a. The high pressure piping and missile analyses are described in Sections 3.6 and 3.5, respectively.
equivalent to enclosures provided for electrical separation and will have 1 hour or longer fire rating.  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 47 of 91 b. The fire protection analyses are outlined in Section 9.5.1 and the Fire Protection Evaluation Report (see Table 1.7-3).   
 
: c. Flame retardant characteristics of cable systems are described in Section 8.3.3.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 46 of 91 Metal clad cable, type MC, utilized in low energy, 120 V ac and 125 V dc nominal circuits and in low density applications is considered adequately  
: d. The building design for external and internal flooding is described in Section 3.4 and 3.8, respectively. The environmental effects on safety-related components due to internal flooding are described in Sections 3.6B, 3.4, and 3.11. An extensive test program has been conducted at Wyle Labs in Huntsville, Alabama in accordance with Section 5.1.1.2 of IEEE Standard 384-1974, "IEEE Trial-Use Criteria for Separation of Class lE Equipment and Circuits", to establish minimum separation distances for BVPS-2. A test report, "Test Report on Electrical Separation Verification Testing for Duquesne Light Company's Beaver Valley Power Station - Unit 2", including the Wyle test report has been submitted under separate submittal.   
 
(See Table 1.7-3). The conclusions of this report are as follows:
protected. As such, the minimum separation between these cables and other cables, or raceway (where required) is 1 in. These cables are further described  
: a. In the General Plant Areas, the minimum horizontal spatial separation is reduced from 3 feet to 1 foot. b. Ventilated tray covers and cable bus enclosures are equivalent to solid tray covers.
 
: c. Protective Wraps. i) Lengths of cable enclosed in a protective wrap of woven silicon dioxide with a minimum of one inch free space protects adjacent cables from electrically induced problems in the cables within the protective wrap. ii) Length of cable enclosed in a protective wrap of woven silicon dioxide with a minimum of one inch free air space are protected from electrically induced problems in adjacent cables. iii) Lengths of cable enclosed in a protective wrap of woven silicon dioxide are protected from electrically induced problems in adjacent cables when the adjacent cables are also enclosed in a protective wrap of woven silicon dioxide.
as follows:  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 48 of 91 iv) The protective wrap of woven silicon dioxide (Trade Name:  SIL-TEMP) is normally 54 mils thick and is wrapped longitudinally around cable(s) with a 100 percent overlap (i.e. two thicknesses). The protective wrap of woven silicon dioxide may also be a tape, nominally 125 mils thick, applied helically with a 50 percent lap (half-lapped). In either case an overall 50 percent lap (half-lapped) of 3M No. 69 glass tape is required. d. In plant areas (both GPA and CSA) where plant arrangement precludes minimum spatial separation between redundant Class 1E circuits or between Class lE and non-Class lE circuits separation is achieved as follows: i) Tray to Tray (Section 8.3.1.4.2 Items a.1 through a.20) Vertical - One inch minimum free air space and a single tray cover Horizontal - One inch minimum free air space and a tray cover top and bottom on one tray. ii) Tray to Conduit (Section 8.3.1.4.2 Items b.1 through b.18) Vertical - One inch minimum free air space Horizontal - One inch minimum free air space iii) Cable in Air to Cable in Air (Section 8.3.1.4.2 Items d.1 through d.12) Vertical - One inch minimum free air space and enclosure of one circuit (group) in conduit or a protective wrap.             or Zero inch minimum free air space and enclosure of both circuits (groups) in protective wraps.
: a. Type MC cable is a factory assembly of conductors, each individually insulated, enclosed in a metallic sheath of interlocking type, or a smooth or corrugated tube.  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 49 of 91 Horizontal - One inch minimum free air space and enclosure of one circuit (group) in conduit or a protective wrap.             or   Zero inch minimum free air space and enclosure of both circuits (groups) in protective wraps. iv) Cable in Air to Tray (Section 8.3.1.4.2 Items e.1 through e.12) Vertical - One inch minimum free air space and a tray cover             or   Zero inch minimum free air space with both a tray cover and enclosure of the cable in a protective wrap. Horizontal - One inch minimum free air space and enclosure of one circuit (group) in conduit or a protective wrap.
: b. Largest conductor size is No. 10 AWG.  
or   Zero inch minimum free air space and enclosure of both circuits (groups) in protective wraps. v) Cable in Air to Conduit (Section 8.3.1.4.2 Items f.1 through f.6) Vertical - One inch minimum free air space Horizontal - One inch minimum free air space BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 50 of 91 e. Inside Control Switchboards and Instrument Cabinets separation between redundant Class lE or Class lE and non-Class lE wire (bundles) is provided by one of the following: i) A barrier.
: c. No more than six conductors.  
ii) A minimum of one inch free air space.
: d. No more than three No. 10 AWG conductors with remaining conductors of smaller size.  
iii) Enclosing each wire (bundles) in a protective wrap of woven silicon dioxide (no overall glass type). For justification refer to the test report. 3. Paragraph C.7 (Section 4.6 of IEEE Standard 384-1974 Minimum separation between Class lE and non-Class lE circuits is as specified in Sections 5.1.3, 5.1.4, or 5.6.2 of IEEE Standard 384-1974, except as discussed in the position under Paragraph C.6.  
: e. Aluminum sheath cable (a Type MC cable in which the aluminum is continuously welded) and/or interlocked armor cable may have an overall jacket of neoprene or hypalon.
: 4. Paragraph C.9 Cable trays for control and instrumentation cables may be filled above the side rails where the overfill has been limited to a maximum of 1 1/2 in. above the top of the side rail and where solid hat covers with a 2 in. raised flat center section are used to enclose the top of the cable tray.
Type SO or SJO cords for lighting drops to fixtures are size 12 AWG or smaller and supply low energy, 120 V ac or  
Cable splices in raceways are prohibited with the exception of the cables which are spliced in trays at penetration types IX and IX-A. The penetration manufacturers standard practice for these penetration types directs that the connection between the penetration conductor and field run cable be made by splicing. Due to the limited space at the penetrations and the size of these large power cables, installation of the termination boxes to enclose the splices is impractical. The cable trays will be enclosed by top and bottom tray covers per Section 8.3.1.4. The cable splices are made according to the cable manufacturer's procedures. The resulting splice is as good as the cable and in no way degrades the performance of the cable. 5. Paragraph C.10 Class lE cable and raceways shall be marked at intervals not exceeding 15 feet and shall be plainly visible.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 51 of 91 6. Paragraph C.12 a. Power cables that supply power to the control, computer, or cable spreading room panels, limited to 120 V ac or 125 V dc, are enclosed in rigid metallic conduit or flexible conduit at the entrance to panels.
125 V dc, in low density applications. Adequate protection is provided by 1 inch or greater distance to Class lE raceways.  
: b. Power cables serving facilities in or traversing the control, computer, or cable spreading rooms, limited to 480 V ac, 120 V ac, or 125 V dc, are enclosed in rigid metallic conduit or in flexible conduit at the entrance to panels or equipment.
 
: c. As noted above in items a and b, all power cables are totally enclosed in rigid metallic conduit or in flexible conduit or in enclosed raceways and are not exposed to free air. Any potential electrical fires caused by fault current in the power cables are not considered to be a credible hazard, since fires resulting from fault current would be contained in the conduit. In addition, these rooms are protected areas and are not subject to external energetic events such as floods, high energy pipe breaks, and missiles.
A raised floor panel can be used as a barrier. Panels are 1 in. thick particle board with 22 gauge steel top and  
: d. The loss of the above cables, or the control, computer, or cable spreading rooms due to the design basis event fire, will not compromise the capability to achieve cold shutdown as outlined in Section 9.5.1 and in the Fire Protection Evaluation Report. e. The Beaver Valley Power Station - Unit 2 design utilizes a single cable spreading room. 7. Paragraph C.16 (Section 5.6.2 of IEEE-Standard 384-1974)  The minimum 6 in. separation (or a barrier) applies to spacing between exposed terminals, contacts, and equipment of redundant Class lE circuits or Class lE and non-Class lE circuits for testing and maintenance purposes. Separation between redundant Class lE or Class lE and non-Class lE wire (bundles) is as discussed in the position in Paragraph C.6. Separation requirements for Westinghouse NSSS equipment are specifically addressed in Section 7.1.2.2.
 
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont) 52 of 91 8. Paragraph C.1 (IEEE Standard 384-1974 - Section 3, ISOLATION DEVICES) The use of two independent Class lE overcurrent devices (breakers or fuses) in series, provides electrical separation between Class lE and non-Class lE circuits under the following conditions: 1. Coordination is provided between each of the two series devices and the main Class 1E feeder breaker. 2. These devices are included in a surveillance program during normal plant operation.
bottom sheets, and are fire rated Class A. These panels are considered a barrier when used in a configuration as shown in IEEE Standard 384-1974, Figures 2, 3, or 4.
RG No. 1.76, Rev. 0 UFSAR Reference Section 3.3.2.1 DESIGN BASIS TORNADO FOR NUCLEAR POWER PLANTS (APRIL 1974) All applicable Beaver Valley Power Station - Unit 2 structures, systems, or components important to safety will be designed to withstand, or will be enclosed in structures which will withstand, the six descriptive parameters given in Table I of Regulatory Guide 1.76 for the Region I location.
The Cable Spreading Areas (CSA - Main Control Room, Cable Spreading room, and Computer Room) are protected areas and are not exposed to potential hazards such as high pressure piping, missiles, flammable material, flooding, or wiring that is not flame retardant. They do not contain high energy equipment such as switchgear, transformers, rotating equipment, or potential sources of missiles or pipe whip and are not used for storing flammable materials.  
RG No. 1.77, Rev. 0 UFSAR Reference Section 15.4.8 ASSUMPTIONS USED FOR EVALUATING A CONTROL ROD EJECTION ACCIDENT FOR PRESSURIZED WATER REACTORS (MAY 1974)
 
The assumptions used for evaluating the potential radiological consequences of a control rod ejection accident at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183. Refer to the position on Regulatory Guide 1.183, later in this table. This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.  
The General Plant Areas (GPA) have been analyzed for potential hazards and as such are categorized as areas where the damage potential is limited to failures of faults internal to the electrical equipment or circuits.  
: 2. Paragraph C.6 Analyses of potential hazards in Section 5.1.1.1.1 of  
 
IEEE Standard 384-1974 are accomplished as follows:  
: a. The high pressure piping and missile analyses are described in Sections 3.6 and 3.5, respectively.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 47 of 91  
: b. The fire protection analyses are outlined in Section 9.5.1 and the Fire Protection Evaluation Report (see Table 1.7-3).   
: c. Flame retardant characteristics of cable systems are described in Section 8.3.3.  
: d. The building design for external and internal flooding is described in Section 3.4 and 3.8, respectively. The environmental effects on safety-related components due to internal flooding  
 
are described in Sections 3.6B, 3.4, and 3.11.
An extensive test program has been conducted at Wyle Labs in Huntsville, Alabama in accordance with Section 5.1.1.2 of IEEE Standard 384-1974, "IEEE Trial-Use Criteria for Separation of Class lE  
 
Equipment and Circuits", to establish minimum separation distances for BVPS-2. A test report, "Test Report on Electrical Separation Verification Testing for Duquesne Light Company's Beaver Valley Power Station - Unit 2", including the Wyle test report has been submitted under separate submittal.   
(See Table 1.7-3). The conclusions of this report are as follows:  
: a. In the General Plant Areas, the minimum horizontal spatial separation is reduced from 3 feet to 1  
 
foot. b. Ventilated tray covers and cable bus enclosures are equivalent to solid tray covers.  
: c. Protective Wraps.
i) Lengths of cable enclosed in a protective wrap of woven silicon dioxide with a minimum of one inch free space protects adjacent  
 
cables from electrically induced problems in the cables within the protective wrap.
ii) Length of cable enclosed in a protective wrap of woven silicon dioxide with a minimum of one inch free air space are protected from electrically induced problems in adjacent cables.
iii) Lengths of cable enclosed in a protective wrap of woven silicon dioxide are protected from electrically induced problems in adjacent cables when the adjacent cables are also enclosed in a protective wrap of woven silicon dioxide.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 48 of 91 iv) The protective wrap of woven silicon dioxide (Trade Name:  SIL-TEMP) is normally 54 mils thick and is wrapped longitudinally around cable(s) with a 100 percent overlap (i.e. two thicknesses). The protective wrap of woven silicon dioxide may also be a tape,  
 
nominally 125 mils thick, applied helically with a 50 percent lap (half-lapped). In either case an overall 50 percent lap (half-
 
lapped) of 3M No. 69 glass tape is required.  
: d. In plant areas (both GPA and CSA) where plant arrangement precludes minimum spatial separation between redundant Class 1E circuits or between Class lE and non-Class lE circuits separation is  
 
achieved as follows:
i) Tray to Tray (Section 8.3.1.4.2 Items a.1 through a.20)
Vertical - One inch minimum free air space and a single tray cover Horizontal - One inch minimum free air space and a  
 
tray cover top and  
 
bottom on one tray.
ii) Tray to Conduit (Section 8.3.1.4.2 Items b.1 through b.18)
Vertical - One inch minimum free air space  
 
Horizontal - One inch minimum free air space iii) Cable in Air to Cable in Air (Section 8.3.1.4.2 Items d.1 through d.12)
Vertical - One inch minimum free air space and enclosure of one circuit (group) in  
 
conduit or a protective wrap.
or  
 
Zero inch minimum free air space and enclosure of both circuits (groups) in  
 
protective wraps.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 49 of 91 Horizontal - One inch minimum free air space and enclosure of one  
 
circuit (group) in conduit or a protective wrap.
or Zero inch minimum free air space and  
 
enclosure of both  
 
circuits (groups) in protective wraps.
iv) Cable in Air to Tray (Section 8.3.1.4.2 Items e.1 through e.12)
Vertical - One inch minimum free air space and a  
 
tray cover or Zero inch minimum free air space with both a tray cover and enclosure of the cable in a protective wrap.
Horizontal - One inch minimum free air space and enclosure of one circuit (group) in conduit or a  
 
protective wrap.  
 
or Zero inch minimum free air space and enclosure of both circuits (groups) in protective wraps.
v) Cable in Air to Conduit (Section 8.3.1.4.2 Items f.1 through f.6)
Vertical - One inch minimum free air space  
 
Horizontal - One inch minimum free air space  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 50 of 91 e. Inside Control Switchboards and Instrument Cabinets separation between redundant Class lE or Class lE and non-Class lE wire (bundles) is  
 
provided by one of the following:
i) A barrier.  
 
ii) A minimum of one inch free air space.  
 
iii) Enclosing each wire (bundles) in a protective wrap of woven silicon dioxide  
 
(no overall glass type).
For justification refer to the test report.  
: 3. Paragraph C.7 (Section 4.6 of IEEE Standard 384-1974 Minimum separation between Class lE and non-Class lE circuits is as specified in Sections 5.1.3, 5.1.4, or 5.6.2 of IEEE Standard 384-1974, except as discussed in the position under Paragraph C.6.  
: 4. Paragraph C.9 Cable trays for control and instrumentation cables may be filled above the side rails where the overfill has been limited to a maximum of 1 1/2 in. above the top of the side rail and where solid hat covers with a 2 in. raised flat center section are used to enclose the top of the cable tray.
 
Cable splices in raceways are prohibited with the exception of the cables which are spliced in trays at penetration types IX and IX-A. The penetration manufacturers standard practice for these penetration types directs that the connection between the penetration conductor and field run cable be made by splicing. Due to the limited space at the penetrations and the size of these large power cables, installation of the termination boxes to enclose the splices is impractical. The cable trays will be enclosed by top and bottom tray covers per Section  
 
8.3.1.4.
The cable splices are made according to the cable manufacturer's procedures. The resulting splice is as good as the cable and in no way degrades the performance of the cable.  
: 5. Paragraph C.10 Class lE cable and raceways shall be marked at intervals not exceeding 15 feet and shall be plainly visible.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 51 of 91 6. Paragraph C.12
: a. Power cables that supply power to the control, computer, or cable spreading room panels, limited to 120 V ac or 125 V dc, are enclosed in rigid metallic conduit or flexible conduit at the  
 
entrance to panels.  
: b. Power cables serving facilities in or traversing the control, computer, or cable spreading rooms, limited to 480 V ac, 120 V ac, or 125 V dc, are enclosed in rigid metallic conduit or in flexible  
 
conduit at the entrance to panels or equipment.  
: c. As noted above in items a and b, all power cables are totally enclosed in rigid metallic conduit or in flexible conduit or in enclosed raceways and are not exposed to free air. Any potential  
 
electrical fires caused by fault current in the power cables are not considered to be a credible hazard, since fires resulting from fault current  
 
would be contained in the conduit. In addition, these rooms are protected areas and are not subject to external energetic events such as  
 
floods, high energy pipe breaks, and missiles.  
: d. The loss of the above cables, or the control, computer, or cable spreading rooms due to the design basis event fire, will not compromise the capability to achieve cold shutdown as outlined in Section 9.5.1 and in the Fire Protection Evaluation Report.  
: e. The Beaver Valley Power Station - Unit 2 design utilizes a single cable spreading room.  
: 7. Paragraph C.16 (Section 5.6.2 of IEEE-Standard 384-1974)  The minimum 6 in. separation (or a barrier) applies to spacing between exposed terminals, contacts, and equipment of redundant Class lE circuits or Class lE and non-Class lE circuits for testing and maintenance purposes. Separation between redundant Class lE or Class lE and non-Class lE wire (bundles) is as  
 
discussed in the position in Paragraph C.6.
Separation requirements for Westinghouse NSSS  
 
equipment are specifically addressed in Section 7.1.2.2.  
 
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont) 52 of 91 8. Paragraph C.1 (IEEE Standard 384-1974 - Section 3, ISOLATION DEVICES)
The use of two independent Class lE overcurrent devices (breakers or fuses) in series, provides electrical separation between Class lE and non-Class  
 
lE circuits under the following conditions:  
: 1. Coordination is provided between each of the two series devices and the main Class 1E feeder breaker.  
: 2. These devices are included in a surveillance program during normal plant operation.  
 
RG No. 1.76, Rev. 0 UFSAR Reference Section 3.3.2.1  
 
DESIGN BASIS TORNADO FOR NUCLEAR POWER PLANTS (APRIL 1974)
All applicable Beaver Valley Power Station - Unit 2 structures, systems, or components important to safety will be designed to withstand, or will be enclosed in structures which will withstand, the six descriptive parameters given in Table I of Regulatory Guide 1.76 for the Region I location.  
 
RG No. 1.77, Rev. 0 UFSAR Reference Section 15.4.8 ASSUMPTIONS USED FOR EVALUATING A CONTROL ROD EJECTION ACCIDENT FOR PRESSURIZED WATER REACTORS (MAY 1974)
 
The assumptions used for evaluating the potential radiological consequences of a control rod ejection accident at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183.
Refer to the position on Regulatory Guide 1.183, later in this table. This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.  


BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont) 53 of 91 RG No. 1.78, Rev. 0 UFSAR Reference Sections 2.2.3, 6.4, 9.4 ASSUMPTIONS FOR EVALUATING THE HABITABILITY OF A NUCLEAR POWER PLANT CONTROL ROOM DURING A POSTULATED HAZARDOUS CHEMICAL RELEASE (JUNE 1974)
BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont) 53 of 91 RG No. 1.78, Rev. 0 UFSAR Reference Sections 2.2.3, 6.4, 9.4  
Assumptions for evaluating the habitability of the Beaver Valley Power Station - Unit 2 (BVPS-2) portion of the main control room during a postulated hazardous chemical release meet the intent of this regulatory guide with the following clarifications and alternative:  
 
: 1. Of the various evaluation methods available, BVPS-2 evaluation has been performed by the methodology outlined in NUREG-0570, published in June 1979, which is similar to that presented in Appendix B of Regulatory Guide 1.78 but at a much greater level of detail and refinement.
ASSUMPTIONS FOR EVALUATING THE HABITABILITY OF A NUCLEAR POWER PLANT CONTROL ROOM DURING A POSTULATED HAZARDOUS CHEMICAL RELEASE (JUNE 1974)
: 2. Protection of the control room during a chlorine release is not required due to removal of on-site chlorine storage. Paragraph C.9 The control room emergency ventilation system is used to pressurize the control room envelope. Periodic control room envelope unfiltered air inleakage tests are performed to confirm that the control room envelope is operable.
 
Assumptions for evaluating the habitability of the Beaver Valley Power Station - Unit 2 (BVPS-2) portion of the main control room during a postulated hazardous chemical release meet the intent of this regulatory guide with the following clarifications and  
 
alternative:  
: 1. Of the various evaluation methods available, BVPS-2 evaluation has been performed by the methodology outlined in NUREG-0570, published in June 1979, which is similar to that presented in Appendix B of Regulatory Guide 1.78 but at a much greater level of  
 
detail and refinement.  
: 2. Protection of the control room during a chlorine release is not required due to removal of on-site  
 
chlorine storage.
Paragraph C.9
 
The control room emergency ventilation system is used to pressurize the control room envelope. Periodic control room envelope unfiltered air inleakage tests are performed to confirm that the control room envelope is operable.  


RG No. 1.79, Rev. 1 UFSAR Reference Sections 6.3, 14.2  
RG No. 1.79, Rev. 1 UFSAR Reference Sections 6.3, 14.2  


PREOPERATIONAL TESTING OF EMERGENCY CORE COOLING SYSTEMS FOR PRESSURIZED WATER REACTORS (SEPTEMBER 1975)
PREOPERATIONAL TESTING OF EMERGENCY CORE COOLING SYSTEMS FOR PRESSURIZED WATER REACTORS (SEPTEMBER 1975)
The program for preoperational testing of the Emergency Core Cooling Systems is performed by following the guidance of this regulatory guide with the following clarification:
 
The program for preoperational testing of the Emergency Core Cooling Systems is performed by following the guidance of this  
 
regulatory guide with the following clarification:  
 
Paragraph C.1.c(2) recommends a test of the accumulator isolation valves with full accumulator pressure and zero RCS pressure. R.G. 1.79 clearly states the purpose for the subject test to be "to ensure that inadvertent valve closures do not prevent operation of the core flooding system if required." Administrative controls and technical specification requirements provide assurance that accumulator isolation valves will never be required to change position in performance of a safety function.
Paragraph C.1.c(2) recommends a test of the accumulator isolation valves with full accumulator pressure and zero RCS pressure. R.G. 1.79 clearly states the purpose for the subject test to be "to ensure that inadvertent valve closures do not prevent operation of the core flooding system if required." Administrative controls and technical specification requirements provide assurance that accumulator isolation valves will never be required to change position in performance of a safety function.
These controls include power removal upon opening the valve. Alarms which reflash at regular intervals are provided to alert the operator when a valve is not fully open. Technical specifications require periodic verification of valve position, periodic verification of power removal, and plant shutdown if any valve is not opened.
These controls include power removal upon opening the valve. Alarms which reflash at regular intervals are  
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont) 54 of 91 Therefore, the "inadvertent valve closures" which are the source of concern for this test are eliminated unless multiple failures are postulated. These failures would include combinations of the following: 1. Failure to open the valve per technical and operating procedures.
 
: 2. Failure of the power removal circuit or failure to remove valve power once the valve is open.
provided to alert the operator when a valve is not fully  
: 3. Failure of one or more operators to heed the alarm indicating a valve which is not fully open or failure of the alarm. 4. Failure of one or more operators to heed reflash of the alarm.
 
: 5. Incorrect verification of valve position on a periodic basis in violation of technical specifications.
open. Technical specifications require periodic verification of valve position, periodic verification of power removal, and plant shutdown if any valve is not  
Since combinations of these failures would be required to allow an inadvertent accumulator isolation valve closure to occur and not be noticed and corrected, the situation would be highly unlikely. Protecting or testing for multiple failures is over and above philosophy and is not considered necessary. It should be noted that R.G. 1.79 was issued in 1975. This occurred prior to the initiation of the currently used "power removal techniques" found in the industry today.
 
RG No. 1.80, Rev. 0 UFSAR Reference Section 14.2 PREOPERATIONAL TESTING OF INSTRUMENT AIR SYSTEMS (JUNE 1974) This regulatory guide has been withdrawn (April 1982). Regulatory Guide 1.68.3 ("Preoperational Testing of Instrument and Control Air Systems," Rev. 0, April 1982) now applies.
opened.
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont) 54 of 91 Therefore, the "inadvertent valve closures" which are the source of concern for this test are eliminated unless multiple failures are postulated. These failures would  
 
include combinations of the following:  
: 1. Failure to open the valve per technical and operating procedures.  
: 2. Failure of the power removal circuit or failure to remove valve power once the valve is open.  
: 3. Failure of one or more operators to heed the alarm indicating a valve which is not fully open or failure of the alarm.  
: 4. Failure of one or more operators to heed reflash of the alarm.  
: 5. Incorrect verification of valve position on a periodic basis in violation of technical specifications.  
 
Since combinations of these failures would be required to allow an inadvertent accumulator isolation valve closure to occur and not be noticed and corrected, the situation  
 
would be highly unlikely. Protecting or testing for multiple failures is over and above philosophy and is not considered necessary. It should be noted that R.G. 1.79  
 
was issued in 1975. This occurred prior to the initiation of the currently used "power removal techniques" found in the industry today.  
 
RG No. 1.80, Rev. 0 UFSAR Reference Section 14.2  
 
PREOPERATIONAL TESTING OF INSTRUMENT AIR SYSTEMS (JUNE 1974)
This regulatory guide has been withdrawn (April 1982). Regulatory Guide 1.68.3 ("Preoperational Testing of Instrument  
 
and Control Air Systems," Rev. 0, April 1982) now applies.  
 
RG No. 1.81, Rev. 1 UFSAR Reference Sections 8.1, 8.3.1, 8.3.2  
RG No. 1.81, Rev. 1 UFSAR Reference Sections 8.1, 8.3.1, 8.3.2  


SHARED EMERGENCY AND SHUTDOWN ELECTRIC SYSTEMS FOR MULTI-UNIT NUCLEAR POWER PLANTS (JANUARY 1975)
SHARED EMERGENCY AND SHUTDOWN ELECTRIC SYSTEMS FOR MULTI-UNIT NUCLEAR POWER PLANTS (JANUARY 1975)
The design of the BVPS-2 onsite emergency and shutdown electric systems follows the guidance of this regulatory guide. The safe shutdown basis for BVPS-2 is described in the conformance evaluation for Regulatory Guide 1.139 (UFSAR Section 1.8). None of the equipment required for compliance with this safe shutdown commitment for BVPS-2 is powered from electrical systems shared with BVPS-1.
BVPS-2 UFSAR Rev. 17  TABLE 1.8-1 (Cont)  55 of 91 RG No. 1.82, Rev. 0 UFSAR Reference Section 6.2.2.2 SUMPS FOR EMERGENCY CORE COOLING AND CONTAINMENT SPRAY SYSTEMS (JUNE 1974)
Design of the sumps for emergency core cooling and containment spray systems at Beaver Valley Power Station Unit 2 (BVPS-2) meets the intent of this regulatory guide with the following alternatives:
Paragraphs C.1 and C.2 require two separate sumps in containment to supply the redundant halves of the emergency core cooling system (ECCS) and containment spray systems (CSS). Beaver Valley Power Station - Unit 2 provides a single sump with physical separation by perforated plate between the two halves which supply the redundant ECCS and CSS.


Paragraphs C.3 and C.6 require an outer trash rack. The BVPS-2 strainer is constructed of perforated stainless steel plate. The strength of the plate plus the larger size and complex geometry of the strainer eliminate the need for a separate trash rack. Although the new design does include a trash rack, it simply protects the strainer elements as defense in depth, and is not credited with meeting RG 1.82.
The design of the BVPS-2 onsite emergency and shutdown electric systems follows the guidance of this regulatory guide.
Paragraph C.4 requires that the containment floor slope down away from the sump to minimize debris entering the sump. A portion of BVPS-2 containment floor slopes down toward the sump but a raised lip is provided which directs normal floor drainage to the segmented section of the containment sump and will prevent small debris from being swept directly into the sump due to the slope.  
The safe shutdown basis for BVPS-2 is described in the conformance evaluation for Regulatory Guide 1.139 (UFSAR Section 1.8). None of the equipment required for compliance with this safe shutdown commitment for BVPS-2 is powered from electrical systems shared with BVPS-1.  


Paragraph C.7 requires a reactor coolant velocity through sump screens to be approximately 0.2 ft/sec which will allow fine debris to settle out. The BVPS-2 sump screen velocity is approximately 0.2 ft/sec and is considered satisfactory for the intent of Regulatory Guide 1.82.  
BVPS-2 UFSAR Rev. 17  TABLE 1.8-1 (Cont) 55 of 91 RG No. 1.82, Rev. 0 UFSAR Reference Section 6.2.2.2
 
SUMPS FOR EMERGENCY CORE COOLING AND CONTAINMENT SPRAY SYSTEMS (JUNE 1974)
 
Design of the sumps for emergency core cooling and containment spray systems at Beaver Valley Power Station Unit 2 (BVPS-2) meets the intent of this regulatory guide with the following
 
alternatives:
 
Paragraphs C.1 and C.2 require two separate sumps in containment to supply the redundant halves of the emergency core cooling system (ECCS) and containment spray systems (CSS). Beaver Valley Power Station - Unit 2
 
provides a single sump with physical separation by
 
perforated plate between the two halves which supply the redundant ECCS and CSS.
 
Paragraphs C.3 and C.6 require an outer trash rack. The BVPS-2 strainer is constructed of perforated stainless steel plate. The strength of the plate plus the larger size and complex geometry of the strainer eliminate the need for a separate trash rack. Although the new design does include a trash rack, it simply protects the strainer elements as defense in depth, and is not credited with meeting RG 1.82.
 
Paragraph C.4 requires that the containment floor slope down away from the sump to minimize debris entering the sump. A portion of BVPS-2 containment floor slopes down
 
toward the sump but a raised lip is provided which directs normal floor drainage to the segmented section of the containment sump and will prevent small debris from being
 
swept directly into the sump due to the slope.
 
Paragraph C.7 requires a reactor coolant velocity through sump screens to be approximately 0.2 ft/sec which will  
 
allow fine debris to settle out. The BVPS-2 sump screen velocity is approximately 0.2 ft/sec and is considered  
 
satisfactory for the intent of Regulatory Guide 1.82.  


RG No. 1.83, Rev. 1 UFSAR Reference Section 5.4.2.2.1  
RG No. 1.83, Rev. 1 UFSAR Reference Section 5.4.2.2.1  


INSERVICE INSPECTION OF PRESSURIZED WATER REACTOR STEAM GENERATOR TUBES (JULY 1975)
INSERVICE INSPECTION OF PRESSURIZED WATER REACTOR STEAM GENERATOR TUBES (JULY 1975)
The program for inservice inspection of steam generator tubes at Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide with the following alternative:
 
Inservice inspection of steam generator tubes is performed in accordance with a steam generator program required by Technical Specifications. Required program provisions, such as for condition monitoring assessments and tube inspections, are specifically described in the Technical Specifications.
The program for inservice inspection of steam generator tubes at Beaver Valley Power Station - Unit 2 meets the intent of this  
BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont) 56 of 91 RG No. 1.84, Rev. 24 UFSAR Reference Section 5.2.1.2  
 
regulatory guide with the following alternative:  
 
Inservice inspection of steam generator tubes is performed  
 
in accordance with a steam generator program required by  
 
Technical Specifications. Required program provisions, such as for condition monitoring assessments and tube inspections, are specifically described in the Technical  
 
Specifications.
BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont) 56 of 91 RG No. 1.84, Rev. 24 UFSAR Reference Section 5.2.1.2  


DESIGN AND FABRICATION CODE CASE ACCEPTABILITY ASME SECTION III DIVISION 1 (JUNE 1986)
DESIGN AND FABRICATION CODE CASE ACCEPTABILITY ASME SECTION III DIVISION 1 (JUNE 1986)
Utilization of code cases for design and fabrication for BVPS-2 follows the guidance of this regulatory guide.


All applicable ASME III Code Cases utilized for BVPS-2 are identified in the ASME Code Baseline Document.
Utilization of code cases for design and fabrication for BVPS-2
 
follows the guidance of this regulatory guide.
 
All applicable ASME III Code Cases utilized for BVPS-2 are  
 
identified in the ASME Code Baseline Document.  


RG No. 1.85, Rev. 24 UFSAR Reference Sections 4.5.1, 4.5.2, 5.2.1.2, 5.4.2.1  
RG No. 1.85, Rev. 24 UFSAR Reference Sections 4.5.1, 4.5.2, 5.2.1.2, 5.4.2.1  


MATERIALS CODE CASE ACCEPTABILITY ASME SECTION III DIVISION 1 (JUNE 1986)
MATERIALS CODE CASE ACCEPTABILITY ASME SECTION III DIVISION 1 (JUNE 1986)
Utilization of materials code cases for BVPS-2 follows the guidance of this regulatory guide.


All applicable ASME-III Code Cases utilized for BVPS-2 are identified in the ASME Code Baseline Document.
Utilization of materials code cases for BVPS-2 follows the
 
guidance of this regulatory guide.
 
All applicable ASME-III Code Cases utilized for BVPS-2 are  
 
identified in the ASME Code Baseline Document.  


RG No. 1.86, Rev. 0 UFSAR Reference Section 5.8 (ER-OLS)  
RG No. 1.86, Rev. 0 UFSAR Reference Section 5.8 (ER-OLS)  


TERMINATION OF OPERATING LICENSES FOR NUCLEAR REACTORS (JUNE 1974)
TERMINATION OF OPERATING LICENSES FOR NUCLEAR REACTORS (JUNE 1974)
The guidance of this Regulatory Guide will be followed when termination of the Beaver Valley Power Station - Unit 2 operating license is desired.


RG No. 1.87, Rev. 1 GUIDANCE FOR CONSTRUCTION OF CLASS 1 COMPONENTS IN ELEVATED TEMPERATURE REACTORS (SUPPLEMENT TO ASME SECTION III CODE CASES 1592, 1593, 1594, 1595, AND 1596) (JUNE 1975)
The guidance of this Regulatory Guide will be followed when termination of the Beaver Valley Power Station - Unit 2
 
operating license is desired.
 
RG No. 1.87, Rev. 1
 
GUIDANCE FOR CONSTRUCTION OF CLASS 1 COMPONENTS IN ELEVATED TEMPERATURE REACTORS (SUPPLEMENT TO ASME SECTION III CODE CASES 1592, 1593, 1594, 1595, AND 1596) (JUNE 1975)
 
This regulatory guide is not applicable to Beaver Valley Power
 
Station - Unit 2.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 57 of 91 RG No. 1.88 UFSAR Reference Sections 9.5.1, 17.2
 
COLLECTION, STORAGE, AND MAINTENANCE OF NUCLEAR POWER PLANT QUALITY ASSURANCE RECORDS
 
Application of Regulatory Guide 1.88 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.89, Rev. 1 UFSAR Reference Section 3.11 ENVIRONMENTAL QUALIFICATION OF CERTAIN ELECTRIC EQUIPMENT IMPORTANT TO SAFETY FOR NUCLEAR POWER PLANTS (JUNE 1984)
 
BVPS-2 electric equipment important to safety is qualified to meet or exceed the intent of IEEE Std. 323-1971 and Category II of NUREG 0588, Rev. 1. For BVPS-2, this includes both safety-related and certain post-accident equipment. When determined possible, the qualification of this equipment will be upgraded to meet the standards set forth in Category I of NUREG-0588, Rev. 1. In accordance with 10CFR50.49(k), BVPS-2 is not required to requalify electric equipment important to safety (except replacement equipment) in accordance with Regulatory Guide 1.89, Rev. 1. Replacement electric equipment important to
 
safety will be qualified in accordance with the guidance provided in Paragraph C.6 of this regulatory guide. Qualification records for replacement electric equipment will
 
meet the intent of Appendix E of this regulatory guide by meeting the applicable requirements of 10 CFR 50.49.
 
RG No. 1.90, Rev. 1 IN-SERVICE INSPECTION OF PRESTRESSED CONCRETE CONTAINMENT STRUCTURES WITH GROUTED TENDONS (AUGUST 1977)
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.  
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  57 of 91 RG No. 1.88 UFSAR Reference Sections 9.5.1, 17.2 COLLECTION, STORAGE, AND MAINTENANCE OF NUCLEAR POWER PLANT QUALITY ASSURANCE RECORDS Application of Regulatory Guide 1.88 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.91, Rev. 1 UFSAR Reference Section 2.2.3.1.1 EVALUATIONS OF EXPLOSIONS POSTULATED TO OCCUR ON TRANSPORTATION ROUTES NEAR NUCLEAR POWER PLANTS (FEBRUARY 1978)
RG No. 1.89, Rev. 1 UFSAR Reference Section 3.11  ENVIRONMENTAL QUALIFICATION OF CERTAIN ELECTRIC EQUIPMENT IMPORTANT TO SAFETY FOR NUCLEAR POWER PLANTS (JUNE 1984)
 
BVPS-2 electric equipment important to safety is qualified to meet or exceed the intent of IEEE Std. 323-1971 and Category II of NUREG 0588, Rev. 1. For BVPS-2, this includes both safety-related and certain post-accident equipment. When determined possible, the qualification of this equipment will be upgraded to meet the standards set forth in Category I of NUREG-0588, Rev. 1. In accordance with 10CFR50.49(k), BVPS-2 is not required to requalify electric equipment important to safety (except replacement equipment) in accordance with Regulatory Guide 1.89, Rev. 1. Replacement electric equipment important to safety will be qualified in accordance with the guidance provided in Paragraph C.6 of this regulatory guide. Qualification records for replacement electric equipment will meet the intent of Appendix E of this regulatory guide by meeting the applicable requirements of 10 CFR 50.49.
Evaluation of the consequences of explosions postulated to occur on transportation routes near Beaver Valley Power Station -  
RG No. 1.90, Rev. 1  IN-SERVICE INSPECTION OF PRESTRESSED CONCRETE CONTAINMENT STRUCTURES WITH GROUTED TENDONS (AUGUST 1977)
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
Unit 2 follows the guidance of Regulatory Guide 1.91.  
RG No. 1.91, Rev. 1 UFSAR Reference Section 2.2.3.1.1 EVALUATIONS OF EXPLOSIONS POSTULATED TO OCCUR ON TRANSPORTATION ROUTES NEAR NUCLEAR POWER PLANTS (FEBRUARY 1978)
 
Evaluation of the consequences of explosions postulated to occur on transportation routes near Beaver Valley Power Station -
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 58 of 91 RG No. 1.92, Rev. 1 UFSAR Reference 3.7B.2, 3.7N.2  
Unit 2 follows the guidance of Regulatory Guide 1.91.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 58 of 91 RG No. 1.92, Rev. 1 UFSAR Reference 3.7B.2, 3.7N.2 COMBINING MODAL RESPONSES AND SPATIAL COMPONENTS IN SEISMIC RESPONSE ANALYSIS (FEBRUARY 1976)
COMBINING MODAL RESPONSES AND SPATIAL COMPONENTS IN SEISMIC RESPONSE ANALYSIS (FEBRUARY 1976)
The combining of modal responses in the seismic response analysis for Beaver Valley Power Station - Unit 2 follow the guidance of Regulatory Guide 1.92 with the following clarifications: If there are no closely spaced modes, the responses are combined by using the square root sum of the squares (SRSS) method. When there are closely spaced modes, the responses are combined by using either the grouping method, as discussed in Paragraph 1.2.1 of the regulatory guide or by using the double sum method, as discussed in Paragraph 1.2.3 of the regulatory guide or by using a method similar to the ten percent method as discussed in Paragraph 1.2.2 but with the inclusion of coupling factors as in the double sum method.
 
Responses from the orthogonal earthquake inputs are obtained by either the absolute addition of the worst horizontal plus vertical responses or the SRSS combination of the two horizontal direction responses and then the absolute addition of the vertical response.
The combining of modal responses in the seismic response analysis for Beaver Valley Power Station - Unit 2 follow the guidance of Regulatory Guide 1.92 with the following  
RG No. 1.93, Rev. 0 UFSAR Reference Sections 8.1, 8.3 AVAILABILITY OF ELECTRIC POWER SOURCES (DECEMBER 1974) BVPS-2 will follow the guidance of this regulatory guide for operation of the plant in the event of loss of electric power sources.
 
clarifications:
If there are no closely spaced modes, the responses are combined by using the square root sum of the squares (SRSS) method. When there are closely spaced modes, the responses are combined by using either the grouping method, as discussed in Paragraph 1.2.1 of the regulatory guide or by using the double sum method, as discussed in Paragraph 1.2.3 of the regulatory guide or by using a method similar to the ten percent method as discussed in Paragraph 1.2.2 but with the inclusion of coupling factors as in the double sum method.  
 
Responses from the orthogonal earthquake inputs are obtained by either the absolute addition of the worst horizontal plus vertical responses or the SRSS combination of the two horizontal direction responses and then the absolute addition of the vertical response.  
 
RG No. 1.93, Rev. 0 UFSAR Reference Sections 8.1, 8.3 AVAILABILITY OF ELECTRIC POWER SOURCES (DECEMBER 1974)
BVPS-2 will follow the guidance of this regulatory guide for operation of the plant in the event of loss of electric power  
 
sources.  
 
RG No. 1.94, Rev. 1 UFSAR Reference Sections 3.8.1, 3.8.3, 3.8.4, 17.1, 17.2  
RG No. 1.94, Rev. 1 UFSAR Reference Sections 3.8.1, 3.8.3, 3.8.4, 17.1, 17.2  


QUALITY ASSURANCE REQUIREMENTS FOR INSTALLATION, INSPECTION, AND TESTING OF STRUCTURAL CONCRETE AND STRUCTURAL STEEL DURING THE CONSTRUCTION PHASE OF NUCLEAR POWER PLANTS (APRIL 1976) Quality assurance requirements for installation, inspection, and testing of structural concrete and structural steel during the construction phase at BVPS-2 meet the intent of this Regulatory Guide with the following clarifications and alternatives: The BVPS-2 Quality Assurance Program for structural concrete and steel follows WASH 1283, dated May 24, 1984, and WASH 1309, dated May 10, 1974.  
QUALITY ASSURANCE REQUIREMENTS FOR INSTALLATION, INSPECTION, AND TESTING OF STRUCTURAL CONCRETE AND STRUCTURAL STEEL DURING THE CONSTRUCTION PHASE OF NUCLEAR POWER PLANTS (APRIL 1976)
Quality assurance requirements for installation, inspection, and testing of structural concrete and structural steel during the construction phase at BVPS-2 meet the intent of this Regulatory Guide with the following clarifications and alternatives:
The BVPS-2 Quality Assurance Program for structural concrete and steel follows WASH 1283, dated May 24, 1984, and WASH 1309, dated May 10, 1974.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 59 of 91 The provisions of Articles CC4334 and CC4330 of the "Code for Concrete Reactor Vessels and Containments" (ASME Boiler and Pressure Vessel Code, Section III, Division 2, 1975 Edition) were not applied to BVPS-2 since the BVPS-2 reactor containment purchase order had been placed prior to the 1975 edition of the Division 2 ASME Code.
 
Alternatives to ANSI N45.2.5-1974 are taken with respect to frequency of calibration of impact wrenches and bolt projection criteria. Impact and torque wrenches shall be checked at least once daily per shift, and at least one full thread of all bolts shall project beyond the nut of
 
all tightened connections. These criteria comply with the recommendations of the Research Council on Riveted and Bolted Structural Joints.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  59 of 91 The provisions of Articles CC4334 and CC4330 of the "Code for Concrete Reactor Vessels and Containments" (ASME Boiler and Pressure Vessel Code, Section III, Division 2, 1975 Edition) were not applied to BVPS-2 since the BVPS-2 reactor containment purchase order had been placed prior to the 1975 edition of the Division 2 ASME Code.
Alternatives to ANSI N45.2.5-1974 are taken with respect to frequency of calibration of impact wrenches and bolt projection criteria. Impact and torque wrenches shall be checked at least once daily per shift, and at least one full thread of all bolts shall project beyond the nut of all tightened connections. These criteria comply with the recommendations of the Research Council on Riveted and Bolted Structural Joints.
Application of Regulatory Guide 1.94 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
Application of Regulatory Guide 1.94 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.95, Rev. 1 UFSAR Reference Sections 2.2.1, 2.2.3.1.2, 6.4.4.2, 9.4.1 PROTECTION OF NUCLEAR POWER PLANT CONTROL ROOM OPERATORS AGAINST AN ACCIDENTAL CHLORINE RELEASE (JANUARY 1977)
RG No. 1.95, Rev. 1 UFSAR Reference Sections 2.2.1, 2.2.3.1.2, 6.4.4.2, 9.4.1  
Protection of the Beaver Valley Power Station - Unit 2 control room operators against an accidental chlorine release is not required because there is no on-site chlorine storage. RG No. 1.96, Rev. 1 DESIGN OF MAIN STEAM ISOLATION VALVE LEAKAGE CONTROL SYSTEMS FOR BOILING WATER REACTOR NUCLEAR POWER PLANTS (JUNE 1976)
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
PROTECTION OF NUCLEAR POWER PLANT CONTROL ROOM OPERATORS AGAINST AN ACCIDENTAL CHLORINE RELEASE (JANUARY 1977)
RG No. 1.97, Rev. 2 UFSAR Reference Sections 6.2, 7.4, 7.5, 9.3.2, 11.5, 12.3 INSTRUMENTATION FOR LIGHT-WATER-COOLED NUCLEAR POWER PLANTS TO ASSESS PLANT AND ENVIRONS CONDITIONS DURING AND FOLLOWING AN ACCIDENT (DECEMBER 1980) The instrumentation provided to monitor Beaver Valley Power Station - Unit 2 during and after postulated accident conditions meets the intent of this regulatory guide with the following clarifications and alternatives:  
 
Protection of the Beaver Valley Power Station - Unit 2 control room operators against an accidental chlorine release is not required because there is no on-site chlorine storage.
RG No. 1.96, Rev. 1 DESIGN OF MAIN STEAM ISOLATION VALVE LEAKAGE CONTROL SYSTEMS FOR BOILING WATER REACTOR NUCLEAR POWER PLANTS (JUNE 1976)
 
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.  
 
RG No. 1.97, Rev. 2 UFSAR Reference Sections 6.2, 7.4, 7.5, 9.3.2, 11.5, 12.3 INSTRUMENTATION FOR LIGHT-WATER-COOLED NUCLEAR POWER PLANTS TO ASSESS PLANT AND ENVIRONS CONDITIONS DURING AND FOLLOWING AN ACCIDENT (DECEMBER 1980)
The instrumentation provided to monitor Beaver Valley Power Station - Unit 2 during and after postulated accident conditions meets the intent of this regulatory guide with the following clarifications and alternatives:  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 60 of 91 A plant-specific analysis has been conducted to identify the appropriate variables and to establish the appropriate design basis and qualification criteria in order to provide sufficient information to allow the operating staff to ascertain plant conditions during and following an accident. As a result of this analysis, the variables to be monitored have been selected and they have been included in one or more of five classifications (Types A through E) according to their usage and need, and they
 
have been assigned design and qualification Categories 1, 2, or 3. The selection of some of these plant-specific variables and their classifications and categories are
 
different than those of Regulatory Guide 1.97.
Type A variables are not all designated Category 1. Type A variables are designated Category 2 if they are employed in the emergency operating procedures for the sole purpose of providing preferred backup information.
 
Category 1 instrumentation information is not continuously displayed but it is immediately accessible to the operator. In addition, a historical record of at least one instrumentation channel for each process variable is maintained.
 
Since Category 3 instrumentation is not part of a safety-related system, it is not qualified so that it will provide information when exposed to a post-accident adverse environment. Category 3 instrumentation is subject to servicing, testing, and calibration programs that are specified to maintain their capability. However, these programs are not in accordance with
 
Regulatory Guide 1.118 which applies to safety-related systems.


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  60 of 91 A plant-specific analysis has been conducted to identify the appropriate variables and to establish the appropriate design basis and qualification criteria in order to provide sufficient information to allow the operating staff to ascertain plant conditions during and following an accident. As a result of this analysis, the variables to be monitored have been selected and they have been included in one or more of five classifications (Types A through E) according to their usage and need, and they have been assigned design and qualification Categories 1, 2, or 3. The selection of some of these plant-specific variables and their classifications and categories are different than those of Regulatory Guide 1.97. Type A variables are not all designated Category 1. Type A variables are designated Category 2 if they are employed in the emergency operating procedures for the sole purpose of providing preferred backup information.
Category 1 instrumentation information is not continuously displayed but it is immediately accessible to the operator. In addition, a historical record of at least one instrumentation channel for each process variable is maintained.
Since Category 3 instrumentation is not part of a safety-related system, it is not qualified so that it will provide information when exposed to a post-accident adverse environment. Category 3 instrumentation is subject to servicing, testing, and calibration programs that are specified to maintain their capability. However, these programs are not in accordance with Regulatory Guide 1.118 which applies to safety-related systems.
RG No. 1.98, Rev. 0 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A RADIOACTIVE OFFGAS SYSTEM FAILURE IN A BOILING WATER REACTOR (MARCH 1976)
RG No. 1.98, Rev. 0 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A RADIOACTIVE OFFGAS SYSTEM FAILURE IN A BOILING WATER REACTOR (MARCH 1976)
This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
 
This regulatory guide is not applicable to Beaver Valley Power  
 
Station - Unit 2.  
 
RG No. 1.99, Rev. 1 UFSAR Reference Section 5.3.2.1  
RG No. 1.99, Rev. 1 UFSAR Reference Section 5.3.2.1  


EFFECTS OF RESIDUAL ELEMENTS ON PREDICTED RADIATION DAMAGE TO REACTOR VESSEL MATERIALS (APRIL 1977)
EFFECTS OF RESIDUAL ELEMENTS ON PREDICTED RADIATION DAMAGE TO REACTOR VESSEL MATERIALS (APRIL 1977)
The Beaver Valley Power Station - Unit 2 reactor vessel material meets the end-of-life reference criterion of Regulatory Guide 1.99. However, the procedures set forth in this regulatory guide are believed to be overconservative at the higher fluences, and the restriction of the end-of-life transition temperature to 200F is believed to be technically unnecessary.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 61 of 91 RG No. 1.100, Rev. 1 UFSAR Reference Section 3.10 SEISMIC QUALIFICATION OF ELECTRIC EQUIPMENT FOR NUCLEAR POWER PLANTS (AUGUST 1977)
The Beaver Valley Power Station - Unit 2 reactor vessel material meets the end-of-life reference criterion of Regulatory Guide 1.99. However, the procedures set forth in this regulatory guide are believed to be overconservative at the higher fluences, and the restriction of the end-of-life transition temperature to 200F is believed to be technically unnecessary.  
Since the Beaver Valley Power Station - Unit 2 construction permit application was docketed before October 27, 1972, Class I electrical equipment are seismically qualified in accordance with IEEE Standard 344-1971. In addition, WCAP-8373, "Qualification of Westinghouse Seismic Testing Procedure for Electrical Equipment Tested Prior to May 1974," August 1974, and letter NS-CE-692, dated July 10, 1975 from Westinghouse to D. B. Vassello (USNRC) provide justification and cover the test program that demonstrates that the tests meet the intent of IEEE Standard 344-1975 and Regulatory Guide 1.100.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 61 of 91 RG No. 1.100, Rev. 1 UFSAR Reference Section 3.10  
 
SEISMIC QUALIFICATION OF ELECTRIC EQUIPMENT FOR NUCLEAR POWER PLANTS (AUGUST 1977)
 
Since the Beaver Valley Power Station - Unit 2 construction permit application was docketed before October 27, 1972, Class I electrical equipment are seismically qualified in accordance with IEEE Standard 344-1971. In addition, WCAP-8373, "Qualification of Westinghouse Seismic Testing Procedure for Electrical Equipment Tested Prior to May 1974," August 1974, and  
 
letter NS-CE-692, dated July 10, 1975 from Westinghouse to D. B. Vassello (USNRC) provide justification and cover the test program that demonstrates that the tests meet the intent of IEEE  
 
Standard 344-1975 and Regulatory Guide 1.100.  
 
RG No. 1.101, Rev. 2 UFSAR Reference Section 13.3  
RG No. 1.101, Rev. 2 UFSAR Reference Section 13.3  


EMERGENCY PLANNING AND PREPAREDNESS FOR NUCLEAR POWER REACTORS (OCTOBER 1981)
EMERGENCY PLANNING AND PREPAREDNESS FOR NUCLEAR POWER REACTORS (OCTOBER 1981)
Beaver Valley Power Station - Unit 2 will follow the guidance of the regulatory guide for emergency planning and preparedness.
 
RG No. 1.102, Rev. 1 UFSAR Reference Sections 2.4.14, 3.4.1 FLOOD PROTECTION FOR NUCLEAR POWER PLANTS (SEPTEMBER 1976) The Beaver Valley Power Station - Unit 2 design follows the flood protection guidance of this regulatory guide.
Beaver Valley Power Station - Unit 2 will follow the guidance of the regulatory guide for emergency planning and preparedness.  
RG No. 1.103, Rev. 1 POST-TENSIONED PRESTRESSING SYSTEMS FOR CONCRETE REACTOR VESSELS AND CONTAINMENTS (OCTOBER 1976) This regulatory guide, which has been withdrawn (June 1981), was not applicable to Beaver Valley Power Station - Unit 2.
 
RG No. 1.104, Rev. 0 OVERHEAD CRANE HANDLING SYSTEMS FOR NUCLEAR POWER PLANTS (FEBRUARY 1976)
RG No. 1.102, Rev. 1 UFSAR Reference Sections 2.4.14, 3.4.1 FLOOD PROTECTION FOR NUCLEAR POWER PLANTS (SEPTEMBER 1976)
The Beaver Valley Power Station - Unit 2 design follows the flood protection guidance of this regulatory guide.  
 
RG No. 1.103, Rev. 1 POST-TENSIONED PRESTRESSING SYSTEMS FOR CONCRETE REACTOR VESSELS AND CONTAINMENTS (OCTOBER 1976)
This regulatory guide, which has been withdrawn (June 1981), was  
 
not applicable to Beaver Valley Power Station - Unit 2.  
 
RG No. 1.104, Rev. 0
 
OVERHEAD CRANE HANDLING SYSTEMS FOR NUCLEAR POWER PLANTS (FEBRUARY 1976)
This regulatory guide was withdrawn August 1979.  
This regulatory guide was withdrawn August 1979.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 62 of 91 RG No. 1.105, Rev. 1 UFSAR Reference Section 7.1.2.1.9, 7.5.2.3 INSTRUMENT SETPOINTS (NOVEMBER 1976)
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 62 of 91 RG No. 1.105, Rev. 1 UFSAR Reference Section 7.1.2.1.9, 7.5.2.3  
The establishing of instrument setpoints in systems important to safety which monitor variables that have limiting safety system settings follows the guidance of this regulatory guide with the following alternative and clarification:
 
Paragraph C.5 Administrative procedures coupled with the present cabinet alarms and/or locks provide sufficient control over the setpoint adjustment mechanism such that no integral setpoint securing device is required. Integral setpoint locking devices will not be supplied. Paragraphs C.1 and C.6 The assumptions used in selecting the setpoint values including instrument inaccuracy and calibration uncertainty and the minimum margin with respect to the technical specification limit will be documented by Westinghouse. Drift rates and their relationships to testing intervals will not be documented by Westinghouse.
INSTRUMENT SETPOINTS (NOVEMBER 1976)
RG No. 1.106, Rev. 1 THERMAL OVERLOAD PROTECTION FOR ELECTRIC MOTORS ON MOTOR-OPERATED VALVES (MARCH 1977)
 
Thermal overload protection for electric motors on motor-operated valves follows the guidance of this regulatory guide.
The establishing of instrument setpoints in systems important to safety which monitor variables that have limiting safety system settings follows the guidance of this regulatory guide with the following alternative and clarification:  
RG No. 1.107, Rev. 1 QUALIFICATIONS FOR CEMENT GROUTING FOR PRESTRESSING TENDONS IN CONTAINMENT STRUCTURES (FEBRUARY 1977) This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.
 
Paragraph C.5
 
Administrative procedures coupled with the present cabinet alarms and/or locks provide sufficient control over the setpoint adjustment mechanism such that no integral setpoint securing device is required. Integral setpoint locking devices will not be supplied.
Paragraphs C.1 and C.6 The assumptions used in selecting the setpoint values including instrument inaccuracy and calibration uncertainty and the minimum margin with respect to the technical specification limit will be documented by Westinghouse. Drift rates and their relationships to testing intervals will not be documented by Westinghouse.  
 
RG No. 1.106, Rev. 1
 
THERMAL OVERLOAD PROTECTION FOR ELECTRIC MOTORS ON MOTOR-OPERATED VALVES (MARCH 1977)
 
Thermal overload protection for electric motors on motor-operated valves follows the guidance of this regulatory guide.  
 
RG No. 1.107, Rev. 1 QUALIFICATIONS FOR CEMENT GROUTING FOR PRESTRESSING TENDONS IN CONTAINMENT STRUCTURES (FEBRUARY 1977)
This regulatory guide is not applicable to Beaver Valley Power  
 
Station - Unit 2.  
 
RG No. 1.108, Rev. 1 UFSAR Reference Sections 8.1, 8.3.1, 14.2.12.54, 14.2.12.55  
RG No. 1.108, Rev. 1 UFSAR Reference Sections 8.1, 8.3.1, 14.2.12.54, 14.2.12.55  


PERIODIC TESTING OF DIESEL GENERATOR UNITS USED AS ONSITE ELECTRIC POWER SYSTEMS AT NUCLEAR POWER PLANTS (AUGUST 1977)
PERIODIC TESTING OF DIESEL GENERATOR UNITS USED AS ONSITE ELECTRIC POWER SYSTEMS AT NUCLEAR POWER PLANTS (AUGUST 1977)
The periodic testing of diesel generator units used as on-site electric power systems at BVPS-2 will meet the intent of Regulatory Guide 1.108. All necessary periodic testing, testing frequencies, and reporting requirements are specified in the BVPS-2 Technical Specifications.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  63 of 91 Paragraph C.2.a(3) suggests a periodic 24-hour, full-load-carrying capability test consisting of 22 hours at the continuous diesel generator rating and 2 hours at the 2-hour rating. Such a test is appropriate only for initial qualification of the diesel generator by the vendor or during preoperational testing to demonstrate adequate design and construction. Since this test imposes more severe service than is required by plant design, periodic performance of this test would only serve to repeatedly demonstrate suitable design or sizing of the units and is beyond what is necessary to demonstrate operability or reliability. Testing on a periodic basis is unnecessary and is inconsistent with the goals of Generic Letter 84-15 by providing conditions which could increase diesel generator degradation and reduce reliability. The diesel generator may occasionally be run to demonstrate its capability to operate for prolonged periods (24 hours or longer) when it is determined that such operation is prudent. The periodic complete loss of load test specified in Paragraph C.2.a(4) is intended to demonstrate that the diesel overspeed limits are not exceeded upon simultaneous loss of all loads which could be supplied by the diesel. Since it is not expected that all diesel loads would be operated simultaneously, such a test would not be representative of expected operating transients. Additionally, the safety analyses do not take credit for the ability of a diesel to assume its assigned load once it is lost for any reason. Therefore, if a full load rejection is assumed, any resulting consequences to the diesel itself have been considered in the safety analyses with acceptable results. A full loss of load test is performed initially by the vendor to demonstrate acceptable response, but subsequent periodic testing is not required.
Where applicable, during preoperational testing of diesel generator units, acceptable vendor testing may be substituted in whole or in part for operator testing listed in Regulatory Guide 1.108. Sufficient testing will be conducted during the operational life of the plant to demonstrate the operability, reliability, and functional capability of the diesel generator units.
RG No. 1.109, Rev. 1 UFSAR Reference Sections 2.3.5, 11.3, Appendix 11A, 13.3 CALCULATION OF ANNUAL DOSES TO MAN FROM ROUTINE RELEASES OF REACTOR EFFLUENTS FOR THE PURPOSE OF EVALUATING COMPLIANCE WITH 10 CFR PART 50, APPENDIX I (OCTOBER 1977)  Calculation of annual doses to man from routine releases of reactor effluents at Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide. 


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  64 of 91 RG No. 1.110, Rev. 0 COST-BENEFIT ANALYSIS FOR RADWASTE SYSTEMS FOR LIGHT-WATER-COOLED NUCLEAR POWER REACTORS (MARCH 1976)
The periodic testing of diesel generator units used as on-site electric power systems at BVPS-2 will meet the intent of Regulatory Guide 1.108. All necessary periodic testing, testing frequencies, and reporting requirements are specified in the BVPS-2 Technical Specifications.
Since the Beaver Valley Power Station - Unit 2 (BVPS-2) application for a construction permit was docketed on October 20, 1972, the cost-benefit analysis is optional and will not be developed for BVPS-2.
 
RG No. 1.111, Rev. 1 UFSAR Reference Section 2.3.5 METHODS FOR ESTIMATING ATMOSPHERIC TRANSPORT AND DISPERSION OF GASEOUS EFFLUENTS IN ROUTINE RELEASES FROM LIGHT-WATER-COOLED REACTORS (JULY 1977)
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 63 of 91 Paragraph C.2.a(3) suggests a periodic 24-hour, full-load-carrying capability test consisting of 22 hours at the continuous diesel generator rating and 2 hours at the 2-hour rating. Such a test is appropriate only for initial qualification of the diesel generator by the vendor or during preoperational testing to demonstrate adequate design and construction. Since this test imposes more severe service than is required by plant design, periodic performance of this test would only serve to repeatedly demonstrate suitable design or
The methods for estimating atmospheric transport and dispersion of gaseous effluents in routine releases from Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide.
 
sizing of the units and is beyond what is necessary to demonstrate operability or reliability. Testing on a periodic basis is unnecessary and is inconsistent with the goals of
 
Generic Letter 84-15 by providing conditions which could increase diesel generator degradation and reduce reliability. The diesel generator may occasionally be run to demonstrate its capability to operate for prolonged periods (24 hours or longer) when it is determined that such operation is prudent.
The periodic complete loss of load test specified in Paragraph C.2.a(4) is intended to demonstrate that the diesel overspeed limits are not exceeded upon simultaneous loss of all loads which could be supplied by the diesel. Since it is not expected that all diesel loads would be operated simultaneously, such a test would not be representative of expected operating transients. Additionally, the safety analyses do not take credit for the ability of a diesel to assume its assigned load once it is lost for any reason. Therefore, if a full load rejection is assumed, any resulting consequences to the diesel itself have been considered in the safety analyses with acceptable results. A full loss of load test is performed initially by the vendor to demonstrate acceptable response, but subsequent periodic testing is not required.
 
Where applicable, during preoperational testing of diesel generator units, acceptable vendor testing may be substituted in whole or in part for operator testing listed in Regulatory Guide 1.108. Sufficient testing will be conducted during the operational life of the plant to demonstrate the operability, reliability, and functional capability of the diesel generator
 
units.
RG No. 1.109, Rev. 1
 
UFSAR Reference Sections 2.3.5, 11.3, Appendix 11A, 13.3
 
CALCULATION OF ANNUAL DOSES TO MAN FROM ROUTINE RELEASES OF REACTOR EFFLUENTS FOR THE PURPOSE OF EVALUATING COMPLIANCE WITH 10 CFR PART 50, APPENDIX I (OCTOBER 1977)
Calculation of annual doses to man from routine releases of
 
reactor effluents at Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide.
 
BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 64 of 91 RG No. 1.110, Rev. 0 COST-BENEFIT ANALYSIS FOR RADWASTE SYSTEMS FOR LIGHT-WATER-COOLED NUCLEAR POWER REACTORS (MARCH 1976)
 
Since the Beaver Valley Power Station - Unit 2 (BVPS-2) application for a construction permit was docketed on October 20, 1972, the cost-benefit analysis is optional and will not be developed for BVPS-2.  
 
RG No. 1.111, Rev. 1 UFSAR Reference Section 2.3.5 METHODS FOR ESTIMATING ATMOSPHERIC TRANSPORT AND DISPERSION OF GASEOUS EFFLUENTS IN ROUTINE RELEASES FROM LIGHT-WATER-COOLED REACTORS (JULY 1977)
 
The methods for estimating atmospheric transport and dispersion of gaseous effluents in routine releases from Beaver Valley Power Station - Unit 2 will follow the guidance of this  
 
regulatory guide.  
 
RG No. 1.112, Rev. 0-R UFSAR Reference Sections 2.3.5, 11.1, 11.3.3, 12.2, 15.7  
RG No. 1.112, Rev. 0-R UFSAR Reference Sections 2.3.5, 11.1, 11.3.3, 12.2, 15.7  


CALCULATION OF RELEASES OF RADIOACTIVE MATERIALS IN GASEOUS AND LIQUID EFFLUENTS FROM LIGHT-WATER-COOLED POWER REACTORS (MAY 1977)  The calculation of releases of radioactive materials in gaseous and liquid effluents at Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide.
CALCULATION OF RELEASES OF RADIOACTIVE MATERIALS IN GASEOUS AND LIQUID EFFLUENTS FROM LIGHT-WATER-COOLED POWER REACTORS (MAY 1977)  The calculation of releases of radioactive materials in gaseous and liquid effluents at Beaver Valley Power Station - Unit 2  
 
follows the guidance of this regulatory guide.  
 
RG No. 1.113, Rev. 1 UFSAR Reference Section 2.4.12  
RG No. 1.113, Rev. 1 UFSAR Reference Section 2.4.12  


ESTIMATING AQUATIC DISPERSION OF EFFLUENTS FROM ACCIDENTAL AND ROUTINE REACTOR RELEASES FOR THE PURPOSE OF IMPLEMENTING APPENDIX I (APRIL 1977) The mathematical models and dispersion coefficients selected to calculate aquatic dispersion of effluents from accidental and routine reactor releases at Beaver Valley Power Station - Unit 2 follows the guidance of Regulatory Guide 1.113.
ESTIMATING AQUATIC DISPERSION OF EFFLUENTS FROM ACCIDENTAL AND ROUTINE REACTOR RELEASES FOR THE PURPOSE OF IMPLEMENTING APPENDIX I (APRIL 1977)
RG No. 1.114, Rev. 1 UFSAR Reference Section 13.5.1 GUIDANCE ON BEING OPERATOR AT THE CONTROLS OF A NUCLEAR POWER PLANT (NOVEMBER 1976)
The mathematical models and dispersion coefficients selected to calculate aquatic dispersion of effluents from accidental and  
Operators at the controls of Beaver Valley Power Station - Unit 2 will carry out their responsibilities using the guidance of this regulatory guide.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 65 of 91 RG No. 1.115, Rev. 1 UFSAR Reference Sections 3.5.1.3, 3.5.2, 9.1.2, 9.5.4, 9.5.8 PROTECTION AGAINST LOW-TRAJECTORY TURBINE MISSILES (JULY 1977) Protection against low-trajectory turbine missiles at Beaver Valley Power Station - Unit 2 (BVPS-2) will meet the intent of this regulatory guide.
routine reactor releases at Beaver Valley Power Station - Unit 2 follows the guidance of Regulatory Guide 1.113.  
Paragraph C.4 and associated Standard Review Plan NUREG-0800, Section 3.5.1.3, Acceptance Criterion II.1 do not apply to the BVPS-2 plant design arrangement. As an alternative, the latest technical advances in the design and analysis of Westinghouse low-pressure turbine rotors will be used to provide additional assurance of a low failure probability.
 
A not-to-be-exceeded ultrasonic inspection interval and inservice inspection program is provided in Section 10.2.3 to insure missile generation probability values well below the 10-5 limit. This missile generation probability, in combination with the probability of resulting damage to safety-related equipment, maintains the total probability of turbine missile damage below the regulatory guide limit of 10-7 per year. RG No. 1.116 UFSAR Reference Section 17.2 QUALITY ASSURANCE REQUIREMENTS FOR INSTALLATION, INSPECTION, AND TESTING OF MECHANICAL EQUIPMENT AND SYSTEMS Application of Regulatory Guide 1.116 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.114, Rev. 1 UFSAR Reference Section 13.5.1 GUIDANCE ON BEING OPERATOR AT THE CONTROLS OF A NUCLEAR POWER PLANT (NOVEMBER 1976)
 
Operators at the controls of Beaver Valley Power Station - Unit 2 will carry out their responsibilities using the guidance of  
 
this regulatory guide.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 65 of 91 RG No. 1.115, Rev. 1 UFSAR Reference Sections 3.5.1.3, 3.5.2, 9.1.2, 9.5.4, 9.5.8 PROTECTION AGAINST LOW-TRAJECTORY TURBINE MISSILES (JULY 1977)
Protection against low-trajectory turbine missiles at Beaver Valley Power Station - Unit 2 (BVPS-2) will meet the intent of this regulatory guide.  
 
Paragraph C.4 and associated Standard Review Plan NUREG-0800, Section 3.5.1.3, Acceptance Criterion II.1 do not apply to the  
 
BVPS-2 plant design arrangement.
As an alternative, the latest technical advances in the design  
 
and analysis of Westinghouse low-pressure turbine rotors will be used to provide additional assurance of a low failure probability.  
 
A not-to-be-exceeded ultrasonic inspection interval and inservice inspection program is provided in Section 10.2.3 to insure missile generation probability values well below the 10
-5 limit. This missile generation probability, in combination with the probability of resulting damage to safety-related equipment, maintains the total probability of turbine missile damage below the regulatory guide limit of 10
-7 per year.
RG No. 1.116 UFSAR Reference Section 17.2 QUALITY ASSURANCE REQUIREMENTS FOR INSTALLATION, INSPECTION, AND TESTING OF MECHANICAL EQUIPMENT AND SYSTEMS
 
Application of Regulatory Guide 1.116 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual
.
RG No. 1.117, Rev. 1 UFSAR Reference Sections 3.2, 3.5, 3.8  
RG No. 1.117, Rev. 1 UFSAR Reference Sections 3.2, 3.5, 3.8  


TORNADO DESIGN CLASSIFICATION (APRIL 1978)
TORNADO DESIGN CLASSIFICATION (APRIL 1978)
The method used for identifying those structures, systems, and components at Beaver Valley Power Station Unit 2 that should be designed to withstand the effects of the design basis tornado follows the guidance of this regulatory guide.


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 66 of 91 RG No. 1.118, Rev. 2 UFSAR Reference Sections 7.5, 8.1, 8.3 PERIODIC TESTING OF ELECTRIC POWER AND PROTECTION SYSTEMS (JUNE 1978)
The method used for identifying those structures, systems, and
Periodic testing of electric power and protection systems at Beaver Valley Power Station - Unit 2 follows IEEE Standard 338-1977 and the guidance of Regulatory Guide 1.118 with the following clarifications: Equipment performing control functions, but activated from protection system sensors is not part of the safety system and is not tested for time response. Status, annunciating, display, and monitoring functions, except those related to the safety parameter display system, are considered control functions, and reasonability checks, that is, comparison between or among similar such display functions, are made.
 
Response time testing of nuclear instrumentation system detectors is not required because they exhibit response times that are an insignificant fraction of the total system response time (that is, less than 5 percent). Protection system sensors are demonstrated to be adequate by vendor testing, analysis, operating experience, or by suitable type testing.
components at Beaver Valley Power Station Unit 2 that should be designed to withstand the effects of the design basis tornado follows the guidance of this regulatory guide.
RG No. 1.119, Rev. 0 SURVEILLANCE PROGRAM FOR NEW FUEL ASSEMBLY DESIGNS (JUNE 1976)
 
This regulatory guide was withdrawn June 1977.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 66 of 91 RG No. 1.118, Rev. 2 UFSAR Reference Sections 7.5, 8.1, 8.3  
RG No. 1.120, Rev. 1 UFSAR Reference Section 9.5.1 FIRE PROTECTION GUIDELINES FOR NUCLEAR POWER PLANTS (NOVEMBER 1977)
 
This regulatory guide provides guidelines acceptable to the NRC for implementing General Design Criterion 3 (GDC 3) of 10CFR5O, Appendix A, in the development of a fire protection program. This guide is in an extended comment period and is not yet approved. Branch Technical Position (BTP) CMEB 9.5-1, which is part of the acceptance criteria of Standard Review Plan 9.5.1 (NUREG-0800), dated July 1981, also provides guidelines acceptable to the NRC for implementing GDC 3 in the development of a fire protection program. Regulatory Guide 1.120, Rev. 1, is not listed among the SRP 9.5.1 acceptance criteria. However, the guidelines of this regulatory guide have been incorporated into BTP CMEB 9.5-1. Therefore, the BVPS-2 position on this regulatory guide is covered by the evaluation of the BVPS-2 Fire Protection Program against the guidelines of BTP CMEB 9.5-1.
PERIODIC TESTING OF ELECTRIC POWER AND PROTECTION SYSTEMS (JUNE 1978)
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 67 of 91 This evaluation is provided in Section 9.5A.2.
 
Periodic testing of electric power and protection systems at Beaver Valley Power Station - Unit 2 follows IEEE Standard 338-1977 and the guidance of Regulatory Guide 1.118 with the  
 
following clarifications:
Equipment performing control functions, but activated from protection system sensors is not part of the safety system and is not tested for time response.
Status, annunciating, display, and monitoring functions, except those related to the safety parameter display system, are considered control functions, and reasonability checks, that is, comparison between or among similar such display functions, are made.
Response time testing of nuclear instrumentation system detectors is not required because they exhibit response times that are an insignificant fraction of the total system response  
 
time (that is, less than 5 percent).
Protection system sensors are demonstrated to be adequate by vendor testing, analysis, operating experience, or by suitable type testing.  
 
RG No. 1.119, Rev. 0 SURVEILLANCE PROGRAM FOR NEW FUEL ASSEMBLY DESIGNS (JUNE 1976)
 
This regulatory guide was withdrawn June 1977.  
 
RG No. 1.120, Rev. 1 UFSAR Reference Section 9.5.1 FIRE PROTECTION GUIDELINES FOR NUCLEAR POWER PLANTS (NOVEMBER 1977)
This regulatory guide provides guidelines acceptable to the NRC for implementing General Design Criterion 3 (GDC 3) of 10CFR5O, Appendix A, in the development of a fire protection program. This guide is in an extended comment period and is not yet approved. Branch Technical Position (BTP) CMEB 9.5-1, which is part of the acceptance criteria of Standard Review Plan 9.5.1 (NUREG-0800), dated July 1981, also provides guidelines  
 
acceptable to the NRC for implementing GDC 3 in the development of a fire protection program. Regulatory Guide 1.120, Rev. 1, is not listed among the SRP 9.5.1 acceptance criteria. However, the guidelines of this regulatory guide have been incorporated into BTP CMEB 9.5-1. Therefore, the BVPS-2 position on this regulatory guide is covered by the evaluation of the BVPS-2 Fire  
 
Protection Program against the guidelines of BTP CMEB 9.5-1.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 67 of 91 This evaluation is provided in Section 9.5A.2.  
 
RG No. 1.121, Rev. 0 UFSAR Reference Section 5.4.2  
RG No. 1.121, Rev. 0 UFSAR Reference Section 5.4.2  


BASES FOR PLUGGING DEGRADED PWR STEAM GENERATOR TUBES (AUGUST 1976)
BASES FOR PLUGGING DEGRADED PWR STEAM GENERATOR TUBES (AUGUST 1976)
Bases for plugging degraded steam generator tubes at Beaver Valley Power Station  - Unit 2 will meet the intent of this regulatory guide with the following alternatives:
Bases for plugging degraded steam generator tubes at Beaver Valley Power Station  - Unit 2 will meet the intent of this regulatory guide with the following alternatives:  
Paragraph C.1 The term "Unacceptable defects" is interpreted to apply to those imperfections resulting from service induced mechanical or chemical degradation of the tube walls which have penetrated to a depth in excess of the plugging limit. Paragraphs C.2.a(2) and C.2.a(4) A 200-percent margin of safety will be used based on the following definition of tube failure. Tube failure is defined as plastic deformation of a crack to the extent that the sides of the crack open to a nonparallel, elliptical configuration. Paragraph C.2.b  In cases where sufficient inspection data exist to establish degradation allowance, the rate used will be an average time-rate determined from the mean of the test data.
 
Where requirements for minimum wall are markedly different for different areas of the tube bundle, (for example, U-bend area versus straight length in Westinghouse designs), two plugging limits may be established to address the varying requirements in a manner which will not require unnecessary plugging of tubes.
Paragraph C.1 The term "Unacceptable defects" is interpreted to apply to those imperfections resulting from service induced mechanical or chemical degradation of the tube walls which have penetrated to a depth in excess of the plugging limit. Paragraphs C.2.a(2) and C.2.a(4)
Paragraphs C.3.d(l) and C.3.d(3)  The combined effect of these requirements would be to establish a maximum permissible primary-to-secondary leak rate which may be below the threshold of detection with current methods of measurement. The maximum acceptable length of a through-wall crack has been determined based on secondary pipe break accident loadings which are typically twice the magnitude of normal operating pressure loads. Westinghouse will use a leak rate associated with the crack size determined on the basis of accident loadings.
A 200-percent margin of safety will be used based on the following definition of tube failure. Tube failure is defined as plastic deformation of a crack to the extent that the sides of the crack open to a nonparallel,  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  68 of 91 Paragraph C.3.e(6)  Computer code names and references will be supplied rather than the actual codes. Paragraph C.3.f(l)  A minimum acceptable tube wall thickness (plugging limit) will be established based on structural requirements and consideration of loadings, measurement accuracy, and, where applicable, a degradation allowance as discussed in this position and in accordance with the general intent of this regulatory guide. Analyses to determine the maximum acceptable number of tube failures during a postulated condition are normally done to entirely different bases and criteria and are not within the scope of this regulatory guide. RG No. 1.122, Rev. 1 UFSAR Reference Section 3.7B.2.5  DEVELOPMENT OF FLOOR DESIGN RESPONSE SPECTRA FOR SEISMIC DESIGN OF FLOOR-SUPPORTED EQUIPMENT OR COMPONENTS (FEBRUARY 1978)
The development of floor design response spectra for seismic design of floor-supported equipment or components at Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide with the following alternative and clarification:
The response spectra peak resonant period values are broadened +25 percent and -20 percent with vertical sides for use in the design basis. When ASME III Code Case N-411 damping values are applied for piping analysis peak resonant period values are broadened plus and minus 15 percent with parallel sides. The use of this code case is limited to pipe stress reconciliation and support optimization. RG No. 1.123, Rev. 1 UFSAR Reference Section 17.2


QUALITY ASSURANCE REQUIREMENTS FOR CONTROL OF PROCUREMENT OF ITEMS AND SERVICES FOR NUCLEAR POWER PLANTS (JULY 1977)  The original BVPS-2 Quality Assurance Program was described in Appendix A of the PSAR. This Quality Assurance Program followed the guidance of Regulatory Guide 1.123, Rev. 0. During procurement activities, the Quality Assurance program was upgraded to reflect changes in regulatory requirements, including Regulatory Guide 1.123, Rev. 1.  
elliptical configuration.
Paragraph C.2.b In cases where sufficient inspection data exist to establish degradation allowance, the rate used will be an average time-rate determined from the mean of the test data.
Where requirements for minimum wall are markedly different for different areas of the tube bundle, (for example, U-bend area versus straight length in Westinghouse designs), two plugging limits may be established to address the varying requirements in a manner which will not require unnecessary plugging of tubes.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  69 of 91 Westinghouse topical reports applicable to specific time periods are WCAP-8370, "Westinghouse Quality Assurance Program," Rev. 7A (June 1, 1975 - September 30, 1977), Rev. 8A (October 1, 1977 -
Paragraphs C.3.d(l) and C.3.d(3)
October 31, 1979), Rev. 9A (November 1, 1979 - present) and WCAP-7800, "Nuclear Fuel Division Quality Assurance Program Plan," Rev. 5 (applicable to the entire time period).
The combined effect of these requirements would be to establish a maximum permissible primary-to-secondary leak rate which may be below the threshold of detection with current methods of measurement. The maximum acceptable length of a through-wall crack has been determined based on secondary pipe break accident loadings which are typically twice the magnitude of normal operating pressure loads. Westinghouse will use a leak rate associated with the crack size determined on the basis of accident
Application of Regulatory Guide 1.123 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
 
loadings.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 68 of 91 Paragraph C.3.e(6)
Computer code names and references will be supplied rather than the actual codes.
Paragraph C.3.f(l)
A minimum acceptable tube wall thickness (plugging limit) will be established based on structural requirements and
 
consideration of loadings, measurement accuracy, and, where applicable, a degradation allowance as discussed in this position and in accordance with the general intent of this regulatory guide. Analyses to determine the maximum acceptable number of tube failures during a postulated condition are normally done to entirely different bases and criteria and are not within the scope of this regulatory guide.
RG No. 1.122, Rev. 1 UFSAR Reference Section 3.7B.2.5 DEVELOPMENT OF FLOOR DESIGN RESPONSE SPECTRA FOR SEISMIC DESIGN OF FLOOR-SUPPORTED EQUIPMENT OR COMPONENTS (FEBRUARY 1978)
 
The development of floor design response spectra for seismic design of floor-supported equipment or components at Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide with the following alternative and clarification:
 
The response spectra peak resonant period values are broadened +25 percent and -20 percent with vertical sides
 
for use in the design basis.
When ASME III Code Case N-411 damping values are applied for piping analysis peak resonant period values are broadened plus and minus 15 percent with parallel sides.
The use of this code case is limited to pipe stress
 
reconciliation and support optimization.
RG No. 1.123, Rev. 1 UFSAR Reference Section 17.2
 
QUALITY ASSURANCE REQUIREMENTS FOR CONTROL OF PROCUREMENT OF ITEMS AND SERVICES FOR NUCLEAR POWER PLANTS (JULY 1977)
The original BVPS-2 Quality Assurance Program was described in Appendix A of the PSAR. This Quality Assurance Program followed the guidance of Regulatory Guide 1.123, Rev. 0. During
 
procurement activities, the Quality Assurance program was upgraded to reflect changes in regulatory requirements, including Regulatory Guide 1.123, Rev. 1.
 
BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 69 of 91 Westinghouse topical reports applicable to specific time periods are WCAP-8370, "Westinghouse Quality Assurance Program," Rev. 7A (June 1, 1975 - September 30, 1977), Rev. 8A (October 1, 1977 -  
 
October 31, 1979), Rev. 9A (November 1, 1979 - present) and WCAP-7800, "Nuclear Fuel Division Quality Assurance Program Plan," Rev. 5 (applicable to the entire time period).  
 
Application of Regulatory Guide 1.123 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual
.
RG No. 1.124, Rev. 1 UFSAR Reference Sections 3.9B.3.4.1, 5.4.14  
RG No. 1.124, Rev. 1 UFSAR Reference Sections 3.9B.3.4.1, 5.4.14  


SERVICE LIMITS AND LOADING COMBINATIONS FOR CLASS 1 LINEAR-TYPE COMPONENT SUPPORTS (JANUARY 1978)
SERVICE LIMITS AND LOADING COMBINATIONS FOR CLASS 1 LINEAR-TYPE COMPONENT SUPPORTS (JANUARY 1978)
The design limits and appropriate loading combinations associated with normal operation, postulated accidents and specified seismic events for the design of Class 1 linear-type component supports, as defined in Subsection NF of Section III of the ASME code, are not applicable to Beaver Valley Power Station - Unit 2 since the design and placement of the purchase order for these supports precedes the first issue of ASME III, Subsection NF. The only exception is the reactor pressure vessel leveling devices which were procured after July 1974.
 
The design rules for the leveling devices follow ASME III, Subsection NF, as a guide and meet the intent of Regulatory Guide 1.124 with the following alternative:
The design limits and appropriate loading combinations associated with normal operation, postulated accidents and specified seismic events for the design of Class 1 linear-type component supports, as defined in Subsection NF of Section III of the ASME code, are not applicable to Beaver Valley Power Station - Unit 2 since the design and placement of the purchase  
Paragraph C.8 Supports for the "active" components that are required only during an emergency or faulted plant condition and that are subjected to loading combinations described in Regulatory Positions C.6 and C.7 should be designed within the design limits described in Regulatory Position C.5 or other justifiable design limits. These limits should be defined by the design specification and stated in the PSAR, such that the function of the supported system will be maintained when they are subjected to the loading combinations described in Regulatory Positions 6 and 7. The design limits and loading combinations for the component supports are presented in Section 5.4.14. RG No. 1.125, Rev. 1 UFSAR Reference Section 2.4  
 
order for these supports precedes the first issue of ASME III, Subsection NF. The only exception is the reactor pressure vessel leveling devices which were procured after July 1974.
The design rules for the leveling devices follow ASME III, Subsection NF, as a guide and meet the intent of Regulatory Guide 1.124 with the following alternative:  
 
Paragraph C.8 Supports for the "active" components that are required only during an emergency or faulted plant condition and that are subjected to loading combinations described in Regulatory Positions C.6 and C.7 should be designed within the design limits described in Regulatory Position C.5 or other justifiable design limits. These limits should be defined by the design specification and stated in the PSAR, such that the function of the supported system will be maintained when they are subjected to the loading  
 
combinations described in Regulatory Positions 6 and 7.
The design limits and loading combinations for the  
 
component supports are presented in Section 5.4.14.
RG No. 1.125, Rev. 1 UFSAR Reference Section 2.4  


PHYSICAL MODELS FOR DESIGN AND OPERATION OF HYDRAULIC STRUCTURES AND SYSTEMS FOR NUCLEAR POWER PLANTS (OCTOBER 1978)
PHYSICAL MODELS FOR DESIGN AND OPERATION OF HYDRAULIC STRUCTURES AND SYSTEMS FOR NUCLEAR POWER PLANTS (OCTOBER 1978)
The use of physical models for design and operation of hydraulic structures and systems for Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide.  
The use of physical models for design and operation of hydraulic structures and systems for Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 70 of 91 RG No. 1.126, Rev. 1 UFSAR Reference Section 4.2 AN ACCEPTABLE MODEL AND RELATED STATISTICAL METHODS FOR THE ANALYSIS OF FUEL DENSIFICATION (MARCH 1978)
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 70 of 91 RG No. 1.126, Rev. 1 UFSAR Reference Section 4.2  
The analysis of fuel densification for Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide with the following clarification:
 
The regulatory guide states clearly that, "The model presented in . . . this guide is not intended to supersede NRC-approved vendor models."  Beaver Valley Power Station - Unit 2 uses the Westinghouse densification model presented in WCAP-8218 (Proprietary) which has been approved by the USNRC. Westinghouse's reports WCAP-8219 (Non-proprietary) and WCAP-8264, (Customer Version) are companions to the approved versions. RG No. 1.127, Rev. 1 UFSAR Reference Section 2.4 INSPECTION OF WATER-CONTROL STRUCTURES ASSOCIATED WITH NUCLEAR POWER PLANTS (MARCH 1978)
AN ACCEPTABLE MODEL AND RELATED STATISTICAL METHODS FOR THE ANALYSIS OF FUEL DENSIFICATION (MARCH 1978)
BVPS-2 does not use water-control structures, such as those described in this regulatory guide. Water-control structures along the Ohio River are operated and maintained by the responsible governmental authorities, such as the U.S. Army Corps of Engineers.
 
The analysis of fuel densification for Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide with the following clarification:  
 
The regulatory guide states clearly that, "The model presented in . . . this guide is not intended to supersede  
 
NRC-approved vendor models."  Beaver Valley Power Station  
- Unit 2 uses the Westinghouse densification model presented in WCAP-8218 (Proprietary) which has been approved by the USNRC. Westinghouse's reports WCAP-8219 (Non-proprietary) and WCAP-8264, (Customer Version) are companions to the approved versions.
RG No. 1.127, Rev. 1 UFSAR Reference Section 2.4 INSPECTION OF WATER-CONTROL STRUCTURES ASSOCIATED WITH NUCLEAR POWER PLANTS (MARCH 1978)
 
BVPS-2 does not use water-control structures, such as those described in this regulatory guide. Water-control structures along the Ohio River are operated and maintained by the responsible governmental authorities, such as the U.S. Army  
 
Corps of Engineers.  
 
RG No. 1.128, Rev. 1 UFSAR Reference Sections 8.1.6, 8.3.2  
RG No. 1.128, Rev. 1 UFSAR Reference Sections 8.1.6, 8.3.2  


INSTALLATION DESIGN AND INSTALLATION OF LARGE LEAD STORAGE BATTERIES FOR NUCLEAR POWER PLANTS (OCTOBER 1978)
INSTALLATION DESIGN AND INSTALLATION OF LARGE LEAD STORAGE BATTERIES FOR NUCLEAR POWER PLANTS (OCTOBER 1978)
The installation design and installation of large lead storage batteries at Beaver Valley Power Station Unit 2 follows IEEE Standard 484-1975 and the guidance of Regulatory Guide 1.128, with the following clarification:  Hydrogen detectors are not required because proper ventilation has been provided in the battery rooms to ensure a sufficient air exchange rate. In addition, instrumentation exists so that a lack of sufficient flow will be indicated in the control room by an alarm system. 


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  71 of 91 RG No. 1.129, Rev. 1 UFSAR Reference Section 8.3.2 MAINTENANCE, TESTING, AND REPLACEMENT OF LARGE LEAD STORAGE BATTERIES FOR NUCLEAR POWER PLANTS (FEBRUARY 1978)
The installation design and installation of large lead storage batteries at Beaver Valley Power Station Unit 2 follows IEEE Standard 484-1975 and the guidance of Regulatory Guide 1.128,
Maintenance, testing, and replacement of large lead storage batteries at Beaver Valley Power Station Unit 2 will follow the guidance of this regulatory guide with the following alternatives:  Periodic testing will follow the guidance of IEEE Standard 450-1980. The initial battery service test will be held within 2 years, the customary interval for the first outage; thereafter, the service tests will be held within intervals at 18 months.
 
RG No. 1.130, Rev. 1 UFSAR Reference Sections 3.9B.3.4.1, 5.4.14 SERVICE LIMITS AND LOADING COMBINATIONS FOR CLASS 1 PLATE-AND-SHELL-TYPE COMPONENT SUPPORTS (OCTOBER 1978)
with the following clarification:
The service limits and loading combinations for Class 1 plate-and-shell type component supports meet the intent of Regulatory Guide 1.130 with the following alternatives: Paragraph C.3  Service limits for component supports designed by linear elastic analysis are limited by the critical buckling strength. The critical buckling strength is calculated using material properties at temperature. Conservative factors of safety for flat plates and for shells are maintained for each design and service limit. The allowable stress for Service Limit D does not exceed two-thirds of the critical buckling stress. The safety margins of 3 for shells and 2 for flat plates required by Paragraph C.3 of Regulatory Guide 1.130 are unnecessarily conservative. The margins have been arbitrarily selected by the USNRC; they were influenced by the precedent set in Subsection NE of the ASME Code for shells (F.S. = 3), and by the AISC column factors in the case of plates (F.S. varies from 1.67 to 1.92). The USNRC has authorized a study of generic buckling criteria by a group of consultants. Initial reports indicate they are proposing establishment of critical buckling stresses based on lower bound values of test data from the aerospace industry (thin shells) without specific tolerance requirements on construction.  
Hydrogen detectors are not required because proper ventilation has been provided in the battery rooms to ensure a sufficient air exchange rate. In addition, instrumentation exists so that a lack of sufficient flow
 
will be indicated in the control room by an alarm system.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 72 of 91 Paragraph C.7  Support for active components that are required only during an emergency or faulted plant condition and that are subjected to loading combinations described in Paragraphs C.5 and C.6 are designed within the limits described in Paragraph C.4 or other justifiable design limits. These limits are defined in UFSAR Section 5.4.14. The function of the supported system is maintained when they are subjected to the loading combinations described in Paragraphs C.5 and C.6.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 71 of 91 RG No. 1.129, Rev. 1 UFSAR Reference Section 8.3.2
Paragraph C.7 implies that the lower stress limits associated with Levels A and B Service Limits must be used for any component support that serves a safety-related function during an emergency or faulted (LOCA) plant condition. This would seem to imply that a main coolant pump support, which is a passive element in the main coolant loop, would have to be designed to meet the Level A and B Limits during an emergency or faulted plant condition. This would require that a snubber providing restraint on a residual heat removal line would have to be designed to the Level A and B Service Limits during an emergency or faulted plant condition. If this is the intent, it is a severe departure from current practice. Only active components, such as valves, whose operation is required for safe shutdown during an emergency or faulted conditions have been required to meet design stress limits for these plant  conditions. Level C and D Service Limits have been considered adequate to assure pressure boundary integrity under the more severe operating conditions. RG No. 1.131, Rev. 0 UFSAR Reference Sections 3.11 and 8.3.3


QUALIFICATION TESTS OF ELECTRIC CABLES, FIELD SPLICES, AND CONNECTIONS FOR LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (AUGUST 1977) Qualification tests of electric cables, field splices, and connections for Beaver Valley Power Station - Unit 2 meet the intent of this regulatory guide, with the following alternatives and clarification: a. All cables installed in trays at BVPS-2, either:   1. have passed the vertical cable tray gas burner flame test delineated in Section 2.5.4.4 of IEEE-383-1974 or,   2. additionally, the flame testing for cables specified after January 1978 was modified in accordance with Reg. Guide 1.131-77 or, BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 73 of 91  3. for non-safety applications, are flame retardant and have passed equivalent industry flame testing as approved by engineering evaluation. b. Single conductor 600 V control, coaxial, and triaxial cables installed after December 5, 2000, meet the vertical flame testing listed in item a above. Single conductor 600 V control, coaxial, and triaxial cables installed prior to December 5, 2000, are flame resistant and meet the vertical flame test provisions of the appropriate ICEA standards. These cables were not subjected to the gas burner vertical cable tray flame test of IEEE-383-1974, and as such, are restricted to installation in conduit and electrical enclosures (i.e., panels and junction boxes). RG No. 1.132, Rev. 1 UFSAR Reference Section 2.5.4 SITE INVESTIGATIONS FOR FOUNDATIONS OF NUCLEAR POWER PLANTS (MARCH 1979)
MAINTENANCE, TESTING, AND REPLACEMENT OF LARGE LEAD STORAGE BATTERIES FOR NUCLEAR POWER PLANTS (FEBRUARY 1978)
Site investigations for foundations at Beaver Valley Power Station - Unit 2 meet the intent of Regulatory Guide 1.132 with the following alternatives and clarifications: Paragraph B.5 Surveys of horizontal deviation are made in all boreholes that are used for crosshole seismic tests. This must be done in order to determine the true distance between the energy source and receiver. The suggestion that surveys of vertical deviation be performed appears to be an error. Paragraph C.1 (Item 5) Only typical time-distance plots are included on the geologic profiles. A typical time-distance plot is more appropriate since time-distance plots are not usually included on geologic profiles. Paragraph C.2 Since boring logs do not typically include field and laboratory test results, the results of field permeability tests and borehole logging are presented in tables and figures especially designed for these tests. Paragraph C.3 Measurement of water or drilling mud levels in borings is not required in all cases since water or drilling mud levels in some materials, such as clays, may give false information about ground-water levels. A sufficient number of observation wells are installed to  monitor ground-water levels.  
 
Maintenance, testing, and replacement of large lead storage batteries at Beaver Valley Power Station Unit 2 will follow the guidance of this regulatory guide with the following
 
alternatives:
Periodic testing will follow the guidance of IEEE Standard 450-1980.
The initial battery service test will be held within 2 years, the customary interval for the first outage; thereafter, the service tests will be held within intervals at 18 months.
 
RG No. 1.130, Rev. 1 UFSAR Reference Sections 3.9B.3.4.1, 5.4.14
 
SERVICE LIMITS AND LOADING COMBINATIONS FOR CLASS 1 PLATE-AND-SHELL-TYPE COMPONENT SUPPORTS (OCTOBER 1978)
 
The service limits and loading combinations for Class 1 plate-and-shell type component supports meet the intent of Regulatory Guide 1.130 with the following alternatives:
Paragraph C.3 Service limits for component supports designed by linear
 
elastic analysis are limited by the critical buckling strength. The critical buckling strength is calculated using material properties at temperature. Conservative factors of safety for flat plates and for shells are maintained for each design and service limit. The allowable stress for Service Limit D does not exceed two-
 
thirds of the critical buckling stress.
The safety margins of 3 for shells and 2 for flat plates required by Paragraph C.3 of Regulatory Guide 1.130 are unnecessarily conservative. The margins have been arbitrarily selected by the USNRC; they were influenced by
 
the precedent set in Subsection NE of the ASME Code for shells (F.S. = 3), and by the AISC column factors in the case of plates (F.S. varies from 1.67 to 1.92). The USNRC has authorized a study of generic buckling criteria by a group of consultants. Initial reports indicate they are proposing establishment of critical buckling stresses based on lower bound values of test data from the aerospace industry (thin shells) without specific tolerance requirements on construction.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 72 of 91 Paragraph C.7 Support for active components that are required only during an emergency or faulted plant condition and that are subjected to loading combinations described in Paragraphs C.5 and C.6 are designed within the limits described in
 
Paragraph C.4 or other justifiable design limits. These limits are defined in UFSAR Section 5.4.14. The function of the supported system is maintained when they are subjected to the loading combinations described in Paragraphs C.5 and C.6.
 
Paragraph C.7 implies that the lower stress limits associated with Levels A and B Service Limits must be used for any component support that serves a safety-related function during an emergency or faulted (LOCA) plant condition. This would seem to imply that a main coolant pump support, which is a passive element in the main
 
coolant loop, would have to be designed to meet the Level A and B Limits during an emergency or faulted plant condition. This would require that a snubber providing
 
restraint on a residual heat removal line would have to be designed to the Level A and B Service Limits during an emergency or faulted plant condition. If this is the intent, it is a severe departure from current practice. Only active components, such as valves, whose operation is required for safe shutdown during an emergency or faulted conditions have been required to meet design stress limits for these plant  conditions. Level C and D Service Limits have been considered adequate to assure pressure boundary
 
integrity under the more severe operating conditions.
RG No. 1.131, Rev. 0 UFSAR Reference Sections 3.11 and 8.3.3
 
QUALIFICATION TESTS OF ELECTRIC CABLES, FIELD SPLICES, AND CONNECTIONS FOR LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (AUGUST 1977)
Qualification tests of electric cables, field splices, and connections for Beaver Valley Power Station - Unit 2 meet the  
 
intent of this regulatory guide, with the following alternatives and clarification:  
: a. All cables installed in trays at BVPS-2, either:  
: 1. have passed the vertical cable tray gas burner flame test delineated in Section 2.5.4.4 of IEEE-383-1974 or,  
: 2. additionally, the flame testing for cables specified after January 1978 was modified in  
 
accordance with Reg. Guide 1.131-77 or,  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 73 of 91  3. for non-safety applications, are flame retardant and have passed equivalent industry flame testing as approved by engineering evaluation.  
: b. Single conductor 600 V control, coaxial, and triaxial cables installed after December 5, 2000, meet the vertical flame testing listed in item a above. Single conductor 600 V control, coaxial, and triaxial cables installed prior to December 5, 2000, are flame resistant and meet the vertical flame test provisions of the appropriate ICEA standards. These cables were not subjected to the gas burner vertical cable tray flame test of IEEE-383-1974, and as such, are restricted to installation in conduit and electrical enclosures (i.e., panels and junction boxes).
RG No. 1.132, Rev. 1 UFSAR Reference Section 2.5.4 SITE INVESTIGATIONS FOR FOUNDATIONS OF NUCLEAR POWER PLANTS (MARCH 1979)
 
Site investigations for foundations at Beaver Valley Power Station - Unit 2 meet the intent of Regulatory Guide 1.132 with the following alternatives and clarifications:
Paragraph B.5 Surveys of horizontal deviation are made in all boreholes  
 
that are used for crosshole seismic tests. This must be done in order to determine the true distance between the energy source and receiver. The suggestion that surveys  
 
of vertical deviation be performed appears to be an error.
Paragraph C.1 (Item 5)
Only typical time-distance plots are included on the geologic profiles. A typical time-distance plot is more appropriate since time-distance plots are not usually included on geologic profiles.
Paragraph C.2 Since boring logs do not typically include field and laboratory test results, the results of field permeability tests and borehole logging are presented in tables and figures especially designed for these tests.
Paragraph C.3 Measurement of water or drilling mud levels in borings is not required in all cases since water or drilling mud levels in some materials, such as clays, may give false information about ground-water levels. A sufficient number of observation wells are installed to  monitor ground-water levels.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 74 of 91 Paragraph C.6 Continuous undisturbed samples will be taken in compressible or normally consolidated clays only if required for geotechnical analysis. The need for continuous undisturbed samples is a matter of engineering
 
judgment and is evaluated for each case.
Appendix C
: 1. Earth Dams, Dikes, Levees, and Embankments Boring criteria for rock sites will be developed for each case since penetration to d max at a rock site is excessive.
: 2. Deep Cuts and Canals Boring criteria for rock sites will be developed for each case. Detailed mapping is used for rock sites, supplemented by borings where appropriate.
: 3. Pipelines Boring spacing criteria for rock sites will be developed for each case since the suggested spacing would require an excessive number of borings for rock
 
sites. The boring depth criteria for soil and rock sites will
 
be developed for each case since a minimum depth of 5 diameters may be excessive, depending upon the site geology and pipe diameter.
: 4. Tunnels
 
Boring spacing and depth criteria will be developed for each case. The suggested spacing would require an excessive number of borings if applied to rock sites
 
and a minimum depth of 5 times the tunnel diameter may be excessive, depending upon the site geology.
RG No. 1.133, Rev. 1 UFSAR Reference Section 4.4, 14.2
 
LOOSE-PART DETECTION PROGRAM FOR THE PRIMARY SYSTEM OF LIGHT-WATER-COOLED REACTORS (MAY 1981)
 
The original design of Beaver Valley Power Station Unit 2 included a loose-part monitoring system that was intended to meet the intent of Regulatory Guide 1.133. Subsequent evaluation has determined that this system was not required.
Therefore, various features may be eliminated, modified or
 
maintained as an operating convenience.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 75 of 91 RG No. 1.134, Rev. 1 MEDICAL EVALUATION OF NUCLEAR POWER PLANT PERSONNEL REQUIRING OPERATOR LICENSES (MARCH 1979)
 
Medical evaluation of Beaver Valley Power Station Unit 2 (BVPS-2) personnel requiring operator licenses meets the intent of Regulatory Guide 1.134 by following acceptable alternative criteria. These alternative criteria meet the requirement of 10 CFR 55.10, "Contents of Applications," and 10 CFR 55.33, "Renewal of Licenses," that each initial or renewal operator or senior operator license application contain a report of medical examination by a licensed medical practitioner on the form prescribed in 10 CFR 55.60, "Examination Form."  BVPS-2 also demonstrates compliance with the requirement of 10 CFR 55.11, "Requirements for the Approval of Applications," and 10 CFR 55.33 that the physical condition and general health of BVPS-2 operator applicants are not such as might cause operational
 
errors endangering public health and safety.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  74 of 91 Paragraph C.6  Continuous undisturbed samples will be taken in compressible or normally consolidated clays only if required for geotechnical analysis. The need for continuous undisturbed samples is a matter of engineering judgment and is evaluated for each case. Appendix C  1. Earth Dams, Dikes, Levees, and Embankments  Boring criteria for rock sites will be developed for each case since penetration to dmax at a rock site is excessive. 2. Deep Cuts and Canals  Boring criteria for rock sites will be developed for each case. Detailed mapping is used for rock sites, supplemented by borings where appropriate. 3. Pipelines  Boring spacing criteria for rock sites will be developed for each case since the suggested spacing would require an excessive number of borings for rock sites. The boring depth criteria for soil and rock sites will be developed for each case since a minimum depth of 5 diameters may be excessive, depending upon the site geology and pipe diameter.
: 4. Tunnels Boring spacing and depth criteria will be developed for each case. The suggested spacing would require an excessive number of borings if applied to rock sites and a minimum depth of 5 times the tunnel diameter may be excessive, depending upon the site geology. RG No. 1.133, Rev. 1 UFSAR Reference Section 4.4, 14.2 LOOSE-PART DETECTION PROGRAM FOR THE PRIMARY SYSTEM OF LIGHT-WATER-COOLED REACTORS (MAY 1981)
The original design of Beaver Valley Power Station Unit 2 included a loose-part monitoring system that was intended to meet the intent of Regulatory Guide 1.133. Subsequent evaluation has determined that this system was not required. Therefore, various features may be eliminated, modified or maintained as an operating convenience.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  75 of 91 RG No. 1.134, Rev. 1  MEDICAL EVALUATION OF NUCLEAR POWER PLANT PERSONNEL REQUIRING OPERATOR LICENSES (MARCH 1979)
Medical evaluation of Beaver Valley Power Station Unit 2 (BVPS-2) personnel requiring operator licenses meets the intent of Regulatory Guide 1.134 by following acceptable alternative criteria. These alternative criteria meet the requirement of 10 CFR 55.10, "Contents of Applications," and 10 CFR 55.33, "Renewal of Licenses," that each initial or renewal operator or senior operator license application contain a report of medical examination by a licensed medical practitioner on the form prescribed in 10 CFR 55.60, "Examination Form."  BVPS-2 also demonstrates compliance with the requirement of 10 CFR 55.11, "Requirements for the Approval of Applications," and 10 CFR 55.33 that the physical condition and general health of BVPS-2 operator applicants are not such as might cause operational errors endangering public health and safety.
RG No. 1.135, Rev. 0 UFSAR Reference Section 2.4  
RG No. 1.135, Rev. 0 UFSAR Reference Section 2.4  


NORMAL WATER LEVEL AND DISCHARGE AT NUCLEAR POWER PLANTS (SEPTEMBER 1977)
NORMAL WATER LEVEL AND DISCHARGE AT NUCLEAR POWER PLANTS (SEPTEMBER 1977)
This regulatory guide pertains to those facilities whose construction permit application was docketed after May 1, 1978. Because Beaver Valley Power Station - Unit 2 (BVPS-2) received its docket prior to this date, the regulatory guide is not applicable. However, the methods used for determining normal water levels and surface water discharges for BVPS-2 follows the guidance of this regulatory guide.
 
This regulatory guide pertains to those facilities whose construction permit application was docketed after May 1, 1978. Because Beaver Valley Power Station - Unit 2 (BVPS-2) received  
 
its docket prior to this date, the regulatory guide is not applicable. However, the methods used for determining normal water levels and surface water discharges for BVPS-2 follows the  
 
guidance of this regulatory guide.  
 
RG No. 1.136, Rev. 2 UFSAR Reference Section 3.8.1  
RG No. 1.136, Rev. 2 UFSAR Reference Section 3.8.1  


MATERIALS, CONSTRUCTION, AND TESTING OF CONCRETE CONTAINMENTS (ARTICLES CC-1000, -2000, AND -4000 THROUGH -6000 OF THE "CODE FOR CONCRETE REACTOR VESSELS AND CONTAINMENTS") (JUNE 1981) Regulatory Guide 1.136, Revision 2, June 1981, is not applicable to the Beaver Valley Power Station - Unit 2 (BVPS-2) design and construction since Revision 2 criteria are to be used in the evaluation of construction permit applications docketed after May 1981. However, materials, construction, and testing of the concrete containment for BVPS-2 meet the intent of Regulatory Guide 1.136, Revision 1, October 1978, with the following alternative:
MATERIALS, CONSTRUCTION, AND TESTING OF CONCRETE CONTAINMENTS (ARTICLES CC-1000, -2000, AND -4000 THROUGH -6000 OF THE "CODE FOR CONCRETE REACTOR VESSELS AND CONTAINMENTS") (JUNE 1981)
In Paragraph C.3, the chloride content for grout should not exceed 200 ppm. Reduced chloride content for grout with pH from 11.6 to 12.0 is unnecessary and will require continuous testing of pH value. All normal Portland cement grout has a pH in excess of 12.0. Therefore, up to 200 ppm of chloride should be acceptable.
Regulatory Guide 1.136, Revision 2, June 1981, is not applicable to the Beaver Valley Power Station - Unit 2 (BVPS-2) design and  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 76 of 91 Regulatory Guide 1.136, Revision 2, refers to adoption of articles cc-1000, -2000, and -4000 through -6000 of the ASME Boiler and Pressure Vessel Code, Section III, Division 2, 1980 edition. Revision 2 of Regulatory Guide 1.136 replaces the following regulatory guides:
 
Regulatory Guide 1.10, Revision 1 - Mechanical (Cadweld) Splices in Reinforcing Bars of Category I Concrete Structures. Regulatory Guide 1.15, Revision 1 - Testing of Reinforcing Bars for Category I Concrete Structures. Regulatory Guide 1.18, Revision 1 - Structural Acceptance Test for Concrete Primary Reactor Containments. Regulatory Guide 1.19, Revision 1 - Nondestructive Examination of Primary Containment Liner Welds. Regulatory Guide 1.55, Revision 0 - Concrete Placement in Category I Structures. Regulatory Guide 1.103, Revision 1 - Post-tensioned Prestressing Systems for Concrete Reactor Vessels and Containments.
construction since Revision 2 criteria are to be used in the evaluation of construction permit applications docketed after May 1981. However, materials, construction, and testing of the concrete containment for BVPS-2 meet the intent of Regulatory Guide 1.136, Revision 1, October 1978, with the following alternative:  
The applicability of the preceding regulatory guides to BVPS-2 is as stated in the respective positions on these regulatory guides.
 
RG No. 1.137, Rev. 1 UFSAR Reference Section 9.5.4 FUEL-OIL SYSTEMS FOR STANDBY DIESEL GENERATORS REV. 1 (OCTOBER 1979)
In Paragraph C.3, the chloride content for grout should not exceed 200 ppm. Reduced chloride content for grout  
Beaver Valley Power Station - Unit 2 (BVPS-2) meets the intent of the guidelines of Regulatory Guide 1.137 for fuel-oil systems for standby diesel generators with the following alternatives: ANSI-N195-1976, which is the basis for Regulatory Guide 1.137, recommends the use of duplex strainers to allow continued operation of the system if a strainer becomes plugged. BVPS-2 meets the intent of this recommendation by providing redundant pumps with a simplex wye-type strainer in the discharge line of each pump.
 
Fuel specifications and periodic tests to verify fuel oil quality will be in accordance with the BVPS-2 technical specifications.
with pH from 11.6 to 12.0 is unnecessary and will require continuous testing of pH value. All normal Portland cement grout has a pH in excess of 12.0. Therefore, up to  
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 77 of 91 RG No. 1.138, Rev. 0 UFSAR Reference Section 2.5.4 LABORATORY INVESTIGATIONS OF SOILS FOR ENGINEERING ANALYSIS AND DESIGN OF NUCLEAR POWER PLANTS (APRIL 1978)
 
Laboratory investigations of soils and rocks for engineering analysis and design of Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.138, with the following alternatives. Most of these were noted in a letter from S. B. Jacobs, Stone & Webster Engineering Corporation, to the Secretary of the USNRC, dated July 6, 1978:
200 ppm of chloride should be acceptable.
Paragraph C.1.c Standards used to calibrate laboratory test equipment are of a known higher accuracy than the test equipment, rather than four times more accurate than the working instrument.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 76 of 91 Regulatory Guide 1.136, Revision 2, refers to adoption of articles cc-1000, -2000, and -4000 through -6000 of the  
Calibration of the architect engineer's geotechnical laboratory equipment to higher standards than currently in use is not justified since soils and rocks are material whose properties vary widely within the same deposit or formation. In addition, certain physical properties of soils and rocks are greatly affected by sampling and by preparation for testing in the laboratory. The geotechnical engineer takes these natural variations and sampling/preparation effects into account, and exercises considerable judgment in assigning the material properties to be used in an analysis.  (This is different from the case of manufactured materials, where dimensions and physical properties are maintained within a narrow range by the manufacturing process.) Paragraph C.1.d Index and classification tests are not performed on all soil and rock samples. Classification of soil and rock samples is performed by visual-manual techniques. Index and classification tests are performed on representative samples to confirm the visual-manual classifications. Paragraph C.2 Moisture seals are not periodically checked and renewed as needed. Tube samples are inspected for obvious leakage when a tube has been selected for testing. Each sample is examined when it is extruded, and any evidence of drying in the tube is noted on the sample description log. This procedure is sufficient to evaluate whether drying has occurred. Samples that appear to have dried are not tested. Periodic inspection and replacement of moisture seals would not provide any better protection against testing samples whose water content has changed than the method used.  
 
ASME Boiler and Pressure Vessel Code, Section III, Division 2, 1980 edition. Revision 2 of Regulatory Guide 1.136 replaces the following regulatory guides:  
 
Regulatory Guide 1.10, Revision 1 - Mechanical (Cadweld)
Splices in Reinforcing Bars of Category I Concrete  
 
Structures.
Regulatory Guide 1.15, Revision 1 - Testing of Reinforcing  
 
Bars for Category I Concrete Structures.
Regulatory Guide 1.18, Revision 1 - Structural Acceptance  
 
Test for Concrete Primary Reactor Containments.
Regulatory Guide 1.19, Revision 1 - Nondestructive  
 
Examination of Primary Containment Liner Welds.
Regulatory Guide 1.55, Revision 0 - Concrete Placement in  
 
Category I Structures.
Regulatory Guide 1.103, Revision 1 - Post-tensioned Prestressing Systems for Concrete Reactor Vessels and Containments.  
 
The applicability of the preceding regulatory guides to BVPS-2 is as stated in the respective positions on these regulatory guides.  
 
RG No. 1.137, Rev. 1 UFSAR Reference Section 9.5.4  
 
FUEL-OIL SYSTEMS FOR STANDBY DIESEL GENERATORS REV. 1 (OCTOBER 1979)
Beaver Valley Power Station - Unit 2 (BVPS-2) meets the intent of the guidelines of Regulatory Guide 1.137 for fuel-oil systems for standby diesel generators with the following alternatives:
ANSI-N195-1976, which is the basis for Regulatory Guide 1.137, recommends the use of duplex strainers to allow continued operation of the system if a strainer becomes  
 
plugged. BVPS-2 meets the intent of this recommendation by providing redundant pumps with a simplex wye-type strainer in the discharge line of each pump.  
 
Fuel specifications and periodic tests to verify fuel oil quality will be in accordance with the BVPS-2 technical  
 
specifications.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 77 of 91 RG No. 1.138, Rev. 0 UFSAR Reference Section 2.5.4  
 
LABORATORY INVESTIGATIONS OF SOILS FOR ENGINEERING ANALYSIS AND DESIGN OF NUCLEAR POWER PLANTS (APRIL 1978)
 
Laboratory investigations of soils and rocks for engineering analysis and design of Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.138, with the following alternatives. Most of these were noted in a letter from S. B. Jacobs, Stone & Webster Engineering Corporation, to the Secretary of the USNRC, dated July 6, 1978:  
 
Paragraph C.1.c Standards used to calibrate laboratory test equipment are of a known higher accuracy than the test equipment, rather than four times more accurate than the working instrument.
 
Calibration of the architect engineer's geotechnical laboratory equipment to higher standards than currently in use is not justified since soils and rocks are material whose properties vary widely within the same deposit or formation. In addition, certain physical properties of soils and rocks are greatly affected by sampling and by preparation for testing in the laboratory. The geotechnical engineer takes these natural variations and sampling/preparation effects into account, and exercises considerable judgment in assigning the material properties to be used in an analysis.  (This is different from the case of manufactured materials, where dimensions and physical properties are maintained within a narrow range by the manufacturing process.)
Paragraph C.1.d Index and classification tests are not performed on all soil and rock samples. Classification of soil and rock samples is performed by visual-manual techniques. Index and classification tests are performed on representative  
 
samples to confirm the visual-manual classifications.
Paragraph C.2 Moisture seals are not periodically checked and renewed as needed. Tube samples are inspected for obvious leakage when a tube has been selected for testing. Each sample is examined when it is extruded, and any evidence of drying in the tube is noted on the sample description log. This procedure is sufficient to evaluate whether drying has occurred. Samples that appear to have dried are not tested. Periodic inspection and replacement of moisture seals would not provide any better protection against testing samples whose water content has changed than the method used.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 78 of 91 The duration of storage is not specifically recorded for each test since this can be calculated from the boring logs, where the sampling date is given, and the laboratory test data sheets, where the date of testing is recorded. Therefore, it is unnecessary to make a separate record of storage time.
 
Paragraph C.3.a Classification tests are not performed on every undisturbed test specimen of soil or rock. Visual-manual techniques are the primary means of classifying soil and rock samples. Classification tests are performed on representative samples as necessary to confirm the results of the visual-manual classifications.
 
Measurements and control tests are not performed to determine whether undisturbed samples have changed during
 
shipment, storage, and handling. Undisturbed samples are visually inspected as they are opened and extruded, to determine whether there has been any change in sample length within the tube or if there are any signs of sample disturbance. Results of these inspections are reported on the sample description log. This procedure and examination of the laboratory test results for possible indications of sample disturbance, is sufficient to determine whether sample disturbance has occurred.
 
Paragraph C.3.b A discussion of the validity of test results on scalped materials is not presented as part of the laboratory test data. The laboratory test results indicate which portion of the sample has been scalped, and a competent reviewer of the test results would understand the effect of scalping on the results of specific tests.
 
Paragraph C.4.a(2)
Results of tests with B-values less than 0.95 may be used for analysis in certain cases. For very stiff or hard clays, it may not be possible to achieve a B-value of 0.95. If results of such a test are used, the B-value is reported and the probable effect on results of the test could be evaluated by a competent reviewer.
Paragraph C.5.a All soil and rock identifications and descriptions are not documented. The current practice of recording sample descriptions and determining index properties of representative samples is consistent with good engineering practice.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 79 of 91 Anomalous test data are not reported if they are caused by sample disturbance or equipment malfunction because such data do not reflect the true properties of the material in the field. However, records of such tests are maintained as part of the laboratory records.
Appendix B, Relative Density Test The frequency of the vibratory table cannot be adjusted, because it depends upon the fixed frequency of the input current.
RG No. 1.139, Rev. 0 UFSAR Reference Sections 3.1.2.34, 5.4.7, Appendix 5A, 10.3, 10.4.9, 14.2 GUIDANCE FOR RESIDUAL HEAT REMOVAL (MAY 1978)
While the safe shutdown basis for Beaver Valley Power Station -
Unit 2 (BVPS-2) is hot standby, the cold shutdown capability of
 
the plant meets the intent of Regulatory Guide 1.139 and the Branch Technical Position RSB 5-1 design guidelines for Class 2 plants with the following clarifications:
 
Following a safe shutdown earthquake, assuming loss of onsite or offsite power and the most limiting single failure, the plant is capable of achieving residual heat removal (RHR) system initiation conditions (approximately 350F and 400 psia) within 36 hours.
BVPS-2 designers employed an approach to safety grade cold
 
shutdown by upgrading to safety grade, wherever feasible. It is recognized that achievement of cold shutdown, utilizing normally available non-safety grade systems and components, is desirable with postulation of loss-of-offsite power as the initiating event.
In order to provide adequate cooldown within 36 hours to initiate the RHR system, the steam generator power operated relief valves (PORVS) are qualified to full safety-grade design and an adequate supply of auxiliary feedwater is established.
The primary plant demineralized water storage tank initially establishes the supply of auxiliary feedwater and is provided with backup from the demineralized water storage tank.
Combined, these tanks have adequate storage capacity to remove residual heat for more than three days. Additionally, supply connections from the service water system are available should they be required.
 
Further upgrades for BVPS-2 include the addition of a safety grade atmospheric dump valve which provides backup to the steam generator PORVS and the upgrading of the pressurizer PORVS to
 
safety grade.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 80 of 91 The RHR system is provided with two separate and independent systems. This redundancy provides the system with the capability to maintain its heat removal function even with a
 
major single failure. Each RHR system train is isolated from the reactor coolant system (RCS) on the suction side by two motor operated valves (MOVs) in series. The suction isolation valves are independently interlocked to prevent the valves from being opened unless the RCS pressure is below the RHR system design pressure. Each MOV receives power via a separate motor
 
control center and the two valves in series in each train receive their power from a different vital bus. The suction isolation valves are also independently interlocked so that any open valve will automatically close if RCS pressure increases above the RHR system design pressure.
 
Refer to the positions on Regulatory Guides 1.22 and 1.68 for testing and the position on Regulatory Guide 1.33 for operational procedures.
 
RG No. 1.140, Rev. 1 UFSAR Reference Sections 9.4, 11.1, 11.3, 14.2.12 DESIGN, TESTING, AND MAINTENANCE CRITERIA FOR NORMAL VENTILATION EXHAUST SYSTEM AIR FILTRATION AND ADSORPTION UNITS OF LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (OCTOBER 1979)
 
Design, testing, and maintenance criteria for normal ventilation exhaust system air filtration and adsorption units for Beaver Valley Power Station - Unit 2 meet the intent of Regulatory
 
Guide 1.140 with the following alternatives:
Paragraph C.2.a
: 1. Where a very small amount of dust is anticipated, prefilters instead of upstream HEPA filters are provided.
: 2. Heating coils are provided only where the relative humidity is expected to exceed 70 percent.
Paragraph C.2.f
: 1. The ductwork leak tests are performed in accordance with ANSI N510-1975 with the alternative that ASME
 
Performance Test Code 19.5-1971 will be used in lieu of paragraph 6.3.1. The equipment and equipment arrangement based on the above ASME performance test
 
code will provide test results equivalent to results obtained by equipment specified in paragraph 6.3.1 of ANSI N510-1975.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 81 of 91 2. The air leakage rate for ductwork will be established based on the air cleaning effectiveness provisions defined in paragraph 4.12.1 of ANSI N509-1980. 
 
Because the ductwork carrying contaminated air upstream of filters is under negative pressure and there is no leakage from the ductwork to surrounding space, and because any air leak from the ductwork under positive pressure is on the downstream side of filters (filtered air), the leakage for ductwork upstream of filters and downstream of fans is limited to 5 percent of rated flow at internal design pressure (leakage Class II, Table 4-3 of ANSI N509-1980).
: 3. For ductwork between the outlet of filters and the inlet of fans, the leakage is limited to 0.5 percent of rated flow at internal design pressure (leakage Class I, Table 4-3 of ANSI N509-1980).
: 4. The filter housing leak test will be performed in accordance with paragraph 4.12 of ANSI N509-1976 with the alternative that the housing maximum allowable leakage will be as specified in Table 4-3 of ANSI N509-1980. The leakage test procedure will be developed based on Section 6 of ANSI N510-1980.
Paragraph C.3.c The component mounting frames meet the recommendations of ANSI N509-1976, paragraph 5.6.3, with an alternative for the tolerance provisions. The tolerances for mounting frames are sufficient to pass the bank leak test of paragraphs C.5.c and C.5.d of this Regulatory Guide.
Paragraph C.3.e
: 1. Stainless steel materials for filter housings are procured to ASTM material specifications such as A167 Type 304 and A267 Type 304 in addition to those listed in paragraph 4.3 of NSIC-65/ERDA 76-21.
: 2. Welding is performed in accordance with AWS D1.1 or ASME IX; therefore, the workmanship samples recommended in paragraph 7.3 of ANSI N509-1976 are not used to demonstrate welders' qualifications to perform production work.
Paragraph C.3.f
: 1. Welding procedures, welders, and welding operators are qualified in accordance with designer's welding specifications. These specifications are in general
 
conformance with AWS D1.1 and ASME Section IX, which are recommended in paragraph 7.3 of ANSI N509-1976. Production weld visual acceptance criteria, which are based on AWS D1.1, are used in lieu of workmanship samples recommended in ANSI N509-1976 paragraph 7.3.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 82 of 91 2. Materials for ductwork are procured to ASTM material specifications, such as A276 Type 304, A500 Gr B, A575 Gr N1020, and A576 Gr 1020, in addition to those
 
listed in paragraph 5.10.6 of ANSI N509-1976.
: 3. An alternative is taken to paragraph 5.10.3.5 of ANSI N509-1976. While ductwork, as a structure, has a resonant frequency above 25 Hz, this may not be true for the unsupported plate or sheet sections. ANSI N509-1980, which has been issued since the issuance of this Regulatory Guide, has deleted this provision. Tympanic vibration modes of the duct are not considered in design because the loads will be small, and minimum thickness of duct material is 20 gauge.
This is more conservative then SMACNA provisions.
Paragraph C.3.g The qualification of impregnated carbon will be in accordance with Table 5-1 of ANSI N509-1980. The test will be performed as specified in ASTM D3803-1979,
 
paragraph 4.1, Method A.
Paragraph C.3.i
: 1. The type and application of protective coatings on internal surfaces is controlled in accordance with the designer's specifications, which specify high quality materials and application methods in accordance with the coating manufacturer's instructions. These
 
practices are used in lieu of the recommendations in paragraphs 5.6.4 and 5.7.1 of ANSI N509-1976.
: 2. An alternative is taken to paragraph 5.7.2 of ANSI N509-1976. Copies of fan rating or test reports are not provided. However, certified fan performance
 
curves are furnished.
: 3. An alternative is taken to balancing techniques defined in paragraph 5.7.3 of ANSI N509-1976. Displacement criteria following normal industrial practice are used.
: 4. The fan drawings follow the recommendations of paragraph 5.7.4 of ANSI N509-1976 with the alternative that all information about lubricants and lubrication is contained in operation and instruction manuals.
: 5. Where AMCA certified ratings are submitted, documentation developed in conjunction with the
 
certification of fans is not furnished in accordance
 
with paragraph 5.7.5 of ANSI N509-1976.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 83 of 91 Paragraph C.3.1 The following alternatives are taken to paragraph 5.9 of ANSI N509-1976:
: 1. Isolation dampers used in the contaminated air streams are neither designed nor constructed to the recommendations of ANSI B31.1. The system is designed to ensure that the leakage through the dampers is from the noncontaminated to contaminated portion of the system, and the flow is exhausted through the filters before being released to the atmosphere. Therefore,
 
the uncontrolled release of radioactivity is precluded and the intent of Section 5.9 of ANSI N509-1976 is satisfied.
: 2. Butterfly valves, where used, are in accordance with the ASME III code.
: 3. One Class B damper of each size will be tested for leakage rate instead of testing every damper.
: 4. Welding is controlled in accordance with the designer's specifications using visual acceptance criteria, which are based on AWS D1.1 in lieu of the standards recommended in paragraphs 5.9 and 7.3 of ANSI N509-1976.
: 5. The minimum diameter of damper shafts that are 24 inches and under in length shall be 1/2 inch. The minimum diameter of damper shafts that are greater than 24 inches in length through 48 inches in length shall be 3/4 inch.
Paragraph C.5.a A visual inspection of the atmosphere cleanup system and all associated components is not planned to be made before each in-place air flow distribution test, DOP test, or
 
activated carbon adsorber section leak test, but will be performed after initial installation and on an as-needed basis in accordance with the provisions of Section 5 of
 
ANSI N510-1975.
Paragraph C.5.b The airflow capacity and distribution test procedure will
 
be developed based on Section 8 of ANSI N510-1980 with the
 
following alternatives:
: 1. To avoid damage to system components, an artificial resistance will be used in lieu of the provision of paragraph 8.3.1.1.
 
BVPS-2 UFSAR Rev. 17  TABLE 1.8-1 (Cont) 84 of 91 2. Airflow measurements for the airflow capacity test will be performed in accordance with AABC National Standards for total system balance, Fourth Edition, 1982, instead of Section 9 of ACGIH, Industrial Ventilation, as specified in paragraph 8.3.1(3) of ANSI N510-1975. The above alternative will provide
 
consistency with the airflow measurement method  for balancing of the plant ventilation systems.
: 3. The airflow test will be performed in accordance with paragraphs 8.3.1.1 and 8.3.1.6 only. The test
 
specified in paragraph 8.3.1.7 of ANSI N510-1980 duplicates the test under paragraph 8.3.1.1, because the actual values for pressure drop for both tests are approximately equal. The airflow test specified in paragraph 8.3.1.6 will be performed with the filter bank at 100 percent of design dirty-pressure drop.
The system and equipment instrumentation and
 
surveillance preclude inadvertent operation of the filter banks with the pressure or flow outside of the allowable limits.
: 4. Airflow distribution through prefilters and moisture separator banks is not specified, therefore, the provisions of paragraph 8.3.2.3 do not apply.
Paragraph C.5.c Sealant is used in ductwork field repairs, in addition to rivets, by applying the sealant between the ductwork and a
 
riveted patch. This method of repair is allowed only on non-seismic SMACNA Class ductwork.
 
The in-place DOP Test of HEPA filters will be performed in accordance with Section 10 of ANSI N510-1980. The air-aerosol mixing uniformity test will be performed in
 
accordance with Section 9 of the above code.
In-place DOP testing will be performed on the Filtration Units initially and after an entire or partial bank changeout.
Paragraph C.5.d The in-place test of the carbon adsorber will be performed in accordance with Section 12 of ANSI N510-1980.
In place testing of the carbon absorber units will be performed initially and after an entire or partial bank changeout. 
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 85 of 91 Paragraph C.6.b Laboratory testing frequency for the activated carbon will coincide with scheduled reactor shutdowns for refueling.
The carbon samples not obtained from test cannisters will be obtained with slotted-tube sampler in accordance with ANSI N509-1980.
 
RG No. 1.141, Rev. 0 UFSAR Reference Section 6.2.4
 
CONTAINMENT ISOLATION PROVISIONS FOR FLUID SYSTEMS (APRIL 1978)
Containment isolation provisions for fluid systems at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.
 
RG No. 1.142, Rev. 1 UFSAR Reference Sections 3.8.3, 3.8.4 SAFETY-RELATED CONCRETE STRUCTURES FOR NUCLEAR POWER PLANTS (OTHER THAN REACTOR VESSELS AND CONTAINMENT (OCTOBER 1981)
 
The design and analysis procedures for the Beaver Valley Power Station - Unit 2 safety-related concrete structures other than the reactor vessel and containment meet the intent of Regulatory Guide 1.142 with the following alternative:
 
The load combinations considered conform to the requirements of ACI Standard 318-7 and meet the general intent of ACI Standard 349-76. These combinations are shown in Sections 3.8.3.3 and 3.8.4.3.
 
RG No. 1.143, Rev. 1 UFSAR Reference Sections 3.8.4, 10.4.8, 11.2, 11.3, 11.4, 11.5
 
DESIGN GUIDANCE FOR RADIOACTIVE WASTE MANAGEMENT SYSTEMS, STRUCTURES, AND COMPONENTS INSTALLED IN LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (OCTOBER 1979)
The Beaver Valley Power Station - Unit 2 design of radioactive waste management systems, structures, and components meets the intent of Regulatory Guide 1.143 with the following clarifications and alternatives:
 
Paragraph C.1.1.3 The steam generator blowdown flash tank, the steam generator blowdown demineralizers, and the steam generator blowdown demineralizer heat exchangers are located in the
 
turbine building, a nonseismic structure.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 86 of 91 Leakage from steam generator blowdown system components located in the turbine building is collected in the turbine building sumps and monitored via grab samples prior to release to the
 
environment. The turbine building drain release will be isolated from the storm drainage system and transferred to the liquid waste system when the activity concentration exceeds
 
established site limits.
Paragraph C.1.2.3 The steam generator blowdown evaporator test tanks, the steam generator blowdown demineralizers, and the steam generator blowdown flash tank do not have curbs or elevated thresholds.  


BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  78 of 91 The duration of storage is not specifically recorded for each test since this can be calculated from the boring logs, where the sampling date is given, and the laboratory test data sheets, where the date of testing is recorded. Therefore, it is unnecessary to make a separate record of storage time.
Paragraph C.3.a  Classification tests are not performed on every undisturbed test specimen of soil or rock. Visual-manual techniques are the primary means of classifying soil and rock samples. Classification tests are performed on representative samples as necessary to confirm the results of the visual-manual classifications.
Measurements and control tests are not performed to determine whether undisturbed samples have changed during shipment, storage, and handling. Undisturbed samples are visually inspected as they are opened and extruded, to determine whether there has been any change in sample length within the tube or if there are any signs of sample disturbance. Results of these inspections are reported on the sample description log. This procedure and examination of the laboratory test results for possible indications of sample disturbance, is sufficient to determine whether sample disturbance has occurred.
Paragraph C.3.b  A discussion of the validity of test results on scalped materials is not presented as part of the laboratory test data. The laboratory test results indicate which portion of the sample has been scalped, and a competent reviewer of the test results would understand the effect of scalping on the results of specific tests.
Paragraph C.4.a(2)  Results of tests with B-values less than 0.95 may be used for analysis in certain cases. For very stiff or hard clays, it may not be possible to achieve a B-value of 0.95. If results of such a test are used, the B-value is reported and the probable effect on results of the test could be evaluated by a competent reviewer. Paragraph C.5.a  All soil and rock identifications and descriptions are not documented. The current practice of recording sample descriptions and determining index properties of representative samples is consistent with good engineering practice.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  79 of 91 Anomalous test data are not reported if they are caused by sample disturbance or equipment malfunction because such data do not reflect the true properties of the material in the field. However, records of such tests are maintained as part of the laboratory records. Appendix B, Relative Density Test  The frequency of the vibratory table cannot be adjusted, because it depends upon the fixed frequency of the input current. RG No. 1.139, Rev. 0 UFSAR Reference Sections 3.1.2.34, 5.4.7, Appendix 5A, 10.3, 10.4.9, 14.2  GUIDANCE FOR RESIDUAL HEAT REMOVAL (MAY 1978)  While the safe shutdown basis for Beaver Valley Power Station - Unit 2 (BVPS-2) is hot standby, the cold shutdown capability of the plant meets the intent of Regulatory Guide 1.139 and the Branch Technical Position RSB 5-1 design guidelines for Class 2 plants with the following clarifications:
Following a safe shutdown earthquake, assuming loss of onsite or offsite power and the most limiting single failure, the plant is capable of achieving residual heat removal (RHR) system initiation conditions (approximately 350F and 400 psia) within 36 hours. BVPS-2 designers employed an approach to safety grade cold shutdown by upgrading to safety grade, wherever feasible. It is recognized that achievement of cold shutdown, utilizing normally available non-safety grade systems and components, is desirable with postulation of loss-of-offsite power as the initiating event.
In order to provide adequate cooldown within 36 hours to initiate the RHR system, the steam generator power operated relief valves (PORVS) are qualified to full safety-grade design and an adequate supply of auxiliary feedwater is established. The primary plant demineralized water storage tank initially establishes the supply of auxiliary feedwater and is provided with backup from the demineralized water storage tank. Combined, these tanks have adequate storage capacity to remove residual heat for more than three days. Additionally, supply connections from the service water system are available should they be required.
Further upgrades for BVPS-2 include the addition of a safety grade atmospheric dump valve which provides backup to the steam generator PORVS and the upgrading of the pressurizer PORVS to safety grade.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  80 of 91 The RHR system is provided with two separate and independent systems. This redundancy provides the system with the capability to maintain its heat removal function even with a major single failure. Each RHR system train is isolated from the reactor coolant system (RCS) on the suction side by two motor operated valves (MOVs) in series. The suction isolation valves are independently interlocked to prevent the valves from being opened unless the RCS pressure is below the RHR system design pressure. Each MOV receives power via a separate motor control center and the two valves in series in each train receive their power from a different vital bus. The suction isolation valves are also independently interlocked so that any open valve will automatically close if RCS pressure increases above the RHR system design pressure.
Refer to the positions on Regulatory Guides 1.22 and 1.68 for testing and the position on Regulatory Guide 1.33 for operational procedures.
RG No. 1.140, Rev. 1 UFSAR Reference Sections 9.4, 11.1, 11.3, 14.2.12  DESIGN, TESTING, AND MAINTENANCE CRITERIA FOR NORMAL VENTILATION EXHAUST SYSTEM AIR FILTRATION AND ADSORPTION UNITS OF LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (OCTOBER 1979)
Design, testing, and maintenance criteria for normal ventilation exhaust system air filtration and adsorption units for Beaver Valley Power Station - Unit 2 meet the intent of Regulatory Guide 1.140 with the following alternatives:  Paragraph C.2.a  1. Where a very small amount of dust is anticipated, prefilters instead of upstream HEPA filters are provided. 
: 2. Heating coils are provided only where the relative humidity is expected to exceed 70 percent. Paragraph C.2.f  1. The ductwork leak tests are performed in accordance with ANSI N510-1975 with the alternative that ASME Performance Test Code 19.5-1971 will be used in lieu of paragraph 6.3.1. The equipment and equipment arrangement based on the above ASME performance test code will provide test results equivalent to results obtained by equipment specified in paragraph 6.3.1 of ANSI N510-1975.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  81 of 91 2. The air leakage rate for ductwork will be established based on the air cleaning effectiveness provisions defined in paragraph 4.12.1 of ANSI N509-1980.
Because the ductwork carrying contaminated air upstream of filters is under negative pressure and there is no leakage from the ductwork to surrounding space, and because any air leak from the ductwork under positive pressure is on the downstream side of filters (filtered air), the leakage for ductwork upstream of filters and downstream of fans is limited to 5 percent of rated flow at internal design pressure (leakage Class II, Table 4-3 of ANSI N509-1980). 3. For ductwork between the outlet of filters and the inlet of fans, the leakage is limited to 0.5 percent of rated flow at internal design pressure (leakage Class I, Table 4-3 of ANSI N509-1980). 4. The filter housing leak test will be performed in accordance with paragraph 4.12 of ANSI N509-1976 with the alternative that the housing maximum allowable leakage will be as specified in Table 4-3 of ANSI N509-1980. The leakage test procedure will be developed based on Section 6 of ANSI N510-1980. Paragraph C.3.c  The component mounting frames meet the recommendations of ANSI N509-1976, paragraph 5.6.3, with an alternative for the tolerance provisions. The tolerances for mounting frames are sufficient to pass the bank leak test of paragraphs C.5.c and C.5.d of this Regulatory Guide. Paragraph C.3.e  1. Stainless steel materials for filter housings are procured to ASTM material specifications such as A167 Type 304 and A267 Type 304 in addition to those listed in paragraph 4.3 of NSIC-65/ERDA 76-21. 2. Welding is performed in accordance with AWS D1.1 or ASME IX; therefore, the workmanship samples recommended in paragraph 7.3 of ANSI N509-1976 are not used to demonstrate welders' qualifications to perform production work. Paragraph C.3.f  1. Welding procedures, welders, and welding operators are qualified in accordance with designer's welding specifications. These specifications are in general conformance with AWS D1.1 and ASME Section IX, which are recommended in paragraph 7.3 of ANSI N509-1976. Production weld visual acceptance criteria, which are based on AWS D1.1, are used in lieu of workmanship samples recommended in ANSI N509-1976 paragraph 7.3.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  82 of 91 2. Materials for ductwork are procured to ASTM material specifications, such as A276 Type 304, A500 Gr B, A575 Gr N1020, and A576 Gr 1020, in addition to those listed in paragraph 5.10.6 of ANSI N509-1976. 
: 3. An alternative is taken to paragraph 5.10.3.5 of ANSI N509-1976. While ductwork, as a structure, has a resonant frequency above 25 Hz, this may not be true for the unsupported plate or sheet sections. ANSI N509-1980, which has been issued since the issuance of this Regulatory Guide, has deleted this provision. Tympanic vibration modes of the duct are not considered in design because the loads will be small, and minimum thickness of duct material is 20 gauge. This is more conservative then SMACNA provisions. Paragraph C.3.g  The qualification of impregnated carbon will be in accordance with Table 5-1 of ANSI N509-1980. The test will be performed as specified in ASTM D3803-1979, paragraph 4.1, Method A. Paragraph C.3.i 
: 1. The type and application of protective coatings on internal surfaces is controlled in accordance with the designer's specifications, which specify high quality materials and application methods in accordance with the coating manufacturer's instructions. These practices are used in lieu of the recommendations in paragraphs 5.6.4 and 5.7.1 of ANSI N509-1976. 2. An alternative is taken to paragraph 5.7.2 of ANSI N509-1976. Copies of fan rating or test reports are not provided. However, certified fan performance curves are furnished. 
: 3. An alternative is taken to balancing techniques defined in paragraph 5.7.3 of ANSI N509-1976. Displacement criteria following normal industrial practice are used. 4. The fan drawings follow the recommendations of paragraph 5.7.4 of ANSI N509-1976 with the alternative that all information about lubricants and lubrication is contained in operation and instruction manuals. 5. Where AMCA certified ratings are submitted, documentation developed in conjunction with the certification of fans is not furnished in accordance with paragraph 5.7.5 of ANSI N509-1976.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  83 of 91 Paragraph C.3.1  The following alternatives are taken to paragraph 5.9 of ANSI N509-1976:  1. Isolation dampers used in the contaminated air streams are neither designed nor constructed to the recommendations of ANSI B31.1. The system is designed to ensure that the leakage through the dampers is from the noncontaminated to contaminated portion of the system, and the flow is exhausted through the filters before being released to the atmosphere. Therefore, the uncontrolled release of radioactivity is precluded and the intent of Section 5.9 of ANSI N509-1976 is satisfied. 2. Butterfly valves, where used, are in accordance with the ASME III code. 3. One Class B damper of each size will be tested for leakage rate instead of testing every damper. 
: 4. Welding is controlled in accordance with the designer's specifications using visual acceptance criteria, which are based on AWS D1.1 in lieu of the standards recommended in paragraphs 5.9 and 7.3 of ANSI N509-1976. 5. The minimum diameter of damper shafts that are 24 inches and under in length shall be 1/2 inch. The minimum diameter of damper shafts that are greater than 24 inches in length through 48 inches in length shall be 3/4 inch. Paragraph C.5.a  A visual inspection of the atmosphere cleanup system and all associated components is not planned to be made before each in-place air flow distribution test, DOP test, or activated carbon adsorber section leak test, but will be performed after initial installation and on an as-needed basis in accordance with the provisions of Section 5 of ANSI N510-1975. Paragraph C.5.b  The airflow capacity and distribution test procedure will be developed based on Section 8 of ANSI N510-1980 with the following alternatives:  1. To avoid damage to system components, an artificial resistance will be used in lieu of the provision of paragraph 8.3.1.1.
BVPS-2 UFSAR Rev. 17  TABLE 1.8-1 (Cont)  84 of 91 2. Airflow measurements for the airflow capacity test will be performed in accordance with AABC National Standards for total system balance, Fourth Edition, 1982, instead of Section 9 of ACGIH, Industrial Ventilation, as specified in paragraph 8.3.1(3) of ANSI N510-1975. The above alternative will provide consistency with the airflow measurement method  for balancing of the plant ventilation systems. 3. The airflow test will be performed in accordance with paragraphs 8.3.1.1 and 8.3.1.6 only. The test specified in paragraph 8.3.1.7 of ANSI N510-1980 duplicates the test under paragraph 8.3.1.1, because the actual values for pressure drop for both tests are approximately equal. The airflow test specified in paragraph 8.3.1.6 will be performed with the filter bank at 100 percent of design dirty-pressure drop. The system and equipment instrumentation and surveillance preclude inadvertent operation of the filter banks with the pressure or flow outside of the allowable limits. 4. Airflow distribution through prefilters and moisture separator banks is not specified, therefore, the provisions of paragraph 8.3.2.3 do not apply. Paragraph C.5.c  Sealant is used in ductwork field repairs, in addition to rivets, by applying the sealant between the ductwork and a riveted patch. This method of repair is allowed only on non-seismic SMACNA Class ductwork.
The in-place DOP Test of HEPA filters will be performed in accordance with Section 10 of ANSI N510-1980. The air-aerosol mixing uniformity test will be performed in accordance with Section 9 of the above code. In-place DOP testing will be performed on the Filtration Units initially and after an entire or partial bank changeout. Paragraph C.5.d  The in-place test of the carbon adsorber will be performed in accordance with Section 12 of ANSI N510-1980. In place testing of the carbon absorber units will be performed initially and after an entire or partial bank changeout.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  85 of 91 Paragraph C.6.b  Laboratory testing frequency for the activated carbon will coincide with scheduled reactor shutdowns for refueling. The carbon samples not obtained from test cannisters will be obtained with slotted-tube sampler in accordance with ANSI N509-1980.
RG No. 1.141, Rev. 0 UFSAR Reference Section 6.2.4 CONTAINMENT ISOLATION PROVISIONS FOR FLUID SYSTEMS (APRIL 1978)  Containment isolation provisions for fluid systems at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.
RG No. 1.142, Rev. 1 UFSAR Reference Sections 3.8.3, 3.8.4  SAFETY-RELATED CONCRETE STRUCTURES FOR NUCLEAR POWER PLANTS (OTHER THAN REACTOR VESSELS AND CONTAINMENT (OCTOBER 1981)
The design and analysis procedures for the Beaver Valley Power Station - Unit 2 safety-related concrete structures other than the reactor vessel and containment meet the intent of Regulatory Guide 1.142 with the following alternative:
The load combinations considered conform to the requirements of ACI Standard 318-7 and meet the general intent of ACI Standard 349-76. These combinations are shown in Sections 3.8.3.3 and 3.8.4.3.
RG No. 1.143, Rev. 1 UFSAR Reference Sections 3.8.4, 10.4.8, 11.2, 11.3, 11.4, 11.5 DESIGN GUIDANCE FOR RADIOACTIVE WASTE MANAGEMENT SYSTEMS, STRUCTURES, AND COMPONENTS INSTALLED IN LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (OCTOBER 1979)  The Beaver Valley Power Station - Unit 2 design of radioactive waste management systems, structures, and components meets the intent of Regulatory Guide 1.143 with the following clarifications and alternatives:
Paragraph C.1.1.3  The steam generator blowdown flash tank, the steam generator blowdown demineralizers, and the steam generator blowdown demineralizer heat exchangers are located in the turbine building, a nonseismic structure.
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont)  86 of 91 Leakage from steam generator blowdown system components located in the turbine building is collected in the turbine building sumps and monitored via grab samples prior to release to the environment. The turbine building drain release will be isolated from the storm drainage system and transferred to the liquid waste system when the activity concentration exceeds established site limits. Paragraph C.1.2.3  The steam generator blowdown evaporator test tanks, the steam generator blowdown demineralizers, and the steam generator blowdown flash tank do not have curbs or elevated thresholds.
Test tanks receive distillate from the steam generator blowdown evaporators and provide facilities for storage and sampling prior to release to the environment.
Test tanks receive distillate from the steam generator blowdown evaporators and provide facilities for storage and sampling prior to release to the environment.
Calculations show that the tanks do not require shielding due to the low activity level of water expected in these tanks. A floor drain is provided in the general area of the test tanks to collect leakage and overflow in the auxiliary building sump for pumping to the liquid waste system. Refer to paragraph C.1.1.3 for the steam generator blowdown flash tank. Paragraph C.1.2.5 The refueling water storage tank is not provided with a dike or retention pond. Tank overflow is directed to the liquid waste system via piping. The refueling water storage tank is fabricated in accordance with the requirements of ASME III, Class 2. The atmospheric tank is tested full of water to ensure that there are no leaks, and undergoes 100-percent radiographic examination on the shell. Tank overflow is directed to the liquid waste system via the safeguards building sump piping. The radionuclide concentrations of the refueling water storage tank liquid will be determined following each refueling. Paragraph C.2.1.1 The gaseous waste system equipment meets or exceeds the codes in Table 1. The gaseous waste delay beds, gaseous waste surge tank, waste gas chiller, overhead gas compressors and piping are designed and fabricated to ASME III. The valves are designed and fabricated to ANSI B31.1. The gaseous waste storage tanks are designed and fabricated to ASME VIII, Division 1.
Calculations show that the tanks do not require shielding due to the low activity level of water expected in these tanks. A floor drain is provided in the general area of the test tanks to collect leakage and overflow in the auxiliary building sump for pumping to the liquid waste system. Refer to paragraph C.1.1.3 for the steam  
All equipment manufacturing codes exceed those specified by Table 1 of Regulatory Guide 1.143.
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 87 of 91 Paragraph C.2.1.3 The gaseous waste system piping within the gaseous waste storage tank vault structure is designated non-seismic and has been analyzed for dead-load and thermal stresses only.
generator blowdown flash tank.
Failure of the gaseous waste system piping within the gaseous waste storage tank vault will not adversely affect any other systems or components because the storage tank vault contains only gaseous waste system piping. The Offsite Dose Calculation Manual (ODCM) provides a limit on the quantity of radioactivity contained in each group of gaseous waste storage tanks. The basis of this requirement is to restrict the quantity of radioactivity so any release due to a leak or failure will not exceed the requirements of NRC Branch Technical Position ETSB 11-5, Rev. 0, dated July 1981, of 0.5 Rem at the exclusion area boundary. This accident is described in Section 15.7.1. The storage tank system is used to store all the gas generated by either BVPS-1 or BVPS-2 when going to a cold shutdown condition. The system uses seven tanks, each of which has individual solenoid operated isolation valves, a pressure indicator, a high pressure alarm, and overpressure protection. The storage tanks were purchased and constructed to ASME VIII requirements and subsequently were seismically mounted in the gaseous waste storage tank vault structure. The seven tanks may all be in service at one time, or be operated in smaller groupings.
Paragraph C.1.2.5 The refueling water storage tank is not provided with a  
Paragraph C.4.3 The piping downstream of the overhead gas compressors is one-half inch.
 
The discharge piping for the overhead gas compressors is designed to not impose any unnecessary pressure loss in that portion of the gaseous waste system.
dike or retention pond. Tank overflow is directed to the  
The steam generator blowdown heat exchanger condensate flow sensing lines are one-half inch. These sensing lines are sized to accommodate instrument requirements. Standard 300# orifice flanges are tapped with 1/2" ports. There is no concern for clogging the smaller diameter pipe because there are no resins present in this portion of the system. Paragraph C.5.1.1 Beaver Valley Power Station - Unit 2 (BVPS-2) does not apply the Regulatory Guide 1.60 design ground response spectra. Instead, a BVPS spectrum is applied as described in Section 3.7B.1 BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 88 of 91 Paragraph C.5.2.1 Beaver Valley Power Station - Unit 2 does not use Regulatory Guide 1.60 spectra nor Regulatory Guide 1.61 damping values. Instead, refer to Sections 3.7B.1.1 and 3.7B.1.3.
 
Paragraph C.5.2.2 Beaver Valley Power Station - Unit 2 complies with this section, except that the spectra described in Sections 3.7B.1 and 3.7B.2 are used. Paragraph C.5.2.3 Beaver Valley Power Station - Unit 2 uses the modal time-history technique to generate floor response spectra. Refer to Section 3.7B.2. Paragraph C.5.2.4 Beaver Valley Power Station - Unit 2 uses ACI-318-71. This was the code in effect at the time of design. The differences between this code and ACI-318-77 are insignificant. Paragraph C.6 Quality assurance programs used for the design, manufacture, construction, and inspection of the equipment used in the radwaste management systems are in accordance with a QA Category II classification and the codes and standards specified in the equipment purchase specifications. RG No. 1.144 UFSAR Reference Section 17.2  
liquid waste system via piping.
The refueling water storage tank is fabricated in accordance with the requirements of ASME III, Class 2.
The atmospheric tank is tested full of water to ensure that there are no leaks, and undergoes 100-percent  
 
radiographic examination on the shell. Tank overflow is directed to the liquid waste system via the safeguards building sump piping. The radionuclide concentrations of the refueling water storage tank liquid will be determined following each refueling.
Paragraph C.2.1.1 The gaseous waste system equipment meets or exceeds the  
 
codes in Table 1. The gaseous waste delay beds, gaseous waste surge tank, waste gas chiller, overhead gas compressors and piping are designed and fabricated to ASME III. The valves are designed and fabricated to ANSI B31.1. The gaseous waste storage tanks are designed and fabricated to ASME VIII, Division 1.  
 
All equipment manufacturing codes exceed those specified by Table 1 of Regulatory Guide 1.143.  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 87 of 91 Paragraph C.2.1.3 The gaseous waste system piping within the gaseous waste storage tank vault structure is designated non-seismic and has been analyzed for dead-load and thermal stresses only.  
 
Failure of the gaseous waste system piping within the gaseous waste storage tank vault will not adversely affect any other systems or components because the storage tank vault contains only gaseous waste system piping. The Offsite Dose Calculation Manual (ODCM) provides a limit on the quantity of radioactivity contained in each group of gaseous waste storage tanks. The basis of this requirement is to restrict the quantity of radioactivity so any release due to a leak or failure will not exceed the requirements of NRC Branch Technical Position ETSB 11-5, Rev. 0, dated July 1981, of 0.5 Rem at the exclusion area boundary. This accident is described in Section  
 
15.7.1. The storage tank system is used to store all the gas  
 
generated by either BVPS-1 or BVPS-2 when going to a cold shutdown condition. The system uses seven tanks, each of which has individual solenoid operated isolation valves, a pressure indicator, a high pressure alarm, and overpressure protection. The storage tanks were purchased and constructed to ASME VIII requirements and subsequently were seismically mounted in the gaseous waste storage tank vault structure. The seven tanks may all be in service at one time, or be operated in smaller groupings.  
 
Paragraph C.4.3 The piping downstream of the overhead gas compressors is one-half inch.  
 
The discharge piping for the overhead gas compressors is designed to not impose any unnecessary pressure loss in that portion of the gaseous waste system.  
 
The steam generator blowdown heat exchanger condensate flow sensing lines are one-half inch. These sensing lines are sized to accommodate instrument requirements. Standard 300# orifice flanges are tapped with 1/2" ports. There is no concern for clogging the smaller diameter pipe  
 
because there are no resins present in this portion of the system. Paragraph C.5.1.1
 
Beaver Valley Power Station - Unit 2 (BVPS-2) does not apply the Regulatory Guide 1.60 design ground response spectra. Instead, a BVPS spectrum is applied as described in Section 3.7B.1  
 
BVPS-2 UFSAR Rev. 13  TABLE 1.8-1 (Cont) 88 of 91 Paragraph C.5.2.1 Beaver Valley Power Station - Unit 2 does not use Regulatory Guide 1.60 spectra nor Regulatory Guide 1.61 damping values. Instead, refer to Sections 3.7B.1.1 and 3.7B.1.3.  
 
Paragraph C.5.2.2 Beaver Valley Power Station - Unit 2 complies with this section, except that the spectra described in Sections 3.7B.1 and 3.7B.2 are used.
Paragraph C.5.2.3 Beaver Valley Power Station - Unit 2 uses the modal time-history technique to generate floor response spectra.
Refer to Section 3.7B.2.
Paragraph C.5.2.4 Beaver Valley Power Station - Unit 2 uses ACI-318-71. This was the code in effect at the time of design. The differences between this code and ACI-318-77 are  
 
insignificant.
Paragraph C.6 Quality assurance programs used for the design, manufacture, construction, and inspection of the equipment used in the radwaste management systems are in accordance with a QA Category II classification and the codes and standards specified in the equipment purchase  
 
specifications.
RG No. 1.144 UFSAR Reference Section 17.2  
 
AUDITING OF QUALITY ASSURANCE PROGRAMS FOR NUCLEAR POWER PLANTS
 
Application of Regulatory Guide 1.144 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual
.
RG No. 1.145, Rev. 1 UFSAR Reference Sections 2.3, 13.3
 
ATMOSPHERIC DISPERSION MODELS FOR POTENTIAL ACCIDENT CONSEQUENCE ASSESSMENTS AT NUCLEAR POWER PLANTS (NOVEMBER 1982)
 
Atmospheric dispersion models used for potential accident consequence assessments at Beaver Valley Power Station - Unit 2
 
follow the guidance of this regulatory guide.
 
BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont) 89 of 91 RG No. 1.146 UFSAR Reference Section 17.2
 
QUALIFICATION OF QUALITY ASSURANCE PROGRAM AUDIT PERSONNEL FOR NUCLEAR POWER PLANTS
 
Application of Regulatory Guide 1.146 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance
 
Program Manual.


AUDITING OF QUALITY ASSURANCE PROGRAMS FOR NUCLEAR POWER PLANTS Application of Regulatory Guide 1.144 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.145, Rev. 1 UFSAR Reference Sections 2.3, 13.3 ATMOSPHERIC DISPERSION MODELS FOR POTENTIAL ACCIDENT CONSEQUENCE ASSESSMENTS AT NUCLEAR POWER PLANTS (NOVEMBER 1982)
Atmospheric dispersion models used for potential accident consequence assessments at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.
BVPS-2 UFSAR Rev. 18  TABLE 1.8-1 (Cont)  89 of 91 RG No. 1.146 UFSAR Reference Section 17.2 QUALIFICATION OF QUALITY ASSURANCE PROGRAM AUDIT PERSONNEL FOR NUCLEAR POWER PLANTS Application of Regulatory Guide 1.146 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.
RG No. 1.147, Rev. 5 UFSAR Reference Section 6.6  
RG No. 1.147, Rev. 5 UFSAR Reference Section 6.6  


INSERVICE INSPECTION CODE CASE ACCEPTABILITY ASME SECTION XI DIVISION 1 (AUGUST 1986)
INSERVICE INSPECTION CODE CASE ACCEPTABILITY ASME SECTION XI DIVISION 1 (AUGUST 1986)
Utilization of inservice inspection code cases for BVPS-2 follows the guidance of this regulatory guide.


All applicable  ASME XI Code Cases utilized for BVPS-2 are identified in the ASME Code Baseline Document.
Utilization of inservice inspection code cases for BVPS-2
 
follows the guidance of this regulatory guide.
 
All applicable  ASME XI Code Cases utilized for BVPS-2 are  
 
identified in the ASME Code Baseline Document.  


RG No. 1.148, Rev. 0 UFSAR Reference Section 3.11  
RG No. 1.148, Rev. 0 UFSAR Reference Section 3.11  


FUNCTIONAL SPECIFICATION FOR ACTIVE VALVE ASSEMBLIES IN SYSTEMS IMPORTANT TO SAFETY IN NUCLEAR POWER PLANTS (MARCH 1981)
FUNCTIONAL SPECIFICATION FOR ACTIVE VALVE ASSEMBLIES IN SYSTEMS IMPORTANT TO SAFETY IN NUCLEAR POWER PLANTS (MARCH 1981)
BVPS-2 meets the intent of Regulatory Guide 1.148 for ensuring the operability of active valve assemblies in systems important to safety with the following clarifications and alternatives:
Active valves are defined as those relied upon to perform a safety function (as well as a reactor shutdown function) during the transients or events considered in the respective operating condition categories.


Active valves are subjected to analysis and tests to verify operability during a seismic event as described in UFSAR Section 3.9N.3.2 and 3.9B.3.2.2. Active valves also undergo pre-installation operational tests and periodic in-service operational tests to verify and assure their functional ability.  
BVPS-2 meets the intent of Regulatory Guide 1.148 for ensuring the operability of active valve assemblies in systems important
 
to safety with the following clarifications and alternatives:
 
Active valves are defined as those relied upon to perform a safety function (as well as a reactor shutdown function) during the transients or events considered in the
 
respective operating condition categories.
 
Active valves are subjected to analysis and tests to verify operability during a seismic event as described in UFSAR Section 3.9N.3.2 and 3.9B.3.2.2. Active valves also  
 
undergo pre-installation operational tests and periodic in-service operational tests to verify and assure their  
 
functional ability.  
 
The overall design process includes systems design, valve specifications, and quality assurance procedures. Many of the functional requirements are included in the systems design which dictates the type of valve required for the system application. Inclusion of all requirements in a
 
specification to a valve manufacturer would provide information that is not required to manufacture the valves. Since the requirements are all integrated into the design process, a consolidation of all the requirements into a single document is considered
 
unnecessary.
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont) 90 of 91 RG No. 1.149, Rev. 0 UFSAR Reference Section 13.2 NUCLEAR POWER PLANT SIMULATORS FOR USE IN OPERATOR TRAINING (APRIL 1981)
 
The guidance of this regulatory guide is followed for simulators used in operator training for Beaver Valley Power Station - 


The overall design process includes systems design, valve specifications, and quality assurance procedures. Many of the functional requirements are included in the systems design which dictates the type of valve required for the system application. Inclusion of all requirements in a specification to a valve manufacturer would provide information that is not required to manufacture the valves. Since the requirements are all integrated into the design process, a consolidation of all the requirements into a single document is considered unnecessary.
BVPS-2 UFSAR Rev. 14  TABLE 1.8-1 (Cont)  90 of 91  RG No. 1.149, Rev. 0 UFSAR Reference Section 13.2  NUCLEAR POWER PLANT SIMULATORS FOR USE IN OPERATOR TRAINING (APRIL 1981)
The guidance of this regulatory guide is followed for simulators used in operator training for Beaver Valley Power Station -
Unit 2.
Unit 2.
RG No. 1.150, Rev. 1 UFSAR Reference Section 5.3.1, 5.3.3  
RG No. 1.150, Rev. 1 UFSAR Reference Section 5.3.1, 5.3.3  


ULTRASONIC TESTING OF REACTOR VESSEL WELDS DURING PRESERVICE AND INSERVICE EXAMINATIONS (FEBRUARY 1983)
ULTRASONIC TESTING OF REACTOR VESSEL WELDS DURING PRESERVICE AND INSERVICE EXAMINATIONS (FEBRUARY 1983)
Ultrasonic testing of the reactor vessel welds during preservice and inservice examinations at BVPS-2 will follow the guidance of this regulatory guide as described in the Preservice Inspection Program, which was submitted to the NRC in Letter 2NRC-5-154, dated December 26, 1985, and the Inservice Inspection Program, which is scheduled to be submitted to the NRC in the last quarter of 1986.
 
Ultrasonic testing of the reactor vessel welds during preservice and inservice examinations at BVPS-2 will follow the guidance of this regulatory guide as described in the Preservice Inspection Program, which was submitted to the NRC in Letter 2NRC-5-154, dated December 26, 1985, and the Inservice Inspection Program, which is scheduled to be submitted to the NRC in the last  
 
quarter of 1986.  
 
RG No. 1.155, June 1988 UFSAR Reference Section 8.3.1.1.19  
RG No. 1.155, June 1988 UFSAR Reference Section 8.3.1.1.19  


STATION BLACKOUT BVPS utilizes the emergency diesel generators at each unit as an alternate AC (AAC) power source to operate systems necessary for coping with a station blackout. The design of the cross-tie circuit between BVPS-1 and BVPS-2 AAC power sources conforms with guidance provided by RG No. 1.155.
STATION BLACKOUT
 
BVPS utilizes the emergency diesel generators at each unit as an alternate AC (AAC) power source to operate systems necessary for coping with a station blackout. The design of the cross-tie circuit between BVPS-1 and BVPS-2 AAC power sources conforms  
 
with guidance provided by RG No. 1.155.  
 
RG No. 1.163, September 1995 UFSAR Reference Section 6.2.6  
RG No. 1.163, September 1995 UFSAR Reference Section 6.2.6  


PERFORMANCE-BASED CONTAINMENT LEAK TEST PROGRAM The Containment Leakage Rate Testing Program is in accordance with the guidelines contained in RG No. 1.163 except as noted in the Technical Specifications. This regulatory guide provides guidance on an acceptable performance based leak test program, leakage rate test methods, procedures, and analyses that may be used to comply with the performance based Option B in Appendix J of 10 CFR 50.  
PERFORMANCE-BASED CONTAINMENT LEAK TEST PROGRAM
 
The Containment Leakage Rate Testing Program is in accordance with the guidelines contained in RG No. 1.163 except as noted in the Technical Specifications. This regulatory guide provides guidance on an acceptable performance based leak test program, leakage rate test methods, procedures, and analyses that may be used to comply with the performance based Option B in Appendix J of 10 CFR 50.  
 
BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont) 91 of 91 RG No. 1.183, Rev. 0 ALTERNATIVE RADIOLOGICAL SOURCE TERMS FOR EVALUATING DESIGN BASIS ACCIDENTS AT NUCLEAR POWER REACTORS (JULY 2000)
 
This regulatory guide provides assumptions, methods and acceptance criteria that are acceptable to the NRC staff for performing design basis radiological analyses using an alternate
 
source term. With the exception of the Waste Gas System Rupture, this regulatory guide is utilized to evaluate the potential radiological consequences of all of the BVPS-2 design basis accidents.
RG No. 1.194, Rev. 0 ATMOSPHERIC RELATIVE CONCENTRATIONS FOR CONTROL ROOM RADIOLOGICAL HABITABILITY ASSESSMENTS AT NUCLEAR POWER PLANTS Control Room X/Q values were calculated using the NRC-sponsored ARCON96 computer code (NUREG/CR-6331, Revision 1, "Atmospheric Relative Concentrations in Building Wakes") and in a manner consistent with RG 1.194.
 
BVPS-2 UFSAR Rev. 16 1.9-1 1.9  STANDARD REVIEW PLAN CONFORMANCE EVALUATION In accordance with 10 CFR 50.34(g), this section provided an evaluation of Beaver Valley Power Station - Unit 2 (BVPS-2) against the USNRC Standard Review Plan [NUREG-0800], dated July 1981. Therefore, this section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.
The evaluation of BVPS-2 against each Standard Review Plan (SRP) includes an identification and description of all differences in design features, analytical techniques, and procedural measures proposed for BVPS-2 and those corresponding features, techniques, and measures given in the SRP acceptance criteria. Where such a difference exists, an evaluation is provided which discusses how the proposed alternative provided an acceptable method of complying with those USNRC rules or regulations, or portions thereof, that underlie the corresponding SRP acceptance
 
criteria.
Table 1.9-1 identifies each SRP against which BVPS-2 was evaluated. For those SRPs against which exceptions were taken, SRP conformance statements, which discuss and justify such alternatives to the SRP acceptance criteria, are provided in
 
Table 1.9-2.
BVPS-2 UFSAR  Tables for Section 1.9
 
(Tables in Section 1.9 are historical)
 
BVPS-2 UFSAR Rev. 16 1 of 12 TABLE 1.9-1 STANDARD REVIEW PLAN CONFORMANCE (HISTORICAL)
CHAPTER 1:  INTRODUCTION AND GENERAL DESCRIPTION OF PLANT Rev. Conform Exception 1.8 Interfaces for Standard Design...................................................................................... 1 N/A CHAPTER 2:  SITE CHARACTERISTICS 2.1.1 Site Location a nd Description................................................................................. 2 X  2.1.2 Exclusion Area Authority and Control..................................................................... 2 X  2.1.3 Population Distribution........................................................................................... 2 X  2.2.1 - 2.2.2 Identification of Potential Hazards in Site Vicinity................................................... 2 X  2.2.3 Evaluation of Potential Accidents........................................................................... 2 X 
 
====2.3.1 Regional====
Climatology............................................................................................. 2 X 2.3.2 Local Meteorology.................................................................................................. 2  X 2.3.3 Onsite Meteorological Measurements Programs................................................... 2 X 
 
Appendix A.................................................................................................... 2 X  2.3.4 Short-Term Diffusion Estimates............................................................................. 1 X  2.3.5 Long-Term Diffusion Estimates.............................................................................. 2 X  2.4.1 Hydrologic Description........................................................................................... 2 X 
 
Appendix A.................................................................................................... 2 X 2.4.2 Floods.................................................................................................................... 2 X  2.4.3 Probable Maximum Flood (PMF) on Streams and Rivers...................................... 2 X 2.4.4 Potential Dam Failures (Seismically-Induced)........................................................ 2 X 2.4.5 Probable Maximum Surge and Seiche Flooding.................................................... 2 X  2.4.6 Probable Maximum Ts unami Flooding................................................................... 2 X 2.4.7 Ice Effects.............................................................................................................. 2 X  2.4.8 Cooling Water Canals and Reservoirs................................................................... 2 X 2.4.9 Channel Diversions................................................................................................ 2 X  2.4.10 Flood Protection Requirements.............................................................................. 2 X 2.4.11 Cooling Water Supply............................................................................................
2  X 2.4.12 Ground Water......................................................................................................... BTP HGEB 1.......................................................................................................
2 2  X X 2.4.13 Accidental Releases of Liquid Effluents in Gr ound and Surface Waters................ 2  X 2.4.14 Technical Specifications and Emergency Operation Requirements....................... 2 X  2.5.1 Basic Geologic and Seismic Information................................................................ 2  X 2.5.2 Vibratory Ground Motion........................................................................................ 1  X 2.5.3 Surface Faulting..................................................................................................... 2 X BVPS-2 UFSAR Rev. 0 2 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 2.5.4 Stability of Subsurface Ma terials and Foundations....................................................... 2  X 2.5.5 Stability of Slopes.......................................................................................................... 2 X CHAPTER 3:  DESIGN OF STRUCTURES, COMPONENTS, EQUIPMENT, AND SYSTEMS 3.2.1 Seismic Classification................................................................................................... 1 X  3.2.2 System Quality Group Classification............................................................................. 1  X Appendix A (formerly BTP RSB 3-1).................................................................... 1 X            Appendix B (formerly BTP RSB 3-2).................................................................... 1 X            Appendix C .......................................................................................................... 0 X            Appendix D........................................................................................................... 0 X  3.3.1 Wind Loadings.............................................................................................................. 2  X 3.3.2 Tor nado Loadings......................................................................................................... 2 X  3.4.1 Flood Protection............................................................................................................ 2 X  3.4.2 Analysis Procedures..................................................................................................... 1 X  3.5.1.1 Internally Generated Missi les (Outside Containment)................................................... 2 X  3.5.1.2 Internally Generated Missi les (Inside Containment)...................................................... 2 X  3.5.1.3 Turbi ne Missiles............................................................................................................ 2  X 3.5.1.4 Missiles Generated by Natural Phenomena.................................................................. 2 X BTP AAB 3-2..............................................................................................................
1 X      BTP ASB 3-2..............................................................................................................
2 X  3.5.1.5 Site Proximity Missiles (Except Aircraft)........................................................................ 1 X 3.5.1.6 Aircra ft Hazards............................................................................................................ 1 X 3.5.2 Structures, Systems, and Components to be Protected from    Externally Generated Missiles....................................................................................
2  X  3.5.3 Barrier Design Procedures............................................................................................ 1 X Appendix A................................................................................................................. 0 X  3.6.1 Plant Design for Protection Against Postulated Piping Failures in Fluid    Systems Outs ide Containment...................................................................................
1  X    BTP ASB 3-1..............................................................................................................
1  X 3.6.2 Determination of Rupture Locations and Dynamic Effects Associated    with the Postulated Rupture of Piping........................................................................
1  X    BTP MEB 3-1............................................................................................................. 1 X 3.7.1 Seismic Design Parameters.......................................................................................... 1  X 3.7.2 Seismic System Analysis.............................................................................................. 1 X 3.7.3 Seismic Subsystem Analysis......................................................................................... 1  X 3.7.4 Seismic Instrumentation................................................................................................ 1 X BVPS-2 UFSAR Rev. 0 3 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 3.8.1 Concrete Containment.................................................................................................. 1 X 3.8.2 Steel Containment......................................................................................................... 1  X 3.8.3 Concrete and Steel Internal Structures of Steel or Concrete Containments................. 1  X 3.8.4 Other Seismic Category I Structures.............................................................................
1  X 3.8.5 Found ations.................................................................................................................. 1  X 3.9.1 Special Topics for Mec hanical Components................................................................. 2  X 3.9.2 Dynamic Testing and Analysis of Systems, Components, and Equipment................... 2  X 3.9.3 ASME Code Class 1, 2 and 3 Components, Component Supports, and Core Support Structures.............................................................................................
1  X          Appendix A........................................................................................................... 0  X 3.9.4 Control Rod Drive Systems........................................................................................... 1 X 3.9.6 Inservice Testing of Pumps and Valves........................................................................ 2 X  3.10 Seismic Qualification of Category I Instru mentation and Electrical Equipment.............
2  X 3.11 Environmental Design of Mechanical a nd Electrical Eq uipment.................................... 2  X CHAPTER 4:  REACTOR 4.2 Fuel System Design......................................................................................................
2 X  4.3 Nuclear Design.............................................................................................................. 2 X      BTP CPB 4.3-1........................................................................................................... 2 X  4.4 Thermal and Hydraulic Design...................................................................................... 1 X Appendix.............................................................................................................. 1 X  4.5.1 Control Rod Drive Structural Ma terials.......................................................................... 2  X 4.5.2 Reactor Internal and Core Support Materials................................................................ 2  X 4.6 Functional Design of Control Rod Drive System........................................................... 1 X CHAPTER 5:  REACTOR COOLANT SYSTEM AND CONNECTED SYSTEMS 5.2.1.1 Compliance with Codes and Standard Rule 10 CF R 50.55a......................................... 2  X 5.2.1.2 Applicable Codes Cases............................................................................................... 2  X 5.2.2 Overpressure Protection............................................................................................... 1 X    BTP RSB 5-2..............................................................................................................
0 X  5.2.3 Reactor Coolant Pressure Boundary Materials............................................................. 2  X BTP MTEB 5-7........................................................................................................... 2 X BVPS-2 UFSAR Rev. 0 4 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 5.2.4 Reactor Coolant Pressure Boundary Inservic e Inspection and Testing........................ 1 X 5.2.5 Reactor Coolant Pressure Boundary Leakage Detection.............................................. 1  X 5.3.1 Reactor Vessel Materials.............................................................................................. 1 X 5.3.2 Pressure-Temperat ure Limits........................................................................................ 1 X BTP MTEB 5-2........................................................................................................... 1 X  5.3.3 Reactor Vessel Integrity................................................................................................ 1 X  5.4 Preface.......................................................................................................................... 1 X  5.4.1.1 Pump Flywheel Integrity (PWR).................................................................................... 1  X 5.4.2.1 Steam Generat or Materials........................................................................................... 2 X    BTP MTEB 5-3........................................................................................................... 2 X  5.4.2.2 Steam Generator Tube In service Inspection................................................................. 1 X 5.4.6 Reactor Core Isolation Cooling System (BWR)............................................................. 2 N/A 5.4.7 Residual Heat Removal (RHR) System........................................................................ 2  X    BTP RSB 5-1..............................................................................................................
2 X  5.4.8 Reactor Water Cleanup System (BWR)........................................................................ 2 N/A 5.4.11 Pressurize r Relief Tank................................................................................................. 2 X  5.4.12 Reactor Coolant System High Point Vents.................................................................... 0  X      CHAPTER 6:  ENGINEERED SAFETY FEATURES 6.1.1 Engineered Safety Features Materials.......................................................................... 2  X    BTP MTEB 6-1........................................................................................................... 2 X  6.1.2 Protective Coating Systems (Pai nts) - Organic Materials.............................................. 2 X  6.2.1 Containment Functional Design.................................................................................... 2 X  6.2.1.1A PWR Dry Containments, Including Sub-atmospheric Containments............................. 2  X 6.2.1.1B Ice C ondenser Containments........................................................................................ 2 N
/A  6.2.1.1C Pressure-Suppression Ty pe BWR Containments......................................................... 4 N/A Appendix I............................................................................................................ 1 N/A 6.2.1.2 Subcompartment Analysis............................................................................................. 2 X  6.2.1.3 Mass and Energy Release Analysis for Postulated Loss-of-Coolant Accidents 1  X 6.2.1.4 Mass and Energy Release Analysis for Postulated Secondary System Pipe Ruptures............................................................................................................
1  X BVPS-2 UFSAR Rev. 0 5 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 6.2.1.5 Minimum Containment Pressure Analysis for Emergency Core Cooling    System Performance Capability Studies....................................................................
2  X    BTP CSB 6-1..............................................................................................................
2  X 6.2.2 Containment Heat Removal Systems........................................................................... 3 X  6.2.3 Secondary Containment Functiona l Design.................................................................. 2 X BTP CSB 6-3..............................................................................................................
2 X  6.2.4 Containment Isolation System....................................................................................... 2  X BTP CSB 6-4..............................................................................................................
2 X  6.2.5 Combustible Gas Contro l in Containment..................................................................... 2 X            Appendix A........................................................................................................... 2 X  6.2.6 Containment Leakage Testing...................................................................................... 2 X 6.2.7 Fracture Prevention of Contai nment Pressure Boundary.............................................. 5  6.3 Emergency Core Cooling System................................................................................. 1  X BTP RSB 6-1..............................................................................................................
1  X 6.4 Control Room Habitability Systems............................................................................... 2  X Appendix A........................................................................................................... 2  X 6.5.1 ESF Atmosphere Cleanup Systems.............................................................................. 2  X 6.5.2 Containment Spray as a Fissi on Product Cleanup System........................................... 1 X 6.5.3 Fission Product Control Sy stems and Structures.......................................................... 2 X 6.5.4 Ice Condenser as a Fission Product Cleanup System.................................................. 2 X 6.6 Inservice Inspection of Class 2 and 3 Components...................................................... 1 X 6.7 Main Steam Isol ation Valve Leakage Control System (BWR)....................................... 2 N/A      CHAPTER 7:  INSTRUMENTATION AND CONTROLS
 
===7.1 Instrumentatio===
n and Controls - In troduction.................................................................. 2 X Table 7-1 Acceptance Criteria and Guidelines for Instrumentation and          Controls Sy stems Important to Safety..................................................................
2  X  7.2 Reactor Trip System..................................................................................................... 2 X          Appendix A........................................................................................................... 2 X  7.3 Engineered Safety Features Systems........................................................................... 2  X Appendix A........................................................................................................... 2 X  7.4 Safe Shutdown Systems............................................................................................... 2  X 7.5 Information Systems Impor tant to Safety...................................................................... 2  X BVPS-2 UFSAR Rev. 0 6 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 7.6 Interlock Systems Impor tant to Safety........................................................................... 2  X 7.7 Control Systems............................................................................................................ 2 X  Appendix 7A Branch Technica l Positions (ICSB)............................................................................... 2 X      BTP ICSB 1 (DOR).................................................................................................... 2 X BTP ICSB 3................................................................................................................ 2 X      BTP ICSB 4 (PSB)..................................................................................................... 2 X BTP ICSB 5................................................................................................................ 2 X      BTP ICSB 9................................................................................................................ 2 X      BTP ICSB 12.............................................................................................................. 2 X      BTP ICSB 13.............................................................................................................. 2 X      BTP ICSB 14.............................................................................................................. 2 X      BTP ICSB 16.............................................................................................................. 2 X      BTP ICSB 19.............................................................................................................. 2 X      BTP ICSB 20.............................................................................................................. 2 X      BTP ICSB 21.............................................................................................................. 2 X      BTP ICSB 22.............................................................................................................. 2 X      BTP ICSB 25.............................................................................................................. 2 X      BTP ICSB 26.............................................................................................................. 2 X  Appendix 7B General Agenda, Station Site Visits.............................................................................. 1 X      CHAPTER 8:  ELECTRIC POWER 8.1 Electric Power - Introduction......................................................................................... 2 X Table 8-1 Acceptance Criteria and Guidelines for Electric          Power Systems....................................................................................................
2  X  8.2 Offsite Power System....................................................................................................
2 X  8.3.1 AC Power System s (Onsite).......................................................................................... 2 X 8.3.2 DC Power System s (Onsite)......................................................................................... 2 X  Appendix 8A Branch Techni cal Positions (PSB)................................................................................
2  X    BTP ICSB 2 (PSB)..................................................................................................... 2 X BTP ICSB 4 (PSB)..................................................................................................... 2 X BTP ICSB 8 (PSB)..................................................................................................... 2 X BTP ICSB 11 (PSB)................................................................................................... 2 X BTP ICSB 15 (PSB)................................................................................................... 2 N/A BTP ICSB 17 (PSB)................................................................................................... 2 X BTP ICSB 18 (PSB)................................................................................................... 2  X BTP ICSB 21 (PSB)................................................................................................... 2 X BTP PSB 1................................................................................................................. 0  X    BTP PSB 2................................................................................................................. 0 X  Appendix 8B General Agenda, Station Site Visits.............................................................................. 0 X      CHAPTER 9:  AUXILIARY SYSTEMS 9.1.1 New Fuel Storage......................................................................................................... 2  X BVPS-2 UFSAR Rev. 0 7 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 9.1.2 Spent Fuel Storage....................................................................................................... 3  X 9.1.3 Spent Fuel Pool Cooling and Cleanup System............................................................. 1 X 9.1.4 Light Load Handling System (Related to Ref ueling)...................................................... 2  X BTP ASB 9-1..............................................................................................................
2  X 9.1.5 Overhead Heavy Load Handling Systems.................................................................... 0  X 9.2.1 Station Service Water System....................................................................................... 2 X 9.2.2 Reactor Auxiliary Cooling Water Systems..................................................................... 1  X 9.2.3 Demineralized Water Makeup Systems........................................................................ 2 X 9.2.4 Potable and Sanitary Water System............................................................................. 2 X 9.2.5 Ultimate Heat Sink........................................................................................................ 2 X      BTP ASB 9-2..............................................................................................................
2 X  9.2.6 Condensate Storage Facilities...................................................................................... 2 X 9.3.1 Compressed Air System................................................................................................
1 X  9.3.2 Process and Po st-Accident Sampling Systems............................................................. 2 X 9.3.3 Equipment and Floor Drainage System........................................................................ 2 X  9.3.4 Chemical and Volume Control System (PWR) (Including Boron Recovery System)......................................................................................................
2  X 9.3.5 Standby Liquid Control System (BWR)......................................................................... 2 N/A 9.4.1 Control Room Area Ventilation System......................................................................... 2  X 9.4.2 Spent Fuel Pool Area Ventilation System..................................................................... 2  X 9.4.3 Auxiliary and Radwaste Area Ventilation System.......................................................... 2  X 9.4.4 Turbine Area Ventilation System................................................................................... 2 N/A 9.4.5 Engineered Safety Feature Ventilation System.............................................................
2  X 9.5.1 Fire Protection Program................................................................................................ 3  X    BTP CMEB 9.5-1........................................................................................................ 2  X 9.5.2 Communications Systems............................................................................................. 2 X 9.5.3 Lighting Systems........................................................................................................... 2 X  9.5.4 Emergency Diesel Engine Fuel Oil Storage and Transfer System................................ 2  X 9.5.5 Emergency Diesel Engine Cooling Water System........................................................ 2 X 
 
====9.5.6 Emergenc====
y Diesel Engine Starting System................................................................... 2  X 9.5.7 Emergency Diesel Engine Lubrication System..............................................................
2 X  9.5.8 Emergency Diesel Engine Combustion Air Intake and Exhaust System....................... 2 X BVPS-2 UFSAR Rev. 0 8 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception CHAPTER 10:  STEAM AND POWER CONVERSION SYSTEM 10.2 Turbine Generator......................................................................................................... 2 X  10.2.3 Turbine Disk Integrity.................................................................................................... 1 X  10.3 Main Steam Supply System..........................................................................................
2 X  10.3.6 Steam and Feedwater Sy stem Materials....................................................................... 2 X 10.4.1 Main Condensers.......................................................................................................... 2 X  10.4.2 Main Condenser Evacuation System............................................................................ 2 X  10.4.3 Turbine Gland Sealing System...................................................................................... 2  X 10.4.4 Turbine Bypass System................................................................................................
2 X  10.4.5 Circulating Water System..............................................................................................
2 X  10.4.6 Condensate Cleanup System........................................................................................ 2  X 10.4.7 Condensate and Feedwater System............................................................................. 2  X    BTP ASB 10-2............................................................................................................ 2 X 10.4.8 Steam Generator Blowdown System (PWR)................................................................. 2  X 10.4.9 Auxiliary Feedwater System (PWR).............................................................................. 2 X BTP ASB 10-1............................................................................................................ 2 X      CHAPTER 11:  RADIOACTIVE WASTE MANAGEMENT 11.1 Source Terms................................................................................................................ 2  X 11.2 Liquid Waste Management Systems............................................................................. 2  X 11.3 Gaseous Waste Management Systems........................................................................ 2  X BTP ETSB 11-5.......................................................................................................... 0 X  11.4 Solid Waste Management Systems..............................................................................
2  X    BTP ETSB 11-3.......................................................................................................... 2 X Appendix 11.4-A................................................................................................... 0 X  11.5 Process and Effluent Radiological Monitoring Instrumentation and Sampling Systems.....................................................................................................
3  X          Appendix 11.5-A 1 X      CHAPTER 12:  RADIATION PROTECTION 12.1 Assuring That Occupational Radiation Exposures are as Low as is    Reasonably Achievable..............................................................................................
2  X 12.2 Radiatio n Sources......................................................................................................... 2 X  12.3-12.4 Radiation Protecti on Design Features........................................................................... 2  X 12.5 Operational Radiation Protection Program.................................................................... 2  X CHAPTER 13:  CONDUCT OF OPERATIONS 13.1.1 Management and Technical Support Organization....................................................... 2 X BVPS-2 UFSAR Rev. 0 9 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 1.3.1.2-    13.1.3 Operating Organization................................................................................................. 2 X  13.2.1 Reactor Operating Training........................................................................................... 0 X  13.2.2 Training for Non-Licensed Plant Staff...........................................................................
0  X 13.3 Emergency Planning..................................................................................................... 2 X  13.4 Operational Review....................................................................................................... 2  X 13.5.1 Administrati on Procedures............................................................................................ 0 X  13.5.2 Operating and Maintenance Pr ocedures....................................................................... 0 X  13.6 Physical Security........................................................................................................... 2 X      CHAPTER 14:  INITIAL TEST PROGRAM 14.1 Initial Plant Test Programs - PSAR............................................................................... 2 N/A 14.2 Initial Plant Test Programs - FSAR............................................................................... 2 X 14.3 Standard Plant Designs, Initial Test Program Final Design Approval (FDA)................. 1 N/A      CHAPTER 15:  ACCIDENT ANALYSIS 15.0 Intr oduction................................................................................................................... 2 N/A 15.1  INCREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM 15.1.1-15.1.4 Decrease in Feedwater Temperature, Increase in Feedwater Flow, Increase    in Steam Flow, and Inadvertent Opening of a Steam Generator Relief or Safety Valve...........................................................................................................
1 X  15.1.5 Steam System Piping Fail ures Inside and Outside of Containment (PWR)..................
2  X    Appendix A................................................................................................................. 2 X      15.2  DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM 15.2.1-15.2.5 Loss of External Load, Turbine Trip, Loss of Condenser Vacuum, Closure of    Main Steam Isolation Valve (BWR), and Steam Pressure Regulatory
 
Failure (Closed)..........................................................................................................
1 X  15.2.6 Loss of Nonemergency AC Power to the Station Auxiliaries......................................... 1  X 15.2.7 Loss of Normal Feedwater Flow.................................................................................... 1  X 15.2.8 Feedwater System Pipe Breaks Inside and Outside Containment (PWR)....................
1  X BVPS-2 UFSAR Rev. 0 10 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 15.3  DECREASE IN REACTOR COOLANT SYSTEM FLOW RATE 15.3.1-15.3.2 Loss of Forced Reactor Coolant Flow Including Trip of Pump and Flow Controller Malfunctions...............................................................................................
1  X  15.3.3-15.3.4 Reactor Coolant Pump Rotor Seizure and Reactor Coolant Pump Shaft Break................................................................................................................
2  X      15.4  REACTIVITY AND POWER DISTRIBUTION ANOMALIES 15.4.1 Uncontrolled Control Rod Assembly Withdrawal from a Subcritical or Low    Power Startu p Condition............................................................................................
2  X  15.4.2 Uncontrolled Control Rod Assembly Withdrawal at Power............................................
2 X  15.4.3 Control Rod Misoperation (System Malfunction or Operator Error)............................... 2 X  15.4.4-15.4.5 Startup of an Inactive Loop or Recirculation Loop at an Incorrect    Temperature, and Flow Controller Malfunction Causing an Increase in BWR Core Flow Rate.................................................................................................
1 X  15.4.6 Chemical and Volume Control System Malfunction That Results in a    Decrease in the Boro n Concentration in the R eactor Coolant (PWR)........................
1  X  15.4.7 Inadvertent Loading and Operation of a Fuel Assembly in an Improper Position...................................................................................................................... 1  X  15.4.8 Spectrum of Rod Ejecti on Accidents (PWR)................................................................. 2  X Appendix A........................................................................................................... 1 X  15.4.9 Spectrum of Rod Drop Accidents (BWR)...................................................................... 2 N/A            Appendix A........................................................................................................... 2 N/A      15.5  INCREASE IN REACTOR COOLANT INVENTORY 15.5.1-15.5.2 Inadvertent Operation of ECCS and Chemical and Volume Control System Malfunction that Increases Reactor Coolant Inventory...............................................
1  X BVPS-2 UFSAR Rev. 0 11 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception 15.6  DECREASE IN REACTOR COOLANT INVENTORY 15.6.1 Inadvertent Opening of a PWR Pressurizer Safety/Relief Valve or a BWR    Safety/Rel ief Valve.....................................................................................................
1  X 15.6.2 Radiological Consequences of the Failure of Small Lines Carrying    Primary Coolant Outside Cont ainment.......................................................................
2  X  15.6.3 Radiological Consequences of Steam Generator Tube Failure (PWR)......................... 2 X 15.6.4 Radiological Consequences of Main Steam Line Failure Outside Containment (BWR)...................................................................................................
2  N/A  15.6.5 Loss-of-Coolant Accidents Resulting from Spectrum of Postulated Piping    Breaks Within the Reactor Coolant Pressure Boundary.............................................
2  X          Appendix A........................................................................................................... 1  X          Appendix B........................................................................................................... 1  X          Appendix C........................................................................................................... 2  X          Appendix D........................................................................................................... 1  X      15.7  RADIOACTIVE RELEASE FROM A SUBSYSTEM OR COMPONENT 15.7.1 Waste Gas Syst em Failure............................................................................................ 1 X 15.7.2 Radioactive Liquid Waste System Leak or Failure (Release to Atmosphere)...............................................................................................................
1  N/A  15.7.3 Postulated Radioactive Release Due to Liquid-Containing Tank Failures.................... 2 X  15.7.4 Radiological Consequences of Fuel H andling Accidents.............................................. 1 X 15.7.5 Spent Fuel Cask Dr op Accidents.................................................................................. 2 X 15.8  ANTICIPATED TRANSIENTS WITHOUT SCRAM 15.8 Anticipated Transients Without Scram.......................................................................... 1 X Appendix.............................................................................................................. 1 X      CHAPTER 16:  TECHNICAL SPECIFICATIONS 16.0 Technical Specifications................................................................................................ 1  X      CHAPTER 17:  QUALITY ASSURANCE 17.1 Quality Assurance During the Desi gn and Constructi on Phases................................... 2 X 17.2 Quality Assurance During th e Operations Phase.......................................................... 2  X BVPS-2 UFSAR Rev. 0 12 of 12 TABLE 1.9-1 (Cont)
Rev. Conform Exception CHAPTER 18:  HUMAN FACTORS ENGINEERING 18.0 Human Factors Engineering/Standard Review Plan Development............................... 0 N/A X
 
BVPS-2 SRP Rev. 16  1 of 93 TABLE 1.9-2 SRP CONFORMANCE STATEMENTS (HISTORICAL)
SRP NO. 2.3.2
 
TITLE: LOCAL METEOROLOGY DIFFERENCES FROM THE SRP:
 
5- and 50-mile detailed topographic maps are not provided.
REMARKS:
 
During a telephone communication between S. A. Vigeant (SWEC) and J. Levine (USNRC) on January 13, 1982, the USNRC indicated that topographic cross sections are sufficient for USNRC review and detailed maps do not necessarily need to be provided.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 2 of 93 SRP NO. 2.4.11
 
TITLE: COOLING WATER SUPPLY DIFFERENCES FROM THE SRP:
 
A means of assuring that sediment accumulation is adequately controlled is not discussed in FSAR Section 2.4.11.
 
REMARKS:


BVPS-2 UFSAR Rev. 16  TABLE 1.8-1 (Cont)  91 of 91 RG No. 1.183, Rev. 0  ALTERNATIVE RADIOLOGICAL SOURCE TERMS FOR EVALUATING DESIGN BASIS ACCIDENTS AT NUCLEAR POWER REACTORS (JULY 2000)
Administrative controls assure that sediment is removed periodically.  
This regulatory guide provides assumptions, methods and acceptance criteria that are acceptable to the NRC staff for performing design basis radiological analyses using an alternate source term. With the exception of the Waste Gas System Rupture, this regulatory guide is utilized to evaluate the potential radiological consequences of all of the BVPS-2 design basis accidents. RG No. 1.194, Rev. 0  ATMOSPHERIC RELATIVE CONCENTRATIONS FOR CONTROL ROOM RADIOLOGICAL HABITABILITY ASSESSMENTS AT NUCLEAR POWER PLANTS  Control Room X/Q values were calculated using the NRC-sponsored ARCON96 computer code (NUREG/CR-6331, Revision 1, "Atmospheric Relative Concentrations in Building Wakes") and in a manner consistent with RG 1.194.
BVPS-2 UFSAR Rev. 16 1.9-1 1.9  STANDARD REVIEW PLAN CONFORMANCE EVALUATION  In accordance with 10 CFR 50.34(g), this section provided an evaluation of Beaver Valley Power Station - Unit 2 (BVPS-2) against the USNRC Standard Review Plan [NUREG-0800], dated July 1981. Therefore, this section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR. The evaluation of BVPS-2 against each Standard Review Plan (SRP) includes an identification and description of all differences in design features, analytical techniques, and procedural measures proposed for BVPS-2 and those corresponding features, techniques, and measures given in the SRP acceptance criteria. Where such a difference exists, an evaluation is provided which discusses how the proposed alternative provided an acceptable method of complying with those USNRC rules or regulations, or portions thereof, that underlie the corresponding SRP acceptance criteria. Table 1.9-1 identifies each SRP against which BVPS-2 was evaluated. For those SRPs against which exceptions were taken, SRP conformance statements, which discuss and justify such alternatives to the SRP acceptance criteria, are provided in Table 1.9-2.
BVPS-2 UFSAR  Tables for Section 1.9   


(Tables in Section 1.9 are historical)
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 3 of 93 SRP NO. 2.4.12


BVPS-2 UFSAR Rev. 16 1 of 12 TABLE 1.9-1  STANDARD REVIEW PLAN CONFORMANCE (HISTORICAL)  CHAPTER 1:  INTRODUCTION AND GENERAL DESCRIPTION OF PLANT    Rev. Conform Exception      1.8 Interfaces for Standard Design...................................................................................... 1 N/A      CHAPTER 2:  SITE CHARACTERISTICS      2.1.1 Site Location and Description................................................................................. 2 X  2.1.2 Exclusion Area Authority and Control..................................................................... 2 X  2.1.3 Population Distribution........................................................................................... 2 X  2.2.1 - 2.2.2 Identification of Potential Hazards in Site Vicinity................................................... 2 X  2.2.3 Evaluation of Potential Accidents........................................................................... 2 X  2.3.1 Regional Climatology............................................................................................. 2 X  2.3.2 Local Meteorology.................................................................................................. 2  X 2.3.3 Onsite Meteorological Measurements Programs................................................... 2 X            Appendix A.................................................................................................... 2 X  2.3.4 Short-Term Diffusion Estimates............................................................................. 1 X  2.3.5 Long-Term Diffusion Estimates.............................................................................. 2 X  2.4.1 Hydrologic Description........................................................................................... 2 X            Appendix A.................................................................................................... 2 X  2.4.2 Floods.................................................................................................................... 2 X  2.4.3 Probable Maximum Flood (PMF) on Streams and Rivers...................................... 2 X  2.4.4 Potential Dam Failures (Seismically-Induced)........................................................ 2 X  2.4.5 Probable Maximum Surge and Seiche Flooding.................................................... 2 X  2.4.6 Probable Maximum Tsunami Flooding................................................................... 2 X  2.4.7 Ice Effects.............................................................................................................. 2 X  2.4.8 Cooling Water Canals and Reservoirs................................................................... 2 X  2.4.9 Channel Diversions................................................................................................ 2 X  2.4.10 Flood Protection Requirements.............................................................................. 2 X  2.4.11 Cooling Water Supply............................................................................................ 2  X 2.4.12 Ground Water......................................................................................................... BTP HGEB 1....................................................................................................... 2 2  X X 2.4.13 Accidental Releases of Liquid Effluents in Ground and Surface Waters................ 2  X 2.4.14 Technical Specifications and Emergency Operation Requirements....................... 2 X  2.5.1 Basic Geologic and Seismic Information................................................................ 2  X 2.5.2 Vibratory Ground Motion........................................................................................ 1  X 2.5.3 Surface Faulting..................................................................................................... 2 X BVPS-2 UFSAR Rev. 0 2 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      2.5.4 Stability of Subsurface Materials and Foundations....................................................... 2  X 2.5.5 Stability of Slopes.......................................................................................................... 2 X  CHAPTER 3:  DESIGN OF STRUCTURES, COMPONENTS, EQUIPMENT, AND SYSTEMS      3.2.1 Seismic Classification................................................................................................... 1 X  3.2.2 System Quality Group Classification............................................................................. 1  X          Appendix A (formerly BTP RSB 3-1).................................................................... 1 X            Appendix B (formerly BTP RSB 3-2).................................................................... 1 X            Appendix C .......................................................................................................... 0 X            Appendix D........................................................................................................... 0 X  3.3.1 Wind Loadings.............................................................................................................. 2  X 3.3.2 Tornado Loadings......................................................................................................... 2 X  3.4.1 Flood Protection............................................................................................................ 2 X  3.4.2 Analysis Procedures..................................................................................................... 1 X  3.5.1.1 Internally Generated Missiles (Outside Containment)................................................... 2 X  3.5.1.2 Internally Generated Missiles (Inside Containment)...................................................... 2 X  3.5.1.3 Turbine Missiles............................................................................................................ 2  X 3.5.1.4 Missiles Generated by Natural Phenomena.................................................................. 2 X      BTP AAB 3-2.............................................................................................................. 1 X      BTP ASB 3-2.............................................................................................................. 2 X  3.5.1.5 Site Proximity Missiles (Except Aircraft)........................................................................ 1 X  3.5.1.6 Aircraft Hazards............................................................................................................ 1 X  3.5.2 Structures, Systems, and Components to be Protected from    Externally Generated Missiles.................................................................................... 2  X  3.5.3 Barrier Design Procedures............................................................................................ 1 X      Appendix A................................................................................................................. 0 X  3.6.1 Plant Design for Protection Against Postulated Piping Failures in Fluid    Systems Outside Containment................................................................................... 1  X    BTP ASB 3-1.............................................................................................................. 1  X 3.6.2 Determination of Rupture Locations and Dynamic Effects Associated    with the Postulated Rupture of Piping........................................................................ 1  X    BTP MEB 3-1............................................................................................................. 1  X 3.7.1 Seismic Design Parameters.......................................................................................... 1  X 3.7.2 Seismic System Analysis.............................................................................................. 1  X 3.7.3 Seismic Subsystem Analysis......................................................................................... 1  X 3.7.4 Seismic Instrumentation................................................................................................ 1 X BVPS-2 UFSAR Rev. 0 3 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      3.8.1 Concrete Containment.................................................................................................. 1  X 3.8.2 Steel Containment......................................................................................................... 1  X 3.8.3 Concrete and Steel Internal Structures of Steel or Concrete Containments................. 1  X 3.8.4 Other Seismic Category I Structures............................................................................. 1  X 3.8.5 Foundations.................................................................................................................. 1  X 3.9.1 Special Topics for Mechanical Components................................................................. 2  X 3.9.2 Dynamic Testing and Analysis of Systems, Components, and Equipment................... 2  X 3.9.3 ASME Code Class 1, 2 and 3 Components, Component Supports, and    Core Support Structures............................................................................................. 1  X          Appendix A........................................................................................................... 0  X 3.9.4 Control Rod Drive Systems........................................................................................... 1 X  3.9.6 Inservice Testing of Pumps and Valves........................................................................ 2 X  3.10 Seismic Qualification of Category I Instrumentation and Electrical Equipment............. 2  X 3.11 Environmental Design of Mechanical and Electrical Equipment.................................... 2  X      CHAPTER 4:  REACTOR      4.2 Fuel System Design...................................................................................................... 2 X  4.3 Nuclear Design.............................................................................................................. 2 X      BTP CPB 4.3-1........................................................................................................... 2 X  4.4 Thermal and Hydraulic Design...................................................................................... 1 X            Appendix.............................................................................................................. 1 X  4.5.1 Control Rod Drive Structural Materials.......................................................................... 2  X 4.5.2 Reactor Internal and Core Support Materials................................................................ 2  X 4.6 Functional Design of Control Rod Drive System........................................................... 1 X      CHAPTER 5:  REACTOR COOLANT SYSTEM AND CONNECTED SYSTEMS      5.2.1.1 Compliance with Codes and Standard Rule 10 CFR 50.55a......................................... 2  X 5.2.1.2 Applicable Codes Cases............................................................................................... 2  X 5.2.2 Overpressure Protection............................................................................................... 1  X    BTP RSB 5-2.............................................................................................................. 0 X  5.2.3 Reactor Coolant Pressure Boundary Materials............................................................. 2  X    BTP MTEB 5-7........................................................................................................... 2 X BVPS-2 UFSAR Rev. 0 4 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      5.2.4 Reactor Coolant Pressure Boundary Inservice Inspection and Testing........................ 1 X  5.2.5 Reactor Coolant Pressure Boundary Leakage Detection.............................................. 1  X 5.3.1 Reactor Vessel Materials.............................................................................................. 1  X 5.3.2 Pressure-Temperature Limits........................................................................................ 1 X      BTP MTEB 5-2........................................................................................................... 1 X  5.3.3 Reactor Vessel Integrity................................................................................................ 1 X  5.4 Preface.......................................................................................................................... 1 X  5.4.1.1 Pump Flywheel Integrity (PWR).................................................................................... 1  X 5.4.2.1 Steam Generator Materials........................................................................................... 2  X    BTP MTEB 5-3........................................................................................................... 2 X  5.4.2.2 Steam Generator Tube Inservice Inspection................................................................. 1 X  5.4.6 Reactor Core Isolation Cooling System (BWR)............................................................. 2 N/A  5.4.7 Residual Heat Removal (RHR) System........................................................................ 2  X    BTP RSB 5-1.............................................................................................................. 2 X  5.4.8 Reactor Water Cleanup System (BWR)........................................................................ 2 N/A  5.4.11 Pressurizer Relief Tank................................................................................................. 2 X  5.4.12 Reactor Coolant System High Point Vents.................................................................... 0  X      CHAPTER 6:  ENGINEERED SAFETY FEATURES      6.1.1 Engineered Safety Features Materials.......................................................................... 2  X    BTP MTEB 6-1........................................................................................................... 2 X  6.1.2 Protective Coating Systems (Paints) - Organic Materials.............................................. 2 X  6.2.1 Containment Functional Design.................................................................................... 2 X  6.2.1.1A PWR Dry Containments, Including Sub-atmospheric Containments............................. 2  X 6.2.1.1B Ice Condenser Containments........................................................................................ 2 N/A  6.2.1.1C Pressure-Suppression Type BWR Containments......................................................... 4 N/A            Appendix I............................................................................................................ 1 N/A  6.2.1.2 Subcompartment Analysis............................................................................................. 2 X  6.2.1.3 Mass and Energy Release Analysis for Postulated Loss-of-Coolant Accidents 1  X 6.2.1.4 Mass and Energy Release Analysis for Postulated Secondary System    Pipe Ruptures............................................................................................................ 1  X BVPS-2 UFSAR Rev. 0 5 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      6.2.1.5 Minimum Containment Pressure Analysis for Emergency Core Cooling    System Performance Capability Studies.................................................................... 2  X    BTP CSB 6-1.............................................................................................................. 2  X 6.2.2 Containment Heat Removal Systems........................................................................... 3 X  6.2.3 Secondary Containment Functional Design.................................................................. 2 X      BTP CSB 6-3.............................................................................................................. 2 X  6.2.4 Containment Isolation System....................................................................................... 2  X    BTP CSB 6-4.............................................................................................................. 2 X  6.2.5 Combustible Gas Control in Containment..................................................................... 2 X            Appendix A........................................................................................................... 2 X  6.2.6 Containment Leakage Testing...................................................................................... 2 X  6.2.7 Fracture Prevention of Containment Pressure Boundary.............................................. 5  6.3 Emergency Core Cooling System................................................................................. 1  X    BTP RSB 6-1.............................................................................................................. 1  X 6.4 Control Room Habitability Systems............................................................................... 2  X          Appendix A........................................................................................................... 2  X 6.5.1 ESF Atmosphere Cleanup Systems.............................................................................. 2  X 6.5.2 Containment Spray as a Fission Product Cleanup System........................................... 1 X  6.5.3 Fission Product Control Systems and Structures.......................................................... 2 X  6.5.4 Ice Condenser as a Fission Product Cleanup System.................................................. 2 X  6.6 Inservice Inspection of Class 2 and 3 Components...................................................... 1 X  6.7 Main Steam Isolation Valve Leakage Control System (BWR)....................................... 2 N/A      CHAPTER 7:  INSTRUMENTATION AND CONTROLS      7.1 Instrumentation and Controls - Introduction.................................................................. 2 X            Table 7-1 Acceptance Criteria and Guidelines for Instrumentation and          Controls Systems Important to Safety.................................................................. 2  X  7.2 Reactor Trip System..................................................................................................... 2  X          Appendix A........................................................................................................... 2 X  7.3 Engineered Safety Features Systems........................................................................... 2  X          Appendix A........................................................................................................... 2 X  7.4 Safe Shutdown Systems............................................................................................... 2  X 7.5 Information Systems Important to Safety...................................................................... 2  X BVPS-2 UFSAR Rev. 0 6 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      7.6 Interlock Systems Important to Safety........................................................................... 2  X 7.7 Control Systems............................................................................................................ 2 X  Appendix 7A Branch Technical Positions (ICSB)............................................................................... 2 X      BTP ICSB 1 (DOR).................................................................................................... 2 X      BTP ICSB 3................................................................................................................ 2 X      BTP ICSB 4 (PSB)..................................................................................................... 2 X      BTP ICSB 5................................................................................................................ 2 X      BTP ICSB 9................................................................................................................ 2 X      BTP ICSB 12.............................................................................................................. 2 X      BTP ICSB 13.............................................................................................................. 2 X      BTP ICSB 14.............................................................................................................. 2 X      BTP ICSB 16.............................................................................................................. 2 X      BTP ICSB 19.............................................................................................................. 2 X      BTP ICSB 20.............................................................................................................. 2 X      BTP ICSB 21.............................................................................................................. 2 X      BTP ICSB 22.............................................................................................................. 2 X      BTP ICSB 25.............................................................................................................. 2 X      BTP ICSB 26.............................................................................................................. 2 X  Appendix 7B General Agenda, Station Site Visits.............................................................................. 1 X      CHAPTER 8:  ELECTRIC POWER 8.1 Electric Power - Introduction......................................................................................... 2 X            Table 8-1 Acceptance Criteria and Guidelines for Electric          Power Systems.................................................................................................... 2  X  8.2 Offsite Power System.................................................................................................... 2 X  8.3.1 AC Power Systems (Onsite).......................................................................................... 2 X  8.3.2 DC Power Systems (Onsite)......................................................................................... 2 X  Appendix 8A Branch Technical Positions (PSB)................................................................................ 2  X    BTP ICSB 2 (PSB)..................................................................................................... 2 X      BTP ICSB 4 (PSB)..................................................................................................... 2 X      BTP ICSB 8 (PSB)..................................................................................................... 2 X      BTP ICSB 11 (PSB)................................................................................................... 2 X      BTP ICSB 15 (PSB)................................................................................................... 2 N/A      BTP ICSB 17 (PSB)................................................................................................... 2 X      BTP ICSB 18 (PSB)................................................................................................... 2  X    BTP ICSB 21 (PSB)................................................................................................... 2 X      BTP PSB 1................................................................................................................. 0  X    BTP PSB 2................................................................................................................. 0 X  Appendix 8B General Agenda, Station Site Visits.............................................................................. 0 X      CHAPTER 9:  AUXILIARY SYSTEMS 9.1.1 New Fuel Storage......................................................................................................... 2  X BVPS-2 UFSAR Rev. 0 7 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      9.1.2 Spent Fuel Storage....................................................................................................... 3  X 9.1.3 Spent Fuel Pool Cooling and Cleanup System............................................................. 1 X  9.1.4 Light Load Handling System (Related to Refueling)...................................................... 2  X    BTP ASB 9-1.............................................................................................................. 2  X 9.1.5 Overhead Heavy Load Handling Systems.................................................................... 0  X 9.2.1 Station Service Water System....................................................................................... 2 X  9.2.2 Reactor Auxiliary Cooling Water Systems..................................................................... 1  X 9.2.3 Demineralized Water Makeup Systems........................................................................ 2 X  9.2.4 Potable and Sanitary Water System............................................................................. 2 X  9.2.5 Ultimate Heat Sink........................................................................................................ 2 X      BTP ASB 9-2.............................................................................................................. 2 X  9.2.6 Condensate Storage Facilities...................................................................................... 2 X  9.3.1 Compressed Air System................................................................................................ 1 X  9.3.2 Process and Post-Accident Sampling Systems............................................................. 2 X  9.3.3 Equipment and Floor Drainage System........................................................................ 2 X  9.3.4 Chemical and Volume Control System (PWR) (Including Boron    Recovery System)...................................................................................................... 2  X 9.3.5 Standby Liquid Control System (BWR)......................................................................... 2 N/A  9.4.1 Control Room Area Ventilation System......................................................................... 2  X 9.4.2 Spent Fuel Pool Area Ventilation System..................................................................... 2  X 9.4.3 Auxiliary and Radwaste Area Ventilation System.......................................................... 2  X 9.4.4 Turbine Area Ventilation System................................................................................... 2 N/A  9.4.5 Engineered Safety Feature Ventilation System............................................................. 2  X 9.5.1 Fire Protection Program................................................................................................ 3  X    BTP CMEB 9.5-1........................................................................................................ 2  X 9.5.2 Communications Systems............................................................................................. 2 X  9.5.3 Lighting Systems........................................................................................................... 2 X  9.5.4 Emergency Diesel Engine Fuel Oil Storage and Transfer System................................ 2  X 9.5.5 Emergency Diesel Engine Cooling Water System........................................................ 2 X  9.5.6 Emergency Diesel Engine Starting System................................................................... 2  X 9.5.7 Emergency Diesel Engine Lubrication System.............................................................. 2 X  9.5.8 Emergency Diesel Engine Combustion Air Intake and Exhaust System....................... 2 X BVPS-2 UFSAR Rev. 0 8 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      CHAPTER 10:  STEAM AND POWER CONVERSION SYSTEM      10.2 Turbine Generator......................................................................................................... 2 X  10.2.3 Turbine Disk Integrity.................................................................................................... 1 X  10.3 Main Steam Supply System.......................................................................................... 2 X  10.3.6 Steam and Feedwater System Materials....................................................................... 2 X  10.4.1 Main Condensers.......................................................................................................... 2 X  10.4.2 Main Condenser Evacuation System............................................................................ 2 X  10.4.3 Turbine Gland Sealing System...................................................................................... 2  X 10.4.4 Turbine Bypass System................................................................................................ 2 X  10.4.5 Circulating Water System.............................................................................................. 2 X  10.4.6 Condensate Cleanup System........................................................................................ 2  X 10.4.7 Condensate and Feedwater System............................................................................. 2  X    BTP ASB 10-2............................................................................................................ 2  X 10.4.8 Steam Generator Blowdown System (PWR)................................................................. 2  X 10.4.9 Auxiliary Feedwater System (PWR).............................................................................. 2 X      BTP ASB 10-1............................................................................................................ 2 X      CHAPTER 11:  RADIOACTIVE WASTE MANAGEMENT      11.1 Source Terms................................................................................................................ 2  X 11.2 Liquid Waste Management Systems............................................................................. 2  X 11.3 Gaseous Waste Management Systems........................................................................ 2  X    BTP ETSB 11-5.......................................................................................................... 0 X  11.4 Solid Waste Management Systems.............................................................................. 2  X    BTP ETSB 11-3.......................................................................................................... 2 X            Appendix 11.4-A................................................................................................... 0 X  11.5 Process and Effluent Radiological Monitoring Instrumentation and    Sampling Systems..................................................................................................... 3  X          Appendix 11.5-A 1 X      CHAPTER 12:  RADIATION PROTECTION      12.1 Assuring That Occupational Radiation Exposures are as Low as is    Reasonably Achievable.............................................................................................. 2  X 12.2 Radiation Sources......................................................................................................... 2 X  12.3-12.4 Radiation Protection Design Features........................................................................... 2  X 12.5 Operational Radiation Protection Program.................................................................... 2  X      CHAPTER 13:  CONDUCT OF OPERATIONS      13.1.1 Management and Technical Support Organization....................................................... 2 X BVPS-2 UFSAR Rev. 0 9 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      1.3.1.2-    13.1.3 Operating Organization................................................................................................. 2 X  13.2.1 Reactor Operating Training........................................................................................... 0 X  13.2.2 Training for Non-Licensed Plant Staff........................................................................... 0  X 13.3 Emergency Planning..................................................................................................... 2 X  13.4 Operational Review....................................................................................................... 2  X 13.5.1 Administration Procedures............................................................................................ 0 X  13.5.2 Operating and Maintenance Procedures....................................................................... 0 X  13.6 Physical Security........................................................................................................... 2 X      CHAPTER 14:  INITIAL TEST PROGRAM      14.1 Initial Plant Test Programs - PSAR............................................................................... 2 N/A  14.2 Initial Plant Test Programs - FSAR............................................................................... 2 X  14.3 Standard Plant Designs, Initial Test Program Final Design Approval (FDA)................. 1 N/A      CHAPTER 15:  ACCIDENT ANALYSIS      15.0 Introduction................................................................................................................... 2 N/A            15.1  INCREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM      15.1.1-15.1.4 Decrease in Feedwater Temperature, Increase in Feedwater Flow, Increase    in Steam Flow, and Inadvertent Opening of a Steam Generator Relief    or Safety Valve........................................................................................................... 1 X  15.1.5 Steam System Piping Failures Inside and Outside of Containment (PWR).................. 2  X    Appendix A................................................................................................................. 2 X      15.2  DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM      15.2.1-15.2.5 Loss of External Load, Turbine Trip, Loss of Condenser Vacuum, Closure of    Main Steam Isolation Valve (BWR), and Steam Pressure Regulatory Failure (Closed).......................................................................................................... 1 X  15.2.6 Loss of Nonemergency AC Power to the Station Auxiliaries......................................... 1  X 15.2.7 Loss of Normal Feedwater Flow.................................................................................... 1  X 15.2.8 Feedwater System Pipe Breaks Inside and Outside Containment (PWR).................... 1  X BVPS-2 UFSAR Rev. 0 10 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      15.3  DECREASE IN REACTOR COOLANT SYSTEM FLOW RATE      15.3.1-15.3.2 Loss of Forced Reactor Coolant Flow Including Trip of Pump and Flow    Controller Malfunctions............................................................................................... 1  X  15.3.3-15.3.4 Reactor Coolant Pump Rotor Seizure and Reactor Coolant Pump    Shaft Break................................................................................................................ 2  X      15.4  REACTIVITY AND POWER DISTRIBUTION ANOMALIES      15.4.1 Uncontrolled Control Rod Assembly Withdrawal from a Subcritical or Low    Power Startup Condition............................................................................................ 2  X  15.4.2 Uncontrolled Control Rod Assembly Withdrawal at Power............................................ 2 X  15.4.3 Control Rod Misoperation (System Malfunction or Operator Error)............................... 2 X  15.4.4-15.4.5 Startup of an Inactive Loop or Recirculation Loop at an Incorrect    Temperature, and Flow Controller Malfunction Causing an Increase in    BWR Core Flow Rate................................................................................................. 1 X  15.4.6 Chemical and Volume Control System Malfunction That Results in a    Decrease in the Boron Concentration in the Reactor Coolant (PWR)........................ 1  X  15.4.7 Inadvertent Loading and Operation of a Fuel Assembly in an Improper    Position...................................................................................................................... 1  X  15.4.8 Spectrum of Rod Ejection Accidents (PWR)................................................................. 2  X          Appendix A........................................................................................................... 1 X  15.4.9 Spectrum of Rod Drop Accidents (BWR)...................................................................... 2 N/A            Appendix A........................................................................................................... 2 N/A      15.5  INCREASE IN REACTOR COOLANT INVENTORY      15.5.1-15.5.2 Inadvertent Operation of ECCS and Chemical and Volume Control System    Malfunction that Increases Reactor Coolant Inventory............................................... 1  X BVPS-2 UFSAR Rev. 0 11 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      15.6  DECREASE IN REACTOR COOLANT INVENTORY      15.6.1 Inadvertent Opening of a PWR Pressurizer Safety/Relief Valve or a BWR    Safety/Relief Valve..................................................................................................... 1  X 15.6.2 Radiological Consequences of the Failure of Small Lines Carrying    Primary Coolant Outside Containment....................................................................... 2  X  15.6.3 Radiological Consequences of Steam Generator Tube Failure (PWR)......................... 2 X  15.6.4 Radiological Consequences of Main Steam Line Failure Outside    Containment (BWR)................................................................................................... 2  N/A  15.6.5 Loss-of-Coolant Accidents Resulting from Spectrum of Postulated Piping    Breaks Within the Reactor Coolant Pressure Boundary............................................. 2  X          Appendix A........................................................................................................... 1  X          Appendix B........................................................................................................... 1  X          Appendix C........................................................................................................... 2  X          Appendix D........................................................................................................... 1  X      15.7  RADIOACTIVE RELEASE FROM A SUBSYSTEM OR COMPONENT      15.7.1 Waste Gas System Failure............................................................................................ 1 X  15.7.2 Radioactive Liquid Waste System Leak or Failure (Release to    Atmosphere)............................................................................................................... 1  N/A  15.7.3 Postulated Radioactive Release Due to Liquid-Containing Tank Failures.................... 2 X  15.7.4 Radiological Consequences of Fuel Handling Accidents.............................................. 1 X  15.7.5 Spent Fuel Cask Drop Accidents.................................................................................. 2 X      15.8  ANTICIPATED TRANSIENTS WITHOUT SCRAM      15.8 Anticipated Transients Without Scram.......................................................................... 1 X            Appendix.............................................................................................................. 1 X      CHAPTER 16:  TECHNICAL SPECIFICATIONS      16.0 Technical Specifications................................................................................................ 1  X      CHAPTER 17:  QUALITY ASSURANCE      17.1 Quality Assurance During the Design and Construction Phases................................... 2 X  17.2 Quality Assurance During the Operations Phase.......................................................... 2  X BVPS-2 UFSAR Rev. 0 12 of 12 TABLE 1.9-1 (Cont)    Rev. Conform Exception      CHAPTER 18:  HUMAN FACTORS ENGINEERING      18.0 Human Factors Engineering/Standard Review Plan Development............................... 0 N/A X BVPS-2 SRP Rev. 16  1 of 93 TABLE 1.9-2 SRP CONFORMANCE STATEMENTS (HISTORICAL)  SRP NO. 2.3.2 TITLE: LOCAL METEOROLOGY DIFFERENCES FROM THE SRP:
TITLE: GROUND WATER DIFFERENCES FROM THE SRP:  
5- and 50-mile detailed topographic maps are not provided. REMARKS:
During a telephone communication between S. A. Vigeant (SWEC) and J. Levine (USNRC) on January 13, 1982, the USNRC indicated that topographic cross sections are sufficient for USNRC review and detailed maps do not necessarily need to be provided.
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  2 of 93 SRP NO. 2.4.11


TITLE: COOLING WATER SUPPLY  DIFFERENCES FROM THE SRP:
The information requested by SRP 2.4.12 is provided in FSAR Section 2.4.13. A discussion of accident effects on ground
A means of assuring that sediment accumulation is adequately controlled is not discussed in FSAR Section 2.4.11.
 
REMARKS:
water is also provided.
Administrative controls assure that sediment is removed periodically.
REMARKS:
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  3 of 93 SRP NO. 2.4.12


TITLE: GROUND WATER  DIFFERENCES FROM THE SRP:
The information requested by SRP 2.4.12 is provided in FSAR Section 2.4.13. A discussion of accident effects on ground water is also provided. REMARKS:
The discussion of ground water presented in FSAR Section 2.4.13 is in accordance with the content requirements of Regulatory Guide 1.70, Rev. 3. The discussion of ground water in FSAR Section 2.4.13 is in full conformance with SRPs 2.4.12 and 2.4.13.  
The discussion of ground water presented in FSAR Section 2.4.13 is in accordance with the content requirements of Regulatory Guide 1.70, Rev. 3. The discussion of ground water in FSAR Section 2.4.13 is in full conformance with SRPs 2.4.12 and 2.4.13.  


BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)   4 of 93 SRP NO. 2.4.13  
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 4 of 93 SRP NO. 2.4.13  
 
TITLE: ACCIDENTAL RELEASES OF LIQUID EFFLUENTS IN GROUND AND SURFACE WATERS
 
DIFFERENCES FROM THE SRP:
The information requested by SRP 2.4.13 on dilution and travel times of accidental releases in surface waters is provided in FSAR Section 2.4.12.
 
REMARKS:
The discussion of accidental releases of liquid effluents in ground and surface waters is in accordance with the content requirements of Regulatory Guide 1.70, Rev. 3. The discussions of accidental releases to ground water in FSAR Section 2.4.13 and accidental releases to surface water in FSAR Section 2.4.12 are in full conformance with SRP 2.4.13.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 5 of 93 SRP NO. 2.5.1


TITLE: ACCIDENTAL RELEASES OF LIQUID EFFLUENTS IN GROUND AND SURFACE WATERS DIFFERENCES FROM THE SRP: The information requested by SRP 2.4.13 on dilution and travel times of accidental releases in surface waters is provided in FSAR Section 2.4.12.
TITLE: BASIC GEOLOGIC AND SEISMIC INFORMATION DIFFERENCES FROM THE SRP:  
REMARKS:  The discussion of accidental releases of liquid effluents in ground and surface waters is in accordance with the content requirements of Regulatory Guide 1.70, Rev. 3. The discussions of accidental releases to ground water in FSAR Section 2.4.13 and accidental releases to surface water in FSAR Section 2.4.12 are in full conformance with SRP 2.4.13.
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  5 of 93 SRP NO. 2.5.1


TITLE: BASIC GEOLOGIC AND SEISMIC INFORMATION  DIFFERENCES FROM THE SRP:
Gravity and aeromagnetic maps are not provided.  
Gravity and aeromagnetic maps are not provided.
REMARKS:  At the present time a gravity map of Pennsylvania that includes the site region is not available. Aeromagnetic maps are available but show only broad regional trends which provide no additional site-specific information.
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  6 of 93 SRP NO. 2.5.2


TITLE: VIBRATORY GROUND MOTION  DIFFERENCES FROM THE SRP:
SRP 2.5.2 suggests that a calculation to determine the probability of exceeding the accelerating level of the OBE during the life of the plant may be helpful. Regulatory Guide 1.70 requires the calculation. This determination is not provided.
REMARKS:
REMARKS:
A determination of the probability of exceeding the OBE during the operating life of the plant was not considered necessary because the OBE acceleration level was taken as one-half the SSE in accordance with Appendix A to 10 CFR 100.
At the present time a gravity map of Pennsylvania that includes
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)   7 of 93 SRP NO. 2.5.4  
 
the site region is not available.
Aeromagnetic maps are available but show only broad regional
 
trends which provide no additional site-specific information.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 6 of 93 SRP NO. 2.5.2
 
TITLE: VIBRATORY GROUND MOTION DIFFERENCES FROM THE SRP:
 
SRP 2.5.2 suggests that a calculation to determine the probability of exceeding the accelerating level of the OBE during the life of the plant may be helpful. Regulatory Guide 1.70 requires the calculation. This determination is not provided.
 
REMARKS:
 
A determination of the probability of exceeding the OBE during the operating life of the plant was not considered necessary because the OBE acceleration level was taken as one-half the SSE  
 
in accordance with Appendix A to 10 CFR 100.  
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 7 of 93 SRP NO. 2.5.4  
 
TITLE: STABILITY OF SUBSURFACE MATERIALS AND FOUNDATIONS DIFFERENCES FROM THE SRP:
 
The SRP suggests that static and dynamic properties of in situ and backfill materials be supported by laboratory test data.
 
Laboratory testing was  not performed on samples of the in situ sands and gravels within the main plant area since it was not possible to obtain undisturbed samples from the boring investigations due to the gravel content of the soils.
 
Grain size analyses, in-place density tests, and compaction tests were performed on compacted backfill material as part of the site quality assurance program. However, laboratory
 
determinations of engineering strength properties were not made.
REMARKS:
 
Since suitable undisturbed soil samples could not be obtained, the static and dynamic properties of the in situ sands and gravels at the site were determined from accepted, conservative empirical correlations of engineering properties to subsurface conditions determined by test borings, geophysical testing,  and
 
field testing. For instance, shear modulus was evaluated by the equation presented by Hardin and Drenevich (1972) and was compared with that computed from in situ measurements of shear
 
wave velocity. The permeability of the in situ sands was determined from field permeability tests. Soil unit weights were evaluated from the results of in-place density tests made at the foundation level of the reactor containment. The friction angle was based upon correlations with relative density determined from standard penetration test blow count data
 
obtained from test borings. The susceptibility of the soils at the site was based upon the observed behavior of similar sites during previous earthquakes (DLC 1976) and by using test data from dynamic laboratory tests performed to be more susceptible to liquefaction than the soils at the site (DLC 1972).


TITLE: STABILITY OF SUBSURFACE MATERIALS AND FOUNDATIONS  DIFFERENCES FROM THE SRP:
The SRP suggests that static and dynamic properties of in situ and backfill materials be supported by laboratory test data.
Laboratory testing was  not performed on samples of the in situ sands and gravels within the main plant area since it was not possible to obtain undisturbed samples from the boring investigations due to the gravel content of the soils.
Grain size analyses, in-place density tests, and compaction tests were performed on compacted backfill material as part of the site quality assurance program. However, laboratory determinations of engineering strength properties were not made. REMARKS:
Since suitable undisturbed soil samples could not be obtained, the static and dynamic properties of the in situ sands and gravels at the site were determined from accepted, conservative empirical correlations of engineering properties to subsurface conditions determined by test borings, geophysical testing,  and field testing. For instance, shear modulus was evaluated by the equation presented by Hardin and Drenevich (1972) and was compared with that computed from in situ measurements of shear wave velocity. The permeability of the in situ sands was determined from field permeability tests. Soil unit weights were evaluated from the results of in-place density tests made at the foundation level of the reactor containment. The friction angle was based upon correlations with relative density determined from standard penetration test blow count data obtained from test borings. The susceptibility of the soils at the site was based upon the observed behavior of similar sites during previous earthquakes (DLC 1976) and by using test data from dynamic laboratory tests performed to be more susceptible to liquefaction than the soils at the site (DLC 1972).
Similar methods were used to evaluate the engineering properties of the material used for compacted structural or select granular fill.
Similar methods were used to evaluate the engineering properties of the material used for compacted structural or select granular fill.
Liquefaction analyses are generally performed with the ground-water level assumed coincident with that corresponding to the 25-year flood, which for BVPS-2 is at el 690. With the exception of an area beneath the reactor containment (FSAR Figure 2.5.4-19), structural or select granular fill was placed above el 690 and as such would not be subject to liquefaction. Consequently, tests to evaluate its susceptibility to liquefaction were not performed.  
Liquefaction analyses are generally performed with the ground-water level assumed coincident with that corresponding to the 25-year flood, which for BVPS-2 is at el 690. With the exception of an area beneath the reactor containment (FSAR Figure 2.5.4-19), structural or select granular fill was placed above el 690 and as such would not be subject to liquefaction. Consequently, tests to evaluate its susceptibility to liquefaction were not performed.  


BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)   8 of 93  
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 8 of 93  


==REFERENCES:==
==REFERENCES:==


Duquesne Light Company (DLC) 1972. Preliminary Safety Analysis Report - Beaver Valley Power Station - Unit 2, Section 2.6.5.2. Prepared by SWEC, Boston, Mass.
Duquesne Light Company (DLC) 1972. Preliminary Safety Analysis Report - Beaver Valley Power Station - Unit 2, Section 2.6.5.2.
Duquesne Light Company (DLC) 1976. Report on  the Soil Densification Program - Beaver Valley Power Station - Unit 2.
Prepared by SWEC, Boston, Mass.  
Harding, B.O. and Drenevich, V.P. 1972. Shear Modulus and Damping in Soils, Design Equations. Journal of Soil Mechanics and Foundation Division, Vol. 98, SM-7. ASCE.
 
BVPS-2 SRP Rev. 18  TABLE 1.9-2 (Cont) 9 of 93 SRP NO. 3.2.2  
Duquesne Light Company (DLC) 1976. Report on  the Soil Densification Program - Beaver Valley Power Station - Unit 2.  
 
Harding, B.O. and Drenevich, V.P. 1972. Shear Modulus and Damping in Soils, Design Equations. Journal of Soil Mechanics  
 
and Foundation Division, Vol. 98, SM-7. ASCE.  
 
BVPS-2 SRP Rev. 18  TABLE 1.9-2 (Cont)  
 
9 of 93 SRP NO. 3.2.2  


TITLE: SYSTEM QUALITY GROUP CLASSIFICATION  
TITLE: SYSTEM QUALITY GROUP CLASSIFICATION  
Line 1,201: Line 5,080:
DIFFERENCES FROM THE SRP:  
DIFFERENCES FROM THE SRP:  


BVPS-2 uses the safety classification system provided in ANSI N18.2 as an acceptable alternative to the Regulatory Guide 1.26 quality group classification system. FSAR Section 3.2.2 provides a cross reference between the ANS safety classifications end the quality groups defined in Regulatory Guide 1.26.
BVPS-2 uses the safety classification system provided in ANSI N18.2 as an acceptable alternative to the Regulatory Guide 1.26 quality group classification system. FSAR Section 3.2.2 provides a cross reference between the ANS safety classifications end the quality groups defined in Regulatory  


Guide 1.26.
REMARKS:
The ANS classification system implemented for BVPS-2 has been
endorsed by industry as an alternative accepted by the USNRC for many other plants and meets the requirements of GDC 1 and 10 CFR
50.55a.
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 10 of 93 SRP NO. 3.3.1
TITLE: WIND LOADINGS DIFFERENCES FROM THE SRP:
ANSI A58.1, "Building Code Requirements for Minimum Design Loads in Buildings and Other Structures," was not used as a basis for
developing wind loads.
REMARKS:  
REMARKS:  


The ANS classification system implemented for BVPS-2 has been endorsed by industry as an alternative accepted by the USNRC for many other plants and meets the requirements of GDC 1 and 10 CFR 50.55a.  
ASCE Paper No. 3269, "Wind Force on Structures," was used as a basis for developing wind loads; this provides sufficient
 
guidance for satisfying the requirements of GDC 2.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 11 of 93 SRP NO. 3.5.1.3
 
TITLE: TURBINE MISSILES DIFFERENCES FROM THE SRP:
 
Acceptance Criterion II.1 does not apply to the BVPS-2 plant design arrangement. However, protection against low-trajectory
 
turbine missiles at Beaver Valley Power Station - Unit 2 (BVPS-2) does meet the overall risk acceptance guidelines recommended by this SRP.
 
REMARKS:
 
The latest technical advances in the design and analysis of Westinghouse low-pressure turbine rotors is used to provide assurance of turbine disc integrity. Improved disc integrity,
 
overspeed protection, and a comprehensive inspection program provides sufficient missile protection to meet the overall risk acceptance guidelines and maintain acceptably low probabilities.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 12 of 93 SRP NO. 3.6.1
 
TITLE: PLANT DESIGN FOR PROTECTION AGAINST POSTULATED PIPING FAILURES IN FLUID SYSTEMS OUTSIDE CONTAINMENT
 
DIFFERENCES FROM THE SRP (BRANCH TECHNICAL POSITION ASB 3-l):
: 1. BTP ASB-1, paragraph B.1.a(l) suggests that essential equipment be separated from the main steam and feedwater piping and be protected from the effects of a one square foot break of these lines, even though these lines are designed to the "break exclusion" criteria of MEB 3-1. BVPS-2 has determined the resultant environment (pressure, temperature, and humidity) due to the one square foot break and has evaluated the effects on safety-related equipment. Dynamic effects (e.g. pipe whip, jet impingement, and pressurization), structural effects, and flooding have not been considered for the arbitrary one square foot break. Additionally, essential components are not enclosed within structures or compartments as suggested in BTP ASB-1,
 
paragraph B.1.b.
: 2. Item B.2.c recommends that high energy piping between the containment isolation valves be designed to meet the "break exclusion" criteria of MEB 3-1. On BVPS-2, the only high energy piping in containment penetration areas designed for "break exclusion" are the main steam and feedwater lines as well as  the high energy branch lines contained within the main steam valve house. In addition, non-nuclear safety
 
class piping is contained within the break exclusion zone.
: 3. Item B.2.d requires the break excluded piping outboard of the isolation valves to the first restraint be maintained as the same piping classification as the inboard piping. On BVPS-2, the piping class outboard of the isolation valve is
 
designated non-nuclear safety, QA Category II.
: 4. Item B.3.b(3) limits the exclusion of single active component failures to certain dual-purpose moderate energy essential systems. However, BVPS-2 employs this criterion to dual-purpose systems in general (i.e., high and moderate energy systems). For example, after a postulated pipe rupture in a CVCS pump discharge line, a single active failure of the idle pump in the redundant train to start is
 
not postulated.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 12a of 93 REMARKS:
: 1. These differences are due to the addition of later NRC criteria than were utilized during the plant design stage,
 
i.e.; the arbitrary one square foot break. BVPS-2 has met
 
the intent of BTP-ASB 3-1, B.la. and lb., by evaluating the environmental effects of the arbitrary break on safety-related equipment. This degree of conformance is allowed by


BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  10 of 93 SRP NO. 3.3.1
BTP-ASB 3-1, paragraph B.lc.  
: 2. The only other high energy piping systems which penetrate the reactor containment are the steam generator blowdown and chemical and volume control systems. It is not necessary to break exclude either of these two systems in containment


TITLE: WIND LOADINGS  DIFFERENCES FROM THE SRP:
penetration areas because:  
ANSI A58.1, "Building Code Requirements for Minimum Design Loads in Buildings and Other Structures," was not used as a basis for developing wind loads. REMARKS:
: 1. Containment isolation capability is not required to mitigate the effects of a break in either system.  
ASCE Paper No. 3269, "Wind Force on Structures," was used as a basis for developing wind loads; this provides sufficient guidance for satisfying the requirements of GDC 2.
: 2. These pipe breaks can all be isolated in consideration of single active failures.  
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  11 of 93 SRP NO. 3.5.1.3


TITLE: TURBINE MISSILES  DIFFERENCES FROM THE SRP:
Refer to Difference and Remark 3 for an explanation of the
Acceptance Criterion II.1 does not apply to the BVPS-2 plant design arrangement. However, protection against low-trajectory turbine missiles at Beaver Valley Power Station - Unit 2 (BVPS-2) does meet the overall risk acceptance guidelines recommended by this SRP.
 
REMARKS:
NNS piping.
The latest technical advances in the design and analysis of Westinghouse low-pressure turbine rotors is used to provide assurance of turbine disc integrity. Improved disc integrity, overspeed protection, and a comprehensive inspection program provides sufficient missile protection to meet the overall risk acceptance guidelines and maintain acceptably low probabilities.  
: 3. The piping outboard of the isolation valve, although QA Category II, is analyzed to Seismic Category I criteria from the isolation valve to the terminal anchor (6-way restraint) which is located outside the break exclusion area. The
 
actual break excluded piping is the Class 2 portion from the penetration to the isolation valve and then the non-nuclear safety class high energy piping and branch lines to the main steam valve house wall. Although non-nuclear safety class piping which consists of ANSI B31.1 material has been included in the break exclusion zone, it has been analyzed
 
in accordance with the criteria of MB 3-1, Item B1.b for ASME III Class 2 material. All piping within the extended break exclusion zone is subjected to the augmented ISI criteria of MEB 3-1, Item B1.b.(7). Also refer to differences from SRP Section 3.6.2.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 12b of 93 4. The BVPS-2 position is in accordance with current industry practice as defined in American National Standard ANSI/ANS 51.1 - 1983 (Appendix B, Section B5 "Application of the Single Failure Criterion"), and ANSI/ANS 58.9 - 1981 (Section 4.5) which makes no distinction between high and
 
moderate energy dual purpose safety-related fluid systems.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 12c of 93 SRP NO. 3.6.2
 
TITLE: DETERMINATION OF RUPTURE LOCATIONS AND DYNAMIC EFFECTS ASSOCIATED WITH THE POSTULATED RUPTURE OF PIPING
 
DIFFERENCES FROM THE SRP:  
: 1. BTP MEB 3-1, paragraph B.1.b, states that breaks need not be postulated in those portions of Class 2 piping from the containment wall to and including the inboard or outboard isolation valve.
The BVPS-2 criteria state that breaks need not be postulated in those portions of high energy lines designated as break
 
exclusion zones:
: a. Between the containment penetration and the outboard isolation valve. These portions of Class 2 piping are designed to ASME III, Subarticle NE-1120.
: b. Between the containment isolation valves and the Main Steam Valve House (MSVH)/Service Building wall. This includes all MSS high-energy branch lines within the MSVH. All non-nuclear safety (NNS) portions of the break excluded piping are designed in accordance with ANSI B31.1.
: 2. BTP MEB 3-1, paragraph B.1.c(l), states that breaks should be  postulated...at intermediate locations where the maximum
 
stress range as calculated by Eq. (10) and either Eq. (12) or (13) exceeds 2.4 Sm.
The BVPS-2 criteria states that breaks should be postulated at any intermediate location where the maximum stress range as  calculated by Eq. (10) and either Eq. (12) or (13)
 
exceeds 3.0 Sm.
: 3. SRP 3.6.2 paragraph III.2.C.(4) states that for the jet thrust force T=KpA to be acceptable, K values should not be
 
less than 1.26 for steam, saturated water, or steam-water mixtures, or 2.0 for subcooled, nonflashing water. The
 
BVPS-2 criteria states that values of K or K for jet impingement evaluation may be reduced below the 1.26 and 2.00 limits where justified by consideration of pressure
 
drop due to frictional effects.
: 4. BTP MB 3-1, paragraph B.1.c(l)(d), states that if stresses and usage factors at two intermediate locations in a Class 1 piping or branch run do not exceed the threshold values for postulating
 
BVPS-2 SRP Rev. 13  TABLE 1.9-2 (Cont) 12d of 93 break then the...two highest stress locations based on
 
Equation (10) should be selected.  
 
The BVPS-2 criteria states that intermediate breaks are postulated only at those locations where the stresses and/or usage factors exceed the threshold values specified in BTP MEB 3-1, paragraph B.l.c(l)(b) and B.1.c(l)(c).
: 5. BTP MEB 3-1, paragraph B.1.c(2)(b)(ii), states that if the stresses in a Class 2 or 3 piping or branch run do not exceed the threshold value for postulating breaks then intermediate breaks are postulated...at not less than two separated locations chosen on the basis of highest stress.
The BVPS-2 criteria states that intermediate breaks are postulated only at those locations where the stresses exceed the threshold values specified in paragraph B.1.c(2)(b)(ii) for the following system:
: 1. Reactor Coolant System (not including the primary loop)
: 2. Hydrogenated Drain System
: 3. Residual Heat Removal System
: 4. Safety Injection System
: 5. Main Steam System
: 6. Main Feedwater System
: 7. Auxiliary Feedwater System
: 8. Steam Generator Blowdown System
: 9. Chemical and Volume Control System
: 10. Gaseous Nitrogen System
: 11. Auxiliary Steam System
: 6. SRP 3.6.2, Section III.3(c) states that "...the jet (from a ruptured high energy pipe) is time and distance
 
invarient...".
The BVPS-2 criteria allows the use of a 10 diameter limit for certain piping systems in establishing the range of jet
 
effects.
: 7. SRP 3.6.2 and associated sections of BTP MEB 3-1 specify criteria for postulation of piping ruptures.
 
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 12e of 93 BVPS-2 has invoked the current GDC-4 and an earlier schedular exemption granted to delete these pipe ruptures
 
from the design basis.
: 8. SRP 3.6.2 and associated sections of BTP MEB 3-1 specify criteria for postulation of high energy line piping
 
ruptures.
BVPS-2 has submitted analyses under NUREG-1061 (Vol. 3) qualifying certain ASME III Class 1 and 2 lines for exemption from pipe rupture postulation.  
 
REMARKS:  
: 1. The BVPS-2 criteria provide an acceptable alternative method of complying with GDC 4 by following the guidance of NUREG-
 
75/087 (November 1975). In addition:
: a. The NNS piping has been seismically designed as described in Section 3.2.1.2.
: b. The NNS piping has been designed to the additional design criteria per paragraphs B.1.b(l)(d), B.1.b(l)(e) and B.1.b(2) - B.1.b(7).
: c. The NNS piping except for the 32" main steam piping is of seamless construction.
: d. The 32" NNS main steam piping is electric fusion welded pipe manufactured to ASTM A-155, KC-70. Class 1 requirements. In addition, the plate used in this manufacturing process was ultrasonically examined in
 
accordance with ASTM A-577-69.
: e. The weld material used in NNS pipe spool fabrication and installation conforms and is certified to ASME Code, Section II requirements.
: 2. BVPS-2 Code Class 1 piping has been designed to the requirements of the ASME Code, Section III (ASME III), 1971 Edition through the Winter 1972 Addenda. In this version of ASME III (ref. paragraph NB-3653) Equation 10 includes a stress term for a linear through wall temperature gradient referred to as 1T.1. This stress term is not included in Equation 10 specified in versions of ASME III later than the 1977 Edition through Summer 1979 Addenda. Applying 2.4 Sm as the threshold level in determining intermediate break
 
locations is not considered appropriate when stress intensity ranges are calculated using the more conservative version of Equation 10 specified in the ASME III edition and Addenda applicable for BVPS-2 Code Class 1 piping. When using this more conservative version of Equation 10 it is more appropriate to apply 3.0 Sm as the threshold level.
: 3. American National Standard ANSI/ANS-58.2-1980, titled "Design Basis for Protection of Light Water Nuclear Power Plants Against Effects of Postulated Pipe Rupture" provide an acceptable alternative method for BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont) 12f of 93 the calculation of jet force (Appendix D) and fluid thrust
 
force (Appendix B) based upon inclusion of the effects of


BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  12 of 93 SRP NO. 3.6.1
pipe friction.
: 4. The deviations were requested by DLC in DLC letter no. 2NRC-5-042, docket no. 50-412 and granted in NRC letter dated


TITLE: PLANT DESIGN FOR PROTECTION AGAINST POSTULATED PIPING FAILURES IN FLUID SYSTEMS OUTSIDE CONTAINMENT DIFFERENCES FROM THE SRP (BRANCH TECHNICAL POSITION ASB 3-l): 1. BTP ASB-1, paragraph B.1.a(l) suggests that essential equipment be separated from the main steam and feedwater piping and be protected from the effects of a one square foot break of these lines, even though these lines are designed to the "break exclusion" criteria of MEB 3-1. BVPS-2 has determined the resultant environment (pressure, temperature, and humidity) due to the one square foot break and has evaluated the effects on safety-related equipment. Dynamic effects (e.g. pipe whip, jet impingement, and pressurization), structural effects, and flooding have not been considered for the arbitrary one square foot break. Additionally, essential components are not enclosed within structures or compartments as suggested in BTP ASB-1, paragraph B.1.b. 
May 27, 1985 for Docket No. 50-412
: 2. Item B.2.c recommends that high energy piping between the containment isolation valves be designed to meet the "break exclusion" criteria of MEB 3-1. On BVPS-2, the only high energy piping in containment penetration areas designed for "break exclusion" are the main steam and feedwater lines as well as  the high energy branch lines contained within the main steam valve house. In addition, non-nuclear safety class piping is contained within the break exclusion zone. 
: 5. Same as Remark 4.
: 3. Item B.2.d requires the break excluded piping outboard of the isolation valves to the first restraint be maintained as the same piping classification as the inboard piping. On BVPS-2, the piping class outboard of the isolation valve is designated non-nuclear safety, QA Category II.   
: 6. NUREG/CR-2913, 1983 establishes that piping containing steam or subcooled, flashing water at pressures between 870 and 2,465 psia and with no greater than 70C subcooling may be evaluated for a jet impingement effective range equal to ten times the nominal pipe diameter.  
: 4. Item B.3.b(3) limits the exclusion of single active component failures to certain dual-purpose moderate energy essential systems. However, BVPS-2 employs this criterion to dual-purpose systems in general (i.e., high and moderate energy systems). For example, after a postulated pipe rupture in a CVCS pump discharge line, a single active failure of the idle pump in the redundant train to start is not postulated.
: 7. SRP 3.6.2, paragraph II.1 and associated sections of Branch Technical Position MEB 3-1 require conformance with the previous version of General Design Criterion 4. The current version of GDC-4 (Federal Register, Volume 51, No. 70, Friday, April 11, 1986) permits exclusion of such breaks from the design basis "when analysis demonstrates the probability of rupturing such piping is extremely low under design basis conditions." Prior to the formal revision of GDC-4, BVPS-2 was granted a schedular exemption (Reference NRC letter dated October 11, 1985, Knighton to Carey) based upon review of such analyses. This exemption is maintained under the current GDC-4.  
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  12a of 93 REMARKS:
: 8. A combination of conventional methodology (Standard Review Plan Section 3.6.2) along with an alternative leak-before-break (WHIPJET) approach is used for the provision of protection from the mechanistic effects of postulated pipe rupture. WHIPJET demonstrates that the fluid leakage from a postulated defect at the highest stress location (in terms of normal plus safe shutdown earthquake loads) concurrent with minimum material properties in a high energy piping line can be detected well before the rupture of the pipe.
: 1. These differences are due to the addition of later NRC criteria than were utilized during the plant design stage, i.e.; the arbitrary one square foot break. BVPS-2 has met the intent of BTP-ASB 3-1, B.la. and lb., by evaluating the environmental effects of the arbitrary break on safety-related equipment. This degree of conformance is allowed by BTP-ASB 3-1, paragraph B.lc. 
WHIPJET is consistent with the procedural recommendations and analytical criteria found in NUREG-1061, Volume 3.
: 2. The only other high energy piping systems which penetrate the reactor containment are the steam generator blowdown and chemical and volume control systems. It is not necessary to break exclude either of these two systems in containment penetration areas because:  1. Containment isolation capability is not required to mitigate the effects of a break in either system. 
Portions of the reactor coolant system (RCS), residual heat removal system (RHR), and safety injection system (SIS) have
: 2. These pipe breaks can all be isolated in consideration of single active failures.
Refer to Difference and Remark 3 for an explanation of the NNS piping. 3. The piping outboard of the isolation valve, although QA Category II, is analyzed to Seismic Category I criteria from the isolation valve to the terminal anchor (6-way restraint) which is located outside the break exclusion area. The actual break excluded piping is the Class 2 portion from the penetration to the isolation valve and then the non-nuclear safety class high energy piping and branch lines to the main steam valve house wall. Although non-nuclear safety class piping which consists of ANSI B31.1 material has been included in the break exclusion zone, it has been analyzed in accordance with the criteria of MB 3-1, Item B1.b for ASME III Class 2 material. All piping within the extended break exclusion zone is subjected to the augmented ISI criteria of MEB 3-1, Item B1.b.(7). Also refer to differences from SRP Section 3.6.2.
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)   12b of 93 4. The BVPS-2 position is in accordance with current industry practice as defined in American National Standard ANSI/ANS 51.1 - 1983 (Appendix B, Section B5 "Application of the Single Failure Criterion"), and ANSI/ANS 58.9 - 1981 (Section 4.5) which makes no distinction between high and moderate energy dual purpose safety-related fluid systems. 


BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  12c of 93 SRP NO. 3.6.2
been exempted from consideration of pipe whip and jet impingement effects by the application of WHIPJET. Specific lines covered by this alternative approach are listed by


TITLE: DETERMINATION OF RUPTURE LOCATIONS AND DYNAMIC EFFECTS ASSOCIATED WITH THE POSTULATED RUPTURE OF PIPING DIFFERENCES FROM THE SRP:  1. BTP MEB 3-1, paragraph B.1.b, states that breaks need not be postulated in those portions of Class 2 piping from the containment wall to and including the inboard or outboard isolation valve. The BVPS-2 criteria state that breaks need not be postulated in those portions of high energy lines designated as break exclusion zones:  a. Between the containment penetration and the outboard isolation valve. These portions of Class 2 piping are designed to ASME III, Subarticle NE-1120. b. Between the containment isolation valves and the Main Steam Valve House (MSVH)/Service Building wall. This includes all MSS high-energy branch lines within the MSVH. All non-nuclear safety (NNS) portions of the break excluded piping are designed in accordance with ANSI B31.1. 2. BTP MEB 3-1, paragraph B.1.c(l), states that breaks should be  postulated...at intermediate locations where the maximum stress range as calculated by Eq. (10) and either Eq. (12) or (13) exceeds 2.4 Sm. The BVPS-2 criteria states that breaks should be postulated at any intermediate location where the maximum stress range as  calculated by Eq. (10) and either Eq. (12) or (13) exceeds 3.0 Sm. 3. SRP 3.6.2 paragraph III.2.C.(4) states that for the jet thrust force T=KpA to be acceptable, K values should not be less than 1.26 for steam, saturated water, or steam-water mixtures, or 2.0 for subcooled, nonflashing water. The BVPS-2 criteria states that values of K or K for jet impingement evaluation may be reduced below the 1.26 and 2.00 limits where justified by consideration of pressure drop due to frictional effects. 
line number in Table 3.6B-4.
: 4. BTP MB 3-1, paragraph B.1.c(l)(d), states that if stresses and usage factors at two intermediate locations in a Class 1 piping or branch run do not exceed the threshold values for postulating BVPS-2 SRP Rev. 13  TABLE 1.9-2 (Cont)  12d of 93 break then the...two highest stress locations based on Equation (10) should be selected.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 13 of 93 SRP NO. 3.7.1  
The BVPS-2 criteria states that intermediate breaks are postulated only at those locations where the stresses and/or usage factors exceed the threshold values specified in BTP MEB 3-1, paragraph B.l.c(l)(b) and B.1.c(l)(c). 5. BTP MEB 3-1, paragraph B.1.c(2)(b)(ii), states that if the stresses in a Class 2 or 3 piping or branch run do not exceed the threshold value for postulating breaks then intermediate breaks are postulated...at not less than two separated locations chosen on the basis of highest stress. The BVPS-2 criteria states that intermediate breaks are postulated only at those locations where the stresses exceed the threshold values specified in paragraph B.1.c(2)(b)(ii) for the following system:  1. Reactor Coolant System (not including the primary loop)
: 2. Hydrogenated Drain System 
: 3. Residual Heat Removal System  4. Safety Injection System
: 5. Main Steam System 
: 6. Main Feedwater System  7. Auxiliary Feedwater System
: 8. Steam Generator Blowdown System 
: 9. Chemical and Volume Control System  10. Gaseous Nitrogen System
: 11. Auxiliary Steam System  6. SRP 3.6.2, Section III.3(c) states that "...the jet (from a ruptured high energy pipe) is time and distance invarient...". The BVPS-2 criteria allows the use of a 10 diameter limit for certain piping systems in establishing the range of jet effects. 7. SRP 3.6.2 and associated sections of BTP MEB 3-1 specify criteria for postulation of piping ruptures.
BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  12e of 93 BVPS-2 has invoked the current GDC-4 and an earlier schedular exemption granted to delete these pipe ruptures from the design basis. 8. SRP 3.6.2 and associated sections of BTP MEB 3-1 specify criteria for postulation of high energy line piping ruptures. BVPS-2 has submitted analyses under NUREG-1061 (Vol. 3) qualifying certain ASME III Class 1 and 2 lines for exemption from pipe rupture postulation.
REMARKS:  1. The BVPS-2 criteria provide an acceptable alternative method of complying with GDC 4 by following the guidance of NUREG-75/087 (November 1975). In addition:  a. The NNS piping has been seismically designed as described in Section 3.2.1.2. b. The NNS piping has been designed to the additional design criteria per paragraphs B.1.b(l)(d), B.1.b(l)(e) and B.1.b(2) - B.1.b(7). 
: c. The NNS piping except for the 32" main steam piping is of seamless construction. 
: d. The 32" NNS main steam piping is electric fusion welded pipe manufactured to ASTM A-155, KC-70. Class 1 requirements. In addition, the plate used in this manufacturing process was ultrasonically examined in accordance with ASTM A-577-69. 
: e. The weld material used in NNS pipe spool fabrication and installation conforms and is certified to ASME Code, Section II requirements. 2. BVPS-2 Code Class 1 piping has been designed to the requirements of the ASME Code, Section III (ASME III), 1971 Edition through the Winter 1972 Addenda. In this version of ASME III (ref. paragraph NB-3653) Equation 10 includes a stress term for a linear through wall temperature gradient referred to as 1T.1. This stress term is not included in Equation 10 specified in versions of ASME III later than the 1977 Edition through Summer 1979 Addenda. Applying 2.4 Sm as the threshold level in determining intermediate break locations is not considered appropriate when stress intensity ranges are calculated using the more conservative version of Equation 10 specified in the ASME III edition and Addenda applicable for BVPS-2 Code Class 1 piping. When using this more conservative version of Equation 10 it is more appropriate to apply 3.0 Sm as the threshold level. 3. American National Standard ANSI/ANS-58.2-1980, titled "Design Basis for Protection of Light Water Nuclear Power Plants Against Effects of Postulated Pipe Rupture" provide an acceptable alternative method for BVPS-2 SRP Rev. 0  TABLE 1.9-2 (Cont)  12f of 93 the calculation of jet force (Appendix D) and fluid thrust force (Appendix B) based upon inclusion of the effects of pipe friction. 4. The deviations were requested by DLC in DLC letter no. 2NRC-5-042, docket no. 50-412 and granted in NRC letter dated May 27, 1985 for Docket No. 50-412  5. Same as Remark 4. 6. NUREG/CR-2913, 1983 establishes that piping containing steam or subcooled, flashing water at pressures between 870 and 2,465 psia and with no greater than 70C subcooling may be evaluated for a jet impingement effective range equal to ten times the nominal pipe diameter. 7. SRP 3.6.2, paragraph II.1 and associated sections of Branch Technical Position MEB 3-1 require conformance with the previous version of General Design Criterion 4. The current version of GDC-4 (Federal Register, Volume 51, No. 70, Friday, April 11, 1986) permits exclusion of such breaks from the design basis "when analysis demonstrates the probability of rupturing such piping is extremely low under design basis conditions."  Prior to the formal revision of GDC-4, BVPS-2 was granted a schedular exemption (Reference NRC letter dated October 11, 1985, Knighton to Carey) based upon review of such analyses. This exemption is maintained under the current GDC-4. 8. A combination of conventional methodology (Standard Review Plan Section 3.6.2) along with an alternative leak-before-break (WHIPJET) approach is used for the provision of protection from the mechanistic effects of postulated pipe rupture. WHIPJET demonstrates that the fluid leakage from a postulated defect at the highest stress location (in terms of normal plus safe shutdown earthquake loads) concurrent with minimum material properties in a high energy piping line can be detected well before the rupture of the pipe. WHIPJET is consistent with the procedural recommendations and analytical criteria found in NUREG-1061, Volume 3. Portions of the reactor coolant system (RCS), residual heat removal system (RHR), and safety injection system (SIS) have been exempted from consideration of pipe whip and jet impingement effects by the application of WHIPJET. Specific lines covered by this alternative approach are listed by line number in Table 3.6B-4.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   13 of 93 SRP NO. 3.7.1  


TITLE: SEISMIC DESIGN PARAMETERS DIFFERENCES FROM THE SRP:  
TITLE: SEISMIC DESIGN PARAMETERS DIFFERENCES FROM THE SRP:  
: 1. Design response spectra were not derived using Regulatory Guide 1.60 guidelines.
: 1. Design response spectra were not derived using Regulatory Guide 1.60 guidelines.  
REMARKS: 
: 1. The design response spectra are unique to BVPS-2 and were derived in accordance with Section 2.5 and question 3.15 of the BVPS-2 PSAR. That is, the shape and the magnitude of values in the design response spectra were specified by the USNRC in question 3.15. 2. Refer to Table 1.8-1 for conformance to Regulatory Guide 1.61.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  14 of 93 SRP NO. 3.7.2


TITLE: SEISMIC SYSTEM ANALYSIS  DIFFERENCES FROM THE SRP:
: 1. The BVPS-2 design is based on two-dimensional earthquake effects. 
: 2. BVPS-2 design floor response spectra are developed considering one component of earthquake motion at a time. 3. BVPS-2 design responses are not developed by enveloping the results from a half-space analysis and a finite element analysis for soil-structure interaction.
REMARKS:  
REMARKS:  
: 1. The guidelines to base designs on three dimensional earthquake effects were not in effect when BVPS-2 was designed and its construction permit issued. The BVPS-2 PSAR commits to using the two dimensional earthquake criteria. 2. Design response spectra are developed based on the response only in the direction of input motion. Coupling between three-directions of input motion is not a BVPS-2 design requirement; BVPS-2 uses a two-direction of input-motion criterion with no consideration of statistical independence between the different input time histories. Coupling between orthogonal directions of response is not considered since the structures are reasonably symmetric, and BVPS-2 is a soil site for which the structural responses are due largely to soil response and not to actual structural distortion responses. 3. The BVPS-2 design is in accordance with the previous SRP (NUREG-75/087, SRP 3.7.2). BVPS-2 was designed using a half-space approach and justified by using a finite element approach to demonstrate the conservatism of the half-space method for soil-structure interaction (refer to FSAR Section 3.7B-2 for further discussion of this issue).
: 1. The design response spectra are unique to BVPS-2 and were derived in accordance with Section 2.5 and question 3.15 of the BVPS-2 PSAR. That is, the shape and the magnitude of values in the design response spectra were specified by the USNRC in question 3.15.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   15 of 93 SRP NO. 3.7.3  
: 2. Refer to Table 1.8-1 for conformance to Regulatory Guide 1.61.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 14 of 93 SRP NO. 3.7.2
 
TITLE: SEISMIC SYSTEM ANALYSIS DIFFERENCES FROM THE SRP:
: 1. The BVPS-2 design is based on two-dimensional earthquake effects.
: 2. BVPS-2 design floor response spectra are developed considering one component of earthquake motion at a time.
: 3. BVPS-2 design responses are not developed by enveloping the results from a half-space analysis and a finite element analysis for soil-structure interaction.


TITLE: SEISMIC SUBSYSTEM ANALYSIS  DIFFERENCES FROM THE SRP:
: 1. SRP 3.7.3, paragraph II.2.g, suggests that closely spaced modes be combined in accordance with Regulatory Guide 1.92. Westinghouse combines closely spaced modes in accordance with the methods described in FSAR Section 3.7N.2.7. 2. Paragraph II.2.h requires adjacent Non-Category I systems to be analyzed according to the same seismic criteria as applicable to the Category I system, if it is not feasible or practical to isolate the Category I system. Such non-Category I piping, which is not attached to Category I piping systems, is not qualified for the seismic event associated with the upset plant condition. 
: 3. Paragraph II.2.1 addresses buried conduit and tunnels. The FSAR does not address the issue in this section.
REMARKS:  
REMARKS:  
: 1. The Westinghouse methods for combining closely spaced modes represents an alternative accepted by the USNRC for recent plants and meets the requirements of GDC 2 and Appendix A to 10 CFR 100. 2. For Non-Category I piping which is not attached to Category I piping systems, the Non-Category piping is qualified only for the seismic event associated with the faulted plant condition. This will ensure the structural integrity of the Non-Category I piping, thus precluding damage to Category I components/systems and is in agreement with the BVPS-2 position on Regulatory Guide 1.29.
: 1. The guidelines to base designs on three dimensional earthquake effects were not in effect when BVPS-2 was designed and its construction permit issued. The BVPS-2 PSAR commits to using the two dimensional earthquake criteria.
: 3. Tunnels are addressed in FSAR Section 3.7.2. Conduit will be addressed later via an FSAR amendment to show compliance.
: 2. Design response spectra are developed based on the response only in the direction of input motion. Coupling between three-directions of input motion is not a BVPS-2 design requirement; BVPS-2 uses a two-direction of input-motion criterion with no consideration of statistical independence between the different input time histories. Coupling between orthogonal directions of response is not considered since the structures are reasonably symmetric, and BVPS-2 is a soil site for which the structural responses are due largely to soil response and not to actual structural distortion responses.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   16 of 93 SRP NO. 3.8.1  
: 3. The BVPS-2 design is in accordance with the previous SRP (NUREG-75/087, SRP 3.7.2). BVPS-2 was designed using a half-space approach and justified by using a finite element approach to demonstrate the conservatism of the half-space method for soil-structure interaction (refer to FSAR Section
 
3.7B-2 for further discussion of this issue).
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 15 of 93 SRP NO. 3.7.3
 
TITLE: SEISMIC SUBSYSTEM ANALYSIS DIFFERENCES FROM THE SRP:
: 1. SRP 3.7.3, paragraph II.2.g, suggests that closely spaced modes be combined in accordance with Regulatory Guide 1.92. Westinghouse combines closely spaced modes in accordance with the methods described in FSAR Section 3.7N.2.7.
: 2. Paragraph II.2.h requires adjacent Non-Category I systems to be analyzed according to the same seismic criteria as
 
applicable to the Category I system, if it is not feasible
 
or practical to isolate the Category I system. Such non-Category I piping, which is not attached to Category I piping systems, is not qualified for the seismic event
 
associated with the upset plant condition.
: 3. Paragraph II.2.1 addresses buried conduit and tunnels. The FSAR does not address the issue in this section.
 
REMARKS:
: 1. The Westinghouse methods for combining closely spaced modes represents an alternative accepted by the USNRC for recent plants and meets the requirements of GDC 2 and Appendix A to 10 CFR 100.  
: 2. For Non-Category I piping which is not attached to Category I piping systems, the Non-Category piping is qualified only for the seismic event associated with the faulted plant condition. This will ensure the structural integrity of the Non-Category I piping, thus precluding damage to Category I components/systems and is in agreement with the BVPS-2  
 
position on Regulatory Guide 1.29.  
: 3. Tunnels are addressed in FSAR Section 3.7.2. Conduit will be addressed later via an FSAR amendment to show compliance.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 16 of 93 SRP NO. 3.8.1  
 
TITLE: CONCRETE CONTAINMENT DIFFERENCES FROM THE SRP:
: 1. BVPS-2 does not use the ACI/ASME (ACI 359) Code as a basis for load equations, design allowables, materials, quality control, or special construction techniques.
: 2. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.19, 1.55, and 1.94.


TITLE: CONCRETE CONTAINMENT  DIFFERENCES FROM THE SRP:
: 1. BVPS-2 does not use the ACI/ASME (ACI 359) Code as a basis for load equations, design allowables, materials, quality control, or special construction techniques. 
: 2. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.19, 1.55, and 1.94.
REMARKS:  
REMARKS:  
: 1. The BVPS-2 design uses ACI 318-71, with the alternative noted in Section 3.8.1.2.1.1, as a basis for the concrete portions of the containment and ASME Section III, Division I (1971 edition with Addenda through winter 1972) as a guide for liner portions instead of the  ACI/ASME (ACI 359) Code.
: 1. The BVPS-2 design uses ACI 318-71, with the alternative noted in Section 3.8.1.2.1.1, as a basis for the concrete portions of the containment and ASME Section III, Division I (1971 edition with Addenda through winter 1972) as a guide for liner portions instead of the  ACI/ASME (ACI 359) Code.
The ACI/ASME Code was not in effect at the time BVPS-2 was designed and its construction permit issued. 2. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
The ACI/ASME Code was not in effect at the time BVPS-2 was designed and its construction permit issued.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   17 of 93 SRP NO. 3.8.2  
: 2. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 17 of 93 SRP NO. 3.8.2  


TITLE: STEEL CONTAINMENT DIFFERENCES FROM THE SRP:
TITLE: STEEL CONTAINMENT DIFFERENCES FROM THE SRP:  
The structural acceptance criteria used for BVPS-2 differ from that in this SRP and Regulatory Guide 1.57.
 
REMARKS:
The structural acceptance criteria used for BVPS-2 differ from that in this SRP and Regulatory Guide 1.57.  
The structural acceptance criteria (that is, design limits and loading combinations) used for BVPS-2 is consistent with NUREG-75/087, which satisfies the requirements of the GDC. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.57.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   18 of 93 SRP NO. 3.8.3  
REMARKS:  
 
The structural acceptance criteria (that is, design limits and loading combinations) used for BVPS-2 is consistent with NUREG-
 
75/087, which satisfies the requirements of the GDC. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.57.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 18 of 93 SRP NO. 3.8.3  
 
TITLE: CONCRETE AND STEEL INTERNAL STRUCTURES OF STEEL OR CONCRETE CONTAINMENTS
 
DIFFERENCES FROM THE SRP:
: 1. The ACI-349 Code was not used for BVPS-2.
: 2. The ASME Boiler and Pressure Vessel Code, Section III, was not used for BVPS-2.
: 3. BVPS-2 takes exception to one of the requirements of the AISC Specification for the Design, Fabrication, and Erection of Structural Steel for Buildings.
: 4. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.15, 1.55, 1.94 and 1.142.


TITLE: CONCRETE AND STEEL INTERNAL STRUCTURES OF STEEL OR CONCRETE CONTAINMENTS DIFFERENCES FROM THE SRP:  1. The ACI-349 Code was not used for BVPS-2.
: 2. The ASME Boiler and Pressure Vessel Code, Section III, was not used for BVPS-2. 3. BVPS-2 takes exception to one of the requirements of the AISC Specification for the Design, Fabrication, and Erection of Structural Steel for Buildings. 
: 4. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.15, 1.55, 1.94 and 1.142.
REMARKS:  
REMARKS:  
: 1. The BVPS-2 design uses ACI 318-71, with the alternative noted in Section 3.8.1.2.1.1, as a basis for the concrete internal structures; the ACI 349 Code was not in effect at the time BVPS-2 was designed and its construction permit issued. 2. The ASME Boiler and Pressure Vessel Code is not applicable to the  internal structures of BVPS-2. 3. Refer to Section 3.8.1.2.1.3 for this exception.
: 1. The BVPS-2 design uses ACI 318-71, with the alternative noted in Section 3.8.1.2.1.1, as a basis for the concrete internal structures; the ACI 349 Code was not in effect at the time BVPS-2 was designed and its construction permit issued. 2. The ASME Boiler and Pressure Vessel Code is not applicable to the  internal structures of BVPS-2.  
: 3. Refer to Section 3.8.1.2.1.3 for this exception.  
: 4. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
: 4. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 20  TABLE 1.9-2 (Cont) 19 of 93 SRP NO. 3.8.4  
BVPS-2 UFSAR Rev. 20  TABLE 1.9-2 (Cont)  
 
19 of 93 SRP NO. 3.8.4  


TITLE: OTHER SEISMIC CATEGORY I STRUCTURES  
TITLE: OTHER SEISMIC CATEGORY I STRUCTURES  


DIFFERENCES FROM THE SRP:  
DIFFERENCES FROM THE SRP:  
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.55, 1.69, 1.94, 1.115, 1.142, and 1.143.
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.55, 1.69, 1.94, 1.115, 1.142, and 1.143.  
: 2. BVPS-2 does not use the ACI 349 Code as a basis for reinforced concrete design and analysis procedures.
: 2. BVPS-2 does not use the ACI 349 Code as a basis for reinforced concrete design and analysis procedures.  
: 3. BVPS-2 takes exception to one of the requirements of the AISC Specification for the Design, Fabrication, and Erection of Structural Steel for Buildings.
: 3. BVPS-2 takes exception to one of the requirements of the AISC Specification for the Design, Fabrication, and Erection  
: 4. Loads, load combinations, and structural acceptance criteria are not in complete agreement with SRP 3.8.4.
 
: 5. Appendices A, B, C, and D to SRP 3.8.4 are not addressed in Section 3.8.4.
of Structural Steel for Buildings.  
: 4. Loads, load combinations, and structural acceptance criteria are not in complete agreement with SRP 3.8.4.  
: 5. Appendices A, B, C, and D to SRP 3.8.4 are not addressed in Section 3.8.4.  
 
REMARKS:  
REMARKS:  
: 1. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.   
: 1. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.   
: 2. Reinforced concrete design and analysis procedures conform to the ACI 318-71 Code, with the alternative noted in Section 3.8.1.2.1.1. The ACI 349 Code was not issued at the time the BVPS-2 Construction Permit was issued nor by the time the majority of the reinforced concrete was designed.
: 2. Reinforced concrete design and analysis procedures conform to the ACI 318-71 Code, with the alternative noted in Section 3.8.1.2.1.1. The ACI 349 Code was not issued at the  
 
time the BVPS-2 Construction Permit was issued nor by the  
 
time the majority of the reinforced concrete was designed.  
: 3. Refer to Section 3.8.1.2.1.3 for this exception.  
: 3. Refer to Section 3.8.1.2.1.3 for this exception.  
: 4. Certain load combinations have not been postulated. These combinations would not govern the design of the structures.
: 4. Certain load combinations have not been postulated. These combinations would not govern the design of the structures.  
: 5. Appendix A:  BVPS-2 has no safety-related concrete masonry walls. Appendix B:  The Appendix, "Structural Design Audits,"
: 5. Appendix A:  BVPS-2 has no safety-related concrete masonry walls. Appendix B:  The Appendix, "Structural Design Audits,"  
 
contains no specific acceptance criteria.  
contains no specific acceptance criteria.  


Appendix C:  Items comprising "The Design Report" were discussed during the NRC Structural Design Audit.  
Appendix C:  Items comprising "The Design Report" were  
 
discussed during the NRC Structural Design Audit.  
 
Appendix D:  The spent fuel racks are addressed in Section
 
9.1.2.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 20 of 93 SRP NO. 3.8.5


Appendix D: The spent fuel racks are addressed in Section 9.1.2.
TITLE: FOUNDATIONS DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  20 of 93 SRP NO. 3.8.5
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.19, 1.55, 1.94, 1.136, and 1.142.
: 2. BVPS-2 does not use the ACI 349 Code as a basis for reinforced concrete design and analysis procedures.  
: 3. Overturning moments do not consider the combination of the three components of the earthquake.  


TITLE: FOUNDATIONS  DIFFERENCES FROM THE SRP:
REMARKS:  
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.19, 1.55, 1.94, 1.136, and 1.142. 
: 2. BVPS-2 does not use the ACI 349 Code as a basis for reinforced concrete design and analysis procedures. 3. Overturning moments do not consider the combination of the three components of the earthquake.
REMARKS:
: 1. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.   
: 1. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.   
: 2. Reinforced concrete design and analysis procedures conform to the ACI 318-71 Code, with the alternative noted in Section 3.8.1.2.1.1. The ACI 349 Code was  not issued at the time the BVPS-2 construction permit was issued nor by the time the majority of the reinforced concrete was designed. 3. BVPS-2 is committed to two-dimension earthquake criteria. Refer to Section 3.7B.2 for a description of the analytical techniques used to determine earthquake forces.
: 2. Reinforced concrete design and analysis procedures conform to the ACI 318-71 Code, with the alternative noted in Section 3.8.1.2.1.1. The ACI 349 Code was  not issued at  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   21 of 93 SRP NO. 3.9.1  
 
the time the BVPS-2 construction permit was issued nor by the time the majority of the reinforced concrete was designed.  
: 3. BVPS-2 is committed to two-dimension earthquake criteria. Refer to Section 3.7B.2 for a description of the analytical techniques used to determine earthquake forces.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 21 of 93 SRP NO. 3.9.1  
 
TITLE: SPECIAL TOPICS FOR MECHANICAL COMPONENTS DIFFERENCES FROM THE SRP:
 
SRP 3.9.1, paragraph II.2, requests a considerable amount of information for all the computer codes used in the design and analysis of seismic Category I components. Westinghouse only provides a brief description of the computer codes used by Westinghouse for component design and analysis in FSAR Section 3.9N.1.2. Additional information required by this SRP for the computer codes referred to in FSAR  Section 3.9N.1.2 is provided by reference to WCAP-8252 and -8929. Computer codes used by
 
Westinghouse vendors are not included in the FSAR.
REMARKS:
 
The information requested by the SRP for referenced Westinghouse computer codes is provided in WCAP-8252 and -8929 and meets the relevant requirements of GDC 1 and Appendix B to 10 CFR 50.
Both of these documents have been submitted to the USNRC for review.
Vendor computer codes are not included in the FSAR because of the large number of codes used and the proprietary nature of this vendor information. Westinghouse ensures the acceptability of vendor computer codes through quality assurance audits at vendor facilities and the technical review of various design
 
documents submitted by vendors to Westinghouse.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 22 of 93 SRP NO. 3.9.2


TITLE: SPECIAL TOPICS FOR MECHANICAL COMPONENTS DIFFERENCES FROM THE SRP:
TITLE: DYNAMIC TESTING AND ANALYSIS OF SYSTEMS, COMPONENTS, AND EQUIPMENT
SRP 3.9.1, paragraph II.2, requests a considerable amount of information for all the computer codes used in the design and analysis of seismic Category I components. Westinghouse only provides a brief description of the computer codes used by Westinghouse for component design and analysis in FSAR Section 3.9N.1.2. Additional information required by this SRP for the computer codes referred to in FSAR  Section 3.9N.1.2 is provided by reference to WCAP-8252 and -8929. Computer codes used by Westinghouse vendors are not included in the FSAR. REMARKS:
The information requested by the SRP for referenced Westinghouse computer codes is provided in WCAP-8252 and -8929 and meets the relevant requirements of GDC 1 and Appendix B to 10 CFR 50. Both of these documents have been submitted to the USNRC for review.
Vendor computer codes are not included in the FSAR because of the large number of codes used and the proprietary nature of this vendor information. Westinghouse ensures the acceptability of vendor computer codes through quality assurance audits at vendor facilities and the technical review of various design documents submitted by vendors to Westinghouse.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  22 of 93 SRP NO. 3.9.2


TITLE: DYNAMIC TESTING AND ANALYSIS OF SYSTEMS, COMPONENTS, AND EQUIPMENT DIFFERENCES FROM THE SRP: 1. SRP 3.9N.2, paragraph II.2.e, defines criteria for combining closely spaced modes. The Westinghouse method for combining closely spaced modes is provided in FSAR Section 3.7N.2.7. 2. Differences in methods exist of combining individual orthogonal stresses resulting from the dynamic responses of the equipment and the modeling techniques employed in the seismic qualification of mechanical and electrical equipment. 3. BVPS-2 employs alternatives to Regulatory Guides 1.20, 1.61. 1.68, and 1.92.
DIFFERENCES FROM THE SRP:  
REMARKS:  1. Refer to the justification provided for SRP 3.7.3.
: 1. SRP 3.9N.2, paragraph II.2.e, defines criteria for combining closely spaced modes. The Westinghouse method for combining closely spaced modes is provided in FSAR Section 3.7N.2.7.  
: 2. FSAR Section 3.9B.2.2 was written to a previous revision of the SRP. Based on previous successfully submitted SARs the general intent should be satisfied by the present 3.9.2.2 and other referenced sections. Technically acceptable alternate methods are identified in FSAR Section 3.7B.3. 3. Refer to Section 1.8 of the FSAR for BVPS-2 positions on regulatory guides.
: 2. Differences in methods exist of combining individual orthogonal stresses resulting from the dynamic responses of  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  23 of 93 SRP NO. 3.9.3
 
the equipment and the modeling techniques employed in the  
 
seismic qualification of mechanical and electrical equipment.  
: 3. BVPS-2 employs alternatives to Regulatory Guides 1.20, 1.61.
1.68, and 1.92.  


TITLE: ASME CODE CLASS 1, 2, AND 3 COMPONENTS, COMPONENT SUPPORTS, AND CORE SUPPORT STRUCTURES DIFFERENCES FROM THE SRP:  1. Design of ASME Code Class 1, 2, and 3 Components do not include specific provisions for addressing functional capability as outlined in SRP 3.9.3. 2. SRP 3.9.3, Appendix A.1.3.3, defines the design basis pipe break (DBPB) as an emergency condition. For ASME Code Class 1, 2, and 3 components and component supports, the DBPB is a faulted condition.  (Refer to the loading combination tables in Section 3.9.)  3. SRP 3.9.3, paragraph II.3, requests deformation limits to be included in the FSAR for component supports when the support affects the operability of the component. This requirement would only apply to active pump supports. Active valves are supported in the piping system. No information on deformation limits is provided in the FSAR for supports of active pumps. 
: 4. BVPS-2 provides acceptable alternatives to various portions of Regulatory Guides 1.48, 1.67, 1.124, and 1.130. 
: 5. A fatigue evaluation of shock arrestors is requested by SRP 3.9.3, paragraph II.3.b.l unless it can be demonstrated that the number of load cycles which the snubber will experience during normal plant operating conditions is small (less than 2500), or motion during normal plant operating conditions does not exceed snubber dead band. This fatigue evaluation is not done. 6. SRP 3.9.3, paragraph II.3.b.2 discusses the need to consider snubber end fitting clearance and lost motion when calculating snubber reaction loads and stress which are based on a linear analysis of the system or component. Piping analysis and component analysis do not consider snubber end fitting clearance and lost motion. 
: 7. BVPS-2 does not use service stress limits A, B, C, and D as described in Appendix A to SRP 3.9.3.
REMARKS:  
REMARKS:  
: 1. Conformance with ASME III requirements and experience with components experiencing significant earthquakes and fluid transient loads (NUREGs/CR-2137 and CR-1665) provides adequate assurance of functional capability.
: 1. Refer to the justification provided for SRP 3.7.3.
BVPS-2 UFSAR Rev. 18  TABLE 1.9-2 (Cont) 24 of 93 2. The DBPB is a faulted condition event consistent with the criteria defined in ANSI N18.2. Additionally, the stress limits and analysis methods for faulted conditions  defined in the ASME Code and Section 3.9N of the FSAR are sufficiently conservative to ensure the structural integrity and operability of components when subjected to faulted condition loads including the DBPB.
: 2. FSAR Section 3.9B.2.2 was written to a previous revision of the SRP. Based on previous successfully submitted SARs the general intent should be satisfied by the present 3.9.2.2 and other referenced sections. Technically acceptable alternate methods are identified in FSAR Section 3.7B.3.
: 3. BVPS-2 is committed to a pump operability program which does not permit permanent deformation of component supports for active pumps. Although specific deformation limits are not quantified, they are addressed in a qualitative manner in FSAR Sections 3.9N.3.2 and 3.9B.3.2.
: 3. Refer to Section 1.8 of the FSAR for BVPS-2 positions on regulatory guides.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 23 of 93 SRP NO. 3.9.3
 
TITLE: ASME CODE CLASS 1, 2, AND 3 COMPONENTS, COMPONENT SUPPORTS, AND CORE SUPPORT STRUCTURES
 
DIFFERENCES FROM THE SRP:
: 1. Design of ASME Code Class 1, 2, and 3 Components do not include specific provisions for addressing functional capability as outlined in SRP 3.9.3.
: 2. SRP 3.9.3, Appendix A.1.3.3, defines the design basis pipe break (DBPB) as an emergency condition. For ASME Code Class 1, 2, and 3 components and component supports, the DBPB is a faulted condition.  (Refer to the loading combination tables in Section 3.9.)
: 3. SRP 3.9.3, paragraph II.3, requests deformation limits to be included in the FSAR for component supports when the support affects the operability of the component. This requirement
 
would only apply to active pump supports. Active valves are supported in the piping system. No information on deformation limits is provided in the FSAR for supports of
 
active pumps.
: 4. BVPS-2 provides acceptable alternatives to various portions of Regulatory Guides 1.48, 1.67, 1.124, and 1.130.
: 5. A fatigue evaluation of shock arrestors is requested by SRP 3.9.3, paragraph II.3.b.l unless it can be demonstrated that the number of load cycles which the snubber will experience during normal plant operating conditions is small (less than 2500), or motion during normal plant operating conditions does not exceed snubber dead band. This fatigue evaluation is not done.
: 6. SRP 3.9.3, paragraph II.3.b.2 discusses the need to consider snubber end fitting clearance and lost motion when calculating snubber reaction loads and stress which are based on a linear analysis of the system or component. Piping analysis and component analysis do not consider
 
snubber end fitting clearance and lost motion.
: 7. BVPS-2 does not use service stress limits A, B, C, and D as described in Appendix A to SRP 3.9.3.
 
REMARKS:
: 1. Conformance with ASME III requirements and experience with components experiencing significant earthquakes and fluid transient loads (NUREGs/CR-2137 and CR-1665) provides adequate assurance of functional capability.  
 
BVPS-2 UFSAR Rev. 18  TABLE 1.9-2 (Cont)  
 
24 of 93 2. The DBPB is a faulted condition event consistent with the criteria defined in ANSI N18.2. Additionally, the stress limits and analysis methods for faulted conditions  defined  
 
in the ASME Code and Section 3.9N of the FSAR are  
 
sufficiently conservative to ensure the structural integrity and operability of components when subjected to faulted  
 
condition loads including the DBPB.  
: 3. BVPS-2 is committed to a pump operability program which does not permit permanent deformation of component supports for active pumps. Although specific deformation limits are not  
 
quantified, they are addressed in a qualitative manner in  
 
FSAR Sections 3.9N.3.2 and 3.9B.3.2.  
: 4. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.   
: 4. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.   
: 5. Normal plant surveillance of snubbers will detect and report any lack of function or deterioration of performance due to system vibration. Any defective snubbers will be replaced. 
: 5. Normal plant surveillance of snubbers will detect and report any lack of function or deterioration of performance due to  
: 6. Snubber end fitting clearance and lost motion are not considered significant in piping analysis or component analysis. 
: 7. The ASME III Code editions applicable to BVPS-2 components (refer to the ASME Code Baseline Document) do not include the use of service stress limits A, B, C, and D.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  25 of 93 SRP NO. 3.10


TITLE: SEISMIC QUALIFICATION OF CATEGORY I INSTRUMENTATION AND ELECTRICAL EQUIPMENT DIFFERENCES FROM THE SRP: 1. The SRP requests that acceptable load combination and methods for defining dynamic responses for mechanical and electrical equipment be defined in SRP Section 3.9.3. There are differences in the SRP guidelines and the Westinghouse and balance of plant (BOP) methods of load combination and methods for combining dynamic responses for mechanical equipment (refer to Section 3.9.3 remarks). For electrical equipment, the only dynamic loads considered in testing are seismic loads. These seismic loads are not combined by test with other dynamic loads. 2. BVPS-2 takes some alternatives to Regulatory Guides 1.61, 1.89, 1.92, 1.100, and 1.122.
system vibration. Any defective snubbers will be replaced.
: 3. Seismic qualification of mechanical equipment is not addressed in FSAR Section 3.10.
: 6. Snubber end fitting clearance and lost motion are not considered significant in piping analysis or component
: 4. Section 3.10 of the FSAR does not cover operability of active pumps and valves.
 
: 5. Paragraph II.l.a.(2) of the SRP suggests that equipment should be tested in the operational condition and that loadings simulating normal plant conditions should be superimposed on seismic and dynamic loads. This includes flow induced loads and degraded flow conditions. For the tests performed, operational conditions are included where practical, simulated in some manner, or addressed by analysis. Flow loads are not superimposed on seismic loads for valve operability tests.
analysis.
: 6. Paragraph II.l.a.(8) suggests that fixture design for seismic tests should simulate actual service mounting and should not cause any extraneous dynamic coupling to the test item. 7. If the dynamic testing of a pump or valve is impractical, static testing of the assembly can be performed in accordance with paragraph II.1.a(l0). End loadings are not applied, and all dynamic amplification effects are not included in the static deflection tests for active valves. 8. Paragraph 3.10.II.l.a.(14)(b)iii requires that an analysis be performed to determine the pressure differential and impact energy on a valve disc during a LOCA, and to verify the design adequacy of the disc. Westinghouse specified the loading conditions applicable to each valve. Westinghouse performs design verification on vendor supplied valves to assure that the valves are designed properly and meet the BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   26 of 93 stress acceptance criteria specified both in the Equipment Specifications and the ASME Code Standards. The valve suppliers use the guidance provided in NB-3552(C) of the ASME Code to determine if any analysis is warranted. 9. Paragraph II.1.a.(14)(b)viii suggests the use of Regulatory Guide 1.92 for combination of multimodal and multidirectional responses in analyses. Westinghouse uses the methods defined in FSAR Section 3.7 for combining closely spaced modes. 10. Paragraph II.5.b suggests that a list of systems necessary to perform the functions outlined in the SRP Section 3.10 be included in the FSAR Section 3.10. This list is not included in FSAR Section 3.10N.
: 7. The ASME III Code editions applicable to BVPS-2 components (refer to the ASME Code Baseline Document) do not include the use of service stress limits A, B, C, and D.
: 11. Paragraph II.5.b(2) suggests that a description of the results of any in-plant tests used to confirm qualification of equipment be included in the FSAR. 12. Paragraph II.5.c suggests a Seismic Qualification Report. Westinghouse does not maintain such a report for BVPS-2.
 
REMARKS: 1. Seismic loads are the only dynamic loads considered for electrical equipment. Interface requirements dictate that electrical equipment be protected from such dynamic loads as jet impingement and pipe whip. The exceptions to the above statement are line mounted electrical components (such as RTDs and valve accessories) in ASME Class 1 systems. This line mounted equipment is subjected to blowdown loads from a LOCA. However, these blowdown loads are enveloped by the seismic loads and are not combined with the seismic loads because of the low probability of the simultaneous occurrence of the two events. The second exception is the electrically operated pressurizer PORV which is subject to transient flow loads. These loads are not combined with seismic loads during test. However, the design load combination includes consideration of transient flow load effects (pressure loads resulting from LOCA) combined with seismic loads. This combined effect is evaluated by analysis for the pressurizer PORVS. In addition, seismic testing in accordance with WCAP-8587 has been conducted on this device.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 25 of 93 SRP NO. 3.10
 
TITLE: SEISMIC QUALIFICATION OF CATEGORY I INSTRUMENTATION AND ELECTRICAL EQUIPMENT  
 
DIFFERENCES FROM THE SRP:  
: 1. The SRP requests that acceptable load combination and methods for defining dynamic responses for mechanical and electrical equipment be defined in SRP Section 3.9.3. There are differences in the SRP guidelines and the Westinghouse and balance of plant (BOP) methods of load combination and methods for combining dynamic responses for mechanical equipment (refer to Section 3.9.3 remarks). For electrical equipment, the only dynamic loads considered in testing are seismic loads. These seismic loads are not combined by test with other dynamic loads.  
: 2. BVPS-2 takes some alternatives to Regulatory Guides 1.61, 1.89, 1.92, 1.100, and 1.122.  
: 3. Seismic qualification of mechanical equipment is not addressed in FSAR Section 3.10.  
: 4. Section 3.10 of the FSAR does not cover operability of active pumps and valves.  
: 5. Paragraph II.l.a.(2) of the SRP suggests that equipment should be tested in the operational condition and that loadings simulating normal plant conditions should be superimposed on seismic and dynamic loads. This includes flow induced loads and degraded flow conditions. For the tests performed, operational conditions are included where practical, simulated in some manner, or addressed by analysis. Flow loads are not superimposed on seismic loads  
 
for valve operability tests.  
: 6. Paragraph II.l.a.(8) suggests that fixture design for seismic tests should simulate actual service mounting and should not cause any extraneous dynamic coupling to the test  
 
item. 7. If the dynamic testing of a pump or valve is impractical, static testing of the assembly can be performed in accordance with paragraph II.1.a(l0). End loadings are not applied, and all dynamic amplification effects are not included in the static deflection tests for active valves.  
: 8. Paragraph 3.10.II.l.a.(14)(b)iii requires that an analysis be performed to determine the pressure differential and impact energy on a valve disc during a LOCA, and to verify the design adequacy of the disc. Westinghouse specified the loading conditions applicable to each valve. Westinghouse performs design verification on vendor supplied valves to assure that the valves are designed properly and meet the  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 26 of 93 stress acceptance criteria specified both in the Equipment Specifications and the ASME Code Standards. The valve suppliers use the guidance provided in NB-3552(C) of the ASME Code to determine if any analysis is warranted.  
: 9. Paragraph II.1.a.(14)(b)viii suggests the use of Regulatory Guide 1.92 for combination of multimodal and multidirectional responses in analyses. Westinghouse uses  
 
the methods defined in FSAR Section 3.7 for combining closely spaced modes.  
: 10. Paragraph II.5.b suggests that a list of systems necessary to perform the functions outlined in the SRP Section 3.10 be  
 
included in the FSAR Section 3.10. This list is not  
 
included in FSAR Section 3.10N.  
: 11. Paragraph II.5.b(2) suggests that a description of the results of any in-plant tests used to confirm qualification of equipment be included in the FSAR.  
: 12. Paragraph II.5.c suggests a Seismic Qualification Report.
Westinghouse does not maintain such a report for BVPS-2.  
 
REMARKS:  
: 1. Seismic loads are the only dynamic loads considered for electrical equipment. Interface requirements dictate that electrical equipment be protected from such dynamic loads as jet impingement and pipe whip. The exceptions to the above statement are line mounted electrical components (such as RTDs and valve accessories) in ASME Class 1 systems. This line mounted equipment is subjected to blowdown loads from a  
 
LOCA. However, these blowdown loads are enveloped by the seismic loads and are not combined with the seismic loads because of the low probability of the simultaneous  
 
occurrence of the two events. The second exception is the electrically operated pressurizer PORV which is subject to transient flow loads. These loads are not combined with seismic loads during test. However, the design load combination includes consideration of transient flow load effects (pressure loads resulting from LOCA) combined with seismic loads. This combined effect is evaluated by analysis for the pressurizer PORVS. In addition, seismic testing in accordance with WCAP-8587 has been conducted on  
 
this device.  
: 2. In accordance with the SRP, since the BVPS-2 construction permit application was docketed before October 27, 1972, Class I electrical equipment will be seismically qualified in accordance with IEEE 344-1971. Although not required (due to Beaver Valley's docket date being before October 27, 1972), IEEE 344-1975 was employed for seismic qualification of Seismic Category I electrical equipment when feasible.
: 2. In accordance with the SRP, since the BVPS-2 construction permit application was docketed before October 27, 1972, Class I electrical equipment will be seismically qualified in accordance with IEEE 344-1971. Although not required (due to Beaver Valley's docket date being before October 27, 1972), IEEE 344-1975 was employed for seismic qualification of Seismic Category I electrical equipment when feasible.
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   27 of 93 3. Seismic qualification of mechanical equipment is addressed in FSAR Sections 3.7 and 3.9 in accordance with SRPS 3.7 and 3.9. 4. The BVPS-2 operability program is covered in FSAR Sections 3.9N.3.2. and 3.9B.3.2. The latest version of the SRP has included operability under Section 3.10 and has deleted it from Section 3.9. 5. Full operational testing conditions are not included in testing because performing such a test is impractical. For example, when  static deflection tests on valves are performed, the P across the valve disc is simulated.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 27 of 93 3. Seismic qualification of mechanical equipment is addressed in FSAR Sections 3.7 and 3.9 in accordance with SRPS 3.7 and  
However, the test is not performed with the valve in a flow loop. As stated above, operational conditions are addressed other than by test. The active valve operability program defined in FSAR Sections 3.9N.3.2 and 3.9B.3.2 outlines the program for demonstrating operability under all required plant conditions. This program of conservative design, analysis, and test provides adequate assurance that safety related equipment will perform the required safety functions under the appropriate plant conditions. 6. Seismic qualification testing configurations are designed to represent the typical plant installation for the tested component. Interface requirements are defined based on the test configuration and other design requirements. Installation is then completed in accordance with the component interface requirements. Any dynamic coupling effects that result from mounting the component in accordance with these interface criteria would have been adequately considered during the test program. 7. Conservative restrictions are placed on the allowable piping loads transmitted to the valve or pump body such that these loads cannot cause detrimental deflections of the active component. This restriction of allowable piping loads combined with the static deflection testing performed on active valves provides adequate assurance of valve performance and obviates the need to apply end loadings during the static deflection tests for active valves. The operability program for active valves addresses dynamic amplification effects by increasing the g loadings utilized in static deflection tests and analyses when dynamic equipment response is a concern. In most cases the equipment is rigid and does not display dynamic amplification characteristics. 8. In conformance with NA-3254 of the ASME Code Section III, Westinghouse utilizes the mechanism of Equipment Design Specifications to address the equipment boundaries of jurisdiction. All loading conditions which are expected to be applicable to the hardware are therefore covered explicitly in the Equipment Specifications. By so doing, Westinghouse conforms to NA-3254. In most cases, the vendor invokes NB-3552(c) of BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   28 of 93 the ASME Code states that any transient effects due to maloperation or accident whose number of occurrences does not exceed 5 need not be considered. 9. The Westinghouse methods for combining closely spaced modes has been previously justified and accepted by the USNRC. 10. The information requested is included in FSAR Chapters 6 and 7, Safety Related Mechanical and Electrical Systems.
 
: 11. The test results for Westinghouse supplied equipment are referenced in the FSAR. Actual test results are not included in the FSAR. 12. Seismic qualification of equipment is documented in test reports, analysis reports, and calculation notes contained in Westinghouse files. The documentation maintained by Westinghouse satisfies existing regulatory requirements and, therefore, it is not considered necessary to prepare an additional Seismic Qualification Report.
3.9. 4. The BVPS-2 operability program is covered in FSAR Sections 3.9N.3.2. and 3.9B.3.2. The latest version of the SRP has included operability under Section 3.10 and has deleted it from Section 3.9. 5. Full operational testing conditions are not included in testing because performing such a test is impractical. For example, when  static deflection tests on valves are performed, the P across the valve disc is simulated.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   29 of 93 SRP NO. 3.11  
However, the test is not performed with the valve in a flow loop. As stated above, operational conditions are addressed other than by test.
The active valve operability program defined in FSAR Sections 3.9N.3.2 and 3.9B.3.2 outlines the program for demonstrating operability under all required plant  
 
conditions. This program of conservative design, analysis, and test provides adequate assurance that safety related equipment will perform the required safety functions under  
 
the appropriate plant conditions. 6. Seismic qualification testing configurations are designed to represent the typical plant installation for the tested component. Interface requirements are defined based on the test configuration and other design requirements.
Installation is then completed in accordance with the component interface requirements. Any dynamic coupling effects that result from mounting the component in accordance with these interface criteria would have been  
 
adequately considered during the test program. 7. Conservative restrictions are placed on the allowable piping loads transmitted to the valve or pump body such that these loads cannot cause detrimental deflections of the active component. This restriction of allowable piping loads combined with the static deflection testing performed on active valves provides adequate assurance of valve performance and obviates the need to apply end loadings during the static deflection tests for active valves.
The operability program for active valves addresses dynamic amplification effects by increasing the g loadings utilized in static deflection tests and analyses when dynamic equipment response is a concern. In most cases the equipment is rigid and does not display dynamic amplification characteristics. 8. In conformance with NA-3254 of the ASME Code Section III, Westinghouse utilizes the mechanism of Equipment Design Specifications to address the equipment boundaries of jurisdiction. All loading conditions which are expected to be applicable to the hardware are therefore covered explicitly in the Equipment Specifications. By so doing, Westinghouse conforms to NA-3254. In most cases, the vendor invokes NB-3552(c) of BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 28 of 93 the ASME Code states that any transient effects due to maloperation or accident whose number of occurrences does  
 
not exceed 5 need not be considered.  
: 9. The Westinghouse methods for combining closely spaced modes has been previously justified and accepted by the USNRC.  
: 10. The information requested is included in FSAR Chapters 6 and 7, Safety Related Mechanical and Electrical Systems.  
: 11. The test results for Westinghouse supplied equipment are referenced in the FSAR. Actual test results are not included in the FSAR.  
: 12. Seismic qualification of equipment is documented in test reports, analysis reports, and calculation notes contained in Westinghouse files. The documentation maintained by  
 
Westinghouse satisfies existing regulatory requirements and, therefore, it is not considered necessary to prepare an additional Seismic Qualification Report.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 29 of 93 SRP NO. 3.11  
 
TITLE: ENVIRONMENTAL DESIGN OF MECHANICAL AND ELECTRICAL EQUIPMENT
 
DIFFERENCES FROM THE SRP:
: 1. SRP 3.11 suggests that all mechanical and electrical systems and equipment necessary to perform the functions listed in paragraph 1 of Section I of the SRP 3.11 should be listed in Section 3.11 of the FSAR. Section 3.11 does not include the


TITLE: ENVIRONMENTAL DESIGN OF MECHANICAL AND ELECTRICAL EQUIPMENT DIFFERENCES FROM THE SRP:  1. SRP 3.11 suggests that all mechanical and electrical systems and equipment necessary to perform the functions listed in paragraph 1 of Section I of the SRP 3.11 should be listed in Section 3.11 of the FSAR. Section 3.11 does not include the entire list.
entire list.  
: 2. BVPS-2 meets or exceeds the guidelines of NUREG-0588, Rev. 1, for a Category II plant in lieu of IEEE Standard 323-1974 which is endorsed by Regulatory Guide 1.89. 3. Qualification of safety related mechanical equipment consists of seismic and operability type programs as addressed in FSAR Sections 3.7 and 3.9. REMARKS:
: 2. BVPS-2 meets or exceeds the guidelines of NUREG-0588, Rev. 1, for a Category II plant in lieu of IEEE Standard 323-1974 which is endorsed by Regulatory Guide 1.89.  
: 1. The information requested by SRP 3.11 is located in different parts of the FSAR as listed below: a. Safety related Mechanical and Electrical Systems - FSAR Chapters 6 and 7.
: 3. Qualification of safety related mechanical equipment consists of seismic and operability type programs as  
 
addressed in FSAR Sections 3.7 and 3.9.
REMARKS:  
: 1. The information requested by SRP 3.11 is located in different parts of the FSAR as listed below:  
: a. Safety related Mechanical and Electrical Systems - FSAR Chapters 6 and 7.  
: b. Active Pumps and Valves - FSAR Tables 3.9N-9 and 3.9N-10.   
: b. Active Pumps and Valves - FSAR Tables 3.9N-9 and 3.9N-10.   
: c. Plant Specific Class 1E components list - FSAR Table 3.11-1.   
: c. Plant Specific Class 1E components list - FSAR Table 3.11-1.   
: d. Other safety related mechanical components - FSAR Sections 3.2N and 3.9N. 2. The environmental qualification of Class I electrical equipment is in accordance with the USNRC Commissioners' memorandum and order CLI-80-21. 3. Preparation and submittal of information pertaining to environmental qualification of mechanical equipment is pending USNRC rule making.
: d. Other safety related mechanical components - FSAR Sections 3.2N and 3.9N.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   30 of 93 SRP NO. 4.5.1  
: 2. The environmental qualification of Class I electrical equipment is in accordance with the USNRC Commissioners'  
 
memorandum and order CLI-80-21.  
: 3. Preparation and submittal of information pertaining to environmental qualification of mechanical equipment is pending USNRC rule making.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 30 of 93 SRP NO. 4.5.1  
 
TITLE: CONTROL ROD DRIVE STRUCTURAL MATERIALS DIFFERENCES FROM THE SRP:
 
Cleaning and cleanliness controls differ slightly from SRP 4.5.1. Alternatives are also taken to Regulatory Guides 1.31
 
and 1.44.
REMARKS:


TITLE: CONTROL ROD DRIVE STRUCTURAL MATERIALS  DIFFERENCES FROM THE SRP:
FSAR Section 1.8 provides a discussion of cleaning and cleanliness controls used at BVPS-2. Although these controls differ from Regulatory Guide 1.37 guidelines, they are in accordance with the requirements of GDC 1.  
Cleaning and cleanliness controls differ slightly from SRP 4.5.1. Alternatives are also taken to Regulatory Guides 1.31 and 1.44. REMARKS:
 
FSAR Section 1.8 provides a discussion of cleaning and cleanliness controls used at BVPS-2. Although these controls differ from Regulatory Guide 1.37 guidelines, they are in accordance with the requirements of GDC 1.
For the BVPS-2 position on Regulatory Guides 1.31 and 1.44, refer to FSAR Section 1.8.  
For the BVPS-2 position on Regulatory Guides 1.31 and 1.44, refer to FSAR Section 1.8.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   30a of 93 SRP No. 4.5.2  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 30a of 93 SRP No. 4.5.2  
 
TITLE: REACTOR INTERNAL AND CORE SUPPORT MATERIALS
 
DIFFERENCE FROM THE SRP:


TITLE: REACTOR INTERNAL AND CORE SUPPORT MATERIALS DIFFERENCE FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.31 and 1.44.
BVPS-2 takes some alternatives to Regulatory Guides 1.31 and 1.44.
REMARKS:
For the BVPS-2 position on these Regulatory Guides, refer to
FSAR Section 1.8.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 31 of 93 SRP NO. 5.2.1.1
TITLE: COMPLIANCE WITH THE CODES AND STANDARD RULE, 10 CFR 50.55a DIFFERENCES FROM THE SRP:
BVPS-2 uses the safety classification system provided in ANSI N18.2 as an acceptable alternative to the Regulatory Guide 1.26 quality group classification system.
REMARKS:
REMARKS:
For the BVPS-2 position on these Regulatory Guides, refer to FSAR Section 1.8.
The ANS classification system implemented for BVPS-2 has been
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  31 of 93 SRP NO. 5.2.1.1


TITLE: COMPLIANCE WITH THE CODES AND STANDARD RULE, 10 CFR 50.55a DIFFERENCES FROM THE SRP:  BVPS-2 uses the safety classification system provided in ANSI N18.2 as an acceptable alternative to the Regulatory Guide 1.26 quality group classification system.
endorsed by industry as an alternative accepted by the USNRC for many other plants. This classification system meets the relevant requirements of GDC 1 and 10 CFR 50.55a.  
REMARKS:  The ANS classification system implemented for BVPS-2 has been endorsed by industry as an alternative accepted by the USNRC for many other plants. This classification system meets the relevant requirements of GDC 1 and 10 CFR 50.55a.  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   32 of 93 SRP NO. 5.2.1.2  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 32 of 93 SRP NO. 5.2.1.2  
 
TITLE: APPLICABLE CODE CASES DIFFERENCES FROM THE SRP:
 
Code cases other than those endorsed by Regulatory Guides 1.84, 1.85, and 1.147 may be used at BVPS-2.
 
REMARKS:


TITLE: APPLICABLE CODE CASES  DIFFERENCES FROM THE SRP:
Code cases other than those endorsed by Regulatory Guides 1.84, 1.85, and 1.147 may be used at BVPS-2.
REMARKS:
Code cases not endorsed by the regulatory guides will be limited to those for which USNRC acceptance has been obtained, otherwise assured, or as discussed in FSAR Section 1.8.  
Code cases not endorsed by the regulatory guides will be limited to those for which USNRC acceptance has been obtained, otherwise assured, or as discussed in FSAR Section 1.8.  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   33 of 93 SRP NO. 5.2.2  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 33 of 93 SRP NO. 5.2.2  
 
TITLE: OVERPRESSURE PROTECTION DIFFERENCES FROM THE SRP:
 
NUREG-0737, Items II.D.1 and II.D.3, are not discussed in FSAR Section 5.2.2.
 
REMARKS:


TITLE: OVERPRESSURE PROTECTION  DIFFERENCES FROM THE SRP:
This material is discussed in Section 1.10.  
NUREG-0737, Items II.D.1 and II.D.3, are not discussed in FSAR Section 5.2.2.
 
REMARKS:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 34 of 93 SRP NO. 5.2.3  
This material is discussed in Section 1.10.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   34 of 93 SRP NO. 5.2.3  
TITLE: REACTOR COOLANT PRESSURE BOUNDARY MATERIALS
 
DIFFERENCES FROM THE SRP:
 
BVPS-2 takes some alternatives to Regulatory Guides 1.31, 1.36, 1.37, 1.43, 1.44, 1.50 and 1.71.
 
REMARKS:


TITLE: REACTOR COOLANT PRESSURE BOUNDARY MATERIALS DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.31, 1.36, 1.37, 1.43, 1.44, 1.50 and 1.71.
REMARKS:
The BVPS-2 position on these Regulatory Guides is discussed in FSAR Section 1.8.  
The BVPS-2 position on these Regulatory Guides is discussed in FSAR Section 1.8.  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   34a of 93 SRP NO. 5.2.5  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 34a of 93 SRP NO. 5.2.5  
 
TITLE: REACTOR COOLANT PRESSURE BOUNDARY LEAKAGE DETECTION DIFFERENCES FROM THE SRP:
 
BVPS-2 does not fully follow the guidelines of Regulatory Guide 1.45, Position C.6 in that the containment sump level detection systems, which meet the detection sensitivity requirements of normal plant operation (that is, 1 gpm in 1 hour), are not designed to meet seismic requirements.
 
REMARKS:


TITLE: REACTOR COOLANT PRESSURE BOUNDARY LEAKAGE DETECTION  DIFFERENCES FROM THE SRP:
BVPS-2 does not fully follow the guidelines of Regulatory Guide 1.45, Position C.6 in that the containment sump level detection systems, which meet the detection sensitivity requirements of normal plant operation (that is, 1 gpm in 1 hour), are not designed to meet seismic requirements.
REMARKS:
Seismically qualified redundant level instrumentation, powered from Class lE electrical buses, is provided to monitor the containment sump level for excessive leakage following seismic events. The instrumentation is qualified for seismic loads up to SSE loads. Although a sensitivity of 1 gpm in 1 hour is not achieved, narrow range instruments are provided with an accuracy of 1.7 inches. The airborne particulate radiation monitoring system is seismically designed for SSE loads and detects a leakage rate of one gpm in less than one hour. The combination of these two types of instruments satisfies the relevant requirements of GDCS 2 and 30.  
Seismically qualified redundant level instrumentation, powered from Class lE electrical buses, is provided to monitor the containment sump level for excessive leakage following seismic events. The instrumentation is qualified for seismic loads up to SSE loads. Although a sensitivity of 1 gpm in 1 hour is not achieved, narrow range instruments are provided with an accuracy of 1.7 inches. The airborne particulate radiation monitoring system is seismically designed for SSE loads and detects a leakage rate of one gpm in less than one hour. The combination of these two types of instruments satisfies the relevant requirements of GDCS 2 and 30.  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   35 of 93 SRP NO. 5.3.1  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 35 of 93 SRP NO. 5.3.1  
 
TITLE: REACTOR VESSEL MATERIALS DIFFERENCES FROM THE SRP:
 
BVPS-2 takes some alternatives to Regulatory Guides 1.31, 1.37, 1.43, 1.44, 1.50, and 1.65.
 
REMARKS:


TITLE: REACTOR VESSEL MATERIALS DIFFERENCES FROM THE SRP:
The BVPS-2 positions on these regulatory guides are discussed in FSAR Section 1.8.
BVPS-2 takes some alternatives to Regulatory Guides 1.31, 1.37, 1.43, 1.44, 1.50, and 1.65.
 
REMARKS:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 36 of 93 SRP NO. 5.4.1.1
The BVPS-2 positions on these regulatory guides are discussed in FSAR Section 1.8.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   36 of 93 SRP NO. 5.4.1.1
TITLE: PUMP FLYWHEEL INTEGRITY (PWR)
DIFFERENCES FROM THE SRP:
 
The reactor coolant pump flywheel integrity is not completely addressed in FSAR Section 5.4.1.1.
 
REMARKS:
 
The pump flywheel integrity is addressed in FSAR Sections 5.4.11 through 5.4.1.5 and Section 1.8.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 37 of 93 SRP NO. 5.4.2.1
 
TITLE: STEAM GENERATOR MATERIALS DIFFERENCES FROM THE SRP:  
: 1. Specific details of the secondary side chemistry program are not discussed in FSAR Section 5.4.2.1.
: 2. The SRP states that the steam generators should be visually inspected to be in a "metal clean" surface condition before start-up.
: 3. The SRP states that access for tooling to remove sludge by lancing from the tube support plates should be provided.
 
REMARKS:
: 1. The secondary side water chemistry program at BVPS-2 will follow the guidance of Westinghouse document SIP 5-4.
: 2. The lay-up procedure for steam generators during the time after removal from site storage for installation in containment and after installation is described in the Westinghouse document "NSSS Component Receiving and Storage Guidelines" specifically procedure SGE-32001, "Environmental
 
Protection of Steam Generators During Site Installation and the Period  Initially Preceding Water Fill."  (During on-site storage the steam generator is sealed and pressurized
 
in a nitrogen atmosphere to inhibit corrosion.)
Procedure SGE-32001 states that  "light rust film may be present and shall not, by itself, be cause for further cleaning."  Adherence to SGE-32001 will minimize the potential for a significant amount of corrosion to occur in the steam generator during the remainder of site construction. Procedure SGE-32001 is stringent enough to provide adequate protection from significant corrosion during this layup period. A small amount of corrosion product (oxide) retards further corrosion by acting as a barrier to continued corrosion attack.
: 3. Historically, tube lancing from tube support plates has not been performed. Sludge filters down through flow slots and flow holes in the support plates  to accumulate at low flow areas on the top of the tube sheet. There are two techniques used to remove sludge from the top of the tube
 
sheet. During normal operation, utilization of the steam generator blowdown system will remove a portion of the accumulating sludge. During shutdowns, sludge lancing can be employed to remove sludge not removed by normal blowdown. Removal of sludge from the tubesheet is therefore more efficient than sludge removal from the tube support plates
 
would be.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 38 of 93 SRP NO. 5.4.7
 
TITLE: RESIDUAL HEAT REMOVAL (RHR) SYSTEM DIFFERENCES FROM THE SRP:
: 1. Task action plan items II.E.3.2 and II.E.3.3 of NUREG-0660 are not discussed.
: 2. Task action plan item III.D.1.1 of NUREG-0737 is not discussed in FSAR Section 5.4.7.
REMARKS:  
: 1. Since Office of Nuclear Reactor Regulation (NRR) studies regarding these items are incomplete, they need not be
 
addressed.
: 2. Item III.D.1.1 has no basis in the requirements specified in this SRP. It is, however, discussed in FSAR Section 1.10.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 39 of 93 SRP NO. 5.4.12


TITLE: PUMP FLYWHEEL INTEGRITY (PWR)  DIFFERENCES FROM THE SRP:
TITLE: REACTOR COOLANT SYSTEM HIGH POINT VENTS DIFFERENCES FROM THE SRP:  
The reactor coolant pump flywheel integrity is not completely addressed in FSAR Section 5.4.1.1.
: 1. The reactor coolant system high point vents are not discussed in FSAR Section 5.4.12.  
REMARKS:
: 2. The one-inch pipe LOCA is larger than a leak.  
The pump flywheel integrity is addressed in FSAR Sections 5.4.11 through 5.4.1.5 and Section 1.8.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  37 of 93 SRP NO. 5.4.2.1


TITLE: STEAM GENERATOR MATERIALS  DIFFERENCES FROM THE SRP:
: 1. Specific details of the secondary side chemistry program are not discussed in FSAR Section 5.4.2.1. 
: 2. The SRP states that the steam generators should be visually inspected to be in a "metal clean" surface condition before start-up. 
: 3. The SRP states that access for tooling to remove sludge by lancing from the tube support plates should be provided.
REMARKS:  
REMARKS:  
: 1. The secondary side water chemistry program at BVPS-2 will follow the guidance of Westinghouse document SIP 5-4.
: 1. The vents are discussed in FSAR Section 5.4.15, in accordance with the format of Regulatory Guide 1.70.  
: 2. The lay-up procedure for steam generators during the time after removal from site storage for installation in containment and after installation is described in the Westinghouse document "NSSS Component Receiving and Storage Guidelines" specifically procedure SGE-32001, "Environmental Protection of Steam Generators During Site Installation and the Period  Initially Preceding Water Fill."  (During on-site storage the steam generator is sealed and pressurized in a nitrogen atmosphere to inhibit corrosion.)  Procedure SGE-32001 states that  "light rust film may be present and shall not, by itself, be cause for further cleaning." Adherence to SGE-32001 will minimize the potential for a significant amount of corrosion to occur in the steam generator during the remainder of site construction. Procedure SGE-32001 is stringent enough to provide adequate protection from significant corrosion during this layup period. A small amount of corrosion product (oxide) retards further corrosion by acting as a barrier to continued corrosion attack.
: 2. This line is necessary for letdown in the cold shutdown scenario, as discussed in FSAR Appendix 5A.  
: 3. Historically, tube lancing from tube support plates has not been performed. Sludge filters down through flow slots and flow holes in the support plates  to accumulate at low flow areas on the top of the tube sheet. There are two techniques used to remove sludge from the top of the tube sheet. During normal operation, utilization of the steam generator blowdown system will remove a portion of the accumulating sludge. During shutdowns, sludge lancing can be employed to remove sludge not removed by normal blowdown. Removal of sludge from the tubesheet is therefore more efficient than sludge removal from the tube support plates would be.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  38 of 93 SRP NO. 5.4.7


TITLE: RESIDUAL HEAT REMOVAL (RHR) SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 40 of 93 SRP NO. 6.1.1
: 1. Task action plan items II.E.3.2 and II.E.3.3 of NUREG-0660 are not discussed. 
: 2. Task action plan item III.D.1.1 of NUREG-0737 is not discussed in FSAR Section 5.4.7. REMARKS: 
: 1. Since Office of Nuclear Reactor Regulation (NRR) studies regarding these items are incomplete, they need not be addressed. 2. Item III.D.1.1 has no basis in the requirements specified in this SRP. It is, however, discussed in FSAR Section 1.10.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   39 of 93 SRP NO. 5.4.12


TITLE: REACTOR COOLANT SYSTEM HIGH POINT VENTS  DIFFERENCES FROM THE SRP:  
TITLE: ENGINEERED SAFETY FEATURES MATERIALS DIFFERENCES FROM THE SRP:  
: 1. The reactor coolant system high point vents are not discussed in FSAR Section 5.4.12. 
: 1. The recommendations of ASME Section III, Appendix D, Article D-1000 was not required.  
: 2. The one-inch pipe LOCA is larger than a leak.
: 2. Moisture control on low hy drogen welding materials used for shop welding fabrication was not required to conform to both ASME Section III and AWSD1.1.  
REMARKS:  1. The vents are discussed in FSAR Section 5.4.15, in accordance with the format of Regulatory Guide 1.70. 
: 3. BVPS-2 takes some alternatives to Regulatory Guides 1.44, 1.54, and 1.71.  
: 2. This line is  necessary for letdown in the cold shutdown scenario, as discussed in FSAR Appendix 5A.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  40 of 93 SRP NO. 6.1.1


TITLE: ENGINEERED SAFETY FEATURES MATERIALS  DIFFERENCES FROM THE SRP:
: 1. The recommendations of ASME Section III, Appendix D, Article D-1000 was not required. 
: 2. Moisture control on low hydrogen welding materials used for shop welding fabrication was not required to conform to both ASME Section III and AWSD1.1. 
: 3. BVPS-2 takes some alternatives to Regulatory Guides 1.44, 1.54, and 1.71.
REMARKS:  
REMARKS:  
: 1. Welding preheat was specified in accordance with ASME Sections III and IX with the additional provisions of Regulatory Guide 1.50 as discussed in FSAR Section 1.8. It was determined that either subsequent post-weld heat treatment or final nondestructive examination in accordance with ASME Section III provides adequate assurance of weld quality.  
: 1. Welding preheat was specified in accordance with ASME Sections III and IX with the additional provisions of Regulatory Guide 1.50 as discussed in FSAR Section 1.8.
: 2. The requirements of either ASME, Section III, or AWSD.1.1, and the applicable code, Section II, SFA filler material specifications were met for shop fabrications.
It was determined that either subsequent post-weld heat treatment or final nondestructive examination in accordance with ASME Section III provides adequate assurance of weld quality.  
: 2. The requirements of either ASME, Section III, or AWSD.1.1, and the applicable code, Section II, SFA filler material  
 
specifications were met for shop fabrications.  
: 3. Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
: 3. Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   41 of 93 SRP NO. 6.2.1.1.A  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 41 of 93 SRP NO. 6.2.1.1.A  


TITLE: PWR DRY CONTAINMENTS, INCLUDING SUBATMOSPHERIC CONTAINMENTS DIFFERENCES FROM THE SRP: 1. SRP 6.2.1.1.A, paragraph II.g, states that instrumentation capable of operating in the post-accident environment should be provided to monitor containment atmosphere temperature and sump water temperature. 2. SRP 6.2.1.1.A, paragraph II.F states, that adequate margin above the maximum expected external pressure should be provided. This margin was not addressed in the FSAR.
TITLE: PWR DRY CONTAINMENTS, INCLUDING SUBATMOSPHERIC CONTAINMENTS  
 
DIFFERENCES FROM THE SRP:  
: 1. SRP 6.2.1.1.A, paragraph II.g, states that instrumentation capable of operating in the post-accident environment should be provided to monitor containment atmosphere temperature and sump water temperature.  
: 2. SRP 6.2.1.1.A, paragraph II.F states, that adequate margin above the maximum expected external pressure should be provided. This margin was not addressed in the FSAR.
 
REMARKS:
: 1. These two types of post-accident monitors are not required in order to perform a diagnosis as specified by the emergency response guidelines. Attachments 4 and 5 of NUREG-0737, Item II.F.1 are not addressed in FSAR Section 6.2.1.1; they are addressed in Section 7.5.
: 2. Conservatism in the analysis provides for this margin.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 42 of 93 SRP NO. 6.2.1.3
 
TITLE: MASS AND ENERGY RELEASE ANALYSIS FOR POSTULATED LOSS-OF-COOLANT ACCIDENTS
 
DIFFERENCES FROM THE SRP:
SRP 6.2.1.3, paragraph II.B.3e, identifies an acceptable Westinghouse mass and energy release model (Ref. 18 of SRP 6.2.1) which was not used for BVPS-2.
 
REMARKS:
The Westinghouse mass and energy release model for containment
 
design is described in FSAR Sections 6.2.1.3.3, 6.2.1.3.4, 6.2.1.3.5, and 6.2.1.3.6. This model provides sufficient conservatism and satisfies GDC 50 requirements.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 43 of 93 SRP NO. 6.2.1.5
 
TITLE: MINIMUM CONTAINMENT PRESSURE ANALYSIS FOR EMERGENCY CORE COOLING SYSTEM PERFORMANCE CAPABILITY STUDIES
 
DIFFERENCES FROM THE SRP:
BTP 6-1, Section B.3b, recommends conservative condensing heat
 
transfer coefficients which differ from the Westinghouse model.
REMARKS:  
REMARKS:  
: 1. These two types of post-accident monitors are not required in order to perform a diagnosis as specified by the emergency response guidelines. Attachments 4 and 5 of NUREG-0737, Item II.F.1 are not addressed in FSAR Section 6.2.1.1; they are addressed in Section 7.5. 2. Conservatism in the analysis provides for this margin.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  42 of 93 SRP NO. 6.2.1.3


TITLE: MASS AND ENERGY RELEASE ANALYSIS FOR POSTULATED LOSS-OF-COOLANT ACCIDENTS DIFFERENCES FROM THE SRP: SRP 6.2.1.3, paragraph II.B.3e, identifies an acceptable Westinghouse mass and energy release model (Ref. 18 of SRP 6.2.1) which was not used for BVPS-2.
The Westinghouse evaluation model for ECCS minimum containment pressure as presented in Appendix A of WCAP-8339 (1974) satisfies the governing requirements and has been approved by the USNRC staff.  
REMARKS:  The Westinghouse mass and energy release model for containment design is described in FSAR Sections 6.2.1.3.3, 6.2.1.3.4, 6.2.1.3.5, and 6.2.1.3.6. This model provides sufficient conservatism and satisfies GDC 50 requirements.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 44 of 93 This page is intentionally left blank
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 45 of 93 SRP No. 6.2.4  
 
TITLE: CONTAINMENT ISOLATION SYSTEM DIFFERENCES FROM THE SRP:
 
Containment isolation arrangements which differ from the arrangements specified in the General Design Criteria of SRP


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  43 of 93 SRP NO. 6.2.1.5
6.2.4 are found in the following:
: 1. Emergency core cooling system safety injection lines.
: 2. Recirculation spray pump suction lines.
: 3. Containment vacuum pump and hydrogen recombine suction and discharge lines.
: 4. Containment depressurization.
: 5. Containment leakage monitoring.
: 6. Fuel transfer tube.
: 7. Main steam, steam generator blowdown, and feedwater penetrations.
: 8. Auxiliary feedwater.
: 9. Personnel air lock and equipment hatch.
: 10. Reactor coolant pump seal injection.  


TITLE: MINIMUM CONTAINMENT PRESSURE ANALYSIS FOR EMERGENCY CORE COOLING SYSTEM PERFORMANCE CAPABILITY STUDIES DIFFERENCES FROM THE SRP:  BTP 6-1, Section B.3b, recommends conservative condensing heat transfer coefficients which differ from the Westinghouse model. REMARKS:
REMARKS:
The Westinghouse evaluation model for ECCS minimum containment pressure as presented in Appendix A of WCAP-8339  (1974) satisfies the governing requirements and has been approved by the USNRC staff.
The containment isolation system (CIS) meets the intent of NUREG-0737, Item II.E.4.2 with regard to containment isolation dependability. The CIS is activated automatically when monitored system variables exceed pre-established set points. 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   44 of 93 This page is intentionally left blank BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   45 of 93 SRP No. 6.2.4
 
It is neither necessary nor desirable that every containment isolation valve close simultaneously upon a containment isolation signal. The plant design allows selected valves in the engineered safety features systems, which are essential to mitigate the effects of an accident, to remain in or move to their open position. These pre-selected valves are remote and
 
manually-operated from the main control room. Containment isolation arrangements which differ in some manner from the specific arrangements allowed by GDC 54, 55, 56, and 57 are
 
described in Section 6.2.4.2.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 46 of 93 This page is intentionally left blank.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 47 of 93 SRP NO. 6.3
 
TITLE: EMERGENCY CORE COOLING SYSTEM DIFFERENCES FROM THE SRP:
: 1. Task action plan item III.D.1.1 of NUREG-0737 is not discussed in FSAR Section 6.3.
: 2. Item II.K.3.10 of NUREG-0737 is not discussed in FSAR Section 6.3.
REMARKS:
: 1. Item III.D.1.1 has no basis in the underlying requirements for this SRP. It is, however, discussed in FSAR Section


TITLE: CONTAINMENT ISOLATION SYSTEM  DIFFERENCES FROM THE SRP:
1.10. 2. Item II.K.3.10 is addressed in Section 7.2  
Containment isolation arrangements which differ from the arrangements specified in the General Design Criteria of SRP 6.2.4 are found in the following:  1. Emergency core cooling system safety injection lines.  
: 2. Recirculation spray pump suction lines. 
: 3. Containment vacuum pump and hydrogen recombine suction and discharge lines. 
: 4. Containment depressurization. 5. Containment leakage monitoring.
: 6. Fuel transfer tube. 
: 7. Main steam, steam generator blowdown, and feedwater penetrations. 
: 8. Auxiliary feedwater. 9. Personnel air lock and equipment hatch.
: 10. Reactor coolant pump seal injection.
REMARKS:  The containment isolation system (CIS) meets the intent of NUREG-0737, Item II.E.4.2 with regard to containment isolation dependability. The CIS is activated automatically when monitored system variables exceed pre-established set points.
It is neither necessary nor desirable that every containment isolation valve close simultaneously upon a containment isolation signal. The plant design allows selected valves in the engineered safety features systems, which are essential to mitigate the effects of an accident, to remain in or move to their open position. These pre-selected valves are remote and manually-operated from the main control room. Containment isolation arrangements which differ in some manner from the specific arrangements allowed by GDC 54, 55, 56, and 57 are described in Section 6.2.4.2.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  46 of 93 This page is intentionally left blank.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  47 of 93 SRP NO. 6.3


TITLE: EMERGENCY CORE COOLING SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 5  TABLE 1.9-2 (Cont) 48 of 93 SRP NO. 6.4  
: 1. Task action plan item III.D.1.1 of NUREG-0737 is not discussed in FSAR Section 6.3. 
: 2. Item II.K.3.10 of NUREG-0737 is not discussed in FSAR Section 6.3. REMARKS: 
: 1. Item III.D.1.1 has no basis in the underlying requirements for this SRP. It is, however, discussed in FSAR Section 1.10. 2. Item II.K.3.10 is addressed in Section 7.2 BVPS-2 UFSAR Rev. 5  TABLE 1.9-2 (Cont)   48 of 93 SRP NO. 6.4  


TITLE: CONTROL ROOM HABITABILITY SYSTEMS DIFFERENCES FROM THE SRP:  
TITLE: CONTROL ROOM HABITABILITY SYSTEMS DIFFERENCES FROM THE SRP:  
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.78 and 1.95.   
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.78 and 1.95.   
: 2. BVPS-2 takes some alternatives to Regulatory Guide 1.52.
: 2. BVPS-2 takes some alternatives to Regulatory Guide 1.52.  
: 3. BVPS-2 takes some alternatives to the x/Q methodology referenced in SRP 6.4.
: 3. BVPS-2 takes some alternatives to the x/Q methodology referenced in SRP 6.4.  
REMARKS: 1. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.78 and 1.95. The only toxic gas BVPS-2 will monitor is chlorine, based upon the results of the Control Room Habitability Study, described in FSAR Section 2.2.3.1.2. 
 
: 2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.52. 
REMARKS:  
: 3. Refer to UFSAR Section 2.3.4.3 for the x/Q methodology used in analyses performed after 1991. 
: 1. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.78 and 1.95. The only toxic gas BVPS-2 will monitor is chlorine, based upon the results of the Control Room Habitability Study, described in FSAR Section  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  49 of 93 SRP NO. 6.5.1
2.2.3.1.2.
: 2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.52.  
: 3. Refer to UFSAR Section 2.3.4.3 for the x/Q methodology used in analyses performed after 1991.  


TITLE: ESF ATMOSPHERE CLEANUP SYSTEMS DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 49 of 93 SRP NO. 6.5.1
BVPS-2 takes some alternatives to Regulatory Guide 1.52.
 
REMARKS:  Refer to FSAR Section 1.8 for the BVPS-2 position of Regulatory Guide 1.52.
TITLE: ESF ATMOSPHERE CLEANUP SYSTEMS DIFFERENCES FROM THE SRP:  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  50 of 93 SRP NO. 7.2
 
BVPS-2 takes some alternatives to Regulatory Guide 1.52.  


TITLE: REACTOR TRIP SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
REMARKS:
REMARKS:
Refer to FSAR Section 1.8 for the BVPS-2 position of Regulatory
Guide 1.52.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 50 of 93 SRP NO. 7.2
TITLE: REACTOR TRIP SYSTEM DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
REMARKS:
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   51 of 93 SRP NO. 7.3  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 51 of 93 SRP NO. 7.3  
 
TITLE: ENGINEERED SAFETY FEATURES SYSTEMS DIFFERENCES FROM THE SRP:
 
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
 
REMARKS:
 
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 52 of 93 SRP NO. 7.4
 
TITLE: SAFE SHUTDOWN SYSTEMS DIFFERENCES FROM THE SRP:
 
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
 
REMARKS:


TITLE: ENGINEERED SAFETY FEATURES SYSTEMS  DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
REMARKS:
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   52 of 93 SRP NO. 7.4
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 53 of 93 SRP NO. 7.5
 
TITLE: INFORMATION SYSTEMS IMPORTANT TO SAFETY DIFFERENCES FROM THE SRP:
 
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.75, 1.97, and 1.118.
 
REMARKS:


TITLE: SAFE SHUTDOWN SYSTEMS  DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
REMARKS:
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   53 of 93 SRP NO. 7.5
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 54 of 93 SRP NO. 7.6
 
TITLE: INTERLOCK SYSTEMS IMPORTANT TO SAFETY DIFFERENCES FROM THE SRP:
 
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
 
REMARKS:


TITLE: INFORMATION SYSTEMS IMPORTANT TO SAFETY  DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.75, 1.97, and 1.118.
REMARKS:
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   54 of 93 SRP NO. 7.6
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 55 of 93 SRP NO. 8A
 
TITLE: BRANCH TECHNICAL POSITIONS (PSB)
DIFFERENCES FROM THE SRP:
 
Branch Technical Position PSB-1, paragraph B.1:
 
Two separate time delays for the second level of undervoltage protection are not provided. The Class lE distribution system is not separated from offsite on safety injection signal and the load shedding feature is not reinstated once the transfer onto the diesel generator units has occurred.  


TITLE: INTERLOCK SYSTEMS IMPORTANT TO SAFETY  DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.
REMARKS:
REMARKS:
Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.
Two levels of undervoltage protection are provided. The first level detects the loss of power, isolates the emergency system from the normal system, starts the diesel generator, and begins load sequencing. The second level undervoltage scheme detects a
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  55 of 93 SRP NO. 8A
 
degraded voltage condition and, if this condition does not improve within one minute, isolates the emergency system from the normal system, starts the diesel generator, and begins
 
sequencing.
Both of these levels of protection utilize sequential logic from different potential transformers and relays at both the 480 volt and 4,160 volt systems.  
 
The two schemes described satisfy all the safety functions required to assure the protection and safe shutdown of the station.  
 
Branch Technical Position, ICSB 18:


TITLE: BRANCH TECHNICAL POSITIONS (PSB)  DIFFERENCES FROM THE SRP:
Branch Technical Position PSB-1, paragraph B.1:
Two separate time delays for the second level of undervoltage protection are not provided. The Class lE distribution system is not separated from offsite on safety injection signal and the load shedding feature is not reinstated once the transfer onto the diesel generator units has occurred.
REMARKS:  Two levels of undervoltage protection are provided. The first level detects the loss of power, isolates the emergency system from the normal system, starts the diesel generator, and begins load sequencing. The second level undervoltage scheme detects a degraded voltage condition and, if this condition does not improve within one minute, isolates the emergency system from the normal system, starts the diesel generator, and begins sequencing. Both of these levels of protection utilize sequential logic from different potential transformers and relays at both the 480 volt and 4,160 volt systems.
The two schemes described satisfy all the safety functions required to assure the protection and safe shutdown of the station.
Branch Technical Position, ICSB 18:
Redundant position indication in the main control room is not provided for the hydrogen recombiner isolation valves 2HCS*MOV110A, B, 2HCS*MOV113A, B. All of these valves have their power supplies normally disconnected to avoid spurious opening during conditions when it is essential that they remain closed.
Redundant position indication in the main control room is not provided for the hydrogen recombiner isolation valves 2HCS*MOV110A, B, 2HCS*MOV113A, B. All of these valves have their power supplies normally disconnected to avoid spurious opening during conditions when it is essential that they remain closed.
REMARKS:
REMARKS:  
The hydrogen control system (HCS) valves are controlled from remote electrical control stations in the plant and are closed during  normal and post-accident operation. The only time these valves are intended to be open are for testing purposes during normal plant operation or if both hydrogen recombiners were to fail post-accident after the recombiners have been placed in operation. To ensure that spurious opening of the subject valves does not cause failure of the hydrogen BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   56 of 93 control system to perform its safety function in a post-accident condition, an administrative procedure will be implemented to require that the valve breakers are maintained de-energized during normal and post-accident modes of operation.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   56a of 93 SRP NO. 9.1.1  
The hydrogen control system (HCS) valves are controlled from remote electrical control stations in the plant and are closed during  normal and post-accident operation. The only time these  
 
valves are intended to be open are for testing purposes during normal plant operation or if both hydrogen recombiners were to fail post-accident after the recombiners have been placed in operation. To ensure that spurious opening of the subject valves does not cause failure of the hydrogen  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 56 of 93 control system to perform its safety function in a post-accident condition, an administrative procedure will be implemented to require that the valve breakers are maintained de-energized during normal and post-accident modes of operation.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 56a of 93 SRP NO. 9.1.1  
 
TITLE: NEW FUEL STORAGE DIFFERENCES FROM THE SRP:
 
The BVPS-2 design does not follow all the recommendations of ANS 57.1 and ANS 57.3.
 
REMARKS:
 
The ANS standards had not been issued at the time the BVPS-2 design was established.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 56b of 93 SRP No. 9.1.2


TITLE: NEW FUEL STORAGE DIFFERENCES FROM THE SRP:
TITLE: SPENT FUEL STORAGE  
The BVPS-2 design does not follow all the recommendations of ANS 57.1 and ANS 57.3.
REMARKS:
The ANS standards had not been issued at the time the BVPS-2 design was established. 


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  56b of 93 SRP No. 9.1.2
DIFFERENCES FROM THE SRP:


TITLE: SPENT FUEL STORAGE DIFFERENCES FROM THE SRP:
The BVPS-2 design does not follow all the recommendations of ANS 57.2.
The BVPS-2 design does not follow all the recommendations of ANS 57.2.
REMARKS:
REMARKS:  
The ANS standard had not been issued at the time the BVPS-2 design was established.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  57 of 93 SRP NO. 9.1.4
The ANS standard had not been issued at the time the BVPS-2  
 
design was established.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 57 of 93 SRP NO. 9.1.4
 
TITLE: LIGHT LOAD HANDLING SYSTEM (RELATED TO REFUELING)
DIFFERENCES FROM THE SRP:
: 1. Regulatory  Guide 1.13, paragraph C.3, states that an interlock should be provided to prevent cranes from passing over stored spent fuel when fuel handling is not in progress. The BVPS-2 motor-driven platform crane has, instead, an adjustable interlock which will stop hoist motion if a preset weight, based on the weight of a single fuel assembly, is exceeded.
: 2. The maximum potential kinetic energy capable of being developed by any load handled above stored spent fuel may, if dropped, exceed the kinetic energy of one fuel assembly and its associated handling tool when dropped from the height at which it is normally handled above the spent fuel storage racks.
: 3. The BVPS-2 design does not follow all the recommendations of ANS-57.1.
 
REMARKS:
: 1. Refer to Section 1.8 for the BVPS-2 position on Regulatory Guide 1.13.
: 2. An analysis has been performed to demonstrate that although the kinetic energy of a dropped tool exceeds that of a fuel assembly and its associated handling tool, there is no
 
adverse safety impact.
: 3. The ANS standard had not been issued at the time the BVPS-2 design was established.
 
BVPS-2 UFSAR Rev. 0   TABLE 1.9-2 (Cont) 58 of 93 SRP NO. 9.1.5
 
TITLE: OVERHEAD HEAVY LOAD HANDLING SYSTEMS DIFFERENCES FROM THE SRP:
: 1. SRP 9.1.5 suggests using NUREG-0554, "Single Failure Proof Cranes."  None of the cranes or monorails at BVPS-2 were designed to be single failure proof.
: 2. FSAR Section 9.1.5 does not follow the guidance of NUREG-0612 in the following areas.
: a. The design of special lifting devices at BVPS-2 did not follow ANSI N14.6-1978.
: b. Lifting devices of standard industry design should meet the ANSI B30.9-1971 standard.
: c. NUREG-0612 calls for safe load paths to be marked on floors and for safe load paths to follow structural floor members.
: d. NUREG-0612 states that if physical separation of safe shutdown equipment or a load drop analysis for a load falling through a floor is not provided, then cranes
 
must be upgraded to single failure proof.
: 3. The BVPS-2 design does not follow all the recommendations of ANS-57.1 and ANS-57.2
 
REMARKS:
: 1. NUREG-0554 was issued in 1979, which is after all BVPS-2 cranes and monorails were designed. Also, the NUREG does not make any specific references to being applicable to General Design Criteria 2, 4, 5, or 61. Duquesne Light Company (DLC) submitted a report, "Control of Heavy Loads,"
 
to the USNRC in 1982, which addresses the design criteria and operating procedures for the load handling systems at BVPS-2, which are two major concerns of NUREG-0554.
: 2. Administrative procedures to limit crane operations within the safe load paths are utilized to address items 2c and 2d. NUREG-0612 was issued in 1980, which is after all BVPS-2 cranes and monorails were designed. Also, the NUREG does not make any specific references to being applicable to General Design Criteria 2, 4, 5 or 61. The DLC, "Control of Heavy Loads," report examined BVPS-2 compliance with NUREG-0612. 3. The ANS standards had not been issued at the time the BVPS-2 design was established.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 59 of 93 SRP NO. 9.2.2
 
TITLE: REACTOR AUXILIARY COOLING WATER SYSTEMS DIFFERENCES FROM THE SRP:
: 1. BVPS-2 Reactor coolant pumps have not been demonstrated by testing to withstand a 20-minute loss of cooling water.
: 2. Primary component cooling water flow to the reactor coolant pumps is monitored by instrumentation which was designed and procured to standards other than IEEE 279.
 
REMARKS:
: 1. GDC 44 is cited by the SRP as a basis for the 20-minute acceptance criterion. GDC 44 is concerned with Provisions for transfer of heat from structures, systems and components important to safety to an ultimate heat sink and is unrelated to the length of time a reactor coolant pump can operate following loss of cooling water. Pumps similar to those used at BVPS-2 have been demonstrated to function for at least 10 minutes without cooling water.
: 2. Flow instrumentation is described in FSAR Section 9.2.2.1 and is normally supplied with power from an emergency bus.


TITLE: LIGHT LOAD HANDLING SYSTEM (RELATED TO REFUELING)  DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 60 of 93 SRP NO. 9.3.4
: 1. Regulatory  Guide 1.13, paragraph C.3, states that an interlock should be provided to prevent cranes from passing over stored spent fuel when fuel handling is not in progress. The BVPS-2 motor-driven platform crane has, instead, an adjustable interlock which will stop hoist motion if a preset weight, based on the weight of a single fuel assembly, is exceeded. 2. The maximum potential kinetic energy capable of being developed by any load handled above stored spent fuel may, if dropped, exceed the kinetic energy of one fuel assembly and its associated handling tool when dropped from the height at which it is normally handled above the spent fuel storage racks. 3. The BVPS-2 design does not follow all the recommendations of ANS-57.1.
REMARKS: 
: 1. Refer to Section 1.8 for the BVPS-2 position on Regulatory Guide 1.13. 
: 2. An analysis has been performed to demonstrate that although the kinetic energy of a dropped tool exceeds that of a fuel assembly and its associated handling tool, there is no adverse safety impact. 
: 3. The ANS standard had not been issued at the time the BVPS-2 design was established.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   58 of 93 SRP NO. 9.1.5


TITLE: OVERHEAD HEAVY LOAD HANDLING SYSTEMS  DIFFERENCES FROM THE SRP:
TITLE: CHEMICAL AND VOLUME CONTROL SYSTEM (PWR) (INCLUDING BORON RECOVERY SYSTEM)  
: 1. SRP 9.1.5 suggests using NUREG-0554, "Single Failure Proof Cranes."  None of the cranes or monorails at BVPS-2 were designed to be single failure proof. 
: 2. FSAR Section 9.1.5 does not follow the guidance of NUREG-0612 in the following areas. a. The design of special lifting devices at BVPS-2 did not follow ANSI N14.6-1978. 
: b. Lifting devices of standard industry design should meet the ANSI B30.9-1971 standard. 
: c. NUREG-0612 calls for safe load paths to be marked on floors and for safe load paths to follow structural floor members. d. NUREG-0612 states that if physical separation of safe shutdown equipment or a load drop analysis for a load falling through a floor is not provided, then cranes must be upgraded to single failure proof. 3. The BVPS-2 design does not follow all the recommendations of ANS-57.1 and ANS-57.2 REMARKS:
: 1. NUREG-0554 was issued in 1979, which is after all BVPS-2 cranes and monorails were designed. Also, the NUREG does not make any specific references to being applicable to General Design Criteria 2, 4, 5, or 61. Duquesne Light Company (DLC) submitted a report, "Control of Heavy Loads,"
to the USNRC in 1982, which addresses the design criteria and operating procedures for the load handling systems at BVPS-2, which are two major concerns of NUREG-0554. 2. Administrative procedures to limit crane operations within the safe load paths are utilized to address items 2c and 2d. NUREG-0612 was issued in 1980, which is after all BVPS-2 cranes and monorails were designed. Also, the NUREG does not make any specific references to being applicable to General Design Criteria 2, 4, 5 or 61. The DLC, "Control of Heavy Loads," report examined BVPS-2 compliance with NUREG-0612. 3. The ANS standards had not been issued at the time the BVPS-2 design was established.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   59 of 93 SRP NO. 9.2.2


TITLE: REACTOR AUXILIARY COOLING WATER SYSTEMS  DIFFERENCES FROM THE SRP:  
DIFFERENCES FROM THE SRP:
: 1. BVPS-2 Reactor coolant pumps have not been demonstrated by testing to withstand a 20-minute loss of cooling water.
Task action plan item III.D.1.1 of NUREG-0737 is not discussed
: 2. Primary component cooling water flow to the reactor coolant pumps is monitored by instrumentation which was designed and procured to standards other than IEEE 279.
 
in FSAR Section 9.3.4.
REMARKS:  
REMARKS:  
: 1. GDC 44 is cited by the SRP as a basis for the 20-minute acceptance criterion. GDC 44 is concerned with Provisions for transfer of heat from structures, systems and components important to safety to an ultimate heat sink and is unrelated to the length of time a reactor coolant pump can operate following loss of cooling water. Pumps similar to those used at BVPS-2 have been demonstrated to function for at least 10 minutes without cooling water. 2. Flow instrumentation is described in FSAR Section 9.2.2.1 and is normally supplied with power from an emergency bus.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  60 of 93 SRP NO. 9.3.4


TITLE: CHEMICAL AND VOLUME CONTROL SYSTEM (PWR) (INCLUDING BORON RECOVERY SYSTEM)
DIFFERENCES FROM THE SRP:  Task action plan item III.D.1.1 of NUREG-0737 is not discussed in FSAR Section 9.3.4. REMARKS:
Item III.D.1.1 has no basis in the requirements specified in this SRP. It is, however, discussed in FSAR Section 1.10.  
Item III.D.1.1 has no basis in the requirements specified in this SRP. It is, however, discussed in FSAR Section 1.10.  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   61 of 93 SRP NO. 9.4.1  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 61 of 93 SRP NO. 9.4.1  


TITLE: CONTROL ROOM AREA VENTILATION SYSTEM DIFFERENCES FROM THE SRP:  
TITLE: CONTROL ROOM AREA VENTILATION SYSTEM DIFFERENCES FROM THE SRP:  
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.78 and 1.95.   
: 1. BVPS-2 takes some alternatives to Regulatory Guides 1.78 and 1.95.   
: 2. BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140. REMARKS:
: 2. BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140. REMARKS:  
: 1. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.78 and 1.95. The only toxic gas BVPS-2 will monitor is chlorine, based upon the results of the Control Room Habitability Study, described in FSAR Section 2.2.3.1.2. 2. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.52 and 1.140.
: 1. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.78 and 1.95. The only toxic gas BVPS-2 will monitor is chlorine, based upon the results of the Control Room Habitability Study, described in FSAR Section 2.2.3.1.2.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   62 of 93 SRP NO. 9.4.2  
: 2. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.52 and 1.140.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 62 of 93 SRP NO. 9.4.2  
 
TITLE: SPENT FUEL POOL AREA VENTILATION SYSTEM DIFFERENCES FROM THE SRP:


TITLE: SPENT FUEL POOL AREA VENTILATION SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140.
BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140.
REMARKS:
Refer to regulatory guide positions in Section 1.8 of the FSAR.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 63 of 93 SRP NO. 9.4.3
TITLE: AUXILIARY AND RADWASTE AREA VENTILATION SYSTEM DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guide 1.140.
REMARKS:
REMARKS:
Refer to regulatory guide positions in Section 1.8 of the FSAR.
Refer to regulatory guide positions in Section 1.8 of the FSAR.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  63 of 93 SRP NO. 9.4.3


TITLE: AUXILIARY AND RADWASTE AREA VENTILATION SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 64 of 93 SRP NO. 9.4.5
BVPS-2 takes some alternatives to Regulatory Guide 1.140.
REMARKS:  Refer to regulatory guide positions in Section 1.8 of the FSAR.  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  64 of 93 SRP NO. 9.4.5
TITLE: ENGINEERED SAFETY FEATURE VENTILATION SYSTEM DIFFERENCES FROM THE SRP:


TITLE: ENGINEERED SAFETY FEATURE VENTILATION SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140.
BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140.
REMARKS:
Refer to regulatory guide positions in Section 1.8 of the FSAR.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 65 of 93 SRP NO. 9.5.1
TITLE: FIRE PROTECTION PROGRAM DIFFERENCES FROM THE SRP:
BVPS-2 takes alternatives to the guidance provided in Branch Technical Position CMEB 9.5-1. These alternatives and the associated justifications are provided in Appendix 9.5A (Section 9.5A.2).
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 66 of 93 SRP 9.5.4
TITLE: EMERGENCY DIESEL ENGINE FUEL OIL STORAGE AND TRANSFER SYSTEM DIFFERENCES FROM THE SRP:
: 1. BVPS-2 takes an alternative to Regulatory Guide 1.137.
: 2. The fill lines to the diesel generator fuel oil tanks are not tornado protected.
: 3. There are no tank design features which minimize the creation of turbulence of the accumulated residual sediments.
REMARKS:
: 1. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.137.
: 2. Alternate methods of filling the fuel oil tank are provided through the sample connection or the vent flame arrestor connection which are located in a missile protected area.
: 3. The admission of deleterious material is prohibited by strainers in the fuel oil tank fill line. Strainers are also provided on the fuel oil transfer pump discharge, and a duplex filter is provided on the emergency diesel generator
set.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 67 of 93 SRP NO. 9.5.6
TITLE: EMERGENCY DIESEL ENGINE STARTING SYSTEM DIFFERENCES FROM THE SRP:
BVPS-2 does not rely on air dryers in the diesel generator air starting system to assure adequate dehydration.
REMARKS:
Accumulated moisture will be removed from the starting system by blowdown of the air receivers at regular intervals. Blowdown will be ensured by implementing administrative controls such as
operating surveillance tests and will satisfy the relevant requirements of GDC 17.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 68 of 93 SRP NO. 10.4.3
TITLE: TURBINE GLAND SEALING SYSTEM DIFFERENCES FROM THE SRP:
BVPS-2 takes some alternatives to Regulatory Guide 1.26.
REMARKS:
REMARKS:
Refer to regulatory guide positions in Section 1.8 of the FSAR.
Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  65 of 93 SRP NO. 9.5.1  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 69 of 93 SRP NO. 10.4.6
 
TITLE: CONDENSATE CLEANUP SYSTEM DIFFERENCES FROM THE SRP:
 
Specific details of the secondary side chemistry program are not discussed in FSAR Section 10.4.6.
 
REMARKS:
 
The secondary side water chemistry program at BVPS-2 will follow the guidance of Westinghouse document SIP 5-4.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 70 of 93 SRP NO. 10.4.7
 
TITLE: CONDENSATE AND FEEDWATER SYSTEM DIFFERENCES FROM THE SRP:
 
FSAR Section 10.4.7 does not specify provisions for start-up feedwater hammer testing per BTB ASB 10-2, Item 3.
 
REMARKS:
 
The system is adequately protected against damaging feedwater hammer by the feeding J-tube design, coupled with the elbow arrangement at the feedwater piping connection. Therefore, no
 
testing is necessary.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 71 of 93 SRP NO. 10.4.8  
 
TITLE: STEAM GENERATOR BLOWDOWN SYSTEM (PWR)
DIFFERENCES FROM THE SRP:
 
The system does not follow the guidance of Regulatory Guide 1.143, paragraph C.1 with respect to the turbine building
 
seismic criteria.
REMARKS:
 
Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.143. Although the system differs from the SRP acceptance criteria, its design meets the requirements of GDC 1, 2, and 14.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 72 of 93 SRP NO. 11.1
 
TITLE: SOURCE TERMS DIFFERENCES FROM THE SRP:
: 1. SRP 11.1, paragraph II.a suggests that a cost-benefit analysis be performed in accordance with Regulatory Guide 1.110 for the radioactive waste management systems and equipment.
: 2. BVPS-2 takes some alternatives to Regulatory Guide 1.140.
REMARKS:
: 1. BVPS-2 received a construction permit prior to June 4, 1976, the effective date of the cost-benefit analysis requirement. The radwaste systems and equipment described in the FSAR satisfy the regulatory position in Docket RM-50-2, which is reproduced in the Annex to Appendix I to 10 CFR 50.
: 2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.140.
 
BVPS-2 UFSAR Rev. 0   TABLE 1.9-2 (Cont) 73 of 93 SRP NO. 11.2
 
TITLE: LIQUID WASTE MANAGEMENT SYSTEMS DIFFERENCES FROM THE SRP:
: 1. BVPS-2 systems that contain provisions to control leakage and facilitate operation and maintenance meet Regulatory Guide 1.143 with some alternatives.
 
2a. SRP 11.2, paragraph II.1.a, provides only the "per unit" limits for determining compliance with 10 CFR 50, Appendix I. 2b. SRP 11.2, paragraph II.1.b, suggests that the applicant consider refinements to liquid radwaste treatment systems and performed a cost-benefit analysis in accordance with
 
Regulatory Guide 1.110: liquid radwaste treatment systems should include all items of the system sequentially and in order of diminishing cost-benefit return, which can (for a favorable cost-benefit ratio) effect reductions in dose to the population reasonably expected to be within 50 miles of the reactor. This cost-benefit analysis has not been
 
performed.
 
REMARKS:
: 1. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.143.
2a. Analysis for BVPS-2 has been performed on a "per site" basis and resultant doses are within the RM-50-2 design limits and, therefore, is in compliance with 10 CFR 50, Appendix I.
 
2b. The cost-benefit analysis is not applicable for applicants for construction permits which were docketed on or after January 2, 1971, and prior to June 4, 1976, if the radwaste systems and equipment described in the preliminary or final safety analysis report and amendments thereto satisfy the Guides on Design Objectives for Light-Water-Cooled Nuclear Power Reactors proposed in the Concluding Statement of Position of the Regulatory Staff in Docket-RM-50-2 dated February 20, 1974, pp. 25-30.
BVPS-2 received its construction permit prior to the requirement for cost-benefit analyses of radwaste treatment systems. Duquesne Light Company was given the option by the USNRC of performing the cost-benefit analyses, but chose not to perform the analyses due to the stage of system design.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 74 of 93 SRP NO. 11.3
 
TITLE: GASEOUS WASTE MANAGEMENT SYSTEMS DIFFERENCES FROM THE SRP:
: 1. SRP 11.3, paragraph II.B.1.c, requires the gaseous radwaste treatment systems to include all items of reasonably demonstrated technology that when added to the system sequentially and in order of diminishing cost-benefit return, can (for a favorable cost-benefit ratio) effect reductions in dose to the population reasonably expected to be within 50 miles of the reactor. This cost-benefit analysis has not been performed.
: 2. SRP 11.3, paragraph II.B.4, requires system designs that contain provisions to control leakage and to facilitate operation and maintenance in accordance with the guidelines of Regulatory Guide 1.143. BVPS-2 meets Regulatory Guide 1.143 with the following exceptions:
: a. Paragraph C.2.1.1
 
The gaseous waste system meets or exceeds the codes in Table 1. The gaseous waste delay beds, gaseous waste surge tank, and the overhead compressors have been purchased as ASME III. The waste gas chillers, piping, and valves are ANSI B31.1.
: b. Paragraph C.4.3 The piping downstream of the overhead gas compressor discharge lines are 1/2 inch, whereas the guide suggests that process lines should not be less than 3/4 inch (nominal).
: 3. SRP 11.3, paragraph II.B.6.b, requires two independent gas analyzers continuously operating and providing two
 
independent measurements verifying that hydrogen and/or oxygen are not present in potentially explosive concentrations. The two oxygen analyzers do not measure
 
independent locations.
: 4. The SRP provides only the "per unit" limits for determining compliance with 10 CFR 50, Appendix I.
: 5. The design case concentrations for gaseous effluents from the ventilation vent exceed the limits of 10 CFR 20, Appendix B, Table II, Column 1, for five nuclides assuming the design basis ventilation rate is used.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 75 of 93 REMARKS:
: 1. BVPS-2 received a construction permit prior to June 4, 1976, the date that the requirement for the cost-benefit analysis became effective. The radwaste systems and equipment described in the FSAR satisfy the regulatory position in Docket RM-50-2 which is reproduced in the Annex to Appendix I. 2. The FSAR addresses ETSB 11-1.
: a. The waste gas chillers are a pipe-within-a-pipe heat exchanger designed and fabricated in accordance with ANSI B.31.1. The charcoal delay bed vessels and the gaseous waste surge tank are designed and fabricated to ASME III, a design which is superior to the specified ASME VIII. The overhead gas compressors are designed and fabricated to ASME III, a design which is superior to the specified manufacturer's standard.
: b. The overhead gas compressor prefilters provide a clean gas downstream where the lines are 1/2 inch. Pressure
 
drop is not a problem in the 1/2 inch lines downstream


TITLE: FIRE PROTECTION PROGRAM  DIFFERENCES FROM THE SRP:
of the overhead gas compressors.  
BVPS-2 takes alternatives to the guidance provided in Branch Technical Position CMEB 9.5-1. These alternatives and the associated justifications are provided in Appendix 9.5A (Section 9.5A.2).
: 3. The two oxygen analyzers are downstream of the overhead gas compressors with the most likely leakage point being the suction of the compressors.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  66 of 93 SRP 9.5.4
: 4. Analysis for BVPS-2 has been performed on a "per site" basis and resultant doses are within the RM-50-2 design limits.


TITLE: EMERGENCY DIESEL ENGINE FUEL OIL STORAGE AND TRANSFER SYSTEM DIFFERENCES FROM THE SRP:  1. BVPS-2 takes an alternative to Regulatory Guide 1.137.  
It is, therefore, in compliance with 10 CFR 50, Appendix I.
: 2. The fill lines to the diesel generator fuel oil tanks are not tornado protected. 3. There are no tank design features which minimize the creation of turbulence of the accumulated residual sediments.
: 5. Controlled releases will be imposed so as not to exceed the concentration limits of 10 CFR 20, Appendix B, Table II, Column 1.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 76 of 93 SRP NO. 11.4
 
TITLE: SOLID WASTE MANAGEMENT SYSTEMS DIFFERENCES FROM THE SRP:  
: 1. SRP 11.4, paragraphs II.2 and II.3, suggest a description of the methods for solidification, the solidifying agent used, and a process control program to ensure a solid matrix. A process control program has not been submitted by the system vendor but has been discussed for BVPS-2.  
: 2. Regulatory Guide 1.143 suggest 0-15 psig tanks to be designed and fabricated to ASME III, Class 3 or, API 650. The spent resin holding tank and the decanting tank are designed and fabricated to ASME VIII, Division 1.
REMARKS:  
REMARKS:  
: 1. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.137.
: 1. The FSAR states that a process control program is needed to verify the absence of free liquid in the containers. The required program will be written prior to the completion of the environmental radiological Technical Specification.
: 2. Alternate methods of filling the fuel oil tank are provided through the sample connection or the vent flame arrestor connection which are located in a missile protected area.   
: 2. The deviation of the design and fabrication of the spent resin holding tank and the decanting tank from the requirements of  Regulatory Guide 1.143 is due to the geometry of the two tanks. The fabrication codes specified (ASME III, Class 3 or API 650) do not specifically cover tanks of this type, that is, vessel-type nonflat bottom atmospheric tanks. As such, these tanks have been constructed in accordance with ASME VIII, Division 1, which
: 3. The admission of deleterious material is prohibited by strainers in the fuel oil tank fill line. Strainers are also provided on the fuel oil transfer pump discharge, and a duplex filter is provided on the emergency diesel generator set.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   67 of 93 SRP NO. 9.5.6
is more stringent than API 650, thus indicating that the SRP requirements are more than adequately addressed. Exception to ASME VIII, Division 1 requirements are:
: a. The vessels are not stamped.
: b. Radiography of welds is not required.
: c. A water fill leak test in accordance with API-650 is substituted for a hydrostatic test at 1.5 times design pressure.
These tanks were designed and fabricated prior to issuance of NUREG-0800.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 77 of 93 SRP NO. 11.5
 
TITLE: PROCESS AND EFFLUENT RADIOLOGICAL MONITORING INSTRUMENTATION AND SAMPLING SYSTEMS
 
DIFFERENCES FROM THE SRP:
: 1. Regulatory Guide 1.97 suggests post-accident sampling for primary coolant activity. There are no plans to install equipment to continuously monitor reactor coolant following an accident.
: 2. BVPS-2 takes some alternatives to Regulatory Guide 1.21.
: 3. Table 2 of the SRP requires continuous monitoring of the turbine building drain effluents. BVPS-2 does not
 
continuously monitor these effluents.
REMARKS:
: 1. To meet the intent of Regulatory Guide 1.97, reactor coolant can be analyzed by obtaining a grab sample via the post-
 
accident sampling facility (PASS). The PASS does not
 
operate at all times after an accident.
Information provided by this Regulatory Guide 1.97 variable
 
would not be vital to the control room operator for safe shutdown of the plant.
: 2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.21.  
: 3. To obtain gross activity of turbine building drain effluents, grab sampling will be performed as explained in
 
Section 11.2.2
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 78 of 93 SRP NO. 12.1
 
TITLE: ASSURING THAT OCCUPATIONAL RADIATION EXPOSURES ARE AS LOW AS IS REASONABLY ACHIEVABLE
 
DIFFERENCES FROM THE SRP:
: 1. 10 CFR 19.12 is not discussed.
: 2. NUREG-0761 guidelines are not specifically discussed.
 
REMARKS:
: 1. The SRP specifies in part that the FSAR is acceptable if sufficient information identified in Section 12.1 of Regulatory Guide 1.70 is provided to meet the relevant requirements of 10 CFR 19 and 20. Regulatory Guide 1.70 does not identify any necessary discussion of 10 CFR 19. The FSAR does, however, discuss 10 CFR 19.12 in Section 13.2.2.1.
: 2. The Radiation Protection Plan for BVPS-2 will be an extension of the plan currently in effect for the operation of BVPS-1. Having been developed prior to the current guidance (draft NUREG-0761, March 1981), the plan was not designed to follow this guidance document. The plan does
 
meet the intent of draft NUREG-0761 by satisfying the requirements of 10 CFR 20 as described in FSAR Sections 12.5, 13.1, and 13.2.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 79 of 93
 
This page has been intentionally deleted from the FSAR.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 80 of 93 SRP NO. 12.3 - 12.4
 
TITLE: RADIATION PROTECTION DESIGN FEATURES DIFFERENCES FROM THE SRP:
 
FSAR Sections 12.3 and 12.4 do not include:
: 1. A description of the radiation instrumentation that will be used to meet the criticality accident monitoring
 
requirements of 70.24(b) of 10 CFR Part 70 and Regulatory
 
Guide 8.12 for the new fuel storage area.
: 2. A description of intermediate range area monitors used to measure radiation exposure rates in locations contiguous to containment building penetrations and hatches, and in vital access areas as described in Regulatory Guide 1.97, Rev. 2.
REMARKS:
: 1. An application will be filed for an exemption from the installation of the criticality monitor required in
 
accordance with 10 CFR Part 70.24(b) and Regulatory Guide
 
8.12.   
: 2. General Design Criterion 19 is the only underlying requirement of Regulatory Guide 1.97 which is specified in SRP 12.3-12.4, and is unrelated to the area radiation monitors. However, Regulatory Guide 1.97 indicates that the function of the radiation monitors in areas adjacent to containment penetrations is to indicate a breach of the primary containment building. Because of the high radiation levels due to radiation streaming through containment penetration and systems carrying post-LOCA fluid outside containment, these radiation monitors are not expected to
 
perform the intended function.
To ensure that personnel exposures do not exceed the
 
guidelines of NUREG-0737, administrative controls require the use of a two-person team. One person performs the vital post-LOCA function and the other surveys the area with portable survey instruments. Additionally, the area monitors listed in FSAR Table 12.3-10 are mounted in selected areas of the plant to provide an indication of the  
 
radiation levels up to 10 Rem/hr.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 81 of 93 SRP NO. 12.5
 
TITLE: OPERATIONAL RADIATION PROTECTION PROGRAM DIFFERENCES FROM THE SRP:
: 1. NUREG-0761 guidelines are not specifically discussed.
: 2. Regulatory Guide 8.28 is not discussed
: 3. Regulatory Guide 8.3 is not discussed.
 
REMARKS:
: 1. Refer to the SRP 12.1 conformance statement.
: 2. Regulatory Guide 8.28, "Audible Alarm Dosimeters," is not applicable to BVPS-2. The established Radiation Protection Program does not rely upon the use of audible alarm dosimeters to satisfy regulatory requirements.
: 3. Regulatory Guide 8.3, "Film Badge Performance Criteria," is not applicable to BVPS-2. The established Radiation Protection Program does not rely upon the use of film badges to satisfy regulatory requirements.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 82 of 93 SRP NO. 13.2.2
 
TITLE: TRAINING FOR NON-LICENSED PLANT STAFF DIFFERENCES FROM THE SRP:
 
An annual evacuation drill for all employees is not discussed.  


TITLE: EMERGENCY DIESEL ENGINE STARTING SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 does not rely on air dryers in the diesel generator air starting system to assure adequate dehydration.
REMARKS:
REMARKS:
Accumulated moisture will be removed from the starting system by blowdown of the air receivers at regular intervals. Blowdown will be ensured by implementing administrative controls such as operating surveillance tests and will satisfy the relevant requirements of GDC 17.
The BVPS-2 Station Orientation Training Program, which is discussed in FSAR Section 13.2.2.1.1, meets the relevant requirements of 10 CFR 50.34(b) and 10 CFR 50, Appendix E, by providing all employees with adequate training to ensure that
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   68 of 93 SRP NO. 10.4.3
 
they are familiar with their emergency response duties.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 83 of 93 SRP NO. 13.4
 
TITLE: OPERATIONAL REVIEW DIFFERENCES FROM THE SRP:
 
ANSI/ANS-3.l-1978 and Regulatory Guide 1.8 are not addressed with respect to the qualification requirements of personnel
 
assigned to the Offsite Review Committee (ORC).
REMARKS:
 
The independent operational review of BVPS-2 will be performed by the same ORC that has been performing this review for BVPS-1. 
 
Qualification requirements of personnel assigned to the ORC meet those described in ANSI N18.1-1971. Meeting these qualification requirements satisfies the relevant requirements of 10 CFR 50.40(b) by ensuring that the ORC personnel are technically qualified to perform an operational review.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 84 of 93  
 
SRP NO. 15.1.5
 
TITLE: STEAM SYSTEM PIPING FAILURES INSIDE AND OUTSIDE OF CONTAINMENT (PWR)


TITLE: TURBINE GLAND SEALING SYSTEM  DIFFERENCES FROM THE SRP:
DIFFERENCES FROM THE SRP:  
BVPS-2 takes some alternatives to Regulatory Guide 1.26.
REMARKS:  Refer to Section 1.8 for BVPS-2 positions on regulatory guides.


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  69 of 93 SRP NO. 10.4.6
Items II.E.1.2, II.K.3.5, and II.K.3.25 of NUREG-0737 are not discussed in FSAR Section 15.1.5.  


TITLE: CONDENSATE CLEANUP SYSTEM  DIFFERENCES FROM THE SRP:
Specific details of the secondary side chemistry program are not discussed in FSAR Section 10.4.6.
REMARKS:
REMARKS:
The secondary side water chemistry program at BVPS-2 will follow the guidance of Westinghouse document SIP 5-4.
Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3, Item II.K.3.5 is addressed in Section 1.10, and Item II.K.3.25 is addressed in Section 5.4.1.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  70 of 93 SRP NO. 10.4.7


TITLE: CONDENSATE AND FEEDWATER SYSTEM  DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 85 of 93 SRP NO. 15.2.6
FSAR Section 10.4.7 does not specify provisions for start-up feedwater hammer testing per BTB ASB 10-2, Item 3.
REMARKS:
The system is adequately protected against damaging feedwater hammer by the feeding J-tube design, coupled with the elbow arrangement at the feedwater piping connection. Therefore, no testing is necessary.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   71 of 93 SRP NO. 10.4.8


TITLE: STEAM GENERATOR BLOWDOWN SYSTEM (PWR)  DIFFERENCES FROM THE SRP:
TITLE: LOSS OF NONEMERGENCY AC POWER TO THE STATION AUXILIARIES DIFFERENCES FROM THE SRP:  
The system does not follow the guidance of Regulatory Guide 1.143, paragraph C.1 with respect to the turbine building seismic criteria. REMARKS:
Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.143. Although the system differs from the SRP acceptance criteria, its design meets the requirements of GDC 1, 2, and 14.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  72 of 93 SRP NO. 11.1


TITLE: SOURCE TERMS  DIFFERENCES FROM THE SRP:
Items II.E.1.1 and II.E.1.2 of NUREG-0737 are not discussed in FSAR Section 15.2.6.  
: 1. SRP 11.1, paragraph II.a suggests that a cost-benefit analysis be performed in accordance with Regulatory Guide 1.110 for the radioactive waste management systems and equipment. 2. BVPS-2 takes some alternatives to Regulatory Guide 1.140. REMARKS:
: 1. BVPS-2 received a construction permit prior to June 4, 1976, the effective date of the cost-benefit analysis requirement. The radwaste systems and equipment described in the FSAR satisfy the regulatory position in Docket RM-50-2, which is reproduced in the Annex to Appendix I to 10 CFR 50. 2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.140.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  73 of 93 SRP NO. 11.2


TITLE: LIQUID WASTE MANAGEMENT SYSTEMS  DIFFERENCES FROM THE SRP:
: 1. BVPS-2 systems that contain provisions to control leakage and facilitate operation and maintenance meet Regulatory Guide 1.143 with some alternatives.
2a. SRP 11.2, paragraph II.1.a, provides only the "per unit" limits for determining compliance with 10 CFR 50, Appendix I. 2b. SRP 11.2, paragraph II.1.b, suggests that the applicant consider refinements to liquid radwaste treatment systems and performed a cost-benefit analysis in accordance with Regulatory Guide 1.110: liquid radwaste treatment systems should include all items of the system sequentially and in order of diminishing cost-benefit return, which can (for a favorable cost-benefit ratio) effect reductions in dose to the population reasonably expected to be within 50 miles of the reactor. This cost-benefit analysis has not been performed.
REMARKS:  
REMARKS:  
: 1. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.143. 2a. Analysis for BVPS-2 has been performed on a "per site" basis and resultant doses are within the RM-50-2 design limits and, therefore, is in compliance with 10 CFR 50, Appendix I.
2b. The cost-benefit analysis is not applicable for applicants for construction permits which were docketed on or after January 2, 1971, and prior to June 4, 1976, if the radwaste systems and equipment described in the preliminary or final safety analysis report and amendments thereto satisfy the Guides on Design Objectives for Light-Water-Cooled Nuclear Power Reactors proposed in the Concluding Statement of Position of the Regulatory Staff in Docket-RM-50-2 dated February 20, 1974, pp. 25-30. BVPS-2 received its construction permit prior to the requirement for cost-benefit analyses of radwaste treatment systems. Duquesne Light Company was given the option by the USNRC of performing the cost-benefit analyses, but chose not to perform the analyses due to the stage of system design.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  74 of 93 SRP NO. 11.3


TITLE: GASEOUS WASTE MANAGEMENT SYSTEMS  DIFFERENCES FROM THE SRP:
Item II.E.1.1 is addressed in Section 10.4.9; Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3.  
: 1. SRP 11.3, paragraph II.B.1.c, requires the gaseous radwaste treatment systems to include all items of reasonably demonstrated technology that when added to the system sequentially and in order of diminishing cost-benefit return, can (for a favorable cost-benefit ratio) effect reductions in dose to the population reasonably expected to be within 50 miles of the reactor. This cost-benefit analysis has not been performed. 2. SRP 11.3, paragraph II.B.4, requires system designs that contain provisions to control leakage and to facilitate operation and maintenance in accordance with the guidelines of Regulatory Guide 1.143. BVPS-2 meets Regulatory Guide 1.143 with the following exceptions:  a. Paragraph C.2.1.1 The gaseous waste system meets or exceeds the codes in Table 1. The gaseous waste delay beds, gaseous waste surge tank, and the overhead compressors have been purchased as ASME III. The waste gas chillers, piping, and valves are ANSI B31.1. b. Paragraph C.4.3  The piping downstream of the overhead gas compressor discharge lines are 1/2 inch, whereas the guide suggests that process lines should not be less than 3/4 inch (nominal).
: 3. SRP 11.3, paragraph II.B.6.b, requires two independent gas analyzers continuously operating and providing two independent measurements verifying that hydrogen and/or oxygen are not present in potentially explosive concentrations. The two oxygen analyzers do not measure independent locations. 
: 4. The SRP provides only the "per unit" limits for determining compliance with 10 CFR 50, Appendix I. 
: 5. The design case concentrations for gaseous effluents from the ventilation vent exceed the limits of 10 CFR 20, Appendix B, Table II, Column 1, for five nuclides assuming the design basis ventilation rate is used.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  75 of 93 REMARKS:
: 1. BVPS-2 received a construction permit prior to June 4, 1976, the date that the requirement for the cost-benefit analysis became effective. The radwaste systems and equipment described in the FSAR satisfy the regulatory position in Docket RM-50-2 which is reproduced in the Annex to Appendix I. 2. The FSAR addresses ETSB 11-1. a. The waste gas chillers are a pipe-within-a-pipe heat exchanger designed and fabricated in accordance with ANSI B.31.1. The charcoal delay bed vessels and the gaseous waste surge tank are designed and fabricated to ASME III, a design which is superior to the specified ASME VIII. The overhead gas compressors are designed and fabricated to ASME III, a design which is superior to the specified manufacturer's standard. b. The overhead gas compressor prefilters provide a clean gas downstream where the lines are 1/2 inch. Pressure drop is not a problem in the 1/2 inch lines downstream of the overhead gas compressors. 3. The two oxygen analyzers are downstream of the overhead gas compressors with the most likely leakage point being the suction of the compressors. 4. Analysis for BVPS-2 has been performed on a "per site" basis and resultant doses are within the RM-50-2 design limits.
It is, therefore, in compliance with 10 CFR 50, Appendix I. 5. Controlled releases will be imposed so as not to exceed the concentration limits of 10 CFR 20, Appendix B, Table II, Column 1.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  76 of 93 SRP NO. 11.4


TITLE: SOLID WASTE MANAGEMENT SYSTEMS  DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 86 of 93 SRP NO. 15.2.7
: 1. SRP 11.4, paragraphs II.2 and II.3, suggest a description of the methods for solidification, the solidifying agent used, and a  process control program to ensure a solid matrix. A process control program has not been submitted by the system vendor but has been discussed for BVPS-2. 2. Regulatory Guide 1.143 suggest 0-15 psig tanks to be designed and fabricated to ASME III, Class 3 or, API 650. The spent resin holding tank and the decanting tank are designed and fabricated to ASME VIII, Division 1. REMARKS:  1. The FSAR states that a process control program is needed to verify the absence of free liquid in the containers. The required program will be written prior to the completion of the environmental radiological Technical Specification. 2. The deviation of the design and fabrication of the spent resin holding tank and the decanting tank from the requirements of  Regulatory Guide 1.143 is due to the geometry of the two tanks. The fabrication codes specified (ASME III, Class 3 or API 650) do not specifically cover tanks of this type, that is, vessel-type nonflat bottom atmospheric tanks. As such, these tanks have been constructed in accordance with ASME VIII, Division 1, which is more stringent than API 650, thus indicating that the SRP requirements are more than adequately addressed. Exception to ASME VIII, Division 1 requirements are:  a. The vessels are not stamped.
: b. Radiography of welds is not required. c. A water fill leak test in accordance with API-650 is substituted for a hydrostatic test at 1.5 times design pressure. These tanks were designed and fabricated prior to issuance of NUREG-0800.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   77 of 93 SRP NO. 11.5


TITLE: PROCESS AND EFFLUENT RADIOLOGICAL MONITORING INSTRUMENTATION AND SAMPLING SYSTEMS DIFFERENCES FROM THE SRP: 1. Regulatory Guide 1.97 suggests post-accident sampling for primary coolant activity. There are no plans to install equipment to continuously monitor reactor coolant following an accident. 2. BVPS-2 takes some alternatives to Regulatory Guide 1.21. 
TITLE: LOSS OF NORMAL FEEDWATER FLOW DIFFERENCES FROM THE SRP:  
: 3. Table 2 of the SRP requires continuous monitoring of the turbine building drain effluents. BVPS-2 does not continuously monitor these effluents. REMARKS: 
: 1. To meet the intent of Regulatory Guide 1.97, reactor coolant can be analyzed by obtaining a grab sample via the post-accident sampling facility (PASS). The PASS does not operate at all times after an accident. Information provided by this Regulatory Guide 1.97 variable would not be vital to the control room operator for safe shutdown of the plant. 2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.21. 
: 3. To obtain gross activity of turbine building drain effluents, grab sampling will be performed as explained in Section 11.2.2 BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  78 of 93 SRP NO. 12.1


TITLE: ASSURING THAT OCCUPATIONAL RADIATION EXPOSURES ARE AS LOW AS IS REASONABLY ACHIEVABLE DIFFERENCES FROM THE SRP:  1. 10 CFR 19.12 is not discussed.
Items II.E.1.1 and II.E.1.2 of NUREG-0737 are not discussed in FSAR Section 15.2.7.  
: 2. NUREG-0761 guidelines are not specifically discussed.
REMARKS:  1. The SRP specifies in part that the FSAR is acceptable if sufficient information identified in Section 12.1 of Regulatory Guide 1.70 is provided to meet the relevant requirements of 10 CFR 19 and 20. Regulatory Guide 1.70 does not identify any necessary discussion of 10 CFR 19. The FSAR does, however, discuss 10 CFR 19.12 in Section 13.2.2.1. 2. The Radiation Protection Plan for BVPS-2 will be an extension of the plan currently in effect for the operation of BVPS-1. Having been developed prior to the current guidance (draft NUREG-0761, March 1981), the plan was not designed to follow this guidance document. The plan does meet the intent of draft NUREG-0761 by satisfying the requirements of 10 CFR 20 as described in FSAR Sections 12.5, 13.1, and 13.2.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  79 of 93 This page has been intentionally deleted from the FSAR.  


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  80 of 93 SRP NO. 12.3 - 12.4
REMARKS:


TITLE: RADIATION PROTECTION DESIGN FEATURES  DIFFERENCES FROM THE SRP:
Items II.E.1.1 and II.E.1.2 are addressed in Section 10.4.9.  
FSAR Sections 12.3 and 12.4 do not include: 
: 1. A description of the radiation instrumentation that will be used to meet the criticality accident monitoring requirements of 70.24(b) of 10 CFR Part 70 and Regulatory Guide 8.12 for the new fuel storage area.
: 2. A description of intermediate range area monitors used to measure radiation exposure rates in locations contiguous to containment building penetrations and hatches, and in vital access areas as described in Regulatory Guide 1.97, Rev. 2. REMARKS: 
: 1. An application will be filed for an exemption from the installation of the criticality monitor required in accordance with 10 CFR Part 70.24(b) and Regulatory Guide 8.12. 
: 2. General Design Criterion 19 is the only underlying requirement of Regulatory Guide 1.97 which is specified in SRP 12.3-12.4, and is unrelated to the area radiation monitors. However, Regulatory Guide 1.97 indicates that the function of the radiation monitors in areas adjacent to containment penetrations is to indicate a breach of the primary containment building. Because of the high radiation levels due to radiation streaming through containment penetration and systems carrying post-LOCA fluid outside containment, these radiation monitors are not expected to perform the intended function. To ensure that personnel exposures do not exceed the guidelines of NUREG-0737, administrative controls require the use of a two-person team. One person performs the vital post-LOCA function and the other surveys the area with portable survey instruments. Additionally, the area monitors listed in FSAR Table 12.3-10 are mounted in selected areas of the plant to provide an indication of the radiation levels up to 10 Rem/hr.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  81 of 93 SRP NO. 12.5


TITLE: OPERATIONAL RADIATION PROTECTION PROGRAM  DIFFERENCES FROM THE SRP:  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 87 of 93 SRP NO. 15.2.8
: 1. NUREG-0761 guidelines are not specifically discussed.  
 
: 2. Regulatory Guide 8.28 is not discussed  3. Regulatory Guide 8.3 is not discussed.
TITLE: FEEDWATER SYSTEM PIPE BREAKS INSIDE AND OUTSIDE CONTAINMENT (PWR)
 
DIFFERENCES FROM THE SRP:
Items II.E.1.1, II.E.1.2, II.K.3.5, and II.K.3.25 of NUREG-0737
 
are not discussed in FSAR Section 15.2.8.
REMARKS:  
REMARKS:  
: 1. Refer to the SRP 12.1 conformance statement. 2. Regulatory Guide 8.28, "Audible Alarm Dosimeters," is not applicable to BVPS-2. The established Radiation Protection Program does not rely upon the use of audible alarm dosimeters to satisfy regulatory requirements. 3. Regulatory Guide 8.3, "Film Badge Performance Criteria," is not applicable to BVPS-2. The established Radiation Protection Program does not rely upon the use of film badges to satisfy regulatory requirements.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  82 of 93 SRP NO. 13.2.2


TITLE: TRAINING FOR NON-LICENSED PLANT STAFF  DIFFERENCES FROM THE SRP:
Item II.E.1.1 is addressed in Section 10.4.9, Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3, Item II.K.3.5 is addressed in Section 1.10, and Item II.K.3.25 is addressed in Section 5.4.1.
An annual evacuation drill for all employees is not discussed.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 88 of 93 SRP NO. 15.3.3 - 15.3.4  
REMARKS:  The BVPS-2 Station Orientation Training Program, which is discussed in FSAR Section 13.2.2.1.1, meets the relevant requirements of 10 CFR 50.34(b) and 10 CFR 50, Appendix E, by providing all employees with adequate training to ensure that they are familiar with their emergency response duties.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   83 of 93 SRP NO. 13.4  
TITLE: REACTOR COOLANT PUMP ROTOR SEIZURE AND REACTOR COOLANT PUMP SHAFT BREAK


TITLE: OPERATIONAL REVIEW  DIFFERENCES FROM THE SRP:
ANSI/ANS-3.l-1978 and Regulatory Guide 1.8 are not addressed with respect to the qualification requirements of personnel assigned to the Offsite Review Committee (ORC). REMARKS:
The independent operational review of BVPS-2 will be performed by the same ORC that has been performing this review for BVPS-1.
Qualification requirements of personnel assigned to the ORC meet those described in ANSI N18.1-1971. Meeting these qualification requirements satisfies the relevant requirements of 10 CFR 50.40(b) by ensuring that the ORC personnel are technically qualified to perform an operational review.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  84 of 93 SRP NO. 15.1.5 TITLE: STEAM SYSTEM PIPING FAILURES INSIDE AND OUTSIDE OF CONTAINMENT (PWR)
DIFFERENCES FROM THE SRP:
DIFFERENCES FROM THE SRP:
Items II.E.1.2, II.K.3.5, and II.K.3.25 of NUREG-0737 are not discussed in FSAR Section 15.1.5.
Item II.K.3.5 of NUREG-0737 is not discussed in FSAR Section  
REMARKS: Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3, Item II.K.3.5 is addressed in Section 1.10, and Item II.K.3.25 is addressed in Section 5.4.1.
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   85 of 93 SRP NO. 15.2.6
15.3. REMARKS:  
 
Item II.K.3.5 is addressed in Section 1.10.  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 89 of 93 SRP NO. 15.4.8
 
TITLE: SPECTRUM OF ROD EJECTION ACCIDENTS (PWR)
DIFFERENCES FROM THE SRP:
 
The SRP implies that the stresses should be evaluated to emergency conditions defined in ASME III. Westinghouse considers this a faulted condition as stated in ANSI N18.2.
Faulted condition stress limits are applied for this accident.


TITLE: LOSS OF NONEMERGENCY AC POWER TO THE STATION AUXILIARIES  DIFFERENCES FROM THE SRP:
Items II.E.1.1 and II.E.1.2 of NUREG-0737 are not discussed in FSAR Section 15.2.6.
REMARKS:
REMARKS:
Item II.E.1.1 is addressed in Section 10.4.9; Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3.
System overpressurization due to a rod ejection transient was evaluated in WCAP-7588 Rev. 1-A and received USNRC acceptance in the Topical Report Evaluation.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  86 of 93 SRP NO. 15.2.7


TITLE: LOSS OF NORMAL FEEDWATER FLOW  DIFFERENCES FROM THE SRP:
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 90 of 93 SRP NO. 15.6.1
Items II.E.1.1 and II.E.1.2 of NUREG-0737 are not discussed in FSAR Section 15.2.7.
REMARKS:
Items II.E.1.1 and II.E.1.2 are addressed in Section 10.4.9.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   87 of 93 SRP NO. 15.2.8


TITLE: FEEDWATER SYSTEM PIPE BREAKS INSIDE AND OUTSIDE CONTAINMENT (PWR)
TITLE: INADVERTENT OPENING OF A PWR PRESSURIZER RELIEF VALVE OR A BWR RELIEF VALVE
DIFFERENCES FROM THE SRP:  Items II.E.1.1, II.E.1.2, II.K.3.5, and II.K.3.25 of NUREG-0737 are not discussed in FSAR Section 15.2.8. REMARKS:
Item II.E.1.1 is addressed in Section 10.4.9, Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3, Item II.K.3.5 is addressed in Section 1.10, and Item II.K.3.25 is addressed in Section 5.4.1.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  88 of 93 SRP NO. 15.3.3 - 15.3.4


TITLE: REACTOR COOLANT PUMP ROTOR SEIZURE AND REACTOR COOLANT PUMP SHAFT BREAK DIFFERENCES FROM THE SRP: Item II.K.3.5 of NUREG-0737 is not discussed in FSAR Section 15.3. REMARKS:
DIFFERENCES FROM THE SRP:
Item II.K.3.5 is addressed in Section 1.10.
Items II.K.3.1, II.K.3.5, and II.K.3.25 of NUREG-0737 are not
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  89 of 93 SRP NO. 15.4.8


TITLE: SPECTRUM OF ROD EJECTION ACCIDENTS (PWR)  DIFFERENCES FROM THE SRP:
discussed in FSAR Section 15.6.1.
The SRP implies that the stresses should be evaluated to emergency conditions defined in ASME III. Westinghouse considers this a faulted condition as stated in ANSI N18.2. Faulted condition stress limits are applied for this accident.
REMARKS:  
REMARKS: System overpressurization due to a rod ejection transient was evaluated in WCAP-7588 Rev. 1-A and received USNRC acceptance in the Topical Report Evaluation.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  90 of 93 SRP NO. 15.6.1


TITLE: INADVERTENT OPENING OF A PWR PRESSURIZER RELIEF VALVE OR A BWR RELIEF VALVE DIFFERENCES FROM THE SRP:  Items II.K.3.1, II.K.3.5, and II.K.3.25 of NUREG-0737 are not discussed in FSAR Section 15.6.1. REMARKS:
Items II.K.3.1 and II.K.3.5 are addressed in Section 1.10 and Item II.K.3.25 is addressed in Section 5.4.1.  
Items II.K.3.1 and II.K.3.5 are addressed in Section 1.10 and Item II.K.3.25 is addressed in Section 5.4.1.  


BVPS-2 UFSAR Rev. 16  TABLE 1.9-2 (Cont)   91 of 93 SRP NO. 15.6.5  
BVPS-2 UFSAR Rev. 16  TABLE 1.9-2 (Cont) 91 of 93 SRP NO. 15.6.5  
 
TITLE: LOSS-OF-COOLANT ACCIDENTS RESULTING FROM SPECTRUM OF POSTULATED PIPING BREAKS WITHIN THE REACTOR COOLANT
 
PRESSURE BOUNDARY DIFFERENCES FROM THE SRP:
: 1. The parameters presented below were used to calculate the radiological consequences. These values are consistent with
 
NUREG-75/087 and Regulatory Guide 1.4, Revision 2.
Iodine available for release from containment 25%
Iodine composition Elemental 9l%
Particulate 5%
Methyl 4%
Iodine spray removal 10 hr-1 Maximum elemental iodine decontamination factor (NaOH) 100 
: 2. No modifications have been made to the small break model in accordance with Items II.K.3.30 and II.K.3.31 of NUREG-0737.
: 3. The value assumed for ECCS leakage in radiological calculations (i.e., 2.0X10
-2 gpm) is twice the expected leakage. The expected leakage was used as a basis since the
 
BVPS-2 Technical Specifications (like the BVPS-1 version)
 
contains no limit on ECCS leakage.


TITLE: LOSS-OF-COOLANT ACCIDENTS RESULTING FROM SPECTRUM OF POSTULATED PIPING BREAKS WITHIN THE REACTOR COOLANT PRESSURE BOUNDARY  DIFFERENCES FROM THE SRP: 
: 1. The parameters presented below were used to calculate the radiological consequences. These values are consistent with NUREG-75/087 and Regulatory Guide 1.4, Revision 2. Iodine available for release from containment 25% Iodine composition Elemental 9l% Particulate 5% Methyl 4%  Iodine spray removal 10 hr-1 Maximum elemental iodine decontamination factor (NaOH) 100 
: 2. No modifications have been made to the small break model in accordance with Items II.K.3.30 and II.K.3.31 of NUREG-0737. 
: 3. The value assumed for ECCS leakage in radiological calculations (i.e., 2.0X10-2 gpm) is twice the expected leakage. The expected leakage was used as a basis since the BVPS-2 Technical Specifications (like the BVPS-1 version) contains no limit on ECCS leakage.
REMARKS:  
REMARKS:  
: 1. The radiological consequences calculated using the model which is consistent with NUREG-75/087 and Regulatory Guide 1.4, Revision 2, are within the requirements of 10 CFR 100.
: 1. The radiological consequences calculated using the model which is consistent with NUREG-75/087 and Regulatory Guide 1.4, Revision 2, are within the requirements of 10 CFR 100.  
: 2. The BVPS-2 positions on the PWR applicable items from the U.S. Nuclear Regulatory Commission's Clarification of TMI Action Plan Requirements for applicants for an operating license, NUREG-0737, Enclosure 2, dated November 1980 are discussed in FSAR Section 1.10.
: 2. The BVPS-2 positions on the PWR applicable items from the U.S. Nuclear Regulatory Commission's Clarification of TMI Action Plan Requirements for applicants for an operating license, NUREG-0737, Enclosure 2, dated November 1980 are discussed in FSAR Section 1.10.  
: 3. The BVPS-2 Technical Specifications are modeled after the BVPS-1 Technical Specifications in accordance with NRC letter dated September 18, 1984.
: 3. The BVPS-2 Technical Specifications are modeled after the BVPS-1 Technical Specifications in accordance with NRC letter dated September 18, 1984.  
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)   92 of 93 SRP NO. 16.0, Rev. 1  
 
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 92 of 93 SRP NO. 16.0, Rev. 1  


TITLE: TECHNICAL SPECIFICATIONS DIFFERENCES FROM THE SRP:
TITLE: TECHNICAL SPECIFICATIONS DIFFERENCES FROM THE SRP:  
Technical Specifications are not provided.
REMARKS:  BVPS-2 Technical Specifications are currently being developed and will be provided within the schedule suggested by the USNRC staff. A working copy of the Technical Specifications is continuously available for the USNRC Resident Inspector's use.


BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont)  93 of 93 SRP NO. 17.2
Technical Specifications are not provided.  


TITLE: QUALITY ASSURANCE DURING THE OPERATIONS PHASE  DIFFERENCES FROM THE SRP:
REMARKS:
The description of the Duquesne Light Company Operations Quality Assurance (QA) program does not provide discussions of those areas which are considered to be excessively detailed and, therefore, not appropriate as input to the FSAR.
BVPS-2 Technical Specifications are currently being developed


REMARKS:  FSAR Section 17.2 follows the format and content guidelines of Regulatory Guide 1.70 in describing the operations QA program. Although the description does not address the more detailed SRP acceptance criteria, it provides sufficient information to conclude that the program satisfies the requirements of 10 CFR 50, Appendix B. Many of the SRP criteria are of a detailed nature not suitable for discussion in the FSAR. Methods of meeting these criteria or acceptable alternatives are documented in the Operations QA Program, Operations Quality Control Procedures, Quality Assurance Instructions, and detailed implementing procedures, all of which have been successfully implemented since early 1976 for BVPS-1.
and will be provided within the schedule suggested by the USNRC staff. A working copy of the Technical Specifications is continuously available for the USNRC Resident Inspector's use.
BVPS-2 UFSAR Rev. 0 1.10-1 1.10  NUREG 0737 ACTION ITEMS  Table 1.10-1 presents the BVPS-2 positions on the PWR applicable items from the U.S. Nuclear Regulatory Commission's Clarification of TMI Action Plan Requirements for applicants for an operating license, NUREG-0737, Enclosure 2, dated November 1980. In addition, this table identifies the location of each individual item addressed in the UFSAR.
 
BVPS-2 UFSAR  Tables for Section 1.10 BVPS-2 UFSAR Rev. 14  1 of 6 TABLE 1.10-1  NUREG 0737 CONFORMANCE  Item and Title  Position UFSAR Reference    I.A.1.1 Shift Technical Advisor  BVPS-2 will meet the intent of this item. 13.2.2.5 I.A.1.2 Shift Supervisor Administrative Duties  BVPS-2 will meet the intent of this item. 13.5.1 I.A.1.3 Shift Manning  BVPS-2 meets the intent of this item. Minimum shift crew composition is specified by 10 CFR 50.54. Controls on working hours are specified by technical specifications. 13.5.1 I.A.2.1 Immediate Upgrade of RO and SRO Training and Qualifications BVPS-2 will meet the intent of this item. I.A.2.3 Administration of Training Programs BVPS-2 will meet the item by having licensed operation instructors enrolled in the operator's retraining program. I.A.3.1 Revise Scope and Criteria for Licensing Examinations  BVPS is building its own simulator and once complete will make it available for the simulator examination portion of NRC licensing examination. I.B.1.2 Evaluation of Organization and Management  BVPS-2 will meet the intent of this item. 13.4.4 I.C.1 Short-Term Accident Analysis and Procedures Revision Following USNRC review and approval of the Westinghouse Owners Group revised emergency procedure guidelines, BVPS-2 will revise its emergency procedures, as necessary, to incorporate these recommendations. 13.5.2 I.C.2 Shift and Relief Turnover Procedures BVPS-2 Administrative Procedures will meet the intent of this item. 13.5.1 I.C.3 Shift Supervisor Responsibility BVPS-2 Administrative Procedures will comply with the intent of this item. 13.5.1 I.C.4 Control Room Access BVPS-2 Administrative Procedures will comply with the intent of this item. 13.5.1 BVPS-2 UFSAR Rev. 0  2 of 6 TABLE 1.10-1 (Cont)  Item and Title  Position UFSAR Reference    I.C.5 Procedures for Feedback of Operating Experience BVPS-2 Administrative Procedures will comply with the intent of this item. 13.5.1 I.C.6 Procedures for Verification of Correct Performance of Operating Activities  BVPS-2 Administrative Procedures will comply with the intent of this item. 13.5.1 I.C.7 NSSS Vendor Review of Procedures  BVPS-2 remains available to correct any deficiencies found in its low-power, power ascension, and emergency procedures, as necessary, if the NRC opts to require a NSSS vendor review. However, it may not be necessary considering BVPS-2 response to I.C.1.
BVPS-2 UFSAR Rev. 0  TABLE 1.9-2 (Cont) 93 of 93 SRP NO. 17.2
* I.C.8 Pilot Monitoring of Selected Emergency Procedures for NTOLS  BVPS-2 remains available to correct any deficiencies found in its emergency procedures if the USNRC opts to conduct a pilot monitoring program. The PMP may not be necessary considering the BVPS-2 response to Item I.C.1.
 
* I.D.1 Control Room Design Review  A control room design review has been performed for BVPS-2 to meet this item. 18.0 I.D.2 Plant Safety Parameter Display Console  BVPS-2 will install a safety parameter display system. 7.5.6 I.G.1 Training During Low-Power Testing  The training objectives required by NUREG-0737, Item I.G.1 will be satisfied and operator training will be provided on a simulator which adequately represents BVPS-2 performance with regard to natural circulation.
TITLE: QUALITY ASSURANCE DURING THE OPERATIONS PHASE DIFFERENCES FROM THE SRP:
Test data which could be used to update existing simulator training will be obtained using the approved guidelines of the revised Westinghouse Low Power Test Program (W NS-EPR-2465 dated July 8, 1981) as indicated below:  1. During hot functional testing with the reactor coolant pumps supplying heat input to the secondary side, a loss of AC power will be simulated to the auxiliary feed pumps, controls and area ventilation. This will demonstrate that the plant can be stabilized utilizing manual control and the steam driven auxiliary feedwater pump. Informational data will be taken for simulator update as necessary, with no acceptance criteria applied. 
 
: 2. The existing initial startup test, (Section 14.2.12.8.13), "Pressurizer Heater and Spray Capability" test will be revised to include a section with one RCP in operation BVPS-2 UFSAR Rev. 14  2a of 6 TABLE 1.10-1 (Cont)  Item and Title  Position UFSAR Reference      (not to be in loops with pressurizer surge line or spray line). Pressure will be reduced by turning off pressurizer heaters and noting depressurization rate. The heaters will then be re-established and pressure further reduced by use of auxiliary spray. The effects of changes in charging flow and steam flow on margin to saturation temperature will be observed. Test data will be recorded and will be available for simulator update as necessary, with no acceptance criteria applied. 
The description of the Duquesne Light Company Operations Quality Assurance (QA) program does not provide discussions of those
: 3. BVPS-2 does not plan to conduct this natural circulation test since results of testing previously performed at North Anna-2 are sufficient to demonstrate the adequacy of BVPS-2 design features related to natural circulation. BVPS-1 has experienced loss of AC power and has satisfactorily demonstrated natural circulation during this transient.
 
: 4. The existing initial startup test (Section 14.2.12.6.5), "Verification of Plant Performance Following Turbine Trip Coincident with Loss of Offsite Power at Load" is satisfactory for obtaining the necessary plant conditions. Using this test, the plant will be brought to stable conditions using batteries and emergency diesels. II.B.1 Reactor Coolant System Vents BVPS-2 meets the intent of this item. 5.4.13 5.4.15 II.B.2 Plant Shielding  BVPS-2 will meet the intent of this item. 12.3.2 II.B.3 Post-Accident Sampling The requirement for a post-accident sampling system was eliminated by License Amendment No. 123. II.B.4 Training for Mitigating Core Damage BVPS-2 will meet the intent of this item. 13.2.2.6 BVPS-2 UFSAR Rev. 0  3 of 6 TABLE 1.10-1 (Cont)  Item and Title  Position UFSAR Reference    II.D.1 Testing Requirements for Reactor Coolant System Relief and Safety Valves  BVPS-2 meets the intent of this item with the exception of ATWS testing. 3.9N.3 5.4.13 II.D.3 Direct Indication of Relief and Safety Valve Position  BVPS-2 meets the intent of this item. 7.5  II.E.1.1 Auxiliary Feedwater System Evaluation  BVPS-2 meets the intent of this item. 10.4.9.3 10A.1 II.E.1.2 Auxiliary Feedwater System Automatic Initiation and Flow Indication BVPS-2 meets the intent of this item. 7.3 10.4.9 II.E.3.1 Emergency Power Supply for Pressurizer Heaters  BVPS-2 meets the intent of this item. 8.3.1.1.3 8.3.2 II.E.4.1 Dedicated Hydrogen Penetrations (Containment Design)  BVPS-2 meets the intent of this item. 6.2.5.1 II.E.4.2 Containment Isolation Dependability  BVPS-2 meets the intent of this item. 6.2.4 7.3 II.F.1 Additional Accident Monitoring Instrumentation Attachment (1) BVPS-2 will meet the intent of this item. 11.5.1 11.5.2.4.2  Attachment (2) BVPS-2 will meet the intent of this item. 11.5.2.4.2 11.5.1 Attachment (3) BVPS-2 will meet the intent of this item 12.3   Attachment (4) BVPS-2 meets the intent of this item. 7.5  Attachment (5) BVPS-2 meets the intent of this item. 7.5  Attachment (6) BVPS-2 meets the intent of this item.
areas which are considered to be excessively detailed and, therefore, not appropriate as input to the FSAR.  
* BVPS-2 UFSAR Rev. 16  4 of 6 TABLE 1.10-1 (Cont)   Item and Title  Position UFSAR Reference    II.F.2 Identification of and Recovery from Conditions Leading to Inadequate Core Cooling  BVPS-2 will meet the intent of this item. A detailed description of plant design satisfying this item will be provided in an amendment to BVPS-2 UFSAR. 7.5 7.7.2 II.G.1 Power Supplies for Pressurizer Relief Valves, Block Valves, and Level Indicators  BVPS-2 meets the intent of this item. 8.3.1.1.3 8.3.1.2  II.K.1.5 Review ESF Valves  BVPS-2 plant operating procedures will meet the intent of this item. 13.5.2.1 II.K.1.10 Operability Status  BVPS-2 meets the intent of this item. 13.5.2.1 II.K.1.17 Trip per Low-Level B/S  BVPS-2 meets the intent of this item. 7.1 7.2 II.K.2.13 Thermal Mechanical Report  Westinghouse (in support of the Westinghouse Owners Group) has developed methods and performed analyses for a spectrum of small LOCAs. The methods employed the NOTRUMP computer program to generate the thermal/hydraulic transients. The results of the analyses are provided in WCAP-10019.
 
* II.K.2.17 Potential for Voiding in the Reactor Coolant System During Transients  BVPS-2 meets the intent of this item. 5.4.7.2.3 II.K.2.19 Sequential Auxiliary Feedwater Flow Analysis This item is not applicable to BVPS-2. The concerns expressed in this item do not apply to NSSS with inverted U-tubes such as the one utilized in BVPS-2.
REMARKS:
FSAR Section 17.2 follows the format and content guidelines of Regulatory Guide 1.70 in describing the operations QA program. Although the description does not address the more detailed SRP acceptance criteria, it provides sufficient information to conclude that the program satisfies the requirements of 10 CFR 50, Appendix B. Many of the SRP criteria are of a detailed nature not suitable for discussion in the FSAR. Methods of meeting these criteria or acceptable alternatives are documented in the Operations QA Program, Operations Quality Control Procedures, Quality Assurance Instructions, and detailed implementing procedures, all of which have been successfully implemented since early 1976 for BVPS-1.  
 
BVPS-2 UFSAR Rev. 0 1.10-1 1.10  NUREG 0737 ACTION ITEMS Table 1.10-1 presents the BVPS-2 positions on the PWR applicable items from the U.S. Nuclear Regulatory Commission's
 
Clarification of TMI Action Plan Requirements for applicants for an operating license, NUREG-0737, Enclosure 2, dated November 1980. In addition, this table identifies the location of each
 
individual item addressed in the UFSAR.
 
BVPS-2 UFSAR  Tables for Section 1.10  
 
BVPS-2 UFSAR Rev. 14  1 of 6 TABLE 1.10-1 NUREG 0737 CONFORMANCE Item and Title Position UFSAR Reference I.A.1.1 Shift Technical Advisor BVPS-2 will meet the intent of this item.
13.2.2.5 I.A.1.2 Shift Supervisor Administrative Duties BVPS-2 will meet the intent of this item.
13.5.1 I.A.1.3 Shift Manning BVPS-2 meets the intent of this item. Minimum shift crew composition is specified by 10 CFR 50.54. Controls on working hours are specified by technical specifications.
13.5.1 I.A.2.1 Immediate Upgrade of RO and SRO Training and Qualifications
 
BVPS-2 will meet the intent of this item.
I.A.2.3 Administration of Training Programs
 
BVPS-2 will meet the item by having licensed operation instructors enrolled in the operator's retraining program.
I.A.3.1 Revise Scope and Criteria for Licensing Examinations BVPS is building its own simulator and once complete will make it available for the simulator examination portion of NRC licensing examination.
I.B.1.2 Evaluation of Organization and Management BVPS-2 will meet the intent of this item.
13.4.4 I.C.1 Short-Term Accident Analysis and Procedures Revision Following USNRC review and approval of the Westinghouse Owners Group revised emergency procedure guidelines, BVPS-2 will revise its emergency procedures, as necessary, to incorporate these recommendations.
13.5.2 I.C.2 Shift and Relief Turnover Procedures
 
BVPS-2 Administrative Procedures will meet the intent of this item.
13.5.1 I.C.3 Shift Supervisor Responsibility
 
BVPS-2 Administrative Procedures will comply with the intent of this item.
13.5.1 I.C.4 Control Room Access
 
BVPS-2 Administrative Procedures will comply with the intent of this item.
13.5.1 BVPS-2 UFSAR Rev. 0  2 of 6 TABLE 1.10-1 (Cont)
Item and Title Position UFSAR Reference I.C.5 Procedures for Feedback of Operating Experience
 
BVPS-2 Administrative Procedures will comply with the intent of this item.
13.5.1 I.C.6 Procedures for Verification of Correct Performance of Operating Activities BVPS-2 Administrative Procedures will comply with the intent of this item.
13.5.1 I.C.7 NSSS Vendor Review of Procedures BVPS-2 remains available to correct any deficiencies found in it s low-power, power ascension, and emergency procedures, as necessary, if the NRC opts to require a NSSS vendor review. However, it may not be necessary cons idering BVPS-2 response to I.C.1.
* I.C.8 Pilot Monitoring of Selected Emergency Procedures for NTOLS BVPS-2 remains available to correct any deficiencies found in its em ergency pr ocedures if the USNRC opts to conduct a pilot monitoring program. The PMP may not be necessary considering the BVPS-2 response to Item I.C.1.
* I.D.1 Control Room Design Review A control room design review has been performed for BVPS-2 to meet this item. 18.0 I.D.2 Plant Safety Parameter Display Console  BVPS-2 will install a safety parameter display system.
7.5.6 I.G.1 Training During Low-Power Testing The training objectives required by NUREG-0737, Item I.G.1 will be satisfied and operator training will be provided on a simulator which adequately represents BVPS-2 performance with regard to natural circulation.  
 
Test data which could be used to update existing simulator training will be obtained using the approved guidelines of the revised Westinghouse Low Power Test Program (W NS-EPR-2465 dated July 8, 1981) as indicated below:
: 1. During hot functional testing with the reactor coolant pumps supplying heat input to the secondary side, a loss of AC power will be simulated to the auxiliary feed pumps, controls and area ventilation. This will demonstrate that the plant can be stabilized
 
utilizing manual control and the steam driven auxilia ry feedwater pump. Informational data will be taken for simulator update as necessary, with no acceptance criteria applied.
: 2. The existing initial startup test, (Section 14.2.12.8.13), "Pressurizer Heater and Spray Capability" test will be revised to include a section with one RCP in operation
 
BVPS-2 UFSAR Rev. 14 2a of 6 TABLE 1.10-1 (Cont)
Item and Title Position UFSAR Reference (not to be in loops with pressurizer surge line or spray line). Pre ssure will be reduced by turning off pressurizer heaters and noting depressurization rate. The heaters will then be re-established and pressure further reduced by use of auxiliary spray. The effects of changes in charging flow and steam flow on margin to saturation temperature will be observed. Test data will be recorded and will be available for simulator update as necessary, with no acceptance criteria applied.  
: 3. BVPS-2 does not plan to conduct this natural circulation test since results of testing previously performed at North Anna-2 are sufficient to demonstrate the adequacy of BVPS-2 design features related to natural circulation. BVPS-1 has experienced loss of AC power and has satisfactorily demonstrated natural circulation during this transient.  
: 4. The existing initial startup test (Section 14.2.12.6.5), "Verification of Plant Performance Following Turbine Trip Coincident with Loss of Offsite Power at Load" is satisfactory for obtaining the necessary plant conditions. Us ing this test, the plant will be brought to stable conditions using batteries and emergency diesels.
II.B.1 Reactor Coolant System Vents BVPS-2 meets the intent of this item.
5.4.13 5.4.15  II.B.2 Plant Shielding BVPS-2 will meet the intent of this item.
12.3.2 II.B.3 Post-Accident Sampling The requirement for a post-accident sampling system was eliminated by License Amendment No. 123.
II.B.4 Training for Mitigating Core Damage BVPS-2 will meet the intent of this item.
13.2.2.6 BVPS-2 UFSAR Rev. 0  3 of 6 TABLE 1.10-1 (Cont)
Item and Title Position UFSAR Reference II.D.1 Testing Requirements for Reactor Coolant System Relief and Safety Valves  BVPS-2 meets the intent of this item with the exception of ATWS testing.
3.9N.3 5.4.13 II.D.3 Direct Indication of Relief and Safety Valve Position BVPS-2 meets the intent of this item.
7.5 II.E.1.1 Auxiliary Feedwater System Evaluation BVPS-2 meets the intent of this item.
10.4.9.3 10A.1 II.E.1.2 Auxiliary Feedwater System Automatic Initiation and Flow Indication
 
BVPS-2 meets the intent of this item.
7.3 10.4.9 II.E.3.1 Emergency Power Supply for Pressurizer Heaters BVPS-2 meets the intent of this item.
8.3.1.1.3 8.3.2 II.E.4.1 Dedicated Hydrogen Penetrations (Containment Design)
BVPS-2 meets the intent of this item.
6.2.5.1 II.E.4.2 Containment Isolation Dependability BVPS-2 meets the intent of this item.
6.2.4 7.3 II.F.1 Additional Accident Monitoring Instrumentation
 
Attachment (1) BVPS-2 will meet the intent of this item.
11.5.1 11.5.2.4.2 Attachment (2) BVPS-2 will meet the intent of this item.
11.5.2.4.2 11.5.1 Attachment (3) BVPS-2 will meet the intent of this item 12.3  Attachment (4) BVPS-2 meets the intent of this item.
7.5  Attachment (5) BVPS-2 meets the intent of this item.
7.5  Attachment (6) BVPS-2 meets the intent of this item.
* BVPS-2 UFSAR Rev. 16  4 of 6 TABLE 1.10-1 (Cont)
Item and Title Position UFSAR Reference II.F.2 Identification of and Recovery from Conditions Leading to Inadequate Core Cooling  BVPS-2 will meet the intent of this item. A detailed description of plant design satisfying this item will be provided in an amendment to BVPS-2 UFSAR.
7.5 7.7.2 II.G.1 Power Supplies for Pressurizer Relief Valves, Block Valves, and Level Indicators BVPS-2 meets the intent of this item.
8.3.1.1.3 8.3.1.2  II.K.1.5 Review ESF Valves BVPS-2 plant operating procedures will meet the intent of this item.
13.5.2.1 II.K.1.10 Operability Status BVPS-2 meets the intent of this item.
13.5.2.1 II.K.1.17 Trip per Low-Level B/S BVPS-2 meets the intent of this item.
7.1 7.2 II.K.2.13 Thermal Mechanical Report Westinghouse (in support of the Westinghouse Owners Group) has developed methods and performed analyses for a spectrum of small LOCAs. The methods employed the NOTRUMP computer program to generate the thermal/hydraulic transients. The results of the analyses are provided in WCAP-10019.
* II.K.2.17
 
Potential for Voiding in the Reactor Coolant System During Transients BVPS-2 meets the intent of this item.
5.4.7.2.3 II.K.2.19 Sequential Auxiliary Feedwater Flow Analysis This item is not applicable to BVPS-2. The concerns expressed in this item do not apply to NSSS with inverted U-tubes such as the one utilized in BVPS-2.
* II.K.3.1 Installation and Testing of Automatic Power-Operated Relief Valve Isolation System As a result of the evaluation documented in WCAP-9804, February 1981, it has been determined that an automatic pressurizer power-operated relief valve isolation system is not required for BVPS-2.
* II.K.3.1 Installation and Testing of Automatic Power-Operated Relief Valve Isolation System As a result of the evaluation documented in WCAP-9804, February 1981, it has been determined that an automatic pressurizer power-operated relief valve isolation system is not required for BVPS-2.
* BVPS-2 UFSAR Rev. 16  5 of 6 TABLE 1.10-1 (Cont) Item and Title Position UFSAR Reference   II.K.3.2 Report on Overall Safety Effects of Power-Operated Relief Valve Isolation System  A generic report was submitted by the Westinghouse Owners Group which responds to this item (WCAP-9804). This report identifies a significant reduction in the PORV LOCA probability as a result of post-TMI modifications and the calculations compare favorably with the operational data for Westinghouse plants (included as an appendix to the report). II.K.3.3 Reporting SV and RV Failures and Challenges Failures of PORVs or safety valves to close when required will be reported as appropriate in accordance with 10 CFR 50.72 and 10 CFR 50.73. 16 II.K.3.5 Automatic Trip of Reactor Coolant Pumps During Loss-of-Coolant Accident Westinghouse has performed an analysis of delayed reactor coolant pump trip during small-break LOCAs. This analysis is documented in WCAP-9584 and WCAP-9585, August 1979. In addition, Westinghouse has performed test predictions of LOFT experiments L3-1 and L3-6. The results of these predictions are documented in letters OG-49, dated, March 3, 1981; OG-50, dated March 23, 1981; and OG-60, dated, June 15, 1981. Based on:  1) the Westinghouse analysis, 2) the excellent prediction of the LOFT experiment L3-6 results using the Westinghouse analytical model, and 3) Westinghouse simulator data related to operator response time, the Westinghouse & BVPS-2 position is that the automatic reactor coolant pump trip is not necessary, since sufficient time is available for manual tripping of all the pumps.
* BVPS-2 UFSAR Rev. 16  5 of 6 TABLE 1.10-1 (Cont)
* II.K.3.7 Evaluation of PORV Opening Probability This item is applicable to B&W plants only and therefore, does not apply to BVPS-2.
Item and Title Position UFSAR Reference II.K.3.2 Report on Overall Safety Effects of Power-Operated Relief Valve Isolation System  A generic report was submitted by the Westinghouse Owners Group which responds to this item (WCAP-9804). This report identifies a significant reduction in the PORV LOCA probability as a result of post-TMI modifications and the calculations compare favorably with the operational data for Westinghouse plants (included as an appendix to the report).
* II.K.3.9 Proportional Integral Derivative Controller Modification BVPS-2 controller (PID) derivative action setting is zero, thereby eliminating it from consideration. Therefore, II.K.3.9 is not applicable to BVPS-2.
II.K.3.3 Reporting SV and RV Failures and Challenges Failures of PORVs or safety valves to close when required will be reported as appropriate in accordance with 10 CFR 50.72 and 10 CFR 50.73.
* II.K.3.10 Proposed Anticipatory Trip Modification BVPS-2 meets the intent of this item.
16 II.K.3.5 Automatic Trip of Reactor Coolant Pumps During Loss-of-Coolant Accident Westinghouse has performed an analysis of delayed reactor coolant pump trip during small-break LOCAs. This analysis is documented in WCAP-9584 and WCAP-9585, August 1979. In addition, Westinghouse has performed test predictions of LOFT experiments L3-1 and L3-6. The results of these predictions are documented in letters OG-49, dated, March 3, 1981; OG-50, dated March 23, 1981; and OG-60, dated, June 15, 1981. Based on:  1) the Westinghouse analysis, 2) the excellent prediction of the LOFT experiment L3-6 results using the Westinghouse analytical model, and 3) Westinghouse simulator data related to operator response time, the Westinghouse & BVPS-2 position is that the automatic reactor coolant pump trip is not necessary, since sufficient time is available for manual tripping of all the pumps.
7.2.1.1.2 II.K.3.12 Confirm Anticipatory Trip BVPS-2 design meets the intent of this item. 7.2.1.1.2 II.K.3.17 Report on Outages of Emergency Core Cooling Systems Licensee Report and Proposed Technical Specification Changes BVPS-2 will meet the intent of this item. 13.5.2.1 BVPS-2 UFSAR Rev. 0  6 of 6 TABLE 1.10-1 (Cont)   Item and Title Position UFSAR Reference   II.K.3.25 Effect of Loss of Alternating Current Power on Pump Seals BVPS-2 meets the intent of this item. 5.4.1.3.1 II.K.3.30 Revised Small Break Loss-of-Coolant Accident Methods to Show Compliance with 10CFR Part 50, App. K BVPS-2 position on the small-break LOCA analysis model currently approved by the NRC for use on BVPS-2 is conservative and in conformance with Appendix K to 10CFR Part 50. However (as documented in Anderson 1980), Westinghouse believes that improvement in the realism of small-break calculations is a worth-while effort and is currently developing a revised small-break LOCA analysis model to address NRC concerns (e.g. NUREG-0611, NUREG-0623, etc). Review and approval of the revised W small-break model by the NRC is scheduled for December 1, 1983. 15.6.5 II.K.3.31 Plant Specific Calculations to Show Compliance with 10 CFR Part 50.46 A small-break loss-of-coolant accident analysis specific to BVPS-2 is provided using the present Westinghouse small-break evaluation model. This is in conformance with 10CFR Part 50, Appendix K.
* II.K.3.7 Evaluation of PORV Opening Probability This item is applicable to B&W plants only and therefore, does not apply to BVPS-2.
15.6.5 III.A.1.1 Emergency Preparedness, Short Term BVPS Emergency Preparedness Plan (EPP) is in compliance with standards of 10CFR50 Appendix E and meets the intent of this item. 13.3 III.A.1.2 Upgrade Emergency Support Facilities BVPS-2 will meet the intent of this item. 13.3 III.A.2 Emergency Preparedness BVPS-2 Emergency Preparedness Plan will comply with the intent of this item. 13.3 III.D.1.1 Primary Coolant Sources Outside Containment BVPS-2 plant operating procedures will meet the intent of this item. 13.5.2.1 III.D.3.3 Inplant I Radiation Monitoring BVPS-2 will meet the intent of this item. 12.3 III.D.3.4 Control Room Habilitability BVPS-2 meets the intent of this item. 6.4  NOTE:   
* II.K.3.9 Proportional Integral Derivative Controller Modification  
*Statement stands alone, no UFSAR Section reference .
 
BVPS-2 UFSAR Rev. 2B 1.11-1 1.11  ASME CODE CASES Table 1.11-1 is provided as a convenient means for locating discussions of code cases located in the FSAR or other docketed licensing basis documents.
BVPS-2 controller (PID) derivative action setting is zero, thereby eliminating it from consideration. Therefore, II.K.3.9 is not applicable to BVPS-2.
BVPS-2 UFSAR  Tables for Section 1.11 BVPS-2 UFSAR Rev. 14 1 of 1 TABLE 1.11-1 ASME CODE CASE REFERENCES Code Case Location of Reference to Code Case General UFSAR Table 1.8, Regulatory Guides 1.84, 1.85 and 1.147 UFSAR Section 5.4.2.1.1 1177 UFSAR Table 1.8, Regulatory Guide 1.57 UFSAR Section 3.8.1.2.3 1330-3 UFSAR Table 1.8, Regulatory Guide 1.57 UFSAR Sections 3.8.1.2.3 and 3.8.2.7 1332-6 UFSAR Table 3.8-8 1355 Response to NRC question 210.44 1401-1 Response to NRC question 210.44 1423-2 UFSAR Table 5.2-2 Response to NRC question 210.44 1484 Response to NRC question 210.44 1493-1 Response to NRC question 210.44 1501 Response to NRC question 210.44 1526 Response to NRC question 210.44 1528 UFSAR Section 5.2.1.2 Response to NRC question 210.44 1552 Response to NRC question 210.44 1553-1 Response to NRC question 210.44 1605 UFSAR Table 1.8, Regulatory Guide 1.65 1606 UFSAR Table 3.9B-10 1607 UFSAR Table 3.9B-10 1618 UFSAR Table 5.2-4 1635 UFSAR Table 3.9B-10 1636 UFSAR Table 3.9B-10 1644 Response to NRC question 210.35 1649 Response to NRC question 210.44 N-3-10 (1335-10) Response to NRC question 210.44 N-242-1 Response to NRC question 210.44 N-318 UFSAR Sections 3A.3, 3A.3.22.1, 3A.3.23.1 and 3A.3.25 N-392 UFSAR Sections 3A.3, 3A.3.21.1, 3A.3.24.1 and 3A.3.25 N-411 UFSAR Table 1.8, Regulatory Guides 1.61 and 1.122 UFSAR Section 3.7B.3.1.2 UFSAR Table 3.7B-1 BVPS-2 UFSAR Rev. 14 1.12-1 1.12  EQUIVALENT MATERIALS Materials listed in the UFSAR that are qualified with an "or equivalent" statement may be replaced with an evaluated alternative material. Prior to the replacement of an existing material for a component part, an engineering technical evaluation is performed to determine suitability and acceptability for the application. These technical evaluations are performed utilizing approved procedures which meet the design control requirements of the FENOC Quality Assurance Program. The Site Design Control program under which the acceptability of alternate materials is evaluated addresses many material properties and their interactions with the system environment. In a typical evaluation, material properties such as tensile strength, yield strength, ductility, fracture toughness, corrosion resistance, surface conditions, hardness, thermal conductivity, heat treatment, and electro-chemical potential are evaluated as appropriate for the application. The term "equivalent,"
* II.K.3.10 Proposed Anticipatory Trip Modification  
 
BVPS-2 meets the intent of this item.  
 
7.2.1.1.2 II.K.3.12  
 
Confirm Anticipatory Trip  
 
BVPS-2 design meets the intent of this item.
7.2.1.1.2 II.K.3.17 Report on Outages of Emergency Core Cooling Systems Licensee Report and Proposed Technical Specification Changes BVPS-2 will meet the intent of this item.
13.5.2.1 BVPS-2 UFSAR Rev. 0  6 of 6 TABLE 1.10-1 (Cont)
Item and Title Position UFSAR Reference II.K.3.25 Effect of Loss of Alternating Current Power on Pump Seals BVPS-2 meets the intent of this item.
5.4.1.3.1 II.K.3.30 Revised Small Break Loss-of-Coolant Accident Methods to Show Compliance with 10CFR Part 50, App. K  
 
BVPS-2 position on the small-break LOCA analysis model currently approved by the NRC for use on BVPS-2 is conservative and in confor mance with Appendix K to 10CFR Part 50. However (as documented in Anderson 1980), Westinghouse believes that improvement in the realism of small-break calculations is a worth-while effort and is currently developing a revised small-break LOCA analysis model to address NRC concerns (e.g. NUREG-0611, NUREG-0623, etc). Review and approval of the revised W small-break model by the NRC is scheduled for December 1, 1983.
15.6.5 II.K.3.31 Plant Specific Calculations to Show Compliance with 10 CFR Part 50.46 A small-break loss-of-coolant accident analysis specific to BVPS-2 is provided using the present Westinghouse small-break evaluation model. This is in conformance with 10CFR Part 50, Appendix K.  
 
15.6.5 III.A.1.1 Emergency Preparedness, Short Term BVPS Emergency Preparedness Plan (EPP) is in compliance with standards of 10CFR50 Appendix E and meets the intent of this item.
13.3 III.A.1.2 Upgrade Emergency Support Facilities BVPS-2 will meet the intent of this item.
13.3 III.A.2 Emergency Preparedness BVPS-2 Emergency Preparedness Plan will comply with the intent of this item.
13.3 III.D.1.1 Primary Coolant Sources Outside Containment BVPS-2 plant operating procedures will meet the intent of this item.
13.5.2.1 III.D.3.3 Inplant I Radiation Monitoring BVPS-2 will meet the intent of this item.
12.3 III.D.3.4 Control Room Habilitability BVPS-2 meets the intent of this item.
6.4  NOTE:   
*Statement stands alone, no UFSAR Section reference
.
BVPS-2 UFSAR Rev. 2B 1.11-1 1.11  ASME CODE CASES Table 1.11-1 is provided as a convenient means for locating discussions of code cases located in the FSAR or other docketed licensing basis  
 
documents.  
 
BVPS-2 UFSAR  Tables for Section 1.11  
 
BVPS-2 UFSAR Rev. 14 1 of 1 TABLE 1.11-1 ASME CODE CASE REFERENCES Code Case Location of Reference to Code Case General UFSAR Table 1.8, Regulatory Guides 1.84, 1.85 and 1.147 UFSAR Section 5.4.2.1.1 1177 UFSAR Table 1.8, Regulatory Guide 1.57 UFSAR Section 3.8.1.2.3 1330-3 UFSAR Table 1.8, Regulatory Guide 1.57 UFSAR Sections 3.8.1.2.3 and 3.8.2.7 1332-6 UFSAR Table 3.8-8 1355 Response to NRC question 210.44 1401-1 Response to NRC question 210.44 1423-2 UFSAR Table 5.2-2 Response to NRC question 210.44 1484 Response to NRC question 210.44 1493-1 Response to NRC question 210.44 1501 Response to NRC question 210.44 1526 Response to NRC question 210.44 1528 UFSAR Section 5.2.1.2 Response to NRC question 210.44 1552 Response to NRC question 210.44 1553-1 Response to NRC question 210.44 1605 UFSAR Table 1.8, Regulatory Guide 1.65 1606 UFSAR Table 3.9B-10 1607 UFSAR Table 3.9B-10 1618 UFSAR Table 5.2-4 1635 UFSAR Table 3.9B-10 1636 UFSAR Table 3.9B-10 1644 Response to NRC question 210.35 1649 Response to NRC question 210.44 N-3-10 (1335-10)
Response to NRC question 210.44 N-242-1 Response to NRC question 210.44 N-318 UFSAR Sections 3A.3, 3A.3.22.1, 3A.3.23.1 and 3A.3.25 N-392 UFSAR Sections 3A.3, 3A.3.21.1, 3A.3.24.1 and 3A.3.25 N-411 UFSAR Table 1.8, Regulatory Guides 1.61 and 1.122 UFSAR Section 3.7B.3.1.2  
 
UFSAR Table 3.7B-1 BVPS-2 UFSAR Rev. 14 1.12-1 1.12  EQUIVALENT MATERIALS Materials listed in the UFSAR that are qualified with an "or equivalent" statement may be replaced with an evaluated alternative material. Prior to the replacement of an existing material for a component part, an engineering technical evaluation is performed to determine suitability and acceptability for the application. These technical evaluations are performed utilizing approved procedures which meet the design control requirements of the FENOC Quality Assurance Program. The Site Design Control program under which the acceptability of alternate materials is evaluated addresses many material properties and their interactions with the system environment. In a typical evaluation, material properties  
 
such as tensile strength, yield strength, ductility, fracture toughness, corrosion resistance, surface conditions, hardness, thermal conductivity, heat treatment, and electro-chemical potential are evaluated as appropriate for the application. The term "equivalent,"
however, does not apply to materials specified in the UFSAR that are required by a legally binding commitment described in the license or NRC Safety Evaluation Report (SER).}}
however, does not apply to materials specified in the UFSAR that are required by a legally binding commitment described in the license or NRC Safety Evaluation Report (SER).}}

Revision as of 08:07, 1 July 2018

Beaver Valley, Unit 2, Updated Final Safety Analysis Report, Revision 21, Section 1, Introduction and General Description of Plant
ML14339A414
Person / Time
Site: Beaver Valley
Issue date: 11/24/2014
From:
FirstEnergy Nuclear Operating Co
To:
Office of Nuclear Reactor Regulation
Shared Package
ML14339A419 List:
References
L-14-360
Download: ML14339A414 (337)
v • d • e


Text

BVPS-2 UFSAR Rev. 1 1-i CHAPTER 1 TABLE OF CONTENTS Section Title Page 1 INTRODUCTION AND GENERAL DESCRIPTION OF PLANT.....1.1-1

1.1 INTRODUCTION

......................................1.1-1

1.2 GENERAL PLANT DESCRIPTION.........................1.2-1 1.2.1 General...........................................1.2-1 1.2.2 Site..............................................1.2-2 1.2.3 Structures........................................1.2-2 1.2.4 Nuclear Steam Supply System.......................1.2-2 1.2.5 Instrumentation and Control Systems...............1.2-4 1.2.6 Radioactive Waste System..........................1.2-5 1.2.7 Fuel Handling.....................................1.2-6 1.2.8 Turbine and Turbine Auxiliaries...................1.2-6 1.2.9 Electrical Systems................................1.2-9 1.2.10 Engineered Safety Features Systems................1.2-9 1.2.11 Cooling Water and Other Auxiliary Systems.........1.2-10 1.3 COMPARISON TABLES.................................1.3-1

1.3.1 Comparisons with Similar Facility Designs.........1.3-1 1.3.2 Comparison of Final and Preliminary Information...1.3-3 1.3.3 References for Section 1.3........................1.3-3 1.4 IDENTIFICATION OF AGENT AND CONTRACTORS...........1.4-1

1.4.1 Applicant.........................................1.4-1 1.4.2 Architect Engineer................................1.4-2 1.4.3 Nuclear Steam Supply System Manufacturer..........1.4-4 1.4.4 Turbine Generator Vendor..........................1.4-12 1.4.5 Consultants.......................................1.4-12

1.5 REQUIREMENTS FOR FURTHER TECHNICAL INFORMATION....1.5-1

1.5.1 Blowdown Heat Transfer Testing....................1.5-1 1.5.2 Reference for Section 1.5.........................1.5-3

1.6 MATERIAL INCORPORATED BY REFERENCE................1.6-1 1.7 DRAWINGS AND OTHER DETAILED INFORMATION...........1.7-1

1.7.1 Electrical, Instrumentation, and Control Drawings.1.7-1 1.7.2 Piping and Instrumentation Diagrams...............1.7-1 1.7.3 Other Detailed Information (Special Reports and Programs).....................................1.7-1

BVPS-2 UFSAR Rev. 7 1-ii 1.8 CONFORMANCE TO NRC REGULATORY GUIDES..............1.8-1 1.9 STANDARD REVIEW PLAN CONFORMANCE EVALUATION.......1.9-1

1.10 NUREG 0737 ACTION ITEMS...........................1.10-1 1.11 ASME CODE CASES...................................1.11-1

1.12 EQUIVALENT MATERIALS..............................1.12-1

BVPS-2 UFSAR Rev. 16 1-iii LIST OF TABLES Table Number Title 1.3-1 Design Comparison (Historical) 1.3-2 Comparison of Final and Preliminary Information (Historical)

1.4-1 Westinghouse Pressurized Water Reactor Nuclear Power Plants (Historical)

1.5-1 Delayed Departure From Nucleate Boiling Phase I Test Parameters (Historical)

1.5-2 Delayed Departure From Nucleate Boiling Phase II Test Parameters (Historical)

1.6-1 Material Incorporated by Reference (Historical) 1.7-1 Deleted 1.7-2 Deleted

1.7-3 Special Reports and Programs 1.8-1 Regulatory Guides 1.9-1 Standard Review Plan Conformance (Historical) 1.9-2 SRP Conformance Statements (Historical) 1.10-1 NUREG 0737 Conformance 1.11-1 ASME Code Case References

BVPS-2 UFSAR Rev. 20 1-iv LIST OF FIGURES Figure Number Title 1.2-1 Site Plan

1.7-1 Legend: Piping and Instrumentation Diagrams

BVPS-2 UFSAR Rev. 20 1.1-1 CHAPTER 1 INTRODUCTION AND GENERAL DESCRIPTION OF PLANT

1.1 INTRODUCTION

Beaver Valley Power Station Unit 1 (BVPS-1) and BVPS-2 are located on a site in Shippingport Borough on the Ohio River in Beaver County, Pennsylvania. BVPS-2 uses a pressurized water reactor nuclear steam supply system (NSSS) and turbine generator, both furnished by Westinghouse Electric Corporation.

It is similar in design concept to several projects already licensed or under review by the USNRC. The balance of the unit, including the containment structure, is designed and constructed

by the Applicants, with the assistance of their agent, Stone &

Webster Engineering Corporation.

The NSSS was originally designed for a warranted power output of 2,660 MWt, which was the license application rating, with an

equivalent station net electrical output of approximately 836.0 MWe, assuming an atmospheric wet bulb of 44.85F coincident with a dry bulb temperature of 53.4F. The NSSS output of 2,660 MWt resulted from a core power (i.e., rated thermal power) of 2,652 MWt and 8 MWt from the reactor coolant

pumps. The engineered safety features system design was

originally based on 2,780 MWt core power. The reinforced concrete containment structure design was originally based on a core power of 2713 MWt and operation at subatmospheric pressure

(approximately 9.5 psia). The NSSS design was based upon an expected ultimate output of approximately 2,774 MWt. This NSSS output resulted from a core power of 2,766 MWt and 8 MWt from

the reactor coolant pumps with an equivalent station net electrical output of approximately 870.0 MWe, assuming an

atmospheric wet bulb of 44.68F coincident with a dry bulb temperature of 53.2F. However, all safety analyses were originally based on power levels that conservatively reflect

plant operating conditions.

The core power level (i.e., rated thermal power) was increased

in Fall 2001 to 2,689 MWt, taking advantage of the feedwater flow Measurement Uncertainty Recapture (MUR). The corresponding

NSSS thermal power level was 2,697 MWt, which included 8 MWt

from the reactor coolant pumps. The core power level was subsequently licensed to 2,900 MWt in 2006 per Amendment 156.

The corresponding NSSS thermal power level is 2,910 MWt, which includes 10 MWt of heat from non-reactor sources (primarily reactor coolant pump heat). The containment conversion to an

atmospheric containment (License Amendment 153) was based on the

uprated core power level of 2900 MWt. Analyses and engineering evaluations, as appropriate, at these increased thermal power levels were performed in the areas of thermal-hydraulic and nuclear characteristics of the reactor core, postulated accidents, and plant systems and components. The corresponding

uprated gross electrical output is 1,009 MWe.

BVPS-2 UFSAR Rev. 16 1.1-2 The remainder of Chapter 1 summarizes the principal design features and safety criteria of BVPS-2. Comparisons with other pressurized water reactor nuclear power stations now proposed or authorized for operation which employ essentially the same

technology and basic engineering features are provided. The facilities shared between BVPS-1 and BVPS-2 are also discussed in Chapter 1.

The Final Safety Analysis report was originally prepared in accordance with the guidelines of Regulatory Guide 1.70,

Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants (Revision 3, November 1978) as discussed in Section 1.8.

BVPS-2 UFSAR Rev. 14 1.2-1 1.2 GENERAL PLANT DESCRIPTION 1.2.1 General

Beaver Valley Power Station - Unit 2 (BVPS-2) incorporates a three-loop, closed-cycle, pressurized water nuclear steam supply system (NSSS), a tandem compound turbine generator, engineered safeguards systems, radioactive waste systems, a fuel handling system, and other facilities and auxiliaries required for a nuclear power plant.

Beaver Valley Power Station - Unit 1 (BVPS-1) facilities shared by BVPS-2 include the following:

1. Intake structure (Section 9.2.1),
2. Alternate intake structure (Section 9.2.1),
3. Control building,
4. Portions of the service building,
5. Portions of the auxiliary building, including the solid waste extension boron recovery system (BRS)

(Section 9.3.4.6), gaseous waste system (Section 11.3), liquid waste system (Section 11.2), and primary grade water system (Section 9.2.8),

6. Portions of the turbine building, including the demineralized water makeup system (Section 9.2.3),
7. Ultimate heat sink (Section 9.2.5),
8. Primary grade water storage tanks,
9. Meteorological tower,
10. Interconnecting tunnels,
11. Cooling tower elevated release point,
12. Potable and sanitary water system (Section 9.2.4),
13. Site drainage system,
14. Fire protection system (Section 9.5.1),
15. Portions of the communications systems (Section 9.5.2), 16. Emergency diesel generators during a station blackout event (Section 8.3.1.1.19)

BVPS-2 UFSAR Rev. 12 1.2-2 1.2.2 Site The site, comprising approximately 453 acres, is located on the south bank of the Ohio River in Beaver County, approximately 25

miles northwest of Pittsburgh. The site area and adjacent Ohio River provide a minimum exclusion radius of 1,500 feet. The nearest continuously occupied residence is located about 2,300 feet from the reactor. The low population zone area distance is 3.6 miles. The population center distance is 17 miles. The area is primarily industrial with some agricultural activity. A more complete description of the site is presented in Section 2.1.

1.2.3 Structures The general arrangement of structures for BVPS-2 is as shown on

Figure 1.2-1. The major building areas include the containment structure, auxiliary building, fuel and decontamination building, safeguards area, main steam and cable vault area, turbine building, service building, diesel generator building, waste handling building, condensate polishing building, cooling tower, refueling water storage tank (RWST) enclosure, primary demineralized water storage tank enclosure, emergency outfall structure, cooling tower pump house, gaseous waste storage area, and the control building.

Except for the steel framed turbine building and cooling tower pump house, the structures are constructed predominantly of reinforced concrete. The containment is a steel-lined, reinforced concrete cylinder with a hemispherical dome and flat base. The cooling tower is a natural draft hyperbolic type with

a reinforced concrete shell.

Structures housing safety-related equipment are the containment structure, safeguards area, main steam and cable vault, auxiliary building, fuel and decontamination building, control building, diesel generator building, service building, RWST enclosure, and primary demineralized water storage tank enclosure.

The BVPS-2 structures are separate from BVPS-1 structures. Passage between BVPS-1 and BVPS-2 is via a personnel bridge between the auxiliary building of BVPS-2 and the coolant recovery area of BVPS-1, and via an underground passageway between the auxiliary building of BVPS-2 and entrance area of BVPS-1.

Further information on the function, design, and layout of the plant structures is presented in Section 3.8.

1.2.4 Nuclear Steam Supply System

The NSSS consists of a pressurized water reactor, reactor coolant system (RCS), and associated auxiliary systems. The RCS is arranged as three reactor coolant loops connected in parallel to the reactor vessel, each containing a reactor coolant pump (RCP) and a steam generator. An electrically heated pressurizer is connected to the hot leg of one reactor coolant loop.

BVPS-2 UFSAR Rev. 12 1.2-3 High pressure water circulates through the reactor core to remove the heat generated by the nuclear chain reaction. The heated water exits from the reactor vessel and passes, via the coolant loop piping to the steam generators. Here it gives up its heat to the feedwater to generate steam for the turbine generator. The cycle is completed when the water is pumped back to the reactor vessel. The entire RCS is composed of leaktight components to ensure that fluids are confined to the system.

The core is of the multi-region type, which may utilize varying enrichments between regions.

In the initial core loading, three fuel enrichments are used. Fuel assemblies with the highest enrichments are placed at the core periphery, or outer region, and the two groups of lower enrichment fuel assemblies are arranged in a selected pattern in the central region. In subsequent refuelings, a portion of the fuel is replaced and new fuel is loaded in accordance with the core reload design.

Rod cluster control assemblies are used for reactor control and consist of clusters of cylindrical absorber rods. The absorber rods move within guide tubes in certain fuel assemblies. Above the core, each cluster of absorber rods is attached to a spider

connector and drive shaft, which is raised and lowered by a drive mechanism mounted on the reactor vessel head. Downward trip of the rod cluster is by gravity.

The RCPs are Westinghouse Electric Corporation (Westinghouse) vertical, single-stage, centrifugal pumps of the shaft-seal type. The system piping arrangement and the coastdown feature of the RCPs upon loss of electrical power are designed so that adequate coolant flow is maintained to cool the reactor core under all required circumstances considered in the safety analysis.

The steam generators are Westinghouse vertical U-tube units which contain Inconel tubes. Integral moisture separation equipment reduces the moisture content of the effluent steam to

one-quarter of one percent, or less. The reactor coolant loop stop and bypass valves are motor-operated gate valves remotely controlled from the main control room.

The reactor coolant piping and all of the pressure-containing and heat transfer surfaces in contact with primary coolant are

stainless steel or stainless steel clad except the steam generator tubes and fuel tubes, which are Inconel and Zircaloy, respectively. The steam generator tube sheet is Inconel clad on the primary side, and the steam generator channel head divider plate is Inconel. Reactor core internals, including control rod drive shafts, are primarily stainless steel.

BVPS-2 UFSAR Rev. 16 1.2-4 An electrically heated pressurizer, connected to one reactor coolant loop, maintains RCS pressure during normal operation, limits pressure variations during plant load transients, and

keeps system pressure within design limits during abnormal conditions.

Auxiliary systems and components are provided to charge makeup water to the RCS, purify reactor coolant water, provide chemicals for corrosion inhibition and reactivity control, cool system components, remove decay heat when the reactor is shut down, and provide for emergency safety injection.

1.2.5 Instrumentation and Control Systems The instrumentation and controls for the reactor protection system, engineered safety features actuation system, and other safety-related systems, meet the requirements of IEEE Standard 279-1971, "Criteria for Nuclear Power Plant Protection Systems."

In addition, other applicable criteria are met as described in Sections 3.1 and 7.1.2.

The nonsafety-related instrumentation and controls provide reliable control and allow continuous monitoring of the plant status without degradation of safety-related instrumentation.

Design details are described in Section 7.7.

The application of instrumentation and controls to individual

systems is detailed in the FSAR section describing the system.

The reactor is controlled by a coordinated combination of chemical shim and control rod assemblies, which are required for load-follow transients and for start-up and shutdown. The chemical shim is a soluble neutron absorber, boron, in the form of boric acid. The boric acid is added during cold shutdown, partially removed at start-up, and adjusted in concentration during core lifetime to compensate for such effects as fuel

depletion and accumulation of fission products which tend to slow the nuclear chain reaction.

The control system allows the plant to accept step load increases of 10 percent and ramp load increases of 5 percent/minute over a load range of 15 percent to, but not exceeding, 100 percent power under normal operating conditions subject to xenon limitations. Equal step and ramp load reductions are possible, over the range of 100 to 15 percent of

full power.

Technical Specifications require an anticipatory reactor trip following turbine trip above approximately 49% of full reactor power. The turbine bypass system's capability to permit a 50 percent external load rejection without turbine or reactor trip is discussed in Section 10.4.4.

BVPS-2 UFSAR Rev. 15 1.2-5 Control of the reactor and the turbine generator is accomplished from the main control room, which contains all instrumentation and control equipment required for start-up, operation, and shutdown, including normal and accident conditions. The turbine generator controls are designed for manual operation with the operator selecting the load set point and loading rate. The NSSS can follow the turbine generator from loads of 15 to 100 percent power. If during rapid turbine generator loading (5 percent/minute), the response of the control rods and chemical shim is not adequate to supply the needed reactivity, the reactor coolant temperature will drop, resulting in an increase of reactivity.

1.2.6 Radioactive Waste System Radioactive wastes are collected, processed, and disposed of in a safe manner complying with appropriate regulations: in particular, the U.S. Nuclear Regulatory Commission Regulations, 10 CFR 20 and 10 CFR 50, Appendix I Annex. The three interrelated radioactive waste treatment systems for radioactive liquid, gaseous, and solid wastes are described in detail in Chapter 11.

The radioactive liquid waste system, in combination with the steam generator blowdown system, collects and purifies radioactive liquid waste generated during operation and refueling for either recycling within the plant or discharge. The process operations available to treat liquid wastes are

filtration, evaporation, and demineralization. Connections are provided to process liquid wastes with BVPS-1 facilities, when necessary. The system is described in Section 11.2.

Radioactive gaseous wastes are treated before release to the environment. Degasification and purification of the reactor coolant letdown reduces the in-containment radiation exposures and the in- plant consequences of any reactor coolant leakage. The degasification and purification processes produce gaseous streams, which, together with hydrogenated vents, are passed through charcoal delay beds to provide holdup time for the decay of noble gases and the removal of iodine. Air ejector

vents are selectively delayed in separate charcoal beds. Aerated streams, produced by other phases of plant operation, are passed through high efficiency particulate air (HEPA)

filters for particulate removal and charcoal adsorbers for iodine removal, as needed. Periodic batch disposal of degasifier effluent gases (primarily hydrogen) are sent to the BVPS-1 gaseous waste disposal system for discharge. Degasifier gases may be recycled back to the volume control tank. Sweep gases are filtered by a HEPA filter and, along with the containment vacuum pump discharge, are sent to BVPS-1 for final release to the environment. The plant is also equipped with seven gaseous waste storage tanks to provide the available storage space for hydrogen gas, prior to batch discharging for one unit going to cold shutdown. This system is described in Section 11.3.

BVPS-2 UFSAR Rev. 20 1.2-6 The radioactive solid waste system provides packaging and storage facilities for the eventual shipment offsite and ultimate disposal of solid radioactive waste material.

Available process operations include dewatering and pH adjustment of beaded resins, powdered resins, evaporator bottoms, and solidification of the waste with an in-drum cement system. Dry radioactive waste produced in the operation and

maintenance of BVPS-2 may be baled or packaged, for shipment to an authorized offsite disposal location. Provisions for shielding during the processing and shipping preparations are included. As a backup, connections are provided to process

beaded resin and evaporator bottoms with the BVPS-1 solidification facilities. This system is described in

Section 11.4.

1.2.7 Fuel Handling

The reactor is refueled by equipment which handles the spent

fuel underwater from the time it leaves the reactor vessel until it is placed in a shipping cask for shipment from the site.

Underwater transfer of spent fuel provides an economic and transparent radiation shield, as well as a reliable coolant for

removal of decay heat.

The fuel handling system is divided into two areas: the reactor

cavity area, which is flooded for refueling; and the fuel pool,

which is external to the containment and is always accessible to plant personnel. The two areas are connected by a fuel transfer

system which carries the fuel through a containment penetration.

The design of the fuel transfer tube shielding inside the containment utilizes a labyrinth of steel and concrete shields.

Outside of the containment, the shielding design utilizes a notched interlocking wall arrangement. Section 12.3.2.5 provides a detailed description of the fuel transfer tube

shielding and arrangement.

Spent fuel is removed from the reactor vessel by a refueling machine and placed in the fuel transfer system. In the fuel

pool, the fuel is removed from the transfer system and placed

into storage racks. After a suitable decay period, and when offsite storage facilities or processing facilities are available, the fuel is removed from storage and loaded underwater into shipping casks for offsite transport. Storage is provided for no more than 1,690 spent fuel assemblies. Spent fuel storage is discussed in Section 9.1.2.

1.2.8 Turbine and Turbine Auxiliaries

1.2.8.1 Turbine Generator

The turbine is an 1,800 rpm, tandem-compound, four-flow, single-stage reheat unit with provision for six stages of feedwater

heating. The turbine-generator is provided with an electro-

hydraulic control system and with redundant emergency trip systems for turbine overspeed. The output of the turbine-

generator is described in Section 10.2.

BVPS-2 UFSAR Rev. 17 1.2-7 The generator is a direct driven, three-phase, 60 Hz, 22 kV, 1,800 rpm hydrogen inner-cooled, synchronous generator rated at 1,070 MVA at 0.92 power factor, and 0.61 short-circuit ratio at maximum hydrogen pressure of 75 psig.

1.2.8.2 Main Steam System

The main steam system delivers steam from the steam generators via three main steam lines to a 38 inch header which feeds four 28 inch lines to the turbine generator. The 38 inch header also supplies steam to the moisture separator reheaters, the auxiliary steam system, the gland seal steam system, and the

turbine bypass valves. Branches from each of three lines from the steam generators supply steam to the turbine driven auxiliary feed pump.

1.2.8.3 Main Condenser The main condenser condenses the turbine exhaust steam and maintains the turbine back pressure at 2 in Hg abs when

operating at turbine guarantee conditions with approximately

65F circulating water inlet temperature. The condenser includes provisions for accepting steam bypassed around the turbine-generator. Deaeration of condensate is accomplished in

the condenser.

1.2.8.4 Main Condenser Air Removal System

The main condenser air removal system uses steam jet air ejectors for normal operation and vacuum priming ejectors for start-up. The system evacuates noncondensible gases from the main turbine and condenser during plant start-up, and maintains the condenser essentially free of gases during operation. The system handles all inleakage of noncondensible gases through the turbine seals, condensate, feedwater, and steam systems, including the steam generators in the event of primary to secondary leakage.

1.2.8.5 Turbine Gland Sealing System

The turbine gland sealing system provides clean, relatively moisture- free steam to the seals of the turbine throttle valve stem glands and the turbine shaft glands. The sealing steam is normally provided from the 38-inch main steam header. Leakoff from the seals is directed to the gland steam condenser. The generator shaft seals are sealed with lubricating oil to prevent

hydrogen leakage.

BVPS-2 UFSAR Rev. 16 1.2-8 1.2.8.6 Steam Bypass System and Pressure Control System A turbine bypass system is provided to pass steam directly to the main condenser under the control of a pressure/temperature control regulator. Steam is bypassed to the condenser whenever the turbine trips or during start-up and cooldown. The turbine bypass system is capable of discharging steam flow directly to the main condenser. The capability of the turbine bypass system to mitigate a turbine and reactor trip upon loss of electrical load is discussed in Section 10.4.4.

1.2.8.7 Circulating Water System

The circulating water system provides the condenser with a continuous supply of cooling water. The circulating water system is a pumped, closed-loop system utilizing an air-cooled,

natural draft hyperbolic cooling tower as a heat sink. Four one-quarter capacity circulating water pumps are provided to pump cooling water from the discharge of the condenser to the

tower. The cooling water is then gravity-fed back to the condenser. Makeup water is provided from the Ohio River by the service water system. Water quality is controlled by blowdown

to the Ohio River.

1.2.8.8 Condensate and Feedwater Systems

The condensate and feedwater systems supply condensate from the condenser hotwell to the steam generators. The condensate is normally pumped by two of three 50-percent design capacity condensate pumps through the full flow condensate polishing system to the intercooler and aftercooler of the air ejector,

and the gland seal condenser. The condensate then flows through drain coolers and five stages of low pressure heaters. The drain coolers and low pressure heaters are split into two one-half capacity parallel streams. The last low pressure heaters discharge to the suction of two parallel, motor-driven, steam generator feedwater pumps. The discharge of the steam generator feedwater pumps passes through two one-half capacity parallel heaters and into the steam generators. The feedwater flow to each steam generator is controlled by a feedwater flow control

valve located downstream of the heaters.

1.2.8.9 Condensate Polishing System

A powdered resin condensate polishing system with regeneration and dewatering facilities, instrumentation, and semiautomatic

controls is provided to ensure a constant supply of high quality water to the steam generators.

The polishing system is capable of processing the full flow from the discharge of the condensate pumps. The demineralized water is returned to the condensate system upstream of the air

ejectors.

BVPS-2 UFSAR Rev. 20 1.2-9 1.2.9 Electrical Systems

The main generator is an 1,800 rpm, 22 kV, three-phase, 60 Hz, hydrogen inner-cooled unit rated at 1,070 MVA at 0.92 power

factor. One 1020 MVA main step-up transformer is provided to deliver power to the 345 kV switchyard.

The station service system consists of auxiliary transformers,

4,160 V switchgear, 480 V unit substations, 480 V motor control centers, 120 V ac vital and essential buses, and 125 V dc batteries and equipment. The normal source of station service power is obtained from the main generator through the unit

station service transformers. The preferred source is available from the 138 kV high voltage switchyard through the system station service transformers. The BVPS-2 one-line electrical

diagram is shown on Figure 8.3-1.

Two onsite, emergency diesel generators are provided to supply

power in the event of complete loss of normal and preferred alternate station service power. Each emergency diesel generator supplies power to separate and redundant trains of the plant emergency station service system. Each emergency diesel generator has sufficient capacity for operation of all safety-related equipment which must be operated to mitigate the effects

of a design basis accident (DBA) or to shut down the unit in a

safe manner.

In addition, a third onsite, nonsafety diesel generator is

provided to supply power to significant but nonsafety electrical

loads whose loss, in the event of a complete loss of normal

system ac power, would result in substantial equipment damage.

1.2.10 Engineered Safety Features Systems

The engineered safety features systems have sufficient

redundancy and independence of components and power sources such

that, under DBA conditions, the systems can maintain the integrity of the containment and keep potential exposures to the

public within the radiation dose criteria given in 10 CFR 50.67, as appropriate, even when operating with only partial

effectiveness (Chapter 6). The following systems are provided:

1. The steel-lined, reinforced concrete containment structure provides a highly reliable barrier against the escape of radioactivity. The structure and all penetrations, including access openings and

ventilation ducts, are of proven design.

2. The emergency core cooling systems cool the core by injecting borated water into the reactor coolant loops

from the accumulators, the high- and low-head safety injection pumps, and the recirculation spray pumps (during the recirculation phase following a loss-of-

coolant accident (LOCA).

BVPS-2 UFSAR Rev. 18 1.2-10 3. The quench spray subsystem of the containment depressurization system provides a spray of borated water to the containment atmosphere. The recirculation spray system provides a spray of borated water buffered by the containment sump pH control system to the containment atmosphere. Following the DBA, the containment pressure is reduced by the containment depressurization system. The sodium tetraborate in the containment sump pH control system combined in the recirculation spray removes iodine from the containment atmosphere. Subsequent long-term cooldown and depressurization is accomplished by the recirculation spray system.

4. Radioactive leakage through containment penetrations to contiguous plant areas is removed by the supplementary leak collection and release system. The

effluent is monitored for activity and discharged to the atmosphere at a release point above the

containment structure.

5. The post-DBA hydrogen control system has the capability of purging a portion of the containment

atmosphere to the atmosphere outside containment following a DBA. The containment spray system

provides mixing of the containment atmosphere.

6. The containment isolation system isolates pipe lines which penetrate the containment boundary in accordance with Appendix A of 10 CFR 50, General Design Criteria

55 through 57, so that in the event of a LOCA,

radioactivity is not released to the environment.

7. The habitability system for the main control room is provided to ensure that the control room operators are able to remain in the area and operate the nuclear power unit safely under all conditions, including

during and following a postulated DBA.

1.2.11 Cooling Water and Other Auxiliary Systems

Safety-related auxiliary systems are as follows:

1. The service water system transfers heat from the primary component cooling water system and other safety-related systems to the ultimate heat sink.

This system operates during all normal, upset and

faulted conditions.

BVPS-2 UFSAR Rev. 13 1.2-11 2. The primary component cooling water system is an intermediate cooling system provided to transfer heat from the reactor auxiliary systems and from systems containing potentially radioactive liquids. The

primary component cooling water system provides cooling water for systems and components required for a safe shutdown.

3. The emergency diesel generator fuel oil storage and transfer system is designed to store and supply sufficient fuel oil for seven days of continuous operation of each diesel engine. Independent emergency diesel generator cooling water systems,

redundant starting air systems, and lubrication systems, are provided for each diesel.

4. Air conditioning and ventilation systems for safety-related areas control ambient air temperature and

provide a suitable environment for personnel and

equipment, with features to provide protection against the spread of airborne radioactive contamination. Areas subject to radioactive release have provisions for particulate and gaseous radiation monitoring and filtration of the ventilation exhaust air.

5. The spent fuel pool cooling system removes residual and decay heat from the spent fuel stored in the fuel

pool. 6. The functions of the chemical and volume control systems include the control of boron concentrations in the RCS, maintenance of the proper RCS inventory, removal of fission and corrosion products, water chemistry control and continuous supply of filtered water to the reactor coolant pump seals. Portions of the system also provide emergency core cooling following a postulated accident.

7. The auxiliary feedwater system serves as an emergency backup for supplying feedwater to the secondary side of the steam generators upon loss of normal feedwater.
8. The residual heat removal system removes residual and decay heat from the core during reactor cooldown at RCS temperatures of 350F and below.

Auxiliary systems which are nonsafety-related are as follows:

1. The boron recovery system stores and processes borated radioactive water from the RCS. The system employs degasifiers, evaporators, filters, and demineralizers to produce primary grade water and concentrated boric

acid BVPS-2 UFSAR Rev. 0 1.2-12 solution for reuse in plant or disposal. Some of the equipment is shared with BVPS-1.

2. The vent and drain system collects hydrogenated or aerated fluids from various systems and transfers them to either the boron recovery system or the appropriate waste system.
3. The compressed air systems supply service and instrument air required for normal operation (Section 9.3.1).
4. The fire protection system includes a water system shared with BVPS-1, a low pressure CO 2 system, a Halon system, portable fire extinguishers, and a smoke

detection system.

5. The fuel pool purification system clarifies and purifies the water in the fuel pool, the refueling cavity, the transfer canal, and the refueling water storage tank.
6. The sampling systems provide the capability to collect representative reactor and steam plant liquid and

gaseous samples at the sampling sinks for laboratory

analysis.

7. The demineralized water and cask washdown system is used during all modes of operation to supply high quality water to various reactor plant and turbine plant systems for makeup, sample sink flushing, hose

stations for decontamination and other miscellaneous services requiring demineralized water. This system is connected to the BVPS-1 demineralized water system

which provides all demineralized water for both units.

8. The primary grade water system is a storage and distribution system that supplies reactor plant auxiliary systems exclusively. It also supplies makeup water to the reactor plant. The storage tanks

and pumps for this shared system are located in BVPS-

1. 9. The chilled water system provides chilled water to the containment atmosphere recirculation coolers and to

various building air cooling equipment.

10. The turbine plant component cooling water system is an intermediate cooling system provided to transfer heat from the turbine plant equipment to the service water system.

nmIt\)lr-@$i#tFI.l/w-'"-*-/"'\

aa\....)81f,$lQIFN:ol,t.,7"'-'l Y'l\;\.--"4FIi*Es -5:FP-FE ZilHHJ=!3i6etlz-sni$r,'ffii:7\ i@"rdi4 -.,o.OFOO5oo-1FrJ0FFI1oi'JItDN)O(-flNJOld5b\oO5H BVPS-2 UFSAR Rev. 16 1.3-1 1.3 COMPARISON TABLES The comparisons with other stations provided herein reflects the status of Beaver Valley Power Station - Unit 2 at the time of the issuance of the Operating License. This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.

1.3.1 Comparison with Similar Facility Designs

Beaver Valley Power Station - Unit 2 (BVPS-2) utilizes proven mature designs. The nuclear steam supply system (NSSS) is of

proven design and incorporates systems, equipment, and technology which have been successfully applied in more than 100 units designed by Westinghouse Electric Corporation. The balance of the unit, including the containment structure, was designed and constructed by the Applicant through its agent, Stone & Webster Engineering Corporation (SWEC). The SWEC design incorporated mature design concepts which had been utilized in nine operating nuclear power plants and seven nuclear plants which were in various stages of design, U.S. Nuclear Regulatory

Commission (USNRC) review, and construction.

In Table 1.3-1, the general design features of BVPS-2 are

compared with those of Beaver Valley Power Station - Unit 1 (BVPS-1), Millstone Unit 3 (Northeast Utility Company), and North Anna Units 1 and 2 (Virginia Electric Power Company). The plant comparison follows the general outline of the Final Safety Analysis Report (FSAR) chapters and is based on a single unit of each design. The USNRC has reviewed these designs extensively; BVPS-2 design incorporates the experience gained in these applications.

1.3.1.1 Comparison of Nuclear Steam Supply Systems The NSSS for BVPS-2 is similar to that of the other units, except for power level differences. In addition, Millstone Unit 3 has four reactor coolant loops while the other units each have three loops.

1.3.1.2 Comparison of Engineered Safety Features

The engineered safety features (ESF) compared are the emergency core cooling system (ECCS), containment heat removal system, containment combustible gas control system, containment isolation system, control room habitability, and the emergency filtration system. The ESF are the same, except BVPS-2 and Millstone Unit 3 utilize two of the recirculation spray pumps to inject recirculated containment sump water as part of the ECCS. The BVPS-2 recirculation spray pumps also supply the high head safety injection pumps in the ECCS recirculation mode. Beaver Valley Power Station - Unit 1 and North Anna Units 1 and 2 utilize low head safety injection pumps to perform this function.

BVPS-2 UFSAR Rev. 16 1.3-2 1.3.1.3 Comparison of Containment Concepts The containment concept, as shown by the comparison of parameters in Table 1.3-1, is the same as that of the other

plants listed.

These plants have already been extensively reviewed and approved

by the USNRC for operation.

1.3.1.4 Comparison of Instrumentation Systems

Instrumentation and controls are functionally similar to those at the other plants. The term functionally similar is intended

to mean similar in the basic operating and safety functions of the compared systems to which this applies. The specific features of BVPS-2 design are shown in detail and described in

applicable sections of the FSAR.

1.3.1.5 Comparison of Electrical Systems

Sections 8.2 and 8.3 of Table 1.3-1 provide a summary comparison of the electrical systems and parameters. While the transmission systems and onsite power systems differ due to utility preference, the emergency power systems, ac vital bus systems, and 125 V dc systems are similar in design.

1.3.1.6 Comparison of Waste Management Systems

Sections 11.2, 11.3, and 11.4 of Table 1.3-1 provides a summary comparison of the waste management systems. The liquid systems are functionally similar for all units compared. The gaseous waste systems are functionally similar for all units compared except that North Anna Units 1 and 2 use recombiners for gaseous waste volume reduction and all other designs utilize the charcoal delay bed concept for radioactive gas management. Beaver Valley Power Station - Unit 2 utilizes a prefilled, cement-in-drum solid waste system, while BVPS-1 uses an in-line,

cement, solid waste system. The other plants use an urea-formaldehyde or Dow process binder solidification agent.

1.3.1.7 Comparison of Other Nuclear Plant Systems The auxiliary systems (fuel pool cooling, component cooling water, service water, and boron recovery systems) are functionally similar for all units compared. Some differences occur due to siting, plant arrangement, and system design; however, the design basis for the auxiliary systems is essentially the same. In addition, North Anna Units 1 and 2 share the same fuel pool cooling and purification system while BVPS-1 and BVPS-2 share tankage subsystems of the boron recovery system.

1.3.1.8 Comparison of Structural Design Characteristics Sections 2.1, 2.5, 3.3 and 3.8 of Table 1.3-1 compare the BVPS-2

structural design criteria with those of the other plants. Some differences occur due to different site conditions. However, the basic parameters that define structural loadings are essentially

the same.

BVPS-2 UFSAR Rev. 0 1.3-3 1.3.2 Comparison of Final and Preliminary Information The significant changes between the preliminary and final design of BVPS-2 are listed in Table 1.3-2. The sections that address these changes are identified by their FSAR and PSAR section numbers. These changes have occurred since the submission of the PSAR and prior to issuance of the operating license. They have been approved and controlled in accordance with administrative procedures and are within the scope of the principal design criteria. New systems and equipment that are

post-PSAR are also included in the listing.

1.3.3 References for Section 1.3

U.S. Nuclear Regulatory Commission (USNRC) 1981. Asymmetric Blowdown Loads on PWR Primary Systems; Resolution of Generic

Task Action Plan A-2. NUREG-0609.

USNRC 1981. Standard Review Plan For the Review of Safety

Analysis Reports for Nuclear Power Plants. NUREG-0800.

BVPS-2 UFSAR Tables for Section 1.3

(Tables in Section 1.3 are historical)

BVPS-2 UFSAR Rev. 16 1 of 20 TABLE 1.3-1 DESIGN COMPARISON (HISTORICAL)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1 Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Introduction

Reactor type 1.1 PWR Same* Same* Same*

Reactor manufacturer 1.1 Westinghouse Same* Same* Same*

Site Characteristics Exclusion area boundary (minimum) (ft) 2.1 1,500 2,000 1,795 4,432 Low population zone (mi) 2.1 3.6 3.6 2.4 6 Safe shutdown earthquake (horizontal) (g) 2.5 0.125 0.125 0.17 0.12 Operating basis earthquake (horizontal) (g) 2.5 0.06 0.06 0.09 0.06 Structural Design Category I Normal wind (mph) 3.3 80 Same* 115 Same* Tornado region 3.3 1 1 1 1 Foundation type 3.8 Sand and gravel Sand and gravel Bedrock Rock Reactor

Nominal core power (MWt) 4.1 2,689 2,689 3,411 2,775 Fuel 4.2 17 x 17 Same* Same* Same*

BVPS-2 UFSAR Rev. 0 2 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Reactivity control 4.2 Reactor control rods and boric acid shim Same* Same* Same*

Nuclear design 4.3 Slightly enriched U0 ceramic pellets in Zircaloy-4 tubing Same* Same* Same*

Reactor Coolant System and Connected Systems and Equipment 5.1 Reactor vessel 5.3 Cylindrical with welded hemispherical bottom

head and removable hemispherical top head Same* Same* Same*

Reactor coolant pumps 5.4.1 3 single-speed centrifugal units driven

by air-cooled 3-phase induction motors Same* Same* except that it has 4 RCPs due to four loop design Same* Steam generators 5.4.2 Vertical U-tube Same* Same*, except 4 units Same* Residual heat removal system 5.4.7 Number of pumps 2 Same* Same* Same* Number of heat exchangers 2 Same* Same* Same*

Pressurizer 5.4.10 Vertical cylindrical vessel using electric heaters for maintaining system

pressure Same* Same* Same*

BVPS-2 UFSAR Rev. 16 3 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Engineered Safety Features 6.2 Containment 6.2 Type 6.2 Subatmospheric (9-11 psia)

Same* Same* Same*

Design pressure (psig) 6.2 45 Same* Same* Design leak rate (percent per day) 6.2 0.1 Same* 0.9 Same* Containment heat removal systems 6.2.2 Quench spray system, recirculation spray system Same* Same* Same*

Containment isolation system 6.2.4 Complies with General Design Criteria 54,55,56, and 57 Same* Same* Same*

Emergency core cooling system 6.3 Injection of borated water by

accumulators, charging/HHSI pumps, and LHSI pumps during injection phase; recirculation of spilled

coolant from containment sump by recirculation and

charging/HHSI pumps Same* as BVPS-2, except LHSI pumps recirculate the containment sump

water Same* as BVPS-2, except

that the RHR pumps perform the same function

as the LHSI

pumps Same as BVPS-2, except LHSI

pumps recirculate the containment sump water

BVPS-2 UFSAR Rev. 0 4 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Control room habitability 6.4 Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, portable fire protection, personnel protective equipment and first aid, food and water storage, utility and sanitary facilities.

Some components and systems are shared with BVPS-1 Same* Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, portable fire

protection, personnel pro-tective equipment and first aid, food and water storage, utility and

sanitary facilities Radiation shielding, control room pressurization system, emergency air filtration, air-conditioning and ventilation, fire protection, per-sonnel protective equipment and first aid, food and

water storage, utility and sanitary facilities, remote

air intakes Emergency filtration systems 6.5 Control room area pressurization filtration system and supplementary leak collection and release system used to mitigate the

consequence of an accident Same* Same* Same*

BVPS-2 UFSAR Rev. 0 5 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Instrumentation and Controls Reactor trip system 7.2 Process instrumentation and control system, nuclear instrumentation system, solid state logic protection system, reactor trip

switchgear, manual actuation circuit

    • ** **

Engineered safety feature systems 7.3 Process instrumentation and control system, solid state logic protection system, engineered safety features test cabinet, automatic transfer from injection phase to recirculation

phase ** **, Same* except manual transfer from injection

phase to recirc-ulation phase

    • Systems required for safe shutdown 7.4 Monitoring indicators, controls, pumps, fans, diesel generators, valves, and heaters
    • **, Same* except has the capability for a safety grade cold shutdown

from the auxiliary shutdown panel

    • Safety-related display instrumentation 7.5 Feedwater and steam systems parameters, containment pressure, RWST water level, pressurizer water level, containment

recir- ** ** **

BVPS-2 UFSAR Rev. 0 6 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2) culation sump level, nuclear instrumentation, reactor coolant system

parameters, reactor control system parameters Other safety systems 7.6 Instrumentation and control power supply system, ESF protection channels power supply, RCS loop isolation valve interlocks, residual heat removal isolation, accumulator motor-operated isolation valve, switchover from

injection to recirculation, refueling interlocks

    • Instrumentation and control power

supply system, ESF protection channels power

supply, residual heat removal isolation, accumulator motor-operated isolation valve,

switchover from injection to recirculation,

refueling interlocks Instrumentation and control power

supply system, ESF protection channels power

supply, RCS loop isolation valve interlocks, residual heat removal isolation, accumulator motor-operated isolation valve, switchover from

injection to recirculation, refueling

interlocks Control systems not required for safety 7.7 Reactor control system, rod control system, plant control system interlocks,

pressurizer pressure control, pressurizer water level control,

steam generator water level control, turbine bypass control, incore

instrumentation. Designed for 85% loss of external electrical

    • Same*, except 50% load rejection capability without

reactor trip

BVPS-2 UFSAR Rev. 0 7 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2) load without tripping the reactor and for turbine trip below 70%

power without reactor

trip Electrical Power Transmission system to site 8.2.1 3 @ 345 kV lines 3 @ 138 kV lines Same* 3 345 kV lines 3 500 kV lines AC power system 8.3.1 Unit main transformer 1 @ 945 MVA Same* 2 @ 630 MVA 3 @ 330 MVA Unit station service transformer 2 @ 32 MVA Same* 1 @ 40 MVA 1 @ 50 MVA 3 @ 20 MVA System station service transformers (reserve) 2 @ 32 MVA Same* 1 @ 45 MVA 1 @ 50 MVA 3 @ 30 MVA Emergency power system 8.3.1 Emergency 4.16 kV buses 2 @ 1,200 amp Same* 2 @ 2,000 amp 2 @ 1,200 amp Diesel generator sets (2,000 hr rating) 2 @ 4,535 kW 2 @ 2,850 kW 2 @ 5,335 kW 2 @ 3,000 kW AC vital bus system 8.3.1 Inverters 4 @ 20 kVA Same* 4 @ 15 kW 3 @ 15 kVA 1 @ 20 kVA Dist. cabinets 4 Same* 4 4 BVPS-2 UFSAR Rev. 0 8 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2) 125 V dc power system 8.3.2 Unit batteries (125 V) 4 safety-related 2 @ 1,650 AH 2 @ 1,050 AH 2 nonsafety 2 @ 2,400 AH 2 @ 2,400 AH 4 safety-related 2 @ 1,800 AH 1 @ 1,650 AH 1 @ 1,680 AH 1 nonsafety 1 @ 2,400 AH 4 safety-related 2 @ 1,650 AH 2 @ 750 AH 2 nonsafety 2 @ 2,550 AH 4 safety-related 1 @ 1,500 AH 1 @ 800 AH Battery chargers 5 safety-related 4 @ 100 amp 1 spare @ 100 amp 2 nonsafety 1 @ 200 amp 1 @ 150 amp 4 safety related 4 @ 100 amp 1 nonsafety 1 @ 150 amp 6 safety-related 2 @ 200 amp 2 @ 50 amp 2 spare @ 200 amp 3 nonsafety 4 safety-related 4 @ 250 amp 2 spares 2 @ 250 amp 2 @ 200 amp 1 spare @ 200 amp Auxiliary Systems Fuel storage and handling New fuel storage 9.1.1 Dry storage in steel and concrete structure within the fuel building for 1/3 of a core (53 fuel assemblies) plus 17 spare fuel assemblies Same* Same*,

but will use spent fuel area for storage of new fuel using the

dry storage area as an optional backup location Common area for

both units.

Storage the same as BVPS-2 for

each unit

BVPS-2 UFSAR Rev. 0 9 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section BVPS-2 BVPS-1 Millstone (Unit 3) North Anna (Units 1 & 2)

Spent fuel storage 9.1.2 High density poison racks with storage for 1,088 spent fuel assemblies in a reinforced stainless steel-lined pool within

the fuel building High density racks with storage for 833 spent fuel

assemb-lies in a reinforced stainless steel-

lined pool within the fuel building Storage for 1,835

spent fuel assemblies with

room for 1 full core off-load Common area for

both units with storage for 966

spent fuel assemb-lies in a reinforced concrete pool within the fuel building Spent fuel pool cooling and cleanup 9.1.3 2 pumps and 2 coolers; 2 pumps, 2 filters, and 1

demineralizer for purification Similar to BVPS-2 Similar to BVPS-2, except 2 additional filters in the purification system 2 pumps and 2 coolers; 3 pumps, 2 filters, and 1

demineralizer for purification Fuel handling system 9.1.4 System has provisions to prevent fuel handling and cask drop accidents Similar to BVPS-2 Similar to BVPS-2 Similar to BVPS-2 Water Systems Service water system 9.2.1 2 redundant flow paths supplied by three 50%

capacity service water pumps supplying cooling water to

primary and secondary component cooling systems,

control room cooling, charging pump cooling water system, and rod control area air-conditioning systems. For accident conditions, each SWS pump is a 100% capacity pump with all

systems isolated except containment recircula- 3 river water

pumps supplying cooling water to primary component cooling water system, control room cooling, charging pump cooling water system, and pump

and motor bearing cooling on river and raw water

pumps. For accident con-ditions the same as BVPS-2. Turbine plant component cooling water heat exchangers are cooled by a 2 redundant flow-paths, each con-taining two 100% capacity service water pumps,

sup-plying cooling to component cooling systems, charging pump cooling, con-trol buidling air-con-ditioning, SI pump cooler and rod con-trol area air-condi-tioning on loss of power. For acci-dent

conditions, service water sup-plies containment

recirculation spray 2 redundant flow-

paths supplied by four 50% capacity service water pumps (normal operation of both units) and two 50% capacity

auxiliary service water pumps supplying

component cooling systems, control room cooling, charging pump coolers, instrument air

compressors, and pipe penetra-tion cooling. For accident conditions, all systems isolated BVPS-2 UFSAR Rev. 0 10 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2) tion spray coolers, charging pump coolers, control room cooling, and

emergency diesel generator cooling. A standby service water system, consisting of two 100% capacity pumps, takes suction

from an alternate intake structure and discharges to the

redundant service water headers, to provide cooling for unit

shutdown and cooldown after loss of the seismic Category I intake structure.

separate river water system

cooler, containment recirculation pump, ventilation units, SI and charging pump coolers, diesel

generators, control building air-conditioning

and post-accident sample cooler except containment recirculation spray cooling, charging

pump coolers, control room

cooling,

instrument air compressors, and pipe pene-tration

cooling Ultimate heat sink 9.2.5 Ohio River Same as BVPS-2 Long Island Sound (Atlantic Ocean) Service water reservoir with Lake Anna backup Other water systems 9.2.2.1 9.2.2.2

9.2.3 9.2.4 9.2.6 Primary and

secondary plant

component cooling water systems, chilled water system,

demineralized water makeup, potable and sanitary water

systems, and condensate storage facilities.

Same*

Same* Same*

Same* Same*

Same*

BVPS-2 UFSAR Rev. 0 11 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Process auxiliaries Compressed air systems 9.3.1 2 redundant compressors supply air for instruments and service air system. 2 redundant

compressors supply containment instrument air system,

and 1 compressor supplies condensate polishing air. Same as BVPS-

2*, except there is

no condensate polishing air system and the

containment instrument air compressors are

inside the containment.

2 redundant compressors supply air for instruments. 1 compressor supplies service air and 2 redundant compressors supply containment

instrument air. Also, 2 additional compressors

supply air required for cold shutdown.

For both units, 2 compressors

supply service air and 2 compressors supply instrument air. For Unit 1, 2 com-pressors

supply containment instrument air.

For Unit 2, 4 com-pressors supply containment

instrument air (2 operating, 2 back-up) Process sampling system 9.3.2 Collects reactor plant and turbine plant gaseous and liquid samples for chemical and radiochemical

analysis Same* Same* Same*

Equipment and floor drainage system 9.3.3 Collects and treats potentially radioactive liquid drainage and associated entrained

gases Same* Same* Same*

Chemical and volume control system 9.3.4 Letdown and charging system is used for reactivity control, purification of reactor

coolant, RCS inventory control, and provides high pressure

flow to the ECCS Same* Same* Same*

BVPS-2 UFSAR Rev. 7 12 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1 Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Boron recovery system 9.3.4.6 Evaporative concentration of letdown boric acid and production of primary

grade water for recycle (shared tankage located on

BVPS-1) Same* Same*, except for shared portion of BVPS-2 Same*, except for shared portion of BVPS-2 Air-conditioning, heating, cooling, and ventilation systems Control room and control building heating, ventilation, and air-conditioning system 9.4.1 Provides heating, ventilation, and air-conditioning to control room, computer room, process instrument room, equipment room, cable spreading

room, and the auxiliary building cable tunnel Same* Same*, excluding chiller room and cable spreading area Provides heating,

ventilation, and air-conditioning to control room,

office and computer room, process instrument room, relay room, and communications

room. Control room emergency bottled air supply system with subsequent filtered

emergency ventilation system Containment atmosphere recirculation system 9.4.7 Maintains controlled environment for personnel and

equipment during normal operation Same* Same* Same*

BVPS-2 UFSAR Rev. 0 13 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics

Referenced

in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Other heating, cooling, and ventilation systems 9.4.2 to 9.4.6 9.4.8 to 9.4.16 Fuel building, auxiliary building, turbine building, waste handling building,

emergency diesel generator building, condensate polishing

building Same*, except for

condensate polishing building Same* Same*

Other auxiliary systems 9.5 Fire protection system 9.5.1 Detects, extinguishes, and mitigates effects of fires that may occur Same* Same* Same*

Emergency diesel generator cooling water system 9.5.5 Maintains diesel generator jacket water within specified temperature limits by service water system Same* Same* Maintains diesel engine jacket water within specified

temperature limits by self-contained radiator cooling system Additional auxiliary systems 9.5.2, 9.5.3, 9.5.4, 9.5.6, 9.5.7, and 9.5.8 Communications

systems, lighting systems, redundant emergency diesel

generator support systems including:

1 nonsafety (black) diesel generator, fuel oil storage and transfer, starting, lubrication, and combustion air intake and exhaust systems. Same*, except for the nonsafety diesel generator Same*, except for the nonsafety diesel generator Same*, except for the nonsafety diesel generator

BVPS-2 UFSAR Rev. 0 14 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Steam and Power Conversion

System Turbine generator 10.2 Westinghouse tandem-compound, 4-flow, 1,800 rpm steam reheat machine; 1

double-flow HP turbine and 2 double-flow LP turbines Same* Same*, except General Electric 6-flow turbine generators Same* Main steam supply 10.3 797 psia, 11.61 x 10 lb/hr

steam flow, 518F Same* 960 psia, 15.05 x 10 lb/hr steam flow, 540F 850 psia, 12.2 x 10 lb/hr

steam flow, 525F Other features of steam and power conversion system Main condensers 10.4.1 Double shell, single-pass, divided water box Same* Same* Same*

Main condenser evacuation system 10.4.2 Steam jet air ejectors with auxiliary steam

priming ejectors for initial evacuation Same* Steam jet air ejectors with vacuum pumps for initial evacuation Same* Turbine bypass system 10.4.4 Passes up to 90% of full-load steam flow to allow 85% to 100% step load reduction without a reactor trip.

(See Section 10.4.4 for details.) Passes up to 90% of full-load steam

flow to allow up to 100% step load reduction without

reactor trip Passes up to 40%

of maximum

steam flow to allow up to 50%

step load

reduction without reactor or turbine trip Same*

BVPS-2 UFSAR Rev. 0 15 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Circulating water system 10.4.5 Removes heat from the main condenser by circulating water through 1 natural draft cooling tower Same* Removes heat from the main condenser by circulating water

from Long Island Sound Removes heat from the main condenser by circulating water

from Lake Anna Condensate cleanup system 10.4.6 Full flow condensate polishing

demineralizers are

provided at the discharge of the condensate pumps.

Here powdered resin demineralizers are capable of maintaining

a steam generator chemistry well below maximum requirements. None Same* Same*

Condensate and feedwater system 10.4.7 Returns condensed steam from condenser, and drains from regenerative

feedwater heaters (6-stage heater cycle), to steam generators

while maintaining water inventories throughout system Same* Same* Same*

Auxiliary feedwater system 10.4.9 Supplies necessary cooling water to steam generators for decay heat removal, feedwater line malfunction, or main steam line break Same* Same* Same*

BVPS-2 UFSAR Rev. 0 16 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Auxiliary steam and condensate system 10.4.10 Supplies heating throughout the plant to various heating and processing equipment,

and recovers the condensed steam from the equipment

served. Normal source of auxiliary steam is main steam.

Auxiliary boiler used when reactor not at power Same* Same* Same*, except normal source of auxiliary steam is second point

extraction.

Radioactive Waste Management Liquid waste management system 11.2 Type of processing Evaporation Yes Yes Yes Yes Demineralization Yes Yes Yes Yes

Filtration Yes Yes Yes Yes

Treatment of radioactive waste High activity waste 11.2 All liquid waste can be evaporated or filtered depending on its

activity. The distillate from the evaporator can be demineralized and filtered. There is no Evaporation

and/or demineralization/

filtration Similar to BVPS-1 Similar to BVPS-1 BVPS-2 UFSAR Rev. 0 17 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2) separation of high and low activity streams prior to liquid waste tanks Low activity waste 11.2 See "High activity waste" Filtration (low

activity waste can be routed to the high activity waste tanks and

evaporated)

Filtration

(evaporation and

subsequent operations are optional)

Similar to

Millstone Unit 3

with the addition of a clarifier before release to

the environment Steam generator blowdown 10.4.8 Blowdown piped to flash tank where steam is piped to 2nd point heater and liquid is piped to main condenser via 4th point heaters for processing through condensate polishing demineralizers, or liquid is piped to demineralizers for processing prior to routing to the condenser. Blowdown piped to flash tank and steam is then piped to the third point heaters and liquid is piped to demineralizers for processing prior to routing to the condenser Similar to BVPS-2

except steam piped to 4th point heater Blowdown piped

to flash tank where steam is piped to roof vent

and liquid processed by clarification.

Gaseous waste management systems 11.3 Type of treatment Degasification Yes (occurs in boron recovery system) Yes (occurs in boron recovery system) Yes Yes (called gas strippers in boron recovery system)

Decay of noble gases in high activity gas streams Yes Yes Yes Yes BVPS-2 UFSAR Rev. 0 18 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section BVPS-2 BVPS-1 Millstone (Unit 3) North Anna (Units 1 & 2)

Filtration of low activity gas streams Yes Yes No Yes Recombiners No No No Yes Treatment of streams Continuous degasification of reactor letdown capability Yes Yes Yes Yes Degasification of letdown to boron recovery system Yes Yes Yes Yes Degasification of reactor plant gaseous drains Yes Yes Yes Yes Decay method for gases stripped in degasifier Adsorption on charcoal for minimun of 30 days and 2 days

xenon and krypton decay, respectively, before recycle or release to atmosphere through BVPS-1 process vent on BVPS-1 cooling tower Same* Adsorption on charcoal for minimum of 60

days and 4 days xenon and krypton decay,

respectively, before recycle or release to the environment Recombination of hydrogen in the gaseous waste

stream to reduce storage requirements in waste gas decay tanks before release to the environment Low activity air streams (nonventilation streams)

HEPA/charcoal filter assemblies in the process vent on BVPS-1 Same* Release through Millstone 1 stack Similar to BVPS-2 Solid waste management 11.4 Type of treatment Solidification In-drum In-line In-container In-line (1 waste disposal building for both units)

BVPS-2 UFSAR Rev. 0 19 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Solidification agent Cement Cement Dow process binder Urea-formaldehyde Inputs (type) treated Boron evaporator bottoms None; processed by BVPS-1 Yes Yes Yes Waste evaporator bottoms Yes Yes Yes Yes Spent beaded resins Yes Yes Yes Yes Powdered resins Yes No Yes Yes Filtered elements Yes Yes Yes Yes Miscellaneous waste (contaminated clothing, tools, paper products, etc) Yes Yes Yes Yes Radiation Protection Radiation Protection Design Features 12.3 Shielding Shielding thickness and coverage

determined for each area to assure maximum design dose rates are not

exceeded and to prevent activation of components within

containment Same* Same* Same*

BVPS-2 UFSAR Rev. 0 20 of 20 TABLE 1.3-1 (Cont)

Section and Characteristics Referenced in Section

BVPS-2

BVPS-1

Millstone

(Unit 3)

North Anna

(Units 1 & 2)

Ventilation Ventilation, filtration of ventilation streams, and atmospheric release of ventilation

streams to maintain comfortable environment and limit

airborne radioactivity below concentration limits of 10 CFR 20,

Appendix B Same* Same* Same*

NOTES: *Where the word 'Same' appears, the design feature of the listed unit is the same as that of BVPS-2. **Instrumentation and Controls are functionally similar. The term functionally similar is intended to mean similar in the basic operating or safety functions of the compared systems to which this applies. The specific features of the BVPS-2 design are described in detail in applicable sections of the UFSAR.

BVPS-2 UFSAR Rev. 16 1 of 19 TABLE 1.3-2 COMPARISON OF FINAL AND PRELIMINARY INFORMATION (HISTORICAL)

FSAR Section

/PSAR Reference Significant Changes Since PSAR 2.2.3 /2.1 Addressed monitoring of main control room for accidental release of chlorine in accordance

with Regulatory Guide 1.95.

2.5

/2.5 Discussion of subsurface conditions within main plant area revised due to discovery of zone of loose granular soil that required densification.

3.7B.3.1.2

/None Former selection of highest elevation curves of

amplified response spectra (ARS) for piping analysis now envelopes all applicable ARS curves to assure more conservative analysis. Increased ARS peak broadening from 15% to +25% -20% to be comparable with equipment analysis.

3.9B.3.2.1

/15.6.2.3 Seal leakage tests, previously addressed as being performed at the same pressure used in the hydrostatic tests, has been changed to read leakage tests performed at performance test pressures.

3.9N.4.4

/None The control rod drive mechanism (CRDM) seismic

supports were upgraded because subsection NF

requires that the component supports be the same code classification as the equipment they are supporting. Since the CRDM pressure housings are ASME Code Class 1, the supports must also be Class 1.

3.10B /15.5.3.1 Added Standard Review Plan (SRP) Section 3.10 statement dated 24 November 1975 (USNRC NUREG-75/087) in addition to existing IEEE Standard

344-1971 position.

3.10N

/None The seismic and environmental requalification program has been necessitated by a change in licensing codes and regulations from IEEE Standards 323-1471 and 344-1971 to the methodology of IEEE Standard 344-1975 and the environmental test envelopes and analytical techniques associated with IEEE Standard 323-

1974.

BVPS-2 UFSAR Rev. 0 2 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

Appendix 3A

/None Piping analysis computer program changed from SHOCK 3, PIPESTRESS, STRESS COMBINER, AND NCCODE to current Stone & Webster Engineering Corporation (SWEC) computer program, NUPIPE-SW.

4.3.2.1 /None Hafnium conversion made to improve control rod

design. 5.2.2.5 /None Addressed mounting, support, and reaction force capability of pressurizer relief valves.

5.2.3.4.6

/None Analysis of socket welded fittings made to show compliance of the socket weld, of the attached piping, and of the branch nozzle to the requirements of an ASME Section III fatigue evaluation.

5.2.5 /4.2.4 & 9.7 Provisions made for continuous monitoring of leakage from reactor containment pressure boundary into containment sumps with Class 1E narrow range level transmitters and programmable controllers.

5.3 /None Reactor vessel weld material program provides

the information necessary to satisfy USNRC

Bulletins 78-12 and 78-12A.

5.3.3.1

/4.4.2 The reactor pressure vessel insulation provides a thermal neutron shielding to reduce activation of the upper vessel, nozzles, and neutron shield tank. 5.4.1 /None As a result of the change to the surge and protection for the reactor coolant pump (RCP) motors, the RCP turn-to-turn insulation is rated to accept 4,160 V, indicating that surges 2.5 times higher than expected could be accommodated

during pre-operational tests without harming the motors. 5.4.3.2 /None Thermal sleeves in the reactor coolant loop

branch nozzles have been deleted to simplify the nozzle design and to show technical improvement.

BVPS-2 UFSAR Rev. 0 3 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

5.4.4.1

/None Modifications to steam generators integral flow restrictor to provide significant design enhancement. Benefits include improved mass and energy calculation, reduced blowdown during a steam break, and reduced steam break size from 4.6 ft2 to 1.4 ft

2. 5.4.7.2 /4.1.2.1 The change from a one train RHR system to a two train RHR system provides maximum operational flexibility concurrent with maintenance

capabilities.

5.4.7.2.1

/4.1.2.1 The RHR interlocks have been revised to reflect an auto closure set point on increasing reactor coolant system (RCS) pressure >750 psig to allow full relief valve potential and preclude premature isolation of the RCS low pressure relief projection.

5.4.7.2.2

/None The residual heat removal (RHR) miniflow change from automatic to manual provides protection for the RHR pumps from deadheading against high

discharge pressure.

5.4.7.2.3

/None The reactor vessel head vent change is a part of

the cold shutdown modification discussed in UFSAR Section/PSAR Reference 5.4.7.2.6, and provides venting capability from the reactor

vessel head should this action become necessary.

5.4.7.2.6

/None The extensive change in the approach to safety

grade cold shutdown provides a significant improvement in the ability to bring the plant to a cold shutdown condition in the event of an

abnormal occurrence.

5.4.11.2.1

/None Pressurizer relief tank cooldown and drainage provide to protect against overfilling of tanks and introduction of water into the degassification system.

Appendix 5A

/None Same as for UFSAR Section/PSAR Reference

5.4.7.2.6.

BVPS-2 UFSAR Rev. 0 4 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

6.2.1.1.3.1

/6.4 Refueling water storage tank (RWST) capacity increased because of containment depressurization calculation.

6.2.1.1.3.7

/10.3.5 Automatic closure of motor-operated discharge valves in auxiliary feedwater lines to each steam generator replaced with cavitating venturies to limit flow to the steam generator affected by a pipe break.

6.2.1.3 /None Same as for UFSAR Section/PSAR Reference 7.3.1.1.

6.2.2.2.1

/6.4 Quench spray system (QSS) header diameters and design of nozzles changed to provide more uniform delivery of smaller droplets spray for better

thermal effectiveness.

6.2.4

/5.2 Changes to containment isolation system include:

1. Elimination of pressurizer dead weight calibrator.
2. Increased number of penetrations dedicated to containment leakage monitoring from one to two.
3. Added new penetration for chemical addition line to QSS.

6.3.2

/6.3.2.1.2 To provide for reduced plant maintenance/radiation exposure, without compromise in plant safety, the boron injection tank was eliminated.

6.3.2.2 /6.3.2.2.2 The automatic transfer to recirculation design

provides for those essential operations which establish a flow path from the containment sump to the RCS to continue reactor core cooling flowwithout operator action. The PSAR design required two manual operator actions.

6.3.3 /6.3.2.2.1 The coincidence of low pressurizer water level and pressure for the safety injection logic was

deleted, and the existing safeguards actuation logic was converted to two-out-of-three low

BVPS-2 UFSAR Rev. 0 5 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

pressurizer pressure signals. This modification meets the signal failure criterion.

6.4.2.3

/9.13.4 Added quick-acting chlorine detectors to outdoor air intakes of main control room envelope to enhance its habitability, as determined from toxic chemical analysis. Added redundant,

Category 1 area radiation monitor to isolate the control room area environment to maintain control roomhabitability during design basis

accident.

6.5.2

/6.4 Use of positive displacement pump to add sodium hydroxide solution to quench spray, instead of gravity feed system proposed earlier, to improve control of chemical addition.

6.5.3 /5.3.1 Changed elevated release point for fission product control from top of cooling tower to top

of containment.

7.2.1.1.2

/None Steam line break protection system changed to enhance plant safety and to increase plant availability by preventing spurious safety injection actuation.

The analysis for the deletion of reactor trip following a turbine trip below 70 percent power is addressed in Section 15.2.3.

The deletion of coincidence of low pressurizer water level and pressure for the safety injection logic is addressed in FSAR Section/PSAR Reference 6.3.3.

7.2.2.2.3

/7.2.2.2.1 The deletion of the RCP breaker position allows the breaker open indication to be eliminated as a source of reactor trip when this indication is from a single relay source, without affecting plant safety. That is, this change can

potentially eliminate nuisance trips.

7.3.1.1

/7.3.2.1.1 Implementation of N-1 loop steam line break

protection system that actuates safety injection and steam line isolation on receiving two-out-of-three low steam line pressure signals from any one steam line. The protection logic will increase the

BVPS-2 UFSAR Rev. 0 6 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

margins to the trip set points during the start up phase where problems are most likely to occur. The modification to the solid state protection system incorporates a manual initiation of steam line isolation at the system level. Amendment 12 of the PSAR, Question 7.5, committed this design modification to the USNRC.

7.4.1.2.1

/None A process equipment modification was made to nuclear steam supply system instrumentation signals to the emergency shutdown panel.

7.4.1.3 /None In the event of an exposure fire in the

instrumentation and relay room, cable spreading room, west communication room, and the cable tunnel, an alternate shutdown panel is provided in the auxiliary building to provide a means of alternative shutdown capability that bypasses all equipment and electrical cables located in the fire areas.

7.5.3 /None Bypass inoperable status indication system added to monitor Beaver Valley Power Station - Unit 2 (BVPS-2) safety systems for operability prior to an accident condition.

Safety parameter display system added to BVPS-2 to monitor specific plant parameters used in the

emergency response facilities and nuclear data

link.

7.6.5

/7.6.1 & 7.6.5 Transfer from emergency core cooling system

injection mode to recirculation mode is automatic instead of manual, and depends on RWST level and a safety injection/CIB signal. Also

see change for UFSAR Section/PSAR Reference 6.3.2.2.

7.6.2.1 /7.6.1 The suction valves of the RHR pumps can be powered from either Class 1E bus. This ensures that after an isolation that the valves can be opened for RHR pump operation. Interlocks are provided to prevent paralleling of the two Class 1E power sources.

BVPS-2 UFSAR Rev. 0 6a of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

7.6.7.2

/4.2.2 Incorporation of RCS cold overpressurization

mitigation to provide for potential transients by utilizing the existing power-operated relief valves with modifications to their actuation

logic.

BVPS-2 UFSAR Rev. 0 7 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

7.7.1.2

/3.3.2.5.3 Deletion of part length control rods made to comply with regulatory restrictions on use of part length rods.

9.1.1 /9.12 Capacity of hoist for handling new fuel

assemblies increased from 5 tons to 10 tons.

9.1.2 /9.12 Changes to storage and handling of spent fuel

include:

1. Capacity of spent fuel pool increased from 274 spent fuel assemblies to 1,059

assemblies.

2. Assurance of an effective multiplication factor, K effof 0.90, formerly accomplished by center-to-center spacing of spent fuel assemblies,is now attained by use of neutron absorbing material, where K effwill be less than 0.95.
3. Fuel building hoists changed from two hoists of 2 tons and 5 tons capacities to two hoists, each of 10 tons capacity.
4. Failed fuel containers are not being provided now; however, provisions have been made for

future installation.

9.1.4.2.3.4

/None Fuel transfer system upgraded to help ensure trouble-free operation during initial refueling and core loading operations. The replacement enhances the reliabilityand maintainability of the fuel transfer system.

9.1.5 /None Provided description of new system, overhead heavy load handling system, that is used

throughout plant.

9.2.1

/9.9 Station service water system changes include:

1. Service water system load changes for normal operation include:
a. Component cooling water heat exchangers increased from one to two,

BVPS-2 UFSAR Rev. 0 8 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

b. Added air-conditioning unit to safeguards area,
c. Added one set of cooling coils to main steam valve house,
d. Charging pump lube oil coolers decreased from two to one per pump, and
e. Added motor control center cooling coils.
2. Service water system load changes for post-DBA operation are:
a. Added a set of cooling coils for motor control center,
b. Added rod control area air-conditioning unit,
c. Added safeguards area air-conditioning unit, and
d. Added main steam valve house cooling coils.
3. The former provisions for chemical addition to recirculation coolers for corrosion control are deleted.
4. All equipment with safety-related function and not located above probable maximum flood level is now flood-protected.
5. Primary component cooling water temperature is notcontrolled by flow of service water through recirculation coolers. Water temperature now a function of service water flow. 6. Portion of flow from cooling tower makeup diverted to service water discharge for

reasons of avoiding sediment buildup in

discharge lines.

BVPS-2 UFSAR Rev. 0 9 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

9.2.2.1

/9.4 Primary component cooling water system has these

criteria and equipment changes:

1. Cooling water pumps are now environmentally qualifiedfor normal, abnormal, and accident conditions operation, as addressed in Section 3.11. 2. Additional equipment that utilizes the cooling water of this system include: primary drains coolers, auxiliary steam degasifier coolers, radiation monitors, overhead gas compressors, and containment

instrument air compressors.

3. The containment air recirculation cooling coils have been deleted from Figure 9.4-4.

9.2.4

/9.11 Potable water will originate from wells instead of from Beaver Valley Power Station - Unit 1 (BVPS-1) treated river water supply, with head pressure provided by an elevated storage tank.

9.2.7 /10.3.9 Turbine plant component cooling water system

changes are:

1. Control valve added to discharge of each heat exchanger.
2. Makeup water tosystem is from demineralized water system instead of condensate system.
3. Surge tank capacity increased from 2,900 gallons to 3,173 gallons.
4. Total dynamic head rating of dual volume horizontal pumps changed from 120 feet to 160 feet, with same capacity of 11,000 gpm.
5. Additional equipment served by this system include: tank drain cooler, condensate polishing air compressor, evaporator reboiler drain coolers, and condensate polishing

sample sink cooler.

9.2.8

/9.11 Primary grade water storage tank addressed

earlier no longer in present design.

BVPS-2 UFSAR Rev. 0 10 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

9.3.1

/9.8 Changes to compressed air system include:

1. Containment instrument air compressors, air dryer, and airreceiver tanks (including new one of 25 ft 3capacity) now located in main steam line valve area instead of within

containment, although suction is still taken

from within containment.

2. Containment instrument air compressors rating changed from 110 psigat 50 scfm discharge to 120 psig at 30 scfm. Station air compressors rating increased from 110 psig at 358 scfm to

120 psig at 728 scfm.

3. Addition of refrigerant-type air dryer with desiccant filter bypass arrangement to containment instrument air system.
4. Addition of desiccant-type filter bypass arrangement to station instrument air dryer.
5. Both station air and containment instrument air compressors now have capability of

operating with power from the onsite

nonsafety diesel generator.

6. Addition of third system, condensate polishing air system.

9.3.2.1

/9.6 Reactor plant and process sampling system

changes include:

1. Addition of conditioning rack for blowdown grab samples.
2. Addition of on-line pH and Na conductivity monitors for each steam generator.
3. Addition of sampling capabilities for:

gaseous waste storage tanks, primary drains transfer tanks, primary grade water, gaseous waste surge tank, letdown flow, fuel pool, cesium removal ion exchangers, and RHR system liquids.

BVPS-2 UFSAR Rev. 0 11 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

4. Local sampling capabilities provided for RWST, boric acid tank, and QSS chemical addition tank.
5. Provisions made for exhausting potentially radioactive sample panel gases to supplementary leak collection and release

system.

9.3.2.3

/None Addressed new post-accident sampling system.

9.3.3

/9.7 & 4.2.4 Changes to equipment and floor drainage system

are: 1. Reactor coolant system loop drains formerly directed to both primary drains transfer and pressurizer relief tanks now directed to primary drains transfer tank only.

2. Valve stem leakoffs now go directly to primary drains transfer tank in containment instead of to pressurizer relief tank.
3. Addressed containment sump monitoring with Class 1E level transmitters and programmable controller.

9.3.4 /None The chemical and volume control system continuous degasification allows for admittance of hydrogen whenever a low pressure alarm

condition exists.

9.3.4.6

/9.2 Classification of that portion of boron recovery system from degasifiers and downstream piping to gaseous waste system downgraded from Safety Class 3 to non-nuclear safety (NNS) class.

9.4.1 /9.13.4 Same as for UFSAR Section/PSAR Reference

6.4.2.3.

9.4.3 /9.13.2 Changes to auxiliary and radwaste area

ventilation system include:

1. Ambient air temperature lower limit for ventilation equipment area and general areas increased from 60F to 65F.

BVPS-2 UFSAR Rev. 0 12 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

2. Air temperature limits for shielded cubicles at all levels (except those in radwaste area) changed from between 65F and 104F to between 65F and 120F. For radwaste area cubicles, the limits are between 65F and 104F.
3. Upper temperature limit during a DBA for component cooling water pump area and charging pump cubicles increased from 104F to 120F. 9.4.6 /9.13.7 Design temperature of the emergency diesel generator building ventilation system is 122F. Secondary supply fans have been added in order to meet environmental qualification requirements.

9.4.9 /None Upgraded main steam and feedwater valve area ventilation system to safety-related Safety

Class 3 to maintain environmental qualification temperatures.

9.4.11 /6.2.4 Area design temperatures for safeguards area ventilation system following a DBA reduced from 140F for first hour and dropping to 120F after shutdown of quench spray and low head safety injection pumps, to 120F maximum at beginning of DBA and below 120F after 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> when aforementioned pumps are shut down.

9.4.13

/9.15 Added filtration and exhaust subsystem for new gaseous waste storage tank and cask washdown areas to decontamination building ventilation system. 9.4.15 /10.3.3.1 Addressed gland seal steam exhaust ventilation system that filters and monitors noncondensable

gases before being discharged to environment, previously discharged directly to atmosphere.

9.4.16 /None Addressed new condensate polishing building

ventilation system, a NNS class system.

9.5.4 /9.14 Changes to emergency diesel generator fuel oil

storage and transfer system include:

1. Total capacity of two fuel oil storage tanks increased from 40,000 gallons to

BVPS-2 UFSAR Rev. 0 13 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

58,000 gallons to provide for 7 days full load operation of each diesel generator.

2. Cross-connection piping between fuel oil storage tanks now eliminated.
3. Fuel oil transfer pumps, formerly positive displacement type, mounted outside of storage tanks, and with capacity of 10 gpm, are now vertical centrifugal type, mounted inside of

tanks, and with capacity of 40 gpm.

4. Discharge line relief valves replaced with recirculation orifices.
5. Fuel strainers, formerly located in common fuel lines to diesel generators, now located in discharge of each oil transfer pump.
6. Engine-mounted fuel oil tank and day tank, each of 550-gallon capacity, replaced with single 1,100-gallon floor-mounted day tank

for each diesel generator.

7. All storage tanks and associated piping are either indoors or encased in concrete, with no components in direct contact with soil.

9.5.6 /8.5.2 Changes to emergency diesel generator starting

system include:

1. Both air compressors for each diesel generator now motor-driven, as opposed to formerly one motor-driven and one

diesel/electric-driven.

2. Two air receivers now provided for each diesel generator instead of former six air bottles.

10.2.1 /10.3.3.2 Turbine-generator exciter maximum output rating at 1,800 rpm increased from 3,300 kWe and 500 V dc to 3,900 kWe and 525 V dc.

10.3.1 /10.3.1 The residual heat release and atmospheric dump piping and equipment have increased in size and capacity, and the Category I boundary extended to BVPS-2 UFSAR Rev. 0 14 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

accommodate cold shutdown.

10.3.2 /10.3.1.2 Main steam supply system changes include:

1. Replaced nonreturn valves with main steam isolation valves to prevent reverse flow of

steam in event of accidental pressure

reduction.

2. Main steam line trip valves changed from swing disk-type to hydraulically-operated ball type, held open by solenoid-operated mechanical latch.
3. Parallel trip valve configuration for turbine-driven auxiliary feedwater pump steam supply changed. Presently, three pairs of series solenoid-operated trip valves are provided, one pair in each of the three 3-inch lines between the 32-inch main steam line and the 3-inch turbine drive common header. 4. Main steam line trip valves changed from hydraulically operated ball-type to pneumatically operated wye pattern globe valve. 10.4.4 /10.3.1 Added cooling tower pumps and low-low Tavgpermissive interlocks to turbine bypass control valves capabilities.

10.4.5 /10.3.4 Circulating water system changes include:

1. Total dynamic head of cooling tower pumps reduced from 96.4 feet to 73 feet through use

of natural draft counter-flow cooling tower

with its lesser static lift requirements.

2. Addition of flood indicators to: valve pits on suction side of cooling tower pumps, inlet and outlet sides of condenser, and turbine building retention pit, all with flood alarms

to main control room.

BVPS-2 UFSAR Rev. 0 14a of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

10.4.6

/None Addressed new condensate cleanup system, a NNS class system, consisting of two subsystems, condensate polishing system and powdered resin dewatering system.

10.4.7.2

/10.3.5 Changes to condensate and feedwater systems

include:

BVPS-2 UFSAR Rev. 0 15 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

1. Reduction of two half-size motor-driven steam generator feedwater pumps total dynamic head rating from 1,900feet to 1,694 feet for same 15,200 gpm flow.
2. Addition of motor-driven start-up feedwater pump to minimize operation of main feedwater pumps at start-up and low loads. Pump can also be paralleled with a main feedwater pump when either one is out of service.
3. Addition of two separation drain pumps to supplement heater drain pumps during peak plant operation.
4. Addition of full flow condensate polishing system downstream of condensate pumps.
5. Feedwater system containment isolation valve changed from a single motor-operated stop check valve outside containment per supply line to a check valve inside containment with an electro hydraulic-operated isolation valve outside containment.

10.4.8 /11.2.5 Steam generator blowdown system changes include:

1. Blowdown liquids formerly processed by evaporator facilities now are normally processed by the condensate polishing system after they have been routed to the condenser.

Processing by evaporator facilities as a backup has been retained.

2. Former discussion on providing common collection facility for blowdown from both BVPS-1 and BVPS-2 is no longer applicable.

Each plant now has an independent processing system for return of blowdown to the condensers.

10.4.9 /10.3.5 Changes to auxiliary feedwater system include:

1. Former two turbine-driven auxiliary feedwater pumps with motor-drive backup replaced with

three pumps, two half-size motor-driven and

one full capacity turbine-driven.

BVPS-2 UFSAR Rev. 0 16 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

2. Output rating of former two turbine-driven auxiliary feedwater pumps was 700 gpm each. Output ratings of present three pumps are 375 gpm each for two motor-driven ones and 750

gpm for turbine-driven one.

3. Former continuous recirculation flow to primary plant demineralized water storage tank (PPDWST) now controlled automatically by recirculation control valve on discharge

piping of auxiliary feedwater pumps to maintain minimum flow requirements.

4. Added cross-connection piping between 140,000 gallon PPDWST and 600,000 gallon

demineralized water storage tank (DWST) to

provide another source of backup water supply. 5. Hand-wheel type motor-operated control valves in auxiliary feedwater supply lines replaced

with hand-pump hydraulic type electro-hydraulic-operated control valves for more positive control in event of loss of power.

6. Component cooling water to feedwater pump lube oil coolers, formerly in external piping, now in internal lines that are part

of pump design.

7. Added check valves downstream of control valves in auxiliary feedwater lines outside containment to prevent loss of auxiliary feedwater in event of auxiliary feedwater header rupture. Also added check valve in each auxiliary feedwater line inside containment for containment isolation

purposes.

8. Added cavitating venturi flow elements in common auxiliary feedwater supply lines to limit flow in event of main steam or main feedwater line rupture.
9. Provided redundant safety-related flow transmitters for each auxiliary feedwater line outside containment.

BVPS-2 UFSAR Rev. 0 17 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

10. Added separate chemical feed connection on individual auxiliary feedwater supply lines.
11. Chemical addition to PPDWST, formerly

supplied from chemical feed tank, now provided by injection of chemicals into suction piping.

12. Each motor-driven feedwater pump delivers water to separate header while turbine-driven pump can be manually aligned for water delivery to either header.

10.4.10 /10.3.2 Additional equipment served by auxiliary steam and condensate system include:

1. Degasifier steam heaters,
2. Evaporator reboilers,
3. Boric acid batch tank,
4. Carbon dioxide vaporizer, and
5. Cask washdown area.

11.2 /11.2.4 Liquid waste management systems have these

changes:

1. Added piping connection from evaporator bottoms cooler to liquid waste drain tanks.
2. Provided additional discharge points for liquid waste tanks that include steam generator blowdown (SGB) hold tanks, to cleanup filter, and then to cooling tower blowdown.
3. Expanded capability to process liquid waste by use of SGB evaporators and hold tanks as primary means of processing prior to utilizing other facilities of BVPS-1 and BVPS-2.

BVPS-2 UFSAR Rev. 0 18 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

11.3

/11.2.3 Gaseous waste management systems changes

include:

1. Downgraded gaseous waste disposal (GWD) system from Safety Class 3 to NNS class.
2. Added seven gaseous waste storage tanks.

11.4 /11.2.6 Changes to solid waste management systems

include:

1. Formerly, spent resin was flushed to BVPS-1 (without solidification) directly to shipping casks, dewatered, and sealed. Evaporator bottoms were packaged in casks with cement-vermiculite mixture. Both casks were stored at BVPS-1. Now spent resin sludge and evaporator bottoms are normally packaged in 55-gallon drums preloaded with dry cement,

with drums stored in condensate polishing building of BVPS-2. Option of disposal via BVPS-1 dewatering facility is still retained,

however.

2. Formerly, used cartridge filter elements were mixed with other solid waste in same drum.

Now filter elements are packaged by themselves in drums.

11.5 /11.2.7.2 Additional area, effluent, and process monitors

added to process and effluent radiological

monitoring system to improve system monitoring capabilities.

12.3.2.1

/11.3.2.1 Changes made to configuration design of supplementary neutron streaming shield to facilitate refueling operations.

12.3.2.5

/11.3.2.2 Modified fuel transfer tube shield design to prevent direct line streaming of radiation from

spent fuel through seismic gap.

BVPS-2 UFSAR Rev. 0 19 of 19 TABLE 1.3-2 (Cont)

FSAR Section

/PSAR Reference Significant Changes Since PSAR

12.3.4

/11.3 Expanded radiation monitoring system with

additional area, effluent, and process monitors to improve system monitoring capabilities and to provide post-accident detection.

15.2.3 /None The analysis for the deletion of reactor trip following a turbine trip below 70 percent power is required in order to demonstrate reactor safety should the fast bus transfer to offsite power fail following the generator motoring

delay on turbine trip.

15.6.5

/None The loss-of-coolant accident analysis of N-1 loop operation is a prerequisite to plant operation with one loop out of service. The analysis must demonstrate acceptable results for accidents initiated from the steady state N-1 loop mode of operation.

Baffle to barrel region configuration changed from downflow to upflow to reduce baffle plate and baffle bolt loading, and to minimize the

potential for excessive baffle joint jetting.

BVPS-2 UFSAR Rev. 16 1.4-1 1.4 IDENTIFICATION OF AGENT AND CONTRACTORS This section identifies the prime agents and contractors for the design, construction, and operation of the Beaver Valley Power Station - Unit 2 (BVPS-2). This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.

1.4.1 Applicant

The Central Area Power Coordinating Group (CAPCO), which is comprised of Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company, and Duquesne Light Company (DLC), was the Applicant for BVPS-2. The Applicant engaged the contractors identified in Sections 1.4.2 through 1.4.5 to perform engineering, procurements, and construction services for the plant. However, DLC retained overall project responsibility which included engineering;

construction; testing; and from the time of initial fuel loading, operation and maintenance of BVPS-2. DLC maintained a technically competent and safety-oriented staff with the proper

qualifications, training, and licenses.

Most of the senior personnel in the DLC Engineering and

Construction Division and Operations Division were active participants in the design, construction, and operation of the Shippingport Atomic Power Station (SAPS). During the BVPS

evaluation, engineering design, construction, testing, and operations phases, the same successful managerial techniques that were developed over the years were employed.

In March 1981, DLC established the Nuclear Division to meet the needs of the company's nuclear power goals and objectives. The support functions of the Quality Assurance Department remained with the Nuclear Construction Division.

Duquesne Light Company was engaged principally in the production, purchase, transmission, distribution, and sale of electric energy. Duquesne Light Company served an area of approximately 800 square miles in Allegheny and Beaver Counties.

This area, which includes the city of Pittsburgh, is located in southwestern Pennsylvania and has a population of approximately

1,500,000.

A summary of previous experience in the field of power generation shows that DLC was technically qualified to engage in the proposed activities. Duquesne Light Company had been involved in various nuclear projects for over 30 years. They

include the following:

1. A study of the feasibility and economics of constructing a nuclear reactor for the use of atomic

energy and its possible implementation in the commercial power industry - 1952.

2. Establishment of the Atomic Power Development Department - 1953.

BVPS-2 UFSAR Rev. 0 1.4-2 3. An agreement with the U.S. Atomic Energy Commission (USAEC) to operate and maintain SAPS and to conduct an extensive testing program prescribed by the USAEC -

1954. 4. Participation in nuclear research and development programs such as the Westinghouse Electric Corporation Liquid Metal Fast Breeder Reactor project, reactor vessel inspection study, and the plutonium recycle fuel fabrication.

5. The design, construction, and operation of Beaver Valley Power Station - Unit 1 (BVPS-1) - 1976.

1.4.2 Architect Engineer

Stone & Webster Engineering Corporation (SWEC) provided engineering design and construction management services for BVPS-2. The Corporation maintained offices in Boston, Massachusetts, Cherry Hill, New Jersey, Denver, Colorado, New York, New York, and Houston, Texas, with a total manpower resource pool of over 12,000 employees. Approximately 700 engineers, designers, construction specialists, and clerical and administrative personnel were assigned to the BVPS-2 project during its peak level of activity. In addition to its project-dedicated staff, SWEC utilized specialists in various engineering disciplines to ensure that BVPS-2 was designed in accordance with industry codes and standards and met the requirements of the applicable federal, state, and local regulations for commercial nuclear power plants.

SWEC has been associated with the installation of over 77,000 MW of hydroelectric, nuclear, and fossil-fired electric generating facilities for the electric utility industry. The Corporation's

experience in the field of nuclear energy dates from 1942 when it participated in initiating the first self-sustaining nuclear chain reaction at the University of Chicago. Since 1954, SWEC has designed and/or constructed the following nuclear power stations which are either presently operating or have operated successfully:

1. Shippingport Atomic Power Plant of Duquesne Light Company and ERDA
2. Army Package Power Reactor (APPR, also known as Al)
3. Yankee Nuclear Power Station of Yankee Atomic Power Company
4. Carolinas-Virginia Tube Reactor of the Carolinas-Virginia Nuclear Power Associates, Inc.
5. Haddam Neck Plant of Connecticut Yankee Atomic Power Company
6. Nine Mile Point Nuclear Station Unit 1 of Niagara Mohawk Power Corporation BVPS-2 UFSAR Rev. 0 1.4-3 7. Maine Yankee Atomic Power Station of Maine Yankee Atomic Power Company
8. Surry Power Station Units 1 and 2 of Virginia Electric and Power Company
9. James A. Fitzpatrick Nuclear Power Plant - Unit 1 of the Power Authority of the State of New York
10. North Anna Power Station - Units 1 and 2 of Virginia Electric and Power Company
11. Beaver Valley Power Station - Unit 1 of Duquesne Light Company In addition, SWEC had under design and construction at that time

the following nuclear power stations:

1. North Anna Power Station - Unit 3 of Virginia Electric and Power Company
2. Millstone Nuclear Power Station - Unit 3 of Northeast Utilities Service Company
3. Shoreham Nuclear Power Station - Unit 1 of Long Island Lighting Company
4. Nine Mile Point - Unit 2 of Niagara Mohawk Power Corporation
5. River Bend Power Station - Units 1 and 2 of Gulf States Utilities.

Also, SWEC provided construction management services for the Demonstration Liquid Metal Fast Breeder Reactor Plant (Clinch River Project) and the Department of Energy's Gas Centrifuge Uranium Enrichment Plant.

1.4.3 Nuclear Steam Supply System Manufacturer

Westinghouse Electric Corporation (Westinghouse) was responsible for supplying the NSSS and fuel for BVPS-2.

Westinghouse has designed, developed, and manufactured nuclear power facilities since the 1950s, beginning with the world's first large central station nuclear power plant (Shippingport),

which has produced power since 1957. Completed or contracted commercial nuclear capacity totals were in excess of 97,000 MW. Westinghouse pioneered new nuclear design concepts, such as chemical shim control of reactivity and the rod cluster control concept, throughout the last two decades. Westinghouse manufacturing facilities include the largest commercial nuclear fuel fabrication facility in the world, and the world's most modern heat transfer equipment production facility, as well as other facilities producing nuclear steam supply system (NSSS)

BVPS-2 UFSAR Rev. 14 1.4-4 components. Table 1.4-1 lists all Westinghouse pressurized water reactor (PWR) plants to date, including those plants under construction or on order, at the time of BVPS-2 license application.

The U.S. Nuclear Regulatory Commission (USNRC) and the Electric Power Research Institute have contracted with Westinghouse for research into NSSS related activities. Westinghouse experience was also utilized by the USNRC and Metropolitan Edison immediately following the Three Mile Island Unit 2 accident. At the time of license application, the corporation continued to participate with the Westinghouse Owner's Group of utilities in

addressing the USNRC'S action plan for corrective actions.

1.4.3.1 Plants in Operation

Westinghouse PWR plants in operation were as follows:

1. Shippingport Shippingport was the world's first large central station nuclear power plant. The reactor plant was designed by the Bettis Atomic Power Laboratory, which is operated by Westinghouse under a USNRC contract. Shippingport's PWR has produced power for DLC since

December 1957.

2. Yankee-Rowe Singled out by the USNRC as a "Nuclear Success Story" Yankee-Rowe went on-line in November 1960. Owned and operated by the Yankee Atomic Electric Company, Yankee-Rowe has progressed from an initial rating of 120 MWe to its present 175 MWe rating. Westinghouse

supplied the NSSS and the turbine generator.

3. Trino Vercellese (Enrico Fermi)

The Trino Vercellese nuclear plant was one of the

first Westinghouse designed plants to incorporate chemical shim control of reactivity. Chemical shim has since become a standard feature of Westinghouse PWR control. Trino Vercellese achieved initial criticality in June 1964 and began power operation in October 1964. The plant is rated at 260 MWe.

4. Chooz (Ardennes)

The Chooz plant is unique in that the Westinghouse PWR and its auxiliaries are housed in man-made caverns.

Ardennes, a joint Franco-Belgian undertaking, owned and operated by the Societe d'Energie Nucleaire Franco-Belge des Ardennes (SENA), is located in France near the French-Belgian border. Chooz achieved initial criticality in October 1966 and began power

operation in 1967.

BVPS-2 UFSAR Rev. 0 1.4-5 5. San Onofre Unit 1 San Onofre Unit 1 employs the Westinghouse developed

rod cluster control concept which has since become a standard feature on the Westinghouse PWR. Owned by the Southern California Edison Company and the San Diego Gas and Electric Company, the 430 MWe plant is located near San Clemente, California. Westinghouse supplied the NSSS and the turbine generator. Initial criticality was achieved in June 1967, and power

operation began in January 1968.

6. Haddam Neck (Connecticut Yankee)

Owned and operated by the Connecticut Yankee Atomic Power Company, this plant went critical in July 1967 and attained full power operation in December 1967. Like San Onofre Unit 1, the plant employs rod cluster control in conjunction with chemical shim control.

Westinghouse supplied the NSSS and the turbine generator. The plant has been uprated to 575 MWe.

7. Jose Cabrera - Zorita

The Jose Cabrera Station is located near Zorita, Spain. The 153 MWe plant employs rod cluster control, chemical shim control and a Zircaloy-clad core. Construction began in mid-1965 and power operation

began in 1968. Jose Cabrera is owned and operated by the Union Electrica, S. A., a Spanish utility.

8. Beznau Unit 1 and Unit 2 Beznau Unit 1, Switzerland's first commercial nuclear power plant, achieved initial criticality in June 1969 and supplied power to the system in July 1969. The 350 MWe plant was designed and constructed by the

Westinghouse-Brown Boveri Consortium for the owner/operator utility, Nordostschweizerische Kraftwerke AG. The plant started producing power less than 4 years after award of the plant contract. Beznau Unit 2 achieved criticality in October 1971 and began commercial operation in early 1972.

9. Robert Emmett Ginna

The Robert Emmett Ginna Plant, owned and operated by Rochester Gas and Electric Corporation, is located in New York on the south shore of Lake Ontario.

Westinghouse supplied the 490 MWe plant on a turnkey basis. Construction began in April 1966 with initial criticality being achieved in November 1969 (just 42 months after start of construction). Power was supplied to the system in December 1969.

BVPS-2 UFSAR Rev. 0 1.4-6 10. Mihama Unit 1 and Takahama Unit 1 These plants are owned by the Kansai Electric Power

Company, Inc. Mihama Unit 1 is a two-loop, 320 MWe unit and marks the beginning of a line of Westinghouse PWRS supplying the generation needs of the Far East.

Westinghouse International Company was the prime contractor for the Mihama project, supplying the NSSS engineering, nuclear fuel, and some major system components. Mihama Unit 1 required only 44 months from the start of site construction to first power production in August 1970. Takahama Unit 1 is a three-loop, 780 MWe unit. Initial criticality was

achieved in March 1974.

11. H. B. Robinson Unit 2 This plant is a three-loop, 707 MWe unit which was built on a turnkey basis for the Carolina Power and Light Company. The plant is located at a site near Hartsville, South Carolina, on a man-made cooling lake. The construction permit was granted in April

1967. The plant achieved criticality in August 1970 and first power to system in October 1970.

12. Point Beach Unit 1 and Unit 2 The Point Beach Project consists of two 497 MWe units, which were built on a turnkey basis for the Wisconsin Michigan Power Company and the Wisconsin Electric Power Company. The plants are located near Two Creeks, Wisconsin, 90 miles north of Milwaukee on Lake Michigan. This was the first two-unit station to utilize many common facilities and shared auxiliary systems. The construction permit for Point Beach Unit 1 was granted in July 1967 with initial criticality and first power to the system in November 1970. Point Beach Unit 2 went critical in May 1972 and was available for commercial operation in October 1972.
13. Surry Unit 1 and Unit 2 The Surry Power Station, two three-loop 822 MWe units, is owned by the Virginia Electric and Power Company. The James River Station is about 30 miles from Norfolk, Virginia. First criticality on Surry Unit 1 was achieved in July 1972. Commercial operation began in September 1972. Initial criticality on Surry Unit 2 was achieved in March 1973.
14. Turkey Point Unit 3 and Unit 4

Florida Power and Light Company is the owner of a four-unit station on Biscayne Bay, Florida. Turkey Point Units 3 and 4 of the station are three-loop, 745

MWe BVPS-2 UFSAR Rev. 0 1.4-7 plants. Commercial status for Turkey Point Unit 3 was achieved in December 1972. Initial criticality for Turkey Point Unit 4 was achieved in June 1973.

15. Indian Point Unit 2 and Unit 3 Consolidated Edison Company of New York operates three nuclear units located in Buchanan, New York; two (Units 1 and 2) are owned by the Company and one (Unit 3) is owned by the Power Authority of the State of New

York. Units 2 and 3 are Westinghouse PWRS rated at 873 MWe and 965 MWe, respectively. Indian Point Unit 2 achieved initial criticality in May 1973 and Indian Point Unit 3 achieved initial criticality in April 1976. 16. Prairie Island Unit 1 Northern States Power Company, is the owner of these two-loop, 530 MWe units located in Welch, Minnesota. Initial criticality was achieved in December 1973 for Prairie Island Unit 1, and in December 1974 for

Prairie Island Unit 2.

17. Zion Unit 1 and Unit 2 Commonwealth Edison Company is the owner of these two four-loop, 1,050 MWe units. The units are located on Lake Michigan near Zion, Illinois. Initial criticality was achieved in June 1973 for Zion Unit 1 and in December 1973 for Zion Unit 2.
18. Kewaunee

Wisconsin Public Service Corporation, Wisconsin Power and Light Company, and Madison Gas and Electric Company are the owners of this two-loop, 541 MWe plant located in Kewaunee, Wisconsin. Initial criticality was achieved in March 1974.

19. Ringhals Unit 2 Statens Vattenfallsverk (SSPB) is the owner of this three-loop, 822 MWe unit located in Sweden. Initial criticality was achieved in June 1974.
20. Donald C. Cook Unit 1 and Unit 2 Indiana and Michigan Electric Company is the owner of these four-loop 1,090 MWe plants located in Bridgman, Michigan. These plants are the first to use the Westinghouse Ice Condenser Containment design.

Initial criticality was achieved in January 1975 for Unit 1 and March 1978 for Unit 2.

BVPS-2 UFSAR Rev. 0 1.4-8 21. Trojan This four-loop, 1,130 MWe plant is jointly owned by

Portland General Electric Company, Eugene Water and Electric Board, and Pacific Power and Light Company. In addition to being the first commercial nuclear plant to operate in the Pacific Northwest (located on

the Oregon shore of the Columbia River near Rainier, Oregon), Trojan is the first 17 x 17 fuel-rod-per-assembly plant to achieve criticality. Initial

criticality was achieved in December 1975.

22. Beaver Valley Unit 1 This three-loop, 852 MWe plant is jointly owned by

Duquesne Light Company, Ohio Edison Company, and Pennsylvania Power Company, Beaver Valley Unit 1 is located on the Ohio River, 22 miles northwest of Pittsburgh, Pemsylvania. Commercial operation began

in early 1976.

23. Salem Unit 1 and Unit 2 Salem Units 1 and 2, owned jointly by the Public

Service Electric and Gas Company, Philadelphia

Electric Company, Atlantic Electric Company, and Delmarva Power and Light Company, are located on Artificial Island, a man-made peninsula in Salem County, New Jersey. The 1,090 MWe, four-loop plant achieved initial criticality for Unit 1 in late 1976 and Unit 2 achieved criticality in August 1980.

24. North Anna Unit 1 and Unit 2

Virginia Electric and Power Company owns the two approximately 907 MWe (net) plants located 40 miles north of Richmond, Virginia, on Lake Anna. Unit 1

achieved criticality in June 1980.

25. Joseph M. Farley Unit 1 and Unit 2 The two 899 MWe (net) Alabama Power Company units are located at Dothan, Alabama which is approximately 180 miles south-southwest of Atlanta, Georgia. Unit 1 achieved criticality in August 1977 and Unit 2 achieved criticality in February 1981.
26. Sequoyah Unit 1 and Unit 2

The two 1,148 MWe (net) units are located on the Tennessee River near Chattanooga, Tennessee. These units are owned by Tennessee Valley Authority.

Sequoyah Unit 1 received a full power license in September 1980.

BVPS-2 UFSAR Rev. 0 1.4-9 1.4.3.2 Westinghouse Facilities Westinghouse, in its effort to plan for the future, developed a broad range of facilities to satisfy the needs of the nuclear industry. The following paragraphs briefly describe these facilities:

1. Columbia Plant, Nuclear Fuel Division The Columbia Plant was capable of performing all operations necessary to manufacture finished nuclear fuel assemblies. These operations include conversion of uranium hexafluoride to uranium dioxide powder,

fabrication of fuel assembly grids, complete pellet loading, and final fabrication of assemblies. The plant, located at Columbia, South Carolina, began full production in early 1970. The Columbia Plant was the largest commercial nuclear fuel fabrication facility in the world.

2. Tampa Division

The Tampa Division Plant was the world's most modern heat transfer equipment production facility. The plant has 236,000 square feet of working space with two

manufacturing aisles for the production of steam generators and pressurizers. Transportation facilities include four railroad spurs and a complete barge slip

and dock facility for water shipment to all parts of the world. The Tampa Division Plant made its first steam generator and pressurizer shipment in September 1969.

3. Pensacola Division

The Pensacola Division Plant, located on Escambia Bay on the northwest coast of Florida, was a new 140,000 square foot manufacturing plant for producing precision reactor

vessel internals. Contributing to the precision manufacturing capability was an environmental control system which minimized year round temperature changes throughout the shop area. Transportation facilities of the plant include a railroad spur for loading and unloading inside the shop, and access to barge loading

facilities on Escambia Bay. Pensacola shipped its first package of reactor internals in July 1970.

4. Cheswick Plant, Electro-Mechanical Division The Electro-Mechanical Division was established in Cheswick, Pennsylvania in 1953 to manufacture canned motor primary coolant pumps for nuclear reactors. The product line expanded to include shaft seal pumps (reactor coolant pumps), valves from 4 inches to 31 inches, and control rod drive mechanisms, essential components of the Westinghouse PWR. The facility

BVPS-2 UFSAR Rev. 0 1.4-10 occupied 250,000 square feet and contained the most modern facilities available for the production and testing of nuclear plant components.

5. Specialty Metals Division The Specialty Metals Division located in Blairsville, Pennsylvania, was completed in late 1967. Several essential PWR component processes were accomplished at Blairsville, including the precision manufacture of inconel tubing for steam generators, and the complete processing of Zircaloy seamless tubing for nuclear fuel cladding. At Blairsville, complete quality

control facilities were utilized for the evaluation and analysis of all specialty metal products used in Westinghouse nuclear systems.

6. Westinghouse Nuclear Center

The headquarters of Westinghouse Nuclear Energy Systems was located just east of Pittsburgh in Monroeville, Pennsylvania. Operating primarily as a

headquarters and engineering facility, the complex housed many of the divisions which encompassed Westinghouse's nuclear activities associated with the

electric utility industry.

7. Zion Nuclear Training Center The Westinghouse Electric Corporation and the

Commonwealth Edison Company of Chicago built and operated a nuclear training center at Zion, Illinois.

The 28,000 square foot training center contained classrooms, a training reactor, training material

center, video recording facilities, and multi-plant nuclear power plant simulators. Westinghouse staffed and operated the center, supplied all the equipment required, and was responsible for the development and presentation of all training programs. Commonwealth Edison provided the building, access to the Zion

nuclear units for conducting in-plant observation training, and advised and assisted Westinghouse in developing training programs.

BVPS-2 UFSAR Rev. 0 1.4-11 1.4.4 Power Conversion System Supplier Westinghouse was awarded the contracts to design, fabricate, deliver, and erect the turbine generator for BVPS-2.

Westinghouse achieved an excellent operating record in the nuclear turbine generator industry by incorporating product improvements based on operating experience as well as

knowledge gained from research and development programs and the capabilities of modern manufacturing facilities. This nuclear operating performance record made Westinghouse one of

the leaders in total power produced as well as in reliability and availability.

Continuing Westinghouse commitment to this kind of product evaluation produced modern and reliable nuclear turbine-generator units around the world. The Westinghouse nuclear

turbine-generator operating record was as follows:

a. The first Westinghouse nuclear turbine generator was placed in commercial operation in

1957. b. Forty-five Westinghouse nuclear turbine generators were in service, totaling over

36,000 MW.

c. An additional forty-five Westinghouse nuclear turbine generators were on order, in storage, or being erected.

1.4.5 Consultants

Duquesne Light Company directly or through the architect engineer, SWEC, engaged the service of various consultants to perform work relating to the design, construction, operation, and maintenance of BVPS-2. These consultants included, but were not limited to, the following companies:

1. Hansen, Holley, and Biggs

This firm provided consultation services on structural design and analyses for SWEC as well as others. The firm included Professors R. J. Hanson; M. J. Holley, Jr.; and J. M. Biggs - all of whom were actively associated with the Massachusetts Institute of Technology (MIT). The firm provided services to SWEC in support of efforts for Yankee Atomic, Connecticut Yankee, Malibu, and Shoreham Nuclear Power Plants.

2. NUS Corporation

NUS Corporation was retained to provide general consulting services. This corporation was a consulting engineering firm headquartered in Rockville, Maryland, that served utilities, industry, and the government in the fields of nuclear engineering, environmental engineering,

systems analysis and operations research, plant water technology, nuclear personnel training, and

BVPS-2 UFSAR Rev. 0 1.4-12 manpower planning services. It numbered over eighty utilities among its clients and provided these clients with a broad spectrum of nuclear-related services including reactor safeguards analysis, reactor siting,

and reactor design services.

3. Weston Geophysical Research, Inc.

Weston Geophysical Research, Inc., was retained by the

BVPS-2 project to provide consulting services on seismicity. The Reverend Daniel Linehan, Director of Weston Observatory, was a consultant to Weston Geophysical Research, Inc., and participated in these studies. Father Linehan was also a consultant to the U. S. Coast and Geodetic Survey and to numerous reactor projects, including those of Northeast

Utilities Service Company, Connecticut Yankee Atomic Power Company, Virginia Electric and Power Company, and Boston Edison Company.

Weston Geophysical engineers were pioneers in the development of shallow refraction survey techniques,

especially shear wave velocity determinations, which were necessary for establishing dynamic soil moduli for use in analysis of structural response to

earthquakes.

4. Whitman and Rand

This firm provided consulting services in the area of

soil dynamics, geology, and hydrology. Doctor R. V.

Whitman, who was associated with MIT, was an outstanding authority in the field of soil dynamics and published many papers on the subject. His studies have included significant work on amplification of earthquake motion within the overburden. Mr. J. R. Rand, formerly Chief State Geologist for the State of Maine, assisted in geology and ground-water hydrology studies.

BVPS-2 UFSAR Tables for Section 1.4

(Tables in Section 1.4 are historical)

BVPS-2 UFSAR Rev. 16 1 of 9 TABLE 1.4-1 WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS (HISTORICAL)

Plant Owner Utility Location Scheduled Commercial Operation MWe Net Number of Loops Shippingport Duquesne Light Company; Energy Research & Development

Administration (ERDA)

Pennsylvania 1957 90 4 Yankee-Rowe Yankee Atomic Electric Company Massachusetts 1961 175 4 Trino Vercellese (Enrico Fermi) Ente Nazionale per I'Energia Elettrica (ENEL)

Italy 1965 260 4 Chooz Ardennes Societe D'Energie Nucleaire

Franco-Belge des Ardennes (SENA)

France 1967 305 4 San Onofre No. 1 Southern California Edison Co.;

San Diego Gas and Electric Co.

California 1968 430 3 Haddam Neck (Connecticut Yankee) Connecticut Yankee Atomic Power Company

Connecticut 1968 575 4 Jose Cabrera - Zorita Union Electrica, S. A.

Spain 1969 153 1 Beznau No. 1 Nordostschweizerische Kraftwerke AG (NOK)

Switzerland 1969 350 2 Robert Emmett Ginna Rochester Gas and Electric Corporation

New York 1970 490 2 Mihama No. 1 The Kansai Electric Power Company, Inc.

Japan 1970 320 2 Point Beach No. 1 Wisconsin Electric Power Co.; Wisconsin Michigan Power Co.

Wisconsin 1970 497 2 H. B. Robinson No. 2 Carolina Power and Light Co.

South Carolina 1971 712 3 Beznau No. 2 Nordostschweizerische Kraftwerke AG (NOK) Switzerland 1972 350 2 BVPS-2 UFSAR Rev. 14 2 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Point Beach No. 2 Wisconsin Electric Power Co.; Wisconsin Michigan Power Co.

Wisconsin 1972 497 2 Surry No. 1 Virginia Electric and Power Co.

Virginia 1972 822 3 Turkey Point No. 3 Florida Power and Light Co.

Florida 1972 693 3 Indian Point No. 2 Consolidated Edison Company of New York, Inc.

New York 1973 873 4 Prairie Island No. 1 Northern States Power Company Minnesota 1973 530 2 Turkey Point No. 4 Florida Power and Light Co.

Florida 1973 693 3 Surry No. 2 Virginia Electric and Power Co.

Virginia 1973 822 3 Zion No. 1 Commonwealth Edison Company Illinois 1973 1040 4 Kewaunee Wisconsin Public Service Corp.;

Wisconsin Power and Light Co.;

Madison Gas and Electric Co.

Wisconsin 1974 535 2 Prairie Island No. 2 Northern States Power Company Minnesota 1974 530 2 Takahama No. 1 The Kansai Electric Power Company, Inc.

Japan 1974 781 3 Zion No. 2 Commonwealth Edison Company Illinois 1974 1040 4 Doel No. 1 Indivision Doel Belgium 1975 390 2 Doel No. 2 Indivision Doel Belgium 1975 390 2 Donald C. Cook No. 1 Indiana and Michigan Electric Company (AEP)

Michigan 1975 1054 4 Ringhals No. 2 Statens Vattenfallsverk (SSPB)

Sweden 1975 822 3

BVPS-2 UFSAR Rev. 14 3 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Indian Point No. 3 Power Authority of the State of New York (PASNY)

New York 1976 873 4 Salem No. 1 Public Service Electric and Gas Company; Philadelphia Electric Co.;

Atlantic Electric Co.; Delmarva Power and Light Co.

New Jersey 1976 1090 4 Trogan Portland General Electric Co.; Eugene Water and Electric Board; Pacific Power and Light Company

Oregon 1976 1130 4 Beaver Valley No. 1 Duquesne Light Company; Ohio Edison Company; Pennsylvania Power Company Pennsylvania 1977 852 3 Almaraz No. 1 Union Electrica, S.A.;

Compania Sevillana de Electricicdad, S. A.; Hidroelectrica Espanola, S. A.

Spain 1978 902 3 Angra dos Reis No. 1 Furnas-Centrais Electricas, S. A.

Brazil 1978 626 2 Diablo Canyon No. 1 Pacific Gas and Electric Co.

California 1978 1084 4 Donald C. Cook No. 2 Indiana and Michigan Electric Company (AEP)

Michigan 1978 1060 4 Joseph M. Farley No. 1 Alabama Power Company Alabama 1978 829 3 Ko-Ri No. 1 Korea Electric Company Korea 1978 564 2 North Anna No. 1 Virginia Electric and Power Co.

Virginia 1978 907 3 Ringhals No. 3 Statens Vattenfallsvert (SSPB)

Sweden 1978 912 3 Ohi No. 1 The Kansai Electric Power Co., Inc.

Japan 1978 1122 4 BVPS-2 UFSAR Rev. 14 4 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Ohi No. 2 The Kansai Electric Power Co., Inc.

Japan 1978 1122 4 Sequoyah No. 1 Tennessee Valley Authority Tennessee 1978 1148 4 Almaraz No. 2 Union Electrica, S.A.;

Compania Sevillana de Electricidad, S.A.; Hidroelectrica Espanola, S.A.

Spain 1979 902 3 Asco No. 1 Fuerzas Electricas deCataluna, S.A. (FECSA)

Spain 1979 902 3 Asco No. 2 Fuerzas Electricas deCataluna, S.A.

(FECSA); Empresa Nacional Hidroelec-trica del Riborganzana, S.S. (ENHER); Fuerzas Hidroelectricas del Segre, S.A.; Hidroelectroca deCataluna, S.A.

Spain 1979 902 3 Diablo Canyon No. 2 Pacific Gas and Electric Co.

California 1979 1106 4 Lemoniz No. 1 Iberduero, S.A.

Spain 1979 902 3 Sequoyah No. 2 Tennessee Valley Authority Tennessee 1979 1148 4 Watts Bar No. 1 Tennessee Valley Authority Tennessee 1979 1177 4 William B. McGuire No.

1 Duke Power Company

North Carolina 1979 1180 4 Joseph M. Farley No. 2 Alabama Power Company Alabama 1979 829 3 Krsko Savske Elektrarne, Ljubljana, Slovenia; Elektroprivreda, Zagreb, Croatia Yugoslavia 1979 615 2 Ringhals No. 4 Statens Vattenfallsvert (SSPB)

Sweden 1979 912 3

BVPS-2 UFSAR Rev. 14 5 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Salem No. 2 Public Service Electric and Gas Company; Philadelphia Electric Co.;

Atlantic Electric Co.; Delmarva Power and Light Co.

New Jersey 1979 1115 4 Lemonis No. 2 Iberduero, S.A.

Spain 1980 902 3 North Anna No. 2 Virginia Electric and Power Co.

Virginia 1979 907 3 Virgil C. Summer South Carolina Electric and Gas Company

South Carolina 1980 900 3 Watts Bar No. 2 Tennessee Valley Authority Tennessee 1980 1177 4 South Texas Project Unit No. 1 Houston Lighting and Power Co.;

Central Power and Light Co.;

City Public Service of San Antonio;

City of Austin, Texas Texas 1980 1250 4 William B. McGuire No.

2 Duke Power Company

North Carolina 1981 1180 4 Comanche Peak No. 1 Texas Utilities Generating Co.

Texas 1981 1150 4 Byron No. 1 Commonwealth Edison Company Illinois 1981 1120 4 Vandellos No. 2 Fuerzas Electricas de Cataluna, S.A. (FECSA); Empresa Nacional Hidroelectrica del Ribagorzana, S.A. (ENHER);

Fuerzas Hidroelectricas del Segre S.A.;

Hidroelectrica de Cataluna, S.A.

Spain 1981 920 3 Seabrook No. 1 Public Service Company of New Hampshire;

United Illuminating Company New Hampshire 1982 1200 4 Braidwood No. 1 Commonwealth Edison Company Illinois 1982 1120 4 BVPS-2 UFSAR Rev. 14 6 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Catawba No. 1 Duke Power Company South Carolina 1982 1145 4 Callaway No. 1 SNUPPS - Union Electric Co.

Missouri 1982 1150 4 Ko-Ri No. 2 Korea Electric Company Korea 1982 605 2 Comanche Peak No. 2 Texas Utilities Generating Co.

Texas 1982 1150 4 Marble Hill No. 1 Public Service Company of Indiana, Inc.,;

Wabash Valley Power Association Indiana 1982 1130 4 Millstone No. 3 Northeast Nuclear Energy Co.

Connecticut 1982 1156 4 South Texas Project

Unit 2 Houston Lighting and Power Co.;

Central Power and Light Co.

City Public Service of San Antonio; City of Austin, Texas

Texas 1982 1250 4 Napot Point No. 1 National Power Corporation Philippines 1982 620 2 Sayago No. 1 Iberduero, S.A.

Spain 1982 1000 3 Braidwood No. 2 Commonwealth Edison Company Illinois 1983 1120 4 Byron No. 2 Commonwealth Edison Company Illinois 1983 1120 4 Catawba No. 2 Duke Power Company South Carolina 1983 1145 4 Maanshan No. 1 Taiwan Power Company Taiwan 1983 907 3 Alvin W. Vogtle No. 1 Georgia Power Company; Oglethorpe Electric Membership

Corp.; Municipal Electric Authority of Georgia;

City of Dalton, Georgia Georgia 1983 1113 4 BVPS-2 UFSAR Rev. 14 7 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Wolf Creek Unit No. 1 SNUPPS - Kansas Gas and Electric Company; Kansas City Power and Light Company Kansas 1984 1150 4 Seabrook No. 2 Public Service Company of New Hampshire;

United Illuminating Company New Hampshire 1984 1200 4 Jamesport No. 1 Long Island Lighting Company; New York State Electric and Gas

Corp.

New York 1984 1150 4 Maanshan No. 2 Taiwan Power Company Taiwan 1984 907 3 Alvin W. Vogtle No. 2 Georgia Power Company; Oglethorpe Electric Membership

Corp.;

Municipal Electric Authority of Georgia; City of Dalton, Georgia

Georgia 1984 1113 4 Marble Hill No. 2 Public Service Company of Indiana, Inc.;

Wabash Valley Power Association Indiana 1984 1130 4 Shearon Harris No. 1 Carolina Power and Light Co.

North Carolina 1984 900 3 Sterling SNUPPS - Rochester Gas and Electric Corporation; Central Hudson Gas and Electric Corporation; Niagara Mohawk Power Corporation; Orange and Rockland Utilities, Inc.

New York 1984 1150 4 Tyrone No. 1 SNUPPS - Northern States Power Company Wisconsin 1984 1150 4 BVPS-2 UFSAR Rev. 14 8 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Atlantic No. 1 (O.P.S) Public Service Electric and Gas Company;

Atlantic Electric Co.;

Jersey Central Power and Light Company New Jersey - 1150 4 Jamesport No. 2 Long Island Lighting Company; New York State Electric and

Gas Corp.

New York 1986 1150 4 Shearon Harris No. 2 Carolina Power and Light Co.

North Carolina 1986 900 3 Callaway No. 2 SNUPPS - Union Electric Company Missouri 1987 1150 4 Haven No. 1 Wisconsin Electric Power Co.;

Wisconsin Power and Light Co.;

Wisconsin Public Service Corp.

Wisconsin 1987 900 3 Atlantic No. 2 (O.P.S) Public Service Electric and Gas Company;

Atlantic Electric Co.;

Jersey Central Power and Light Company

New Jersey - 1150 4 Shearon Harris No. 4 Carolina Power and Light Co.

North Carolina 1988 900 3 Haven Wisconsin Electric Power Co.;

Wisconsin Power and Light Co.;

Wisconsin Public Service Corp.

Wisconsin 1989 900 3 Unit No. 4 Iberduero, S.A.

Spain 1980's 1000 3 Shearon Harris No. 3 Carolina Power and Light Co. North Carolina 1990 900 3

BVPS-2 UFSAR Rev. 14 9 of 9 TABLE 1.4-1 (Cont)

Plant Owner Utility Location Scheduled Commercial Operation MWE Net Number of Loops Unassigned No. 1

(O.P.S) Public Service Electric and Gas Company; Atlantic Electric Company

New Jersey 1990 1150 4 Unassigned No. 2 Public Service Electric and Gas Company;

Atlantic Electric Company New Jersey 1992 1150 4

BVPS-2 UFSAR Rev. 16 1.5-1 1.5 REQUIREMENTS FOR FURTHER TECHNICAL INFORMATION The requirements for further technical information provided herein reflects the status of Beaver Valley Power Station - Unit 2 (BVPS-2) at the time of the issuance of the Operating License. This section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.

The Westinghouse Electric Corporation (Westinghouse) report WCAP-8768 (Eggleston 1978) presents descriptions of the safety-related research and development programs which are being carried out for, by, or in conjunction with Westinghouse Nuclear Energy Systems and which are applicable to Westinghouse pressurized water reactors (PWRS).

For each program still in progress, the safety-related program is first introduced and is followed where appropriate by background information. A description of the program follows, which relates the program objectives to the problem and presents pertinent recent results. Finally, a backup position may be

given for programs (generally experimental rather than analytical) that have not yet reached a stage at which it is reasonably certain that the results confirm the expectation.

The backup position is one that might be used if the results were to be unfavorable; it is not necessarily the only course that might be taken in the ultimate solution of the problem.

The term "research and development" as used in this report is the same as that used by the U.S. Nuclear Regulatory Commission

(USNRC) in 10 CFR 50.2, and means:

1. Theoretical analysis, exploration, or experimentation, or 2. The extension of investigative findings and theories of a scientific or technical nature into practical application for experimental and demonstration purposes including the experimental production and testing of models, devices, equipment, material, and processes.

The technical information generated by these research and development programs will be used either to demonstrate the safety of the design and more sharply define margins of

conservatism, or could lead to design improvements.

Included in the overall research and development effort are the programs described as follows which are applicable to this plant, but are not required for issuance of either a Construction Permit or Operating License.

1.5.1 Blowdown Heat Transfer Testing

1.5.1.1 Introduction The USNRC acceptance criteria for emergency core cooling systems (ECCSs) for light-water power reactors were issued in Section 50.46 of 10 CFR 50 on December 28, 1973. They define the basis BVPS-2 UFSAR Rev. 16 1.5-2 and conservative assumptions to be used in the evaluation of the performance of ECCSs. Westinghouse believes that some of the conservatism of the criteria is associated with the manner in which transient departure from nucleate boiling (DNB) phenomena are treated in the evaluation models. Transient critical heat flux data presented at the 1972 specialists meeting of the Committee on Reactor Safety Technology indicated that the time to DNB can be delayed under transient conditions. To demonstrate the conservatism of the ECCS evaluation models, Westinghouse has initiated a program to experimentally simulate the blowdown phase of a loss-of-coolant accident (LOCA). This testing is part of the Electric Power Research Institute (EPRI) sponsored Blowdown Heat Transfer Program, which was started in early 1976. Testing was completed in 1979. A DNB correlation developed by Westinghouse from these test results will be used in the ECCS analyses.

1.5.1.2 Objective

The objective of the Blowdown Heat Transfer Test was to determine the time that DNB occurs under LOCA conditions. This information was used to confirm the existing, or develop a new Westinghouse transient DNB correlation. The steady state DNB data obtained from 15 by 15 and 17 by 17 test programs can be used to assure that the geometrical differences between the two fuel arrays can be correctly treated in the transient correlations.

1.5.1.3 Program The program was divided into two phases. Phase I tests started from steady state conditions, with sufficient power to maintain nucleate boiling throughout the bundle, controlled ramps of decreasing test section pressure, or flow initiated DNB. By

applying a series of controlled conditions, investigation of the DNB was studied over a range of qualities, flows, and pressures relevant to a PWR blowdown.

Phase I provided separate-effects data to permit heat transfer correlation development.

Typical parameters used for Phase I testing are presented in Table 1.5-1. Phase II simulated PWR behavior during a LOCA to permit definition of the time delay associated with onset of DNB. Tests in Phase II covered the large double-ended guillotine cold leg break. All tests in Phase II were started after establishment of typical steady state operating conditions. The

fluid transient was then initiated, and the rod power decay was programmed in such a manner as to simulate the actual heat input of fuel rods. The test was terminated when the heater rod

temperatures reached a predetermined limit.

Typical parameters used for Phase II testing are shown in Table 1.5-2.

BVPS-2 UFSAR Rev. 0 1.5-3 1.5.1.4 Test Description The experimental program was conducted in the J-Loop at the Westinghouse Forest Hills Facility with a full length 5 by 5 rod bundle simulating a section of a 15 by 15 assembly to determine DNB occurrence under LOCA conditions.

The heater rod bundles used in this program were internally heated rods, capable of a maximum power of 18.8 kW/ft, with a total power of 135 kW (for extended periods) over the 12-foot

heated length of the rod. Heat was generated internally by means of a varying cross-sectional resistor which approximates a chopped cosine power distribution. Each rod was adequately

instrumented with a total of 12 clad thermocouples.

1.5.1.5 Results

The experiments in the delayed departure from nucleate boiling facility resulted in cladding temperature and inlet fluid

properties measured as a function of time throughout the blowdown range from 0 to 20 seconds.

Facility modifications and installation of the initial test bundle were completed. A series of shakedown tests in the J-Loop were performed. These tests provided data for

instrumentation calibration and check-out, and provided information regarding facility control and performance. Initial program tests were performed during the first half of 1975.

Under the sponsorship of EPRI, testing was reinitiated during 1976 on the same test bundle. The testing was terminated in November 1976 and plans were made for a new test bundle and further testing during 1978-1979. A DNB correlation developed from these results are used in the Westinghouse ECCS analyses for Beaver Valley Power Station - Unit 2.

1.5.2 Reference for Section 1.5

Eggleston, F.T. 1978. Safety-Related Research and Development for Westinghouse Pressurized Water Reactors, Program Summaries -

Winter 1977, Summer 1978. WCAP-8768, Revision 2.

BVPS-2 UFSAR Tables for Section 1.5

(Tables in Section 1.5 are historical)

BVPS-2 UFSAR Rev. 16 1 of 1 TABLE 1.5-1 DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE I TEST PARAMETERS (HISTORICAL)

Parameters Nominal Value Initial Steady State Conditions

Pressure (psia)

1,250 to 2,250 Test section mass velocity (lb/hr-ft

2) 1.12 to 2.5 x 10 6 Core inlet temperature (F) 550 to 600 Maximum heat flux (Btu/hr-ft
2) 306,000 to

531,000 Transient Ramp Conditions

Pressure decrease 0 to 350 psi/sec

and subcooled depressurization

from 2,250 psia Flow decrease (%/sec) 0 to 100 Inlet enthalpy

constant BVPS-2 UFSAR Rev. 16 1 of 1 TABLE 1.5-2 DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE II TEST PARAMETERS (HISTORICAL)

Parameters Nominal Value Initial Steady State Conditions

Pressure (psia)

2,250 Test section mass velocity (lb/hr-ft

2) 2.5 X 106 Inlet coolant temperature (F) 545 Maximum heat flux (Btu/hr-ft
2) 531,000 Transient Conditions Simulated break Double-ended

cold leg guillotine

breaks BVPS-2 UFSAR Rev. 16 1.6-1 1.6 MATERIAL INCORPORATED BY REFERENCE Table 1.6-1 lists topical reports which, prior to issuance of the operating license, provided information in addition to that provided in this Final Safety Analysis Report and which were filed separately with the U.S. Nuclear Regulatory Commission (USNRC) in support of this and similar applications. Therefore, this section is being retained for historical perspectives.

Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.

The legend for the review status code letter follows:

A - U.S. Nuclear Regulatory Commission review complete; USNRC acceptance letter issued.

AE - U. S. Nuclear Regulatory Commission accepted as part of the Westinghouse emergency core cooling system (ECCS) evaluation model only; does not constitute acceptance for any purpose other than for ECCS analyses.

B - Submitted to USNRC as background information; not undergoing formal USNRC review.

O - On file with USNRC; older generation report with current validity; not actively under formal USNRC review.

N - Not applicable; that is, open literature, etc.

U - Actively under formal USNRC review.

BVPS-2 UFSAR Tables for Section 1.6

(Tables in Section 1.6 are historical)

BVPS-2 UFSAR Rev. 16 1 of 15 TABLE 1.6-1 MATERIAL INCORPORATED BY REFERENCE (HISTORICAL)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-2048 The Doppler Effect for a Non-Uniform Temperature Distribution in Reactor Fuel Elements

July 1962 4.3 0 WCAP-2850-L (Proprietary)

Single-Phase Local Boiling & Bulk Boiling

Pressure Drop Correlations

April 1966 4.4 0 WCAP-2923 In-Pile Measurement of UOd Thermal Conductivity

1966 4.4 0 WCAP-3269-8 Hydraulic Tests of the San Onofre Reactor Model June 1964 4.4 0 WCAP-3269-26 LEOPARD: A Spectrum Dependent Non-Spatial Depletion Code for the IBM-7094

Sept. 1963 4.3 0 WCAP-3385-56 Saxton Core II Fuel Performance Evaluation, Part II, and Evaluation of Mass Spectrometric

and Radiochemical Materials Analyses of Irradiated Saxton Plutonium Fuel.

July 1970 4.3 4.4 0 WCAP-3680-20 Xenon-Induced Spatial Instabilities in Large PWRs

March 1968 4.3 0 WCAP-3680-21 Control Procedures for Xenon-Induced X-Y Instabilities in Large PWRs

Feb. 1969 4.3 0 WCAP-3680-22 Xenon-Induced Spatial Instabilities in Three Dimensions

Sept. 1969 4.3 0 WCAP-3696-8 Pressurized Water Reactor pH - Reactivity Effect Final Report

Oct. 1968 4.3 0 WCAP-3726-1 PUOd-UOd Fueled Critical Experiments July 1967 4.3 0 WCAP-6065 Melting Point of Irradiated UOd Feb. 1965 4.2 4.4 0 WCAP-6069 Burnup Physics of Heterogeneous Reactor Lattices June 1965 4.4 0

BVPS-2 UFSAR Rev. 0 2 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-6073 LASAR: A Depletion Program for Lattice Calculations Based on MUFT and THERMOS

April 1966 4.3 0 WCAP-6086 Supplementary Report on Evaluation of Mass Spectrometric and Radiochemical Analyses of Yankee Core I Spent Fuel including Isotopes of Elements Thorium Through Curium Aug. 1969 4.3 0 WCAP-7015 Rev. 1 Subchannel Thermal Analysis of Rod Bundle Cores

Jan. 1969 4.4 0 WCAP-7048-P-A (Proprietary)

The PANDA Code Jan. 1975 4.3 A WCAP-7213-P-A (Proprietary)

The TURTLE 24.0 Diffusion Depletion Code Feb. 1975 4.3 A WCAP-7263 (Proprietary) A Comprehensive Space-Time Dependent Analysis of

Loss of Coolant (SATAN IV Digital Code)

Aug. 1971 3.6 0 WCAP-7306 Reactor Protection System Diversity in Westinghouse Pressurized Water Reactors

April 1969 15.4.10 0 WCAP-7308-L (Proprietary)

Evaluation of Nuclear Hot Channel Factor Uncertainties Dec. 1971 4.3 U WCAP-7359-L (Proprietary)

Applications of the THINC Program to PWR Design Aug. 1969 4.4 0 WCAP-7397-L (Proprietary)

Seismic Testing of Electrical and Control Equipment Jan. 1970 3.10N 0 WCAP-7397-L, Suppl.

1 Seismic Testing of Electrical and Control Equipment Jan. 1971 3.10N 0 WCAP-7488-L (Proprietary)

Solid State Logic Protection System Description March 1971 7.1 7.2 A WCAP-7558 Seismic Vibration Testing With Sine Beats Oct. 1971 3.10N.5 U WCAP-7588 Rev. 1-A An Evaluation of the Rod Ejection Accident in Westinghouse Pressurized Water Reactors Using Spatial Kinetics Methods Jan. 1975 15.4 A

BVPS-2 UFSAR Rev. 0 3 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-7635 MARVEL: A Digital Computer Code for Transient Analysis of a Multi-Loop PWR System

1971 6.2.1.4 O WCAP-7667-A (Proprietary)

Interchannel Thermal Mixing With Mixing Vane Grids Jan. 1975 4.4 A WCAP-7672 Solid State Logic Protection System Description March 1971 7.1 7.2 7.3 A WCAP-7695-P-A (Proprietary)

DNB Test Results for New Mixing Vane Grids Jan. 1975 4.4 A WCAP-7706 An Evaluation of Solid State Logic Reactor Protection in Anticipated Transients

Feb. 1971 7.1 7.2 U WCAP-7706-L (Proprietary)

An Evaluation of Solid State Logic Reactor Protection in Anticipated Transients July 1971 4.6 U WCAP-7735 Sensitized Stainless Steel in Westinghouse PWR Nuclear Steam Supply Systems Aug. 1971 5.2 A WCAP-7750 SATAN IV Digital Code: A Comprehensive Space-Time Dependent Analysis of Loss-of-Coolant Aug. 1971 3.6 O WCAP-7757-A The PANDA Code Jan. 1975 4.3 A WCAP-7758-A

The TURTLE 24.0 Diffusion Depletion Code Feb. 1975 4.3 A WCAP-7765-AR Westinghouse PWR Internals Vibration Summary

Three-Loop Internals Assurance Nov. 1973 3.9 A WCAP-7769 Rev. 1 Overpressure Protection for Westinghouse Pressurized

Water Reactors April 1975 15.2 U WCAP-7775-A Interchannel Thermal Mixing with Mixing Vane Grids Jan. 1975 4.4 A WCAP-7800 Rev. 4-A Nuclear Fuel Division Quality Assurance Program Plan March 1975 4.2 A WCAP-7803 Behavior of Austenitic Stainless Steel in Post-Hypothetical Loss-of-Coolant Environment Dec. 1971 6.1.1 A BVPS-2 UFSAR Rev. 0 4 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-7806 Nuclear Design of Westinghouse Pressurized Water Reactors with Burnable Poison Rods Dec. 1971 4.3 B WCAP-7810 Evaluation of Nuclear Hot Channel Uncertainties Dec. 1971 4.3 U WCAP-7811 Power Distribution Control of Westinghouse Pressurized Water Reactors

Dec. 1971 4.3 O WCAP-7817

Seismic Testing of Electrical and Control Equipment

Dec. 1971 3.10N.5 O WCAP-7817 Suppl. 1 Seismic Testing of Electrical and Control Equipment Dec. 1971 3.10N.5 O WCAP-7817

Suppl. 2 Seismic Testing of Electric and Control Equipment (Low

Seismic Plants)

Dec. 1971 3.10N.5 U WCAP-7817 Suppl. 3 Seismic Testing of Electric and Control Equipment (Westinghouse Solid State Protection System) (Low Seismic Plants)

Dec. 1971 3.10N.5 U WCAP-7817

Suppl. 4

Seismic Testing of Electrical and Control Equipment

(WCID NUCANA 7300 Series) (Low Seismic Plants)

Nov. 1972 3.10N.5 U WCAP-7817

Suppl. 5

Seismic Testing of Electrical and Control Equipment (Instrument Bus Distribution Panel) (Low Seismic

Plants) March 1974 3.10N.5 U WCAP-7817 Suppl. 6 Seismic Testing of Electrical and Control Equipment (Type DB Reactor Trip Switchgear)

Aug. 1974 3.10N.5 U WCAP-7825 Evaluation of Protective Coatings for Use in Reactor Containments Dec. 1971 6.1.2 A WCAP-7836 Inlet Orificing of Open PWR Cores Jan. 1972 4.4

- WCAP-7838 Applications of the THINC Program to PWR Design Jan. 1972 4.4 O

BVPS-2 UFSAR Rev. 0 5 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-7907 LOFTRAN: Code Description June 1972 5.2, 15.0, 15.1, 15.2 15.3, 15.4, 15.5, 15.6 U WCAP-7908 FACTRAN: A FORTRAN IV Code for Thermal Transients in a UO2 Fuel Rod

June, 1972 15.0, 15.3 15.4 U WCAP-7912-A Power Peaking Factors

Jan. 1975 4.3 4.4 A WCAP-7912-P-A (Proprietary)

Power Peaking Factors Jan. 1975 4.3 4.4 A WCAP-7913

Process Instrumentation for Westinghouse Nuclear Steam Supply Systems (Four Loop Plant Using WCID 7300 Series Process Instrumentations)

Jan. 1973 7.2 7.3 B WCAP-7916 Single-Phase Local Boiling and Bulk Boiling Pressure Drop Correlations

June 1972 4.4 O WCAP-7921 Damping Values of Nuclear Power Plant Components May 1974 3.7N.5 A WCAP-7924-A Basis for Heatup and Cooldown Limit Curves

April 1975 5.3 WCAP-7941-P-A (Proprietary)

Effect of Axial Spacing on Interchannel Thermal Mixing with the R-Mixing Vane Grid Jan. 1975 4.4 A WCAP-7956 THINC IV: An Improved Program for Thermal and

Hydraulic Analysis of Rod Bundle Cores Oct. 1973 4.4 A WCAP-7958-A DNB Test Results for New Mixing Vane Grids

Jan. 1975 4.4 A WCAP-7959-A

Effect of Axial Spacing on Interchannel Thermal Mixing with R-Mixing Vane Grid

Jan. 1975 4.4 A WCAP-7964 Axial Xenon Transients Tests at the Rochester Gas and Electric Reactor

June 1971 4.3 O WCAP-7979-P-A (Proprietary) TWINKLE: A Multi-Dimensional Neutron Kinetics

Computer Code Jan. 1975 15.0 15.4 A BVPS-2 UFSAR Rev. 0 6 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-7980 WIT-6: Reactor Transient Analysis Computer Program Description Nov. 1973 15.4 A WCAP-7988 (Proprietary) Application of Modified Spacer Factor to L Grid Typical

and Cold Wall Cell DNB Oct. 1972 4.4 A WCAP-8028-A TWINKLE: A Multi-Dimensional Neutron Kinetics

Computer Code Jan. 1975 15.0 15.4 A WCAP-8030-A Application of Modified Spacer Factor to L Grid Typical

and Cold Wall Cell DNB Oct. 1972 4.4 A WCAP-8054 (Proprietary)

Application of the THINC IV Program to PWR Design Sept. 1973 4.4 O WCAP-8082 (Proprietary)

Pipe Breaks for the LOCA Analysis of the Westinghouse Primary Coolant Loop June 1973 6.2

- WCAP-8099 A Summary Analysis of the April 30 Incident at the San Onofre Nuclear Generating Station Unit 1

April 1973 5.3 B WCAP-8163 Reactor Coolant Pump Integrity in LOCA

Sept. 1973 5.4 U WCAP-8170 (Proprietary)

Calculational Model for Core Reflooding After a Loss-of-

Coolant Accident (WREFLOOD Code)

June 1974 6.2 15.6 AE WCAP-8171

Calculational Model for Core Reflooding After A Loss-

of-Coolant Accident (WREFLOOD Code)

June 1974 6.2 15.6 AE WCAP-8172

Pipe Breaks for the LOCA Analysis of Westinghouse Primary Coolant Loop

July 1973 6.2 - WCAP-8174 (Proprietary)

Effect of Local Heat Flux Spikes on DNB in Non-Uniform Heated Rod Bundles

Aug. 1973 4.4 A WCAP-8183

Rev. 10 Operational Experience with Westinghouse Cores (up to Dec. 31, 1977)

May 1981 4.2 - WCAP-8195 Application of the THINC IV Program to PWR Design Oct. 1973 4.4 O BVPS-2 UFSAR Rev. 0 7 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8200 Rev. 2 (Proprietary) WFLASH: A Fortran IV Computer Program for Simulation of Transients in a Multi-Loop PWR July 1974 15.6 AE WCAP-8202 Effect of Local Heat Flux Spikes on DNB in Non-Uniform Heated Rod Bundles

Aug. 1973 4.2 A WCAP-8218-P-A (Proprietary)

Fuel Densification Experimental Results and Model for Reactor Application March 1975 4.1 4.2 4.3 4.4 A WCAP-8219-A

Fuel Densification Experimental Results and Model for

Reactor Application

March 1975 4.1 4.2 4.3 4.4 A WCAP-8236 (Proprietary)

Safety Analysis of the 17 x 17 Fuel Assembly for Combined Seismic and Loss-of-Coolant Accident Dec. 1973 4.2 U WCAP-8236 Addendum 1 (Proprietary)

Safety Analysis of the 8 Grid 17 x 17 Fuel Assembly for Combined Seismic and Loss-of-Coolant Accident March 1974 3.7N U WCAP-8252 Documentation of Selected Westinghouse Structural Analysis Computer Codes

April 1974 3.6 U WCAP-8252 Rev. 1

Documentation of Selected Westinghouse Structural Analysis Computer Codes

May 1977 3.9 A WCAP-8253

Source Term Data for Westinghouse Pressurized Water

Reactors

July 1975 11.1 B WCAP-8255

Nuclear Instrumentation System

Jan. 1974 7.2 7.7 B WCAP-8261

Rev. 1 WFLASH: A Fortran IV Computer Program for Simulation of Transients in a Multi-Loop PWR

July 1974 15.6 AE WCAP-8264-P-A (Proprietary) Westinghouse Mass and Energy Release Data for Containment Design June 1975 6.2 A

BVPS-2 UFSAR Rev. 0 8 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8278 (Proprietary)

Hydraulic Flow Test of the 17 x 17 Fuel Assembly

Feb. 1974 4.2 4.4 U WCAP-8279 Hydraulic Flow Test of the 17 x 17 Fuel Assembly Feb. 1974 4.2 4.4 U WCAP-8288

Safety Analysis of the 17 x 17 Fuel Assembly for Combined Seismic and Loss-of-Coolant Accident

Dec. 1973 4.2 4.4 U WCAP-8288

Addendum 1

Safety Analysis of the 8 Grid 17 x 17 Fuel Assembly for Combined Seismic and Loss-of-Coolant Accident

April 1974 3.7N U WCAP-8296-P-A (Proprietary)

Effect of 17 x 17 Fuel Assembly Geometry on DNB

Feb. 1975 4.4 U WCAP-8297-A

Effect of 17 x 17 Fuel Assembly Geometry on DNB

Feb. 1975 4.4 A WCAP-8298-P-A (Proprietary) The Effect of 17 x 17 Fuel Assembly Geometry on Interchannel Thermal Mixing Jan. 1975 4.4 A WCAP-8299-A The Effect of 17 x 17 Fuel Assembly Geometry on Interchannel Thermal Mixing Jan. 1975 4.4 A WCAP-8301 (Proprietary)

LOCTA IV Program: Loss-of-Coolant Transient Analysis June 1974 15.6 AE WCAP-8302 (Proprietary)

SATAN VI Program: Comprehensive Space-Time Dependent Analysis of Loss-of-Coolant June 1974 6.2.1.3 15.0 15.6 AE WCAP-8303-P-A (Proprietary)

Prediction of the Flow-Induced Vibration of Reactor

Internals by Scale Model Tests

July 1975 3.9N A WCAP-8305

LOCTA IV Program: Loss-of-Coolant Transient

Analysis June 1974 15.0 15.6 AE WCAP-8306 SATAN VI Program: Comprehensive Space-Time Dependent Analysis of Loss-of-Coolant June 1974 6.2.1.3 15.0 15.6 AE BVPS-2 UFSAR Rev. 0 8a of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8312-A

Rev. 2 Westinghouse Mass and Energy Release Data For Containment Design Aug. 1975 6.2.1.3 15.6 A

BVPS-2 UFSAR Rev. 0 9 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8317-A

Prediction of the Flow-Induced Vibration of Reactor

Internals by Scale Model Tests

July 1975 3.9N A WCAP-8324-A Control of Delta Ferrite in Austentitic Stainless Steel Weldments June 1974 3.8 5.2 6.1 A WCAP-8326 COCO: Containment Pressure Analysis Code June 1974 15.6 AE WCAP-8327 (Proprietary)

COCO: Containment Pressure Analysis Code June 1974 15.6 AE WCAP-8330 Westinghouse Anticipated Transients Without Trip Analysis Aug. 1974 4.3, 4.6 15.1, 15.2

15.4, 15.8 U WCAP-8339 Westinghouse ECCS Evaluation Mode-Summary July 1974 4.3 15.6 AE WCAP-8340 (Proprietary)

Westinghouse ECCS Plant Sensitivity Studies July 1974 15.6 AE WCAP-8341 (Proprietary)

Westinghouse ECCS Evaluation Model Sensitivity Studies July 1974 15.6 AE WCAP-8342 Westinghouse ECCS Evaluation Model Sensitivity Studies July 1974 15.6 AE WCAP-8356 Westinghouse ECCS Plant Sensitivity Studies July 1974 15.6 AE WCAP-8359 Effects of Fuel Densification Power Spikes on Clad Thermal Transients

July 1974 4.3 A WCAP-8373 Qualification of Westinghouse Seismic Testing Procedure for Electrical Equipment Tested Prior to May

1974 Aug. 1974 3.10N U WCAP-8377 (Proprietary)

Revised Clad-Flattening Model July 1974 4.2 A WCAP-8381 Revised Clad-Flattening Model July 1974 4.2 A WCAP-8385 (Proprietary) Power Distribution Control and Load-Following

Procedures Sept. 1974 4.3 4.4 U BVPS-2 UFSAR Rev. 0 10 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8403

Power Distribution Control and Load-Following

Procedures

Sept. 1974 4.3 4.4 U WCAP-8424 Rev. 1 An Evaluation of Loss-of-Flow Accidents Caused by Power System Frequency Transients in Westinghouse

PWRs June 1975 15.3 U WCAP-8446 (Proprietary) 17 x 17 Drive Line Component Tests: Phase IE, II, III D Loop Drop and Deflection Dec. 1974 15.0 A WCAP-8448 17 x 17 Drive Line Component Tests: Phase IE, II, III D Loop Drop and Deflection Dec. 1974 15.0 A WCAP-8454 Analysis of Data from the Zion (Unit 1) THINC Verification Test

May 1976 4.4 A WCAP-8471 (Proprietary)

Westinghouse ECCS Evaluation Model Supplementary Information April 1975 15.6 AE WCAP-8472

Westinghouse ECCS Evaluation Model Supplementary

Information April 1975 15.6 AE WCAP-8498 Incore Power Distribution Determination in Westinghouse Pressurized Water Reactors

July 1975 4.3 U WCAP-8516-P (Proprietary)

UHI Plant Internals Vibration Measurement Program and Pre- and Post-Hot Functional Examinations April 1975 3.9N A WCAP-8517

UHI Plant Internals Vibration Measurement Program and Pre- and Post-Hot Functional Examinations April 1975 3.9N A WCAP-8536 (Proprietary)

Critical Heat Flux Testing of 17 x 17 Fuel Assembly Geometry with 22-Inch Grid Spacing May 1975 4.4 A WCAP-8537

Critical Heat Flux Testing of 17 x 17 Fuel Assembly Geometry with 22-Inch Grid Spacing May 1975 4.4 A WCAP-8565-P-A (Proprietary)

Westinghouse ECCS Four Loop Plant (17 x 17)

Sensitivity Studies July 1975 15.6 A WCAP-8566-A

Westinghouse ECCS Four Loop Plant (17 x 17)

Sensitivity Studies July 1975 15.6 A

BVPS-2 UFSAR Rev. 0 11 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8567

Improved Thermal Design Procedure

Sept. 1975 4.4 A WCAP-8575 Suppl. 1 (Proprietary)

Augmented Start-up and Cycle 1 Physics Program June 1976 4.3 U WCAP-8576 Suppl. 1

Augmented Start-up and Cycle 1 Physics Program

June 1976 4.3 U WCAP-8584 (Proprietary)

Failure Modes and Effects Analysis of the Engineering Safeguard Features Actuation System

April 1976 4.6 7.3 U WCAP-8586-P-A (Proprietary) Westinghouse ECCS Four Loop Plant (17 x 17)

Sensitivity Studies

July 1975 15.6 A WCAP-8587

Suppl. 1

Methodology for Qualifying Westinghouse WRD Supplied NSSS Safety-Related Electrical Equipment Nov. 1978 3.10N 3.11N WCAP-8587

Rev. 2 Methodology for Qualifying Westinghouse WRD Supplied NSSS Safety-Related Electrical Equipment Feb. 1979 3.10N 3.11N U WCAP-8622 (Proprietary)

Westinghouse ECCS Evaluation Model October 1975

Version Nov. 1975 15.6 A WCAP-8623

Westinghouse ECCS Evaluation Model October 1975

Version Nov. 1975 15.6 A WCAP-8624 General Method of Developing Multi-Frequency Biaxial Test Inputs for Bistables

Sept. 1975 3.10N U WCAP-8691

Rev. 1 (Proprietary)

Fuel Rod Bowing Evaluation July 1979 4.2 4.4 U WCAP-8692 Rev. 1 Fuel Rod Bowing Evaluation July 1979 4.2 4.4 U WCAP-8693

Delta Ferrite Production in Austenitic Stainless Steel

Weldments Jan. 1976 5.2 B WCAP-8708 (Proprietary) Multiflex A Fortran IV Computer Program for Analyzing Thermal-Hydraulic Structure System Dynamics Feb. 1976 3.9N A

BVPS-2 UFSAR Rev. 0 12 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8709

Multiflex A Fortran IV Computer Program for Analyzing Thermal-Hydraulic Structure System Dynamics Feb. 1976 3.9N A WCAP-8720 (Proprietary)

Improved Analytical Models Used in Westinghouse Fuel Rod Design Computations Oct. 1976 4.2 A WCAP-8760 Failure Modes and Effects Analysis of the Engineering

Safeguards Features Actuation System April 1976 4.6 7.3 U WCAP-8762 New W Correlation WRB-1 For Predicting Critical Heat Flux In Rod Bundles With Mixing Vane Grids Oct. 1976 4.4 A WCAP-8766 (Proprietary) Verification of Neutron Pad and 17 x 17 Guide Tube Designs by Preoperational Tests on the Trojan 1 Power Plant May 1976 3.9N A WCAP-8768 Rev. 1 Safety-Related Research and Development for Westinghouse Pressurized Water Reactors, Program Summaries - Winter 1976

June 1977 4.3 5.4.1 5.4.15 B WCAP-8768

Rev. 2 Safety-Related Research and Development for Westinghouse Pressurized Water Reactors, Program Summaries - Winter 1977 - Summer 1978 Oct. 1978 1.5 4.2 B WCAP-8780 Verification of Neutron Pad and 17 x 17 Guide Tube Designs by Preoperational Tests on the Trojan 1 Power

Plant May 1976 3.9N A WCAP-8785 Improved Analytical Models Used in Westinghouse Fuel

Rod Design Computations Oct. 1976 4.2 A WCAP-8822 (Proprietary)

Mass and Energy Releases Following a Steam Line Rupture 1976 6.2.1.4 -- WCAP-8843 (Proprietary) MARVEL: A Digital Computer Code for Transient Analysis of a Multi-Loop PWR System Nov. 1977 6.2.1.4 -- WCAP-8844 MARVEL: A Digital Computer Code for Transient Analysis of a Multi-Loop PWR System Nov. 1977 6.2.1.4 --

BVPS-2 UFSAR Rev. 0 13 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-8859

TRANFLO: Steam Generator Code Description

Sept. 1976 6.2.1.4

-- WCAP-8860

Mass and Energy Releases Following a Steam Line

Rupture Sept. 1976 6.2.1.4 -- WCAP-8872

Design, Inspection, Operation, and Maintenance Aspects of the Westinghouse NSSS to Maintain Occupational Radiation Exposure As Low As Reasonably Achievable April 1977 12.3.1.2 -- WCAP-8892-A 7300 Series Process Control System Noise Tests

June 1977 7.1.2 A WCAP-8963 (Proprietary) Safety Analysis for the Revised Fuel Rod Internal

Pressure Design Basis Nov. 1976 4.2 A WCAP-8964 Safety Analysis for the Revised Fuel Rod Internal Pressure Design Basis

Aug. 1977 4.2 A WCAP-8970 (Proprietary)

Westinghouse ECCS Small Break, October 1975 Model April 1977 15.6 U WCAP-8971

Westinghouse ECCS Small Break, October 1975 Model

April 1977 15.6 U WCAP-8976

Failure Modes and Effects Analysis of the Solid State Full Length Rod Control System

Aug. 1977 4.6 7.7 U WCAP-9004 (Proprietary)

Inlet Orificing of Open PWR Cores Jan. 1969 4.4

-- WCAP-9168 (Proprietary)

Westinghouse ECCS Evaluation Model, Modified

October 1975 Version

Sept. 1977 15.6 U WCAP-9169

Westinghouse ECCS Evaluation Model, Modified

October 1975 Version

Sept. 1977 15.6 U WCAP-9179

Rev. 1 (Proprietary)

Properties of Fuel and Core Component Materials July 1978 4.2 U

BVPS-2 UFSAR Rev. 0 14 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-9220 (Proprietary)

Westinghouse ECCS Evaluation Model, February 1978 Version Feb. 1978 6.2.1.3 A WCAP-9220-P-A Westinghouse ECCS Evaluation Model, 1981 Version

Dec. 1981 15.6 U WCAP-9921

Westinghouse ECCS Evaluation Model, February 1978

Version Feb. 1978 6.2.1.3 A WCAP-9221-P-A

Rev. 1 Westinghouse ECCS Evaluation Model, 1981 Version

Dec. 1981 15.6 A WCAP-9224

Properties of Fuel and Core Component Materials

July 1978 4.2 U WCAP-9227 Reactor Core Response to Excessive Secondary Steam Releases Jan. 1978 15.1 U WCAP-9230 (Proprietary)

Report on the Consequences of a Postulated Feedline Rupture Jan. 1978 15.2 U WCAP-9231 Report on the Consequences of a Postulated Feedline

Rupture Jan. 1978 15.2 U WCAP-9279 Combination of Safe Shutdown Earthquake and Loss-of-Coolant Accident Responses for Faulted Condition Evaluation of Nuclear Power Plants

Mar. 1978 3.9N -- WCAP-9283 Integrity of the Primary Piping Systems of Westinghouse Nuclear Power Plants During Postulated Seismic Events Mar. 1978 3.9N -- WCAP-9292 Dynamic Fracture Toughness of ASME SA 508 Class 2a and ASME SA 535 Grade A Class 2 Base and Heat-Affected Zone Material and Applicable Weld Metal March 1978 5.2

-- WCAP-9401-P-A (Proprietary)

Verification Testing and Analyses of the 17 x 17 Optimized Fuel Assembly Aug. 1981 4.2.3.4 -- WCAP-9402-A Verification Testing and Analyses of the 17 x 17

Optimized Fuel Assembly Aug. 1981 4.2.3.4 -- WCAP-9485-A (Proprietary) PALADON: Westinghouse Nodal Computer Code

Dec. 1978 4.3 A

BVPS-2 UFSAR Rev. 0 15 of 15 TABLE 1.6-1 (Cont)

REPORT NO.

TITLE USNRC SUBMITTAL REFERENCE SECTION(S)

REVIEW STATUS WCAP-9486-A

PALADON: Westinghouse Nodal Computer Code

Dec. 1978 4.3 A WCAP-9735 Rev. 1 (Proprietary)

Multiflex 3.0 - A Fortran IV Computer Program for Analyzing Thermal-Hydraulic-Structural System Dynamics (III) Advanced Beam Model 1982 3.9N.1.2

-- WCAP-9736 Multiflex 3.0 - A Fortran IV Computer Program for Analyzing Thermal-Hydraulic-Structural System Dynamics (III) Advanced Beam Model 1982 3.9N.1.2

-- WCAP-9745 Results of a Westinghouse Review of Environmental Qualification References for WRD Supplied Category II Equipment with Respect to the Staff Positions in NUREG-0588 1980 3.11

-- NS-TMA-2075 (W

) Westinghouse LOCA Mass and Energy Release Model for Containment Design, March 1979 Version April 1979 6.2.1.3

-- Report (SWEC)

Report on Soil Densification Program, BVPS-2, September 23, 1976 Sept. 1976 3.7B.2.4 -- Report (SWEC)

Control of Heavy Loads at Nuclear Power Plants, Letters 2DLS-13737, March 26, 1982, and 2DLC-4556, April 2, 1982 April 1982 9.1.5 -- RP-8A (SWEC)

Radiation Shielding Design and Analysis Approach for Light Water Reactor Plants May 1975 12.3 A SWECO-7703 (SWEC) Missile Barrier Interaction Sept. 1977 3.5.3 -- Report (SWEC)

Control Room Habitability Study for BVPS-1 and BVPS-

2 Dec. 1981 2.2.3 A

BVPS-2 UFSAR Rev. 12 1.7-1 1.7 DRAWINGS AND OTHER DETAILED INFORMATION 1.7.1 Electrical, Instrumentation, and Control Drawings

Table 1.7-1 identified the compiled listings of safety related electrical, instrumentation, and control drawings used on BVPS-2 and is not included in this updated FSAR. Three copies of these drawings were provided in a separate enclosure to the original FSAR submittal.

1.7.2 Piping and Instrumentation Diagrams Table 1.7-2 listed the piping and instrumentation diagrams (P&IDs) used on BVPS-2 and is not included in this updated FSAR. Two copies of these drawings were provided in a separate

enclosure to the original FSAR submittal.

Flow diagrams are included with the systems described throughout the Updated FSAR. Symbols and abbreviations used in these flow diagrams are illustrated in Figure 1.7-1.

1.7.3 Other Detailed Information (Special Reports and Programs)

Table 1.7-3 identifies special evaluations, documentation, and programs which were referenced in the FSAR and were submitted

separately from the FSAR.

BVPS-2 UFSAR Tables for Section 1.7

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 1.7-3 SPECIAL REPORTS AND PROGRAMS

1. Transmitted at time of FSAR Submittal
a. Failure Modes and Effects Analysis (FMEA)
2. Transmitted after submittal
a. Fire Protection Evaluation Report (FPER) (Incorporated into the FSAR as Appendix 9.5A in FSAR Amendment 14.)
b. Beaver Valley Nuclear Power Station Emergency Plan
c. Beaver Valley Nuclear Power Station Security Plan
d. Control Room Design Review
e. Inservice Inspection Program
f. Equipment Qualification Report
g. ASME Code Baseline Document (2BVM-179)
h. Preservice Inspection Program I. Technical Specifications
j. Seismic Design Response Spectra, June 1984
k. Site Dependent Response Spectra, February 1985
l. SQRT/PVORT Summary Listing
m. Test Report on Electrical Separation Verification Test
n. Detailed Control Room Design Review - Supplemental Report
o. Fire Protection Safe Shutdown Report
3. Programs reviewed at BVPS-2
a. Equipment Qualification Documentation (EQD)
b. Seismic and Dynamic Qualification Program for Safety-Related Equipment

D N I REV. 12 RECIPROCATING COMPRESSOR AIR HEATING COIL 6 S P R A Y Z Z L E COCJI lNG COIL MOVABLE LOUVER [ LIQUID TANK K(55) ROTARY COMPRESSOR X PROPELLER FAN n "---------'

II A GAS CYLINDER n ld u D (Q? ION EXCHANGER

// FIXED LOUVER CENTRIFUGAL COMPRESSOR CENTRIFUGAL FAN / / 0 [b:::::::J GAS INJECTOR 111 [Q!J rAN COIL UNIT AIR GAS RECEIVER RESTRICTING ORIFICE [] TRAP 1/1 [lJ t! RELIEF VALVE MOISTURE SEPARATOR FLOW INSTRUMENT MANUAL DAMPER m bJd RCJLL iLl t_R 0 [2J SELF-ACTUATING.

[:::::1 CHECK VALVE 521 FILTER BACKFLOW OR RUPTURE DISK GRAVITY DAMPER c=J ENGINE 0 FOUR WAY VALVE G PUMP FIRE DAMPER c=J GENERATOR C><J MANUAL VALVE EJ 0 SKIMMER RADIATION MONITOR D ClfJ THREE WAY VALVE SINGLE STAGE TURBINE n r:-1 u PROPORTIONING MOTOR OPERATOR 0 STRAINER PUMP MULTISTAGE TURBINE u (8) ROTARY PUMP r AIR OPERATOR J DISCHARGE NOZZLE CONDENSER Cfl SOLENOID OPERATOR a g EVAPORATOR (9 COOLER ACCUMULATOR 0 LOOP HEAT EXCHANGER u HYDRAULIC OPERATOR PART[CULATE FILTER ABBREVIATIONS DEMINERALIZER TXV-THERMAL EXPANSION VALVE OOJJ TCV-TEMPERATURE CONTROL VALVE REGENERATIVE ELECTRO-HYDRAULIC il PCV-PRESSURE CONTROL VALVE HEAT EXCHANGER OPERATOR HCV-HAND CONTROL VALVE n CHARCOAL FILTER sv -SAFETY VALVE 0 STEAM GENERATOR TV -THROTTLE VALVE THRU HEAT EXCHANGER

"\ I 0 SPECIAL VALVE GV GOVERNOR VALVE u -NRV-NON-RETURN VALVE U TUBE HEAT EXCHANGER 0 PRESSURIZER

[fJ LOUVER W/SCREEN BLENDER @ FIGURE 1

  • 7-1 DEHYDRATOR AIR DRYER SYMBOLS FOR FIGURES BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT BVPS-2 UFSAR Rev. 0 1.8-1 1.8 CONFORMANCE TO NRC REGULATORY GUIDES Table 1.8-1 provides an evaluation of the degree of Beaver Valley Power Station-Unit 2 (BVPS) conformance to NRC Division 1 Regulatory Guides. The revisions of the regulatory guides against which BVPS-2 is evaluated are indicated. Any alternatives to the provisions of the regulatory guides are identified and justification is provided where appropriate.

FSAR sections applicable to the subject regulatory guide are referenced.

BVPS-2 UFSAR Tables for Section 1.8

BVPS-2 UFSAR Rev. 18 1 of 91 TABLE 1.8-1 USNRC REGULATORY GUIDES

RG No. 1.1, Rev. 0 UFSAR Reference Section 6.2.2, 6.3

NET POSITIVE SUCTION HEAD FOR EMERGENCY CORE COOLING AND CONTAINMENT HEAT REMOVAL SYSTEM PUMPS (NOVEMBER 2, 1970)

Beaver Valley Power Station - Unit 2 meets the intent of

Regulatory Guide 1.1 for providing adequate net positive suction head (NPSH) for emergency core cooling and containment heat

removal systems pumps with the following alternatives:

The containment pressure and sump vapor pressure are calculated explicitly on a transient basis and used to calculate the available NPSH for the Recirculation Spray pumps as described in Section 6.2.2.3.2.

RG No. 1.2, Rev. 0 UFSAR Reference Section 5.3

THERMAL SHOCK TO REACTOR PRESSURE VESSELS (NOVEMBER 2, 1970)

The guidance provided by this regulatory guide regarding Section

5.3 thermal shock to the reactor pressure vessel is followed for Beaver Valley Power Station - Unit 2 with the following

clarification:

Paragraph C.3 The vessel design does not preclude the use of an engineering solution to assure adequate recovery of the fracture toughness properties of the vessel material. If additional margin is needed, the reactor vessel can be

annealed. This solution was shown to be feasible by EPRI program RP1021-1, "Feasibility and Methodology for Thermal

Annealing an Embrittled Reactor Vessel."

RG No. 1.3, Rev. 2 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A LOSS-OF-COOLANT ACCIDENT FOR BOILING WATER REACTORS (JUNE 1974)

This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 2 of 91 RG No. 1.4, Rev. 2 UFSAR Reference Sections 4.2, 6.2.1, 6.2.4, 6.5.1, 15.1.5, 15.6.3, 15.6.5 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A LOSS-OF-COOLANT ACCIDENT FOR PRESSURIZED WATER REACTORS (JUNE 1974)

The assumptions used for evaluating the potential radiological consequences of a loss-of-coolant accident at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183. Refer to the position on Regulatory Guide 1.183, later in this table.

This regulatory guide is not applicable to Beaver Valley Power Station

- Unit 2.

RG No. 1.5, Rev. 0 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A STEAM LINE BREAK ACCIDENT FOR BOILING WATER REACTORS (MARCH 10, 1971)

This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

RG No. 1.6, Rev. 0 UFSAR Reference Sections 7.6, 8.3.1.4, 8.3.2, 7.6.1 INDEPENDENCE BETWEEN REDUNDANT STANDBY (ONSITE) POWER SOURCES AND BETWEEN THEIR DISTRIBUTION SYSTEMS (MARCH 10, 1971)

Methods for establishing the degree of independence between redundant standby (onsite) power sources and between their distribution systems at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.

RG No. 1.7, Rev. 2 UFSAR Reference Section 6.2.5

CONTROL OF COMBUSTIBLE GAS CONCENTRATIONS IN CONTAINMENT FOLLOWING A LOSS-OF-COOLANT ACCIDENT (NOVEMBER 1978)

The hydrogen control system was originally designed following the guidance of Regulatory Guide 1.7, but with the subsequent 10 CFR 50.44 rule change, the hydrogen recombiners are not required; therefore, the hydrogen recombiners may be maintained, modified or eliminated.

RG No. 1.8 UFSAR Reference Sections 12.5, 13.1, 13.2

PERSONNEL SELECTION AND TRAINING Application of Regulatory Guide 1.8 to the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 3 of 91 RG No. 1.9, Rev. 2 UFSAR Reference Sections 8.3.1.1.15, 14.2.12.54, 14.2.12.55

SELECTION, DESIGN, AND QUALIFICATION OF DIESEL-GENERATOR UNITS USED AS STANDBY (ONSITE) ELECTRIC POWER SYSTEMS AT NUCLEAR POWER PLANTS (DECEMBER 1979)

Diesel-generator units used as onsite electric power systems at BVPS-2 have been selected, designed, and qualified following the

guidance of this Regulatory Guide with the following alternative and clarifications:

The Class lE diesel generator units were designed and procured following the guidance of Regulatory Guide 1.9, Rev. 0 (March 1971) and IEEE Standard 387-1972. (Revision

status at time of design/procurement)

However, the Class lE diesel generators were manufactured to IEEE Standard 387-1977 with the following clarifications:

1. Section 4.1[8]: The BVPS-2 Class lE diesels are qualified utilizing the mild environment concept

acknowledged by 10 CFR 50.49(c).

2. Section 4.1[12]: The BVPS-2 Class lE diesels are seismically qualified in accordance with IEEE Standard 344-1971.
3. Section 5.4: The BVPS-2 Class lE diesels are qualified utilizing the mild environment concept acknowledged by 10 CFR 50.49(c).
4. Section 6.3.1: All required tests or analyses have been performed by the manufacturer with the exception of the2-hour short-time/22-hour continuous rating

test. This test will be performed at the site in accordance with Section 6.3.1 and the loading sequence specified in Paragraph C.14 of Regulatory Guide 1.9.

RG No. 1.10, Rev. 1 UFSAR Reference Section 3.8.1.6.2

MECHANICAL (CADWELD) SPLICES IN REINFORCING BARS OF CATEGORY I CONCRETE STRUCTURES (JANUARY 2, 1973)

Regulatory Guide 1.10 was withdrawn (June 1981) and has been

superseded by Regulatory Guide 1.136 ("Materials, Construction, and Testing of Concrete Containments (Articles CC-1OOO, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containment)"). However, since a significant portion of Beaver Valley Power Station - Unit 2 design and construction was completed prior to the withdrawal of this regulatory guide, mechanical (Cadweld) splices in reinforcing bars of Category I concrete structures meet the intent of Regulatory Guide 1.10 with the following alternative:

BVPS-2 UFSAR Rev. 15 TABLE 1.8-1 (Cont) 4 of 91 Reinforcing bars with a radius of curvature 60 feet-0 inches or greater will be tested at the sampling frequency specified in Paragraphs C.4a and C.4b. Reinforcing bars with a radius of

curvature of less than 60 feet-0 inches will be tested using only sister splices with the following frequency for each splicing crew:

1. One sister splice representing the first 10 production
splices,
2. Four sister splices representing the next 90 production splices, and
3. One sister splice representing the next and every subsequent 33 production splices.

Testing of the sister splices is in accordance with Paragraphs C.3 and C.5.

The acceptability of this alternative is based on the following:

The second paragraph of Section 3 of Regulatory Guide 1.10 states that production mechanical splice samples for tensile testing should not be used from curved reinforcing sections, and then refers to Paragraph 4b for sampling frequency. Paragraph 4b provides for a combination of production and sister splices, which appears to be an

inconsistency.

The regulatory guide assumes that the cadwelders perform splices in the horizontal, vertical, and diagonal directions on the same day. Thus, there would be occasional splices on straight vertical bars which could be alternated with the curve bar splicing to permit the frequency of testing in Paragraph 4b of Regulatory Guide 1.10, which requires both production and sister splices.

However, construction is apt to perform splices in one position only for more splices than those requiring another set of tests. The 60-foot radius was established because satisfactory test results have been obtained for splices on bars of this or greater radii.

During the operations phase, splicing reinforcing bars shall be performed in accordance with individual project specifications. Project Specifications shall include or reference manufacturer's instructions and comply with the applicable requirements of ANSI N45.2.5-1974.

FENOC Quality Assurance Program Manual (QAPM) identifies specific subarticles of ASME Section III Division 2-1995 edition that will be used in lieu of the corresponding requirements in ANSI N45.2.5-1974.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 5 of 91 RG No. 1.11, Rev. 0 UFSAR Reference Section 6.2.4

INSTRUMENT LINES PENETRATING PRIMARY REACTOR CONTAINMENT (MARCH 10, 1971)

The guidance of this regulatory guide is followed for instrument lines penetrating primary reactor containment at Beaver Valley Power Station - Unit 2.

RG No. 1.12, Rev. 1 UFSAR Reference Section 3.7B.4.

INSTRUMENTATION FOR EARTHQUAKES (APRIL 1974)

Earthquake instrumentation at Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide with the following exceptions based on industry experience:

1) No triaxial accelerograph unit listed in Section 3.7B.4.2 is located on equipment, piping or supports since experience has shown that data obtained at these locations are obscured by the vibratory motion associated with normal plant operations.
2) There is no immediate indication that the zero period acceleration at the containment mat has been exceeded via a switch. The system will determine within minutes whether actual conditions have exceeded a pre-determined building response spectra and provide indication if the 1/2-SSE has been exceeded.
3) All instruments are oriented to the same azimuths, except one remote accelerograph sensor which is mounted to the containment cranewall. It is oriented such that it will respond to horizontal motion in the radial and tangential directions of the containment.

RG No. 1.13, Rev. 1 UFSAR Reference Sections 9.1.2, 9.1.3, 9.1.4, 9.1.5 SPENT FUEL STORAGE FACILITY DESIGN BASIS (DECEMBER 1975)

The design of spent fuel storage facilities follows the guidance of this regulatory guide with the following alternative:

Local spent fuel pool level alarms are not provided. A fuel pool level alarm is provided in the control room.

The motor-driven platform crane, which is the only crane that is operable over the spent fuel pool, has hoists that are each provided with an adjustable interlock which will

stop hoist motion if a preset weight is exceeded. The setpoint is based upon the weight of a single fuel assembly. Accordingly, the interlock must be overridden

in order to use the hoist for maintenance operations.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 6 of 91 Administrative procedures require that maintenance operations be carried out along a safe path away from the spent fuel pool. When the motor-driven crane is not in use, administrative procedures require that it be positioned away from the spent fuel pool.

RG No. 1.14, Rev. 1 UFSAR Reference Section 5.4.1.5

REACTOR COOLANT PUMP FLYWHEEL INTEGRITY (AUGUST 1975)

Reactor coolant pump flywheel integrity at Beaver Valley Power Station - Unit 2 is assured by meeting the intent of this regulatory guide as specified in WCAP-8163, September 1973,

("Reactor Coolant Pump Integrity in LOCA") and with the following alternative:

No post-spin test inspections are performed and pre-spin test inspections are considered adequate because flaw growth attributable to the spin tests (that is, from a single reversal of stress, up to speed and back), under the most adverse conditions, is about three orders of magnitude smaller than that which nondestructive

inspection techniques are capable of detecting.

RG No. 1.15, Rev. 1 UFSAR Reference Section 3.8.1.6.2

TESTING OF REINFORCING BARS FOR CATEGORY I CONCRETE STRUCTURES (DECEMBER 28, 1972)

Regulatory Guide 1.15 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981 (Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, - 2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station -

Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, testing of reinforcing bars for Category I concrete structures at BVPS-2 follows the

guidance of this Regulatory Guide 1.15, Rev. 1.

During the operations phase, splicing reinforcing bars shall be performed in accordance with individual project specifications. Project Specifications shall include or reference manufacturer's instructions and comply with the applicable requirements of ANSI N45.2.5-1974.

FENOC Quality Assurance Program Manual (QAPM) identifies specific subarticles of ASME Section III

Division 2-1995 edition that will be used in lieu of the

corresponding requirements in ANSI N45.2.5-1974.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 7 of 91 RG No. 1.16, Rev. 4 UFSAR Reference Chapter 16

REPORTING OF OPERATING INFORMATION - APPENDIX A TECHNICAL SPECIFICATIONS (AUGUST 1975)

Reporting of operating information for Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide, except for the Monthly Operating Report, which will follow the guidance provided in NRC Generic Letter 97-02, "Revised Contents of the Monthly Operating Report" dated May 15, 1997.

RG No. 1.17, Rev. 1 UFSAR Reference Section 13.6 PROTECTION OF NUCLEAR POWER PLANTS AGAINST INDUSTRIAL SABOTAGE (JUNE 1973)

The protection of Beaver Valley Power Station - Unit 2 against industrial sabotage is provided for by following the guidance of this regulatory guide.

RG No. 1.18, Rev. 1 UFSAR Reference Section 3.8.1

STRUCTURAL ACCEPTANCE TEST FOR CONCRETE PRIMARY REACTOR CONTAINMENTS (DECEMBER 28, 1972)

Regulatory Guide 1.18 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981 (Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station -

Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, the structural acceptance test for the containment structure at BVPS-2 follows

the guidance of this regulatory guide with the following clarifications:

As permitted by Paragraph C.3 of the Regulatory Guide, minor changes will be made in the selection of locations for deflection measurements around the access openings to

account for the thickened ring beam.

The containment structure is a nonprototype structure similar in design and construction to those referenced in UFSAR Section 3.8.1.1.1. Therefore, the regulatory positions for a nonprototype structure are followed.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 8 of 91 RG No. 1.19, Rev. 1 UFSAR Reference Sections 3.8.1.2.3, 3.8.1.7.2

NONDESTRUCTIVE EXAMINATION OF PRIMARY CONTAINMENT LINER WELDS (AUGUST 11, 1972)

Regulatory Guide 1.19 was withdrawn (June 1981) and has been superseded by Regulatory Guide 1.136, Rev. 2, June 1981,

["Materials, Construction, and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")]. However, since a significant portion of BVPS-2 design and construction was completed prior to the withdrawal of this regulatory guide, nondestructive examination of primary containment liner welds at BVPS-2 meets the intent of Regulatory Guide 1.19 with the

following alternatives:

Paragraph C.1.d Where leak chase system channels are installed over liner seam welds, the nondestructive examination of these seam welds is to be done by either 1) use of a vacuum box test before application of the channel, or 2) application of soapsuds to the liner seam while the channel is air-pressurized to the calculated peak containment pressure.

Necessary repairs are to be made up to completion of a successful leaktight test.

After completion of this test, a test of the channel-to-

liner welds is to be performed by either 1) evacuating the air from the channel, and then pressurizing with Freon 22 to calculated peak containment pressure and examining these welds with a Halogen detector, or 2) pressurizing

the test channels to containment peak pressure with air; and, if any indicated loss of channel test pressure occurs, within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> as evidenced by the test gage, the channel-to-liner welds should be soap bubble tested.

Necessary repairs are to be made up to completion of a successful leaktight test. The Freon is to be purged

after the test.

Paragraphs C.2.a, C.7.a, C.7.b, and C.7.d Nondestructive test methods and acceptance standards are in accordance with ASME Section III, Subsection NE-5300,

which corresponds to the referenced Subsection NE-5120.

RG No. 1.20, Rev. 2 UFSAR Reference Section 3.9.2

COMPREHENSIVE VIBRATION ASSESSMENT PROGRAM FOR REACTOR INTERNALS DURING PREOPERATIONAL AND INITIAL STARTUP TESTING (MAY 1976)

BVPS-2 follows the guidance of Regulatory Guide 1.20 for a comprehensive vibration assessment program which verifies the structural integrity of the reactor internals for flow-induced

vibrations prior to commercial operation.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 9 of 91 Briefly, this comprehensive program considers both the prototype reactor and subsequent reactors as follows:

For each prototype reactor internals design, a program of vibration analysis, measurement, and inspection has been developed and reviewed by the USNRC. This is documented

in WCAP-7879.

The reactor internals similar to the prototype design are subjected during hot functional testing to the same system flow conditions imposed on the prototype design applicable, and for the same duration. Pre- and post-test inspections will be conducted to assure that the internals are well-behaved and that no excessive motion or wear are experienced. Refer to UFSAR Section 3.9N.2.4 for details on the testing and inspections.

RG No. 1.21, Rev. 1 UFSAR Reference Section 11.5.1 MEASURING, EVALUATING, AND REPORTING RADIOACTIVITY IN SOLID WASTES AND RELEASES OF RADIOACTIVE MATERIALS IN LIQUID AND GASEOUS EFFLUENTS FROM LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (JUNE 1974)

The monitoring, evaluating and reporting of radioactivity in solid wastes and releases of radioactive materials in liquid and gaseous effluents at BVPS-2 will meet the intent of this

regulatory guide with the following alternative:

For the turbine building drains, grab sample systems are provided for each of the three transfer pump systems. Normally, grab samples will be taken on a weekly basis.

However, in the event of a high activity alarm from the main steam discharge monitors or the steam generator blowdown sample monitor, grab samples from the turbine building drains will be taken on a hourly basis. If any of these samples exceeds a predetermined activity level, the isolation valve for that transfer system will be closed and the flow will be diverted to the liquid waste

system.

RG No. 1.22, Rev. 0 UFSAR Reference Sections 7.1.2, 7.2, 7.3.2.2, 7.1.2.4

PERIODIC TESTING OF PROTECTION SYSTEM ACTUATION FUNCTIONS (FEBRUARY 17, 1972)

Periodic testing of protection system actuation functions for Beaver Valley Power Station - Unit 2 will follow the guidance of this regulatory guide.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 10 of 91 RG No. 1.23, Rev. 0 UFSAR Reference Section 2.3.3

ONSITE METEOROLOGICAL PROGRAMS (FEBRUARY 17, 1972)

Onsite meteorological programs for Beaver Valley Power Station -

Unit 2 will follow the guidance of this regulatory guide.

RG No. 1.24, Rev. 0 UFSAR Reference Section 15.7.1.3

ASSUMPTIONS USED FOR EVALUATING POTENTIAL RADIOLOGICAL CONSEQUENCES OF A PRESSURIZED WATER REACTOR RADIOACTIVE GAS STORAGE TANK FAILURE (MARCH 23, 1972)

Beaver Valley Power Station - Unit 2 evaluation of the potential radiological consequences of a pressurized water reactor radioactive gas storage tank rupture meets the intent of this regulatory guide. The following alternatives were considered prudent:

Paragraph C.1.a In recognition of specific plant equipment arrangements for gaseous waste handling, the system component producing the worst environmental impact was identified and

additional conservatism was appropriately applied.

Paragraph C.2 Atmospheric diffusion (X/Q) values were calculated using the latest approved techniques which are provided in

Regulatory Guide 1.145.

BVPS takes some alternatives to Section C.3 dose

calculation methodology.

RG No. 1.25, Rev. 0

ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A FUEL HANDLING ACCIDENT IN THE FUEL HANDLING AND STORAGE FACILITY FOR BOILING AND PRESSURIZED WATER REACTORS (MARCH 23, 1972)

The assumptions used for evaluating the potential radiological consequences of a fuel handling accident in the fuel handling and storage facility at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183. Refer to the position on Regulatory Guide 1.183, later in this table.

This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 11 of 91 RG NO. 1.26, Rev. 3 UFSAR Reference Section 3.2.2 QUALITY GROUP CLASSIFICATIONS AND STANDARDS FOR WATER-, STEAM-,

AND RADIOACTIVE-WASTE-CONTAINING COMPONENTS OF NUCLEAR POWER PLANTS (FEBRUARY 1976)

Quality group classifications and standards for water-, steam-,

and radioactive-waste-containing components of Beaver Valley Power Station - Unit 2 meet the intent of Regulatory Guide 1.26 with the following alternatives:

1. The safety class terminology of ANSI N18.2-1973 and ANSI N18.2a-1975 is used instead of the quality group terminology. Thus, the terms Safety Class 1, Safety Class 2, Safety Class 3, and Non-nuclear Safety (NNS)

Class are used instead of Quality Groups A, B, C, and

D, respectively, and are consistent with present nuclear industry practice.

2. Paragraph NB-7153 of the ASME Section III Code requires that there be no valves between a code safety

valve and its relief point unless special interlocks prevent shutoff without other protection capacity.

Therefore, as an alternative to Paragraphs C.1.e and C.2.c, a single safety valve designed, manufactured, and tested in accordance with ASME III Division 1 is considered acceptable as the boundary between the reactor coolant pressure boundary and a lower safety

class or NNS class line.

3. Portions of the emergency diesel generator cooling water system, considered by the vendor to be parts of the engine (as distinguished from auxiliary support systems), were built to the manufacturer's standards rather than ASME III. These are identified in Table 3.2-1 and Section 9.5.5. The components used are of high quality, proven by experience, and were designed, fabricated, erected, and tested under the vendor's Quality Assurance Program which meets the requirements of 10CFR5O, Appendix B. Similar equipment has been accepted by the NRC for other nuclear power plant applications.
4. Regarding Regulatory Positions C.1 and C.2, all instrument tubing, classified as Safety Class 2 or 3,

are designed to ASME Section III rules and installed in accordance with the BVPS-2 quality assurance program for safety-related equipment.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 12 of 91 RG NO. 1.27, Rev. 2 UFSAR Reference Sections 2.4.11.6, 9.2.5

ULTIMATE HEAT SINK FOR NUCLEAR POWER PLANTS (JANUARY 1976)

The ultimate heat sink for Beaver Valley Power Station - Unit 2

follows the guidance of this regulatory guide.

RG No. 1.28, Rev. 2 UFSAR Reference Sections 17.1.2, 17.2

QUALITY ASSURANCE PROGRAM REQUIREMENTS (DESIGN AND CONSTRUCTION)

(FEBRUARY 1979)

This regulatory guide does not apply to the Beaver Valley Power Station - Unit 2 (BVPS-2) Quality Assurance Program since it is applicable to construction permit applicants docketed after October 1979. BVPS-2, docketed October 20, 1972, meets the requirements of Appendix B to 10 CFR 50 with the BVPS-2 Design and Construction Quality Assurance Program submitted and approved through Appendix A of the BVPS-2 PSAR. Regulatory Guide 1.28 does not apply to the BVPS-2 quality assurance program for plant operations since it is applicable only to the plant design and construction phase.

RG No. 1.29, Rev. 3 UFSAR Reference Section 3.2.1

SEISMIC DESIGN CLASSIFICATION (SEPTEMBER 1978)

The seismic design classification of structures, systems, and components at Beaver Valley Power Station Unit 2 follows the guidance of Regulatory Guide 1.29 with the following clarification:

Components within the NSSS vendor scope of supply which are placed in Safety Class 3 per ANSI N18.2, Paragraphs 2.2.3 (l), (3), or (4) may be classified Seismic Category II if failure during or following an ANS Condition II event would result in consequences no more severe than

allowed for an ANS Condition III event.

For the Balance of Plant, each component which is required to mitigate the consequences of an accident, as defined in ANSI N18.2, shall be classified Seismic Category I. In addition, all components classified as Safety Class 1, 2, or 3 shall be designated Seismic Category I. Seismic Category I components, structures, and systems shall be designed to remain functional in the event of the safe

shutdown earthquake (SSE). All Seismic Category I components are designed and constructed to Quality Assurance (QA) Category I requirements.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 13 of 91 Portions of structures, systems, or components whose continued function after an SSE are not required, but whose failure could reduce the functioning of other safety-related structures, systems, or components shall be designated Seismic Category II. These structures, systems, or components shall either be seismically

designed, located to preclude interactions, further restrained, structurally upgraded, or proven incapable of affecting safety.

Seismic Category I design requirements shall extend to the first seismic restraint beyond the seismic boundary and shall include the interface portion of the boundary itself (that is, for piping systems, the isolation valve at a boundary between Seismic Category I and nonseismic portions shall be designated Seismic Category I. The piping up to and including the first seismic restraint beyond the valve shall be designed to Seismic Category I requirements but, since the piping is not required to be ASME III Class 1, 2, or 3, shall not be designated Seismic Category I). By this means, the Seismic Category I boundary is defined with respect to safety-related function, and the interfacing portions meet the seismic design requirements in order to ensure the integrity of

the boundary.

Structures, systems, and components designed in accordance with Paragraphs C.2 and C.3 of the regulatory guide are designated Seismic Category II and are constructed to QA Category II or III requirements.

RG No. 1.30, Rev. 0 UFSAR Reference Sections 17.1, 17.2

QUALITY ASSURANCE REQUIREMENTS FOR THE INSTALLATION, INSPECTION, AND TESTING OF INSTRUMENTATION AND ELECTRIC EQUIPMENT (AUGUST 11, 1972)

The guidance provided by this regulatory guide for quality assurance requirements for the installation, inspection, and testing of instrumentation and electric equipment was followed

during the construction phase of Beaver Valley Power Station Unit 2. Application of Regulatory Guide 1.30 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual

.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 14 of 91 RG No. 1.31, Rev. 3 UFSAR Reference Sections 4.5.2.4, 5.2.3.4.6, 5.3.1.4, 6.1.1.1, 10.3.6.2

CONTROL OF FERRITE CONTENT IN STAINLESS STEEL WELD METAL (APRIL 1978)

For nuclear steam supply system fabrication, Beaver Valley Power Station - Unit 2 (BVPS-2) meets the intent of Regulatory Guide 1.31 for control of ferrite content in stainless steel weld metal by following acceptable alternative criteria. Westinghouse submitted a delta ferrite verification program for austenitic stainless steel weldments in WCAP-8324-A, June 1974, which the staff subsequently approved as a valid approach in a letter on December 30, 1974.

For balance of plant fabrication, BVPS-2 meets the intent of Regulatory Guide 1.31 by following the guidance of either Safety Guide 31, Regulatory Guide 1.31, Revision 1, Materials Engineering Branch Technical Position MTEB 5-1, or Regulatory Guide 1.31, Revision 3.

Following the guidance of any of the preceding document revisions was based primarily on the revision in effect on the date of the last specification revision wherein the regulatory guide was invoked. Since each revision of the regulatory guide is less restrictive than the foregoing, following the guidance

of any of the revisions is considered acceptable.

RG No. 1.32, Rev. 2 UFSAR Reference Sections 7.5, 8.1.5, 8.2, 8.3.1, 8.3.2,

7.5.2.3.1.3

CRITERIA FOR SAFETY-RELATED ELECTRIC POWER SYSTEMS FOR NUCLEAR POWER PLANTS (FEBRUARY 1977)

The design of the safety-related electric power systems for Beaver Valley Power Station - Unit 2 (BVPS-2) follows IEEE Standard 308-1974, and the guidance of Regulatory Guide 1.32, with the following clarifications:

Two immediate access offsite power circuits are provided. Each circuit is designed to be immediately available following a loss of onsite alternating current power supplies so that sufficient power capacity remains for an orderly shutdown and to supply all train related engineered safety feature loads:

Each battery charger that supplies Class IE 125 V dc systems is designed with full capacity and capability to supply the largest combined demands of the various steady state loads while simultaneously providing sufficient power for adequate charging capacity to restore the

battery from the design minimum charged state to the charged state irrespective of the BVPS-2 status during which these demands occur.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 15 of 91 For test methods, procedures, and intervals for all Class IE battery performance discharge and service tests, refer

to the position on Regulatory Guide 1.129.

RG No. 1.33 UFSAR Reference Sections 13.4, 13.5, 17.2

QUALITY ASSURANCE PROGRAM REQUIREMENTS (OPERATION)

Application of Regulatory Guide 1.33 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.34, Rev. 0 UFSAR Reference Section 5.2.3

CONTROL OF ELECTROSLAG WELD PROPERTIES (DECEMBER 28, 1972)

The guidance provided by this regulatory guide regarding control of electroslag weld properties was followed for fabrication of applicable components for Beaver Valley Power Station - Unit 2.

RG NO. 1.35, Rev. 2 INSERVICE INSPECTION OF UNGROUTED TENDONS IN PRESTRESSED CONCRETE CONTAINMENT STRUCTURES (JANUARY 1976)

This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

RG No. 1.36, Rev. 0 UFSAR Reference Sections 5.2.3, 6.1.1 NONMETALLIC THERMAL INSULATION FOR AUSTENITIC STAINLESS STEEL (FEBRUARY 23, 1973)

Nonmetallic thermal insulation for austenitic stainless steel used at Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide. As an alternative to controlled packaging and shipping described in Paragraph C.1, receipt inspection and tests are required by specification. This testing and inspection consists of visual inspection for physical or water damage to all cartons. Damaged cartons are segregated. Potentially contaminated insulation is not accepted, unless randomly selected samples from each carton are shown to be acceptable after being resubjected to the production

test outlined in this regulatory guide.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 16 of 91 RG NO. 1.37, Rev. 0 UFSAR Reference Sections 6.1.1.1, 17.2, 5.2.3.4.1

QUALITY ASSURANCE REQUIREMENTS FOR CLEANING OF FLUID SYSTEMS AND ASSOCIATED COMPONENTS OF WATER-COOLED NUCLEAR POWER PLANTS (MARCH 16, 1973)

During the construction phase, quality assurance requirements for cleaning of fluid systems and associated components at Beaver Valley Power Station - Unit 2 met the intent of this regulatory guide with the following alternatives:

Paragraph C.3 The water quality for final flushes of fluid systems and associated components is at least equivalent to the quality of the operating system water, except for the oxygen content.

Dissolved oxygen content of water cannot be maintained at reactor quality during flushing of open systems.

The maximum particle size criteria for class B cleanness is consistent with Section 3.1.2 except in the

Recirculation Spray System (RSS).

Particles of a maximum size of 1/8 inch in any dimension

are allowed in the RSS. This particle size limit was chosen since it is smaller than the openings in the recirculation spray system nozzles and the smallest coolant flow channel in the reactor core. Therefore, this exception will have no effect on the recirculation spray systems ability to perform its intended safety function.

Paragraph C.4 Expendable materials, that is, inks and related products, temperature indicating sticks, tapes, gummed labels, wrapping materials (other than polyethylene), water

soluble dam materials, lubricants, nondestructive testing penetrant materials and couplants which contact stainless steel or nickel alloy surfaces are in accordance with the

following:

1. They do not contain the following as basic and essential chemical constituents: lead, zinc, copper, mercury, cadmium and other low melting point metals, their alloys and/or compounds.
2. Prescribed maximum levels of water leachable chlorides, total halogens, and sulfur and its compounds are imposed on expendable products.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 17 of 91 Contamination levels in expendable products are based upon safe practices and industrial availability. Contaminant levels are controlled such that subsequent removal by standard cleaning methods will result in the achievement of final acceptable levels which are not detrimental to the materials.

Application of Regulatory Guide 1.37 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.38 UFSAR Reference Section 17.2

QUALITY ASSURANCE REQUIREMENTS FOR PACKAGING, SHIPPING, RECEIVING, STORAGE, AND HANDLING OF ITEMS FOR WATER-COOLED NUCLEAR POWER PLANTS Application of Regulatory Guide 1.38 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.39, UFSAR Reference Sections 12.5.3, 17.2

HOUSEKEEPING REQUIREMENTS FOR WATER-COOLED NUCLEAR POWER PLANTS Application of Regulatory Guide 1.39 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.40, Rev. 0 UFSAR Reference Sections 3.11, 8.3

QUALIFICATION TESTS OF CONTINUOUS-DUTY MOTORS INSTALLED INSIDE THE CONTAINMENT OF WATER-COOLED NUCLEAR POWER PLANTS (MARCH 16, 1973) This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2 since there are no continuous-duty Class IE

motors installed inside the containment.

RG No. 1.41, Rev. 0 UFSAR Reference Sections 8.1, 8.3, 14.2.12.54

PREOPERATIONAL TESTING OF REDUNDANT ONSITE ELECTRIC POWER SYSTEMS TO VERIFY PROPER LOAD GROUP ASSIGNMENTS (MARCH 16, 1973)

Onsite electric power systems at Beaver Valley Power Station - Unit 2 designed in accordance with Regulatory Guides 1.6 and 1.32 will be tested in accordance with the intent of Regulatory

Guide 1.41 during preoperational testing. Following major modifications or repairs appropriate testing will be performed to demonstrate operability and functional capability as

required.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 18 of 91 RG No. 1.42, Rev. 1 INTERIM LICENSING POLICY ON AS LOW AS PRACTICABLE FOR GASEOUS RADIOIODINE RELEASES FROM LIGHT-WATER COOLED NUCLEAR POWER REACTORS (MARCH 1976)

This regulatory guide was withdrawn March 1976.

RG No. 1.43, Rev. 0 UFSAR Reference Section 5.3.1.4, 5.2.3.3.2

CONTROL OF STAINLESS STEEL WELD CLADDING OF LOW-ALLOY STEEL COMPONENTS (MAY 1973)

For balance-of-plant components, Regulatory Guide 1.43 is not applicable, since stainless steel weld cladding of low-alloy steel is not used in fabrication of such components.

For NSSS components, Beaver Valley Power Station - Unit 2 follows the guidance of Regulatory Guide 1.43 with the exception of Paragaph C.1.a. For Paragraph C.1.a, Westinghouse practices are considered to achieve the same purpose as Regulatory Guide 1.43 by requiring qualification of any high heat input process used on ASME SA-508 Class 2 material by following the recommendations of Paragraph C.2 of the regulatory guide.

RG No. 1.44, Rev. 0 UFSAR Reference Sections 4.5.1, 4.5.2.4, 5.2.3.4, 5.3.1.4, 6.1.1.1, 10.3.6.2 CONTROL OF THE USE OF SENSITIZED STAINLESS STEEL (MAY 1973)

Control of the use of stainless steels subject to sensitization at BVPS-2 meets the intent of Regulatory Guide 1.44 with the

following clarifications and alternatives:

The following applies to NSSS fabrication with respect to Regulatory Position C.3:

The Westinghouse practice is that austenitic stainless steel materials of product forms with simple shapes need not be corrosion tested provided that the solution heat treatment is followed by water

quenching. Simple shapes are defined as all plates, sheets, bars, pipe, and tubes, as well as forgings, fittings, and other shaped products which do not have inaccessible cavities or chambers that would preclude rapid cooling when water quenched. Stainless steel cast metal and weld deposits (including weld deposited safe ends), which contain a minimum of 5 percent ferrite, are not considered to be susceptible to sensitization, and therefore, are not corrosion tested. When testing is required, the tests are performed in accordance with ASTM A262-70, BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 19 of 91 Practice A or E, as amended by Westinghouse Process Specification 84201MW. This process specification supplements the A262 specification since the latter does not define specimen removal location and does not adequately define bend testing criteria for thick and complex stainless steel raw material. The

Westinghouse specification requires that 1) specimens be removed from the same location from which mechanical test specimens are removed, and 2) the bend test diameter must be 4X material thickness instead of 1X (Paragraph 36.1, ASTM A262-70). This second modification is based on the fact that almost

all stainless steel materials procured by Westinghouse are eventually welded, and the 4X thickness bend test diameter is required for

weldments.

The following applies to balance of plant fabrication with

respect to Regulatory Position C.6:

1. The ASTM A708-74 standard is used to perform the intergranular corrosion testing for field fabrication

and erection of ASME III piping. The radius of the bend specimen is as specified in ASME IX with the weld metal-base metal interface located at the centerline of the bend.

2. Shop fabrication of ASME III piping and field fabrication of ASME III tanks require control of heat input during welding so as to avoid severe sensitization of the weld zone. The heat input during shop fabrication of ASME III piping is based on procedure qualifications in accordance with Regulatory

Guide 1.31, Rev. 1, and, during field fabrication of ASME III tanks, is 50,000 (maximum) joules per inch. In addition, the maximum interpass temperature is limited to 350F. While no testing for intergranular corrosion during weld procedure qualification is required, the above controls ensure that base material will not be severely sensitized during welding.

3. Fabrication of ASME III components other than those identified in Items 1 and 2 above is performed in fabrication shops and requires a maximum interpass temperature of 350F. While no testing for intergranular corrosion during weld procedure qualification is required, this specific control reduces the possibility of a severely sensitized heat-affected zone during welding. In addition, the need for the shop fabricator to provide unsensitized

components is specifically identified in all procurement specifications by requiring supplied material to be capable of meeting ASTM A262, Practice A or E. Shop practice generally recognizes the need to limit heat input during welding through good fit-up, adequate welder accessibility, proper positioning, BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 20 of 91 and close supervision. Finally, most of the pressure retaining components of the reactor coolant pressure boundary piping system are castings and, because of their delta ferrite content, are highly resistant to stress corrosion cracking.

The following applies to the operational phase of BVPS-2.

Stainless wrought products of the AISI Type 304 and 316 will be obtained in the solution heat treatment condition

with a sufficiently rapid cooling through the 800F to 1500F range by water quench. Materials not meeting this

condition (oil or air quench) will be tested for

sensitization in accordance with ASTM A262-70, Practice A

or E, or with ASTM A708, and bent for examination in accordance with weld test bending requirements of ASME

Section IX.

Qualification of AISI Type 304 and 316 welding procedures will be in accordance with the requirements of ASME Section IX except that the maximum amperage (heat input) specified in weld technique sheets shall not exceed that

qualified by the controlling Weld Procedure Qualification Report. Materials used for qualification will be commercially available AISI Type 304 and 316. ASTM A708

shall be used as the corrosion test on bend specimens to demonstrate that the welding procedure has not caused the base metal heat affected zone to become excessively sensitized. Corrosion test bend specimens shall consist of two side bends or one face bend and one root bend as required by ASME Section IX taken from the qualification test plate thickness. Corrosion test bend specimens shall be bent over the appropriate radius specified in ASME IX for bend specimens with the weld metal-base metal interface located at the centerline of the bend. The specimens shall be evaluated as stated in ASTM A708 and shall indicate the absence of intergranular attack.

Corrosion tests shall be incorporated as part of the weld procedure qualification test record.

RG No. 1.45, Rev. 0 UFSAR Reference Section 5.2.5 REACTOR COOLANT PRESSURE BOUNDARY LEAKAGE DETECTION SYSTEMS (MAY 1973)

The leakage detection systems provided to detect leakage from the reactor coolant pressure boundary (RCPB) meet the intent of Regulatory Guide 1.45 with the following clarification of Paragraph C.5 and alternative to Paragraph C.6:

BVPS-2 UFSAR Rev. 15 TABLE 1.8-1 (Cont) 21 of 91 Paragraph C.5 The sensitivity and response time of each leakage detection system employed to collect unidentified leakage are as shown in the following table:

SYSTEM SENSITIVITY AND RESPONSE TIME Sump levels 1 gpm in less than 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Air cooler condensate Drain flow rate

1 gpm in less than 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Air cooler outlet

Water temperature

increase

5 gpm in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Containment atmosphere

humidity, temperature,

and pressure

5 gpm in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Containment atmosphere

radioactivity monitor

1 gpm in less than 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> assuming primary coolant radioactivity concentrations stated in the environmental report. For other conditions the equilibrium activity of the reactor coolant must be sufficiently high and the equilibrium activity of the containment atmosphere must be below a level that would mask the change in activity corresponding to this leak

rate. Paragraph C.6 BVPS-2 does not fully follow the guidance of Paragraph C.6 in that the containment sump level detection systems which meet the detection sensitivity requirements of normal plant operation (that is, 1 gpm in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />) are not designed to meet seismic requirements. However, a

seismically qualified, less sensitive, additional sump level instrumentation system, powered from Class IE electrical buses, is provided with remote displays in the control room to monitor for excessive leakage following seismic events. This instrumentation is qualified for seismic loads up to safe shutdown earthquake loads.

The SWEC interpretation of the RCPB leakage detection system requirements and Paragraph C.5 of Regulatory Guide 1.45 agrees with the USNRC staff interpretation given in Section 5.2.5 of Regulatory Guide 1.70, "Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants," Rev. 2, dated September 1975, and the corresponding USNRC Standard Review Plan, NUREG-75/087, dated November 1975. In addition, the USNRC staff has agreed to this position by accepting the leakage detection systems that have been described in safety analysis reports for SWEC plants (SWESSAR P-1, Section 5.2.7).

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 22 of 91 RG No. 1.46, Rev. 0 UFSAR Reference Section 3.6

PROTECTION AGAINST PIPE WHIP INSIDE CONTAINMENT (MAY 1973)

Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.46 for the protection against pipe whip inside containment with the following clarifications and alternatives:

Paragraph C.1.b The piping breaks are postulated to occur at any intermediate locations where the maximum stress exceeds 3.0 S as calculated by equation (10) and by either equation (12) or equation (13) in Paragraph NB-3653 of the ASME Code Section III.

Paragraph C.2.b The piping breaks are postulated to occur at any intermediate locations where either the circumferential or the longitudinal stresses derived on an elastically calculated basis under the loadings associated with

specified seismic events and operational plant conditions exceeds 0.8 (1.8 S h + SA) as calculated with equations (9) and (10) in Paragraph NC-3652 of the ASME Code,Section III (Section 3.6B.2).

Paragraph C.3.a Longitudinal breaks are not postulated at terminal points nor at locations where the criterion for a minimum number

of break locations must be satisfied.

Paragraph C.3.b Circumferential breaks are not postulated where detailed stress analysis shows that circumferential stress is at least 1.5 times that in the axial direction. Longitudinal breaks are not postulated where axial stress is at least 1.5 times the circumferential stress.

RG No. 1.47, Rev. 0 UFSAR Reference Section 7.1.2

BYPASSED AND INOPERABLE STATUS INDICATION FOR NUCLEAR POWER PLANT SAFETY SYSTEMS (MAY 1973)

The bypass and inoperable status indication system for Beaver

Valley Power Station - Unit 2 follows the guidance provided by this regulatory guide.

Automatic bypass indication is provided in the control room for each safety-related system train and is at the system level.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 23 of 91 RG No. 1.48, Rev. 0 UFSAR Reference Sections 3.9N.1, 3.9N.3, 3.9B.3

DESIGN LIMITS AND LOADING COMBINATIONS FOR SEISMIC CATEGORY I FLUID SYSTEM COMPONENTS (MAY 1973)

The criteria and procedures used in the design of Beaver Valley Power Station - Unit 2 concerning design limits and loading combinations for Seismic Category 1 fluid system components,

satisfy the requirements of General Design Criterion 2 and thereby meet the intent of Regulatory Guide 1.48 in an alternate acceptable manner.

To ensure the structural integrity of fluid systems components, the limits given in Section 3.9N.1 will be used in the design and analysis of ASME Code Class 1 components within the Westinghouse scope of supply. For ASME Code Class 2 and 3 components within the Westinghouse scope of supply, the limits

given in Section 3.9N.3 are used.

Criteria outlined in Section 3.9B.3 are applicable to balance of plant ASME Code Class 1, 2, and 3 components and are consistent with the applicable provisions of Section III of the ASME Boiler and Pressure Vessel Code. Supplemental criteria relating to assurance of component operability are drawn from developing industry code activities, including the efforts of the ANSI N45 Committees.

RG No. 1.49, Rev. 1 UFSAR Reference Section 1.1 POWER LEVELS OF NUCLEAR POWER PLANTS (DECEMBER 1973)

Beaver Valley Power Station - Unit 2 design and analysis involving power level follows the guidance of this regulatory

guide.

RG No. 1.50, Rev. 0 UFSAR Reference Section 5.2.3.3, 5.3.1.4

CONTROL OF PREHEAT TEMPERATURE FOR WELDING OF LOW-ALLOY STEEL (MAY 1973)

Beaver Valley Power Station - Unit 2 (BVPS-2) meets the intent of Regulatory Guide 1.50 for the control of preheat temperature for welding of low-alloy steel with the following clarifications

and alternatives:

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 24 of 91 Westinghouse considers that Regulatory Guide 1.50 applies only to ASME Code,Section III, Class 1 components. The Westinghouse practice for Class 1 components follows

welding procedures which meet the criteria in Section IX of the ASME Code and WCAP-8577, February 1976, "The Application of Preheat Temperatures after Welding Pressure

Vessel Steels," in lieu of Paragraphs C.1.b and C.2 of Regulatory Guide 1.50. Westinghouse experience has shown high quality and integrity for welds using these

procedures which have been found acceptable by the USNRC.

For the remainder of BVPS-2 welds, in cases when it is impractical to maintain the preheat temperature until a post- weld heat treatment has been performed (Paragraph C.2), a minimum temperature of 300F is maintained for two hours per inch of thickness. This practice of maintaining the completed weld at an elevated temperature for the

prescribed period of time allows hydrogen to effuse from the weld zone, reducing the tendency to form cracks in the weldment.

RG No. 1.51, Rev. 0 INSERVICE INSPECTION OF ASME CODE CLASS 2 AND 3 NUCLEAR POWER PLANT COMPONENTS (MAY 1973)

This regulatory guide was withdrawn July 1975.

RG No. 1.52, Rev. 2 UFSAR Reference Section 6.5.1.2 DESIGN, TESTING, AND MAINTENANCE CRITERIA FOR POST ACCIDENT ENGINEERED-SAFETY-FEATURE ATMOSPHERE CLEANUP SYSTEM AIR FILTRATION AND ADSORPTION UNITS OF LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (MARCH 1978)

The design, testing, and maintenance criteria for the post-accident engineered safety feature (ESF) atmosphere cleanup system at BVPS-2 meets the intent of this regulatory guide with

the following alternatives:

Paragraph C.2.b Tornado protection is not considered necessary for the ESF

atmosphere cleanup systems because of the low probability

of a joint occurrence of a tornado and those DBAs that would require operation of the ESF atmospheric cleanup systems (

References:

SRP 6.5.1 and Regulatory Guide

1.117). Paragraph C.2.f Filter component layouts consist of a maximum of four high efficiency particulate air (HEPA) filters high and five

HEPA filters wide.

BVPS-2 UFSAR Rev. 18 TABLE 1.8-1 (Cont) 25 of 91 Paragraph C.2.g Pressure drop is indicated at each airstream HEPA filter and annunciated in the main control room.

Paragraph C.2.h Annunciator functions are incorporated in the overall system design. Annunciators are not safety-related;

therefore, they are not designed in accordance with IEEE

Standard 279-1971.

Paragraph C.2.j The trains of the ESF atmosphere cleanup systems are

designed to be removed as intact units or as a minimum

number of segmented sections. Individual filter components will be removed prior to cutting the housing

into segmented sections.

Paragraph C.2.l

1. The ductwork leak tests are performed in accordance with ANSI N510-1975 with the alternative that ASME performance test code 19.5-1971 will be used in lieu of paragraph 6.3.1. The equipment and equipment

arrangement based on the above ASME performance test

code will provide test results equivalent to results obtained by equipment specified in paragraph 6.3.1 of

ANSI N510-1975.

2. The air leakage rate for ductwork will be established based on the air cleaning effectiveness provisions defined in Paragraph 4.12.1 of ANSI N509-1976.

Because the ductwork carrying contaminated air upstream of the filters is under negative pressure and

there is no leakage from the ductwork to surrounding space, and because any air leak from the ductwork

under positive pressure is on the downstream side of

the filters (filtered air), the leakage for ductwork upstream of the filters and downstream of the fans is limited to 1 percent of rated flow at internal design

pressure.

3. For ductwork between the outlet of filters and the inlet of fans, the leakage is limited to 0.5 percent

of rated flow at internal design pressure.

4. The duct leakage for the control room emergency ventilation system is limited to 5 percent of rated flow. This rate of leakage will not adversely affect

the system capability to pressurize the control room

envelope.

All components of the system carrying unfiltered

outside air are under negative pressure, precluding

any leakage of unfiltered air to the control room

envelope.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 26 of 91 5. The filter housing leak tests will be performed in accordance with paragraph 4.12 of ANSI N509-1976 with the alternative that the housing maximum allowable leakage will be as specified in Table 4-3 of ANSI N509-1980. The leakage test procedure will be developed based on Section 6 of ANSI N510-1980.

Paragraph C.3.a Demisters meet Underwriters Laboratories (UL) Class 2 requirements.

Paragraph C.3.e Filter and adsorber mounting frames are constructed and designed in accordance with the recommendations of Section 4.3 of ORNL-NSIC-65, except for the frame tolerance guidelines in Table 4.2. The tolerances for HEPA filter and adsorber mountings are sufficient to satisfy the bank leak test criteria of paragraphs C.5.c and C.5.d of this Regulatory Guide.

Paragraph C.3.f Filter component layouts consist of a maximum of four HEPA filters high and five HEPA filters wide.

Paragraph C.3.g

1. Stainless steel materials for filter housings are procured to ASTM material specification A167 Type 304 in addition to those listed in paragraph 4.3 of NSIC-65/ERDA 76-21.
2. Welding is performed in accordance with AWS D1.1 or ASME IX; therefore, the workmanship samples recommended in paragraph 7.3 of ANSI N509-1976 are not used to demonstrate welders' qualifications to perform production work.

Paragraph C.3.l The qualification of unused impregnated carbon will be in accordance with Table 5-1 of ANSI N509-1980.

Paragraph C.3.g

1. The type and application of protective coatings on internal surfaces is controlled in accordance with the

designer's specifications, which specify high quality materials and application methods in accordance with

the coating manufacturer's instructions. These practices are used in lieu of the recommendations in paragraphs 5.7.1 and 5.6.4 of ANSI N509-1976.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 27 of 91 2. An alternative is taken to paragraph 5.7.2 of ANSI N509-1976. Copies of fan ratings or test reports are not provided. However, certified fan performance

curves are furnished.

3. The balancing techniques defined in paragraph 5.7.3 of ANSI N509-1976 will be used except that normal industrial practice will be used to determine the maximum permissible vibration velocity criteria.
4. The fan drawings follow the recommendations of paragraph 5.7.4 of ANSI N509-1976 with the alternative that all information about lubricants and lubrication is contained in operation and instruction manuals.
5. Where AMCA certified ratings are submitted, documentation developed in conjunction with the

certification of fans is not furnished in accordance

with paragraph 5.7.5 of ANSI N509-1976.

Paragraph C.3.n

1. Welding procedures, welders, and welding operators are qualified in accordance with designer's welding specifications. These specifications are in general conformance with AWS D1.1 and ASME Section IX, which are recommended in paragraph 7.3 of ANSI N509-1976.

Production weld visual acceptance criteria, which are based on AWS D1.1, are used in lieu of workmanship samples recommended in ANSI N509-1976, paragraph 7.3.

2. Materials for ductwork are procured to ASTM material specifications, such as A276 Type 304, A500 Gr B, A575 Gr N1020, and A576 Gr 1020, in addition to those listed in paragraph 5.10.6 of ANSI N509-1976.
3. An alternative is taken to paragraph 5.10.3.5 of ANSI N509-1976. While ductwork, as a structure, has a resonant frequency above 25 Hz, this may not be true for the unsupported plate or sheet sections. ANSI N509-1980, which has been issued since the issuance of this regulatory guide, has deleted this provision.

Tympanic vibration modes of the duct are not considered in the design because the loads will be small and minimum thickness of duct material is 20

gauge. This is more conservative than SMACNA provisions.

BVPS-2 UFSAR Rev. 14 TABLE 1.8-1 (Cont) 28 of 91 Paragraph C.3.p The following alternatives are taken to paragraph 5.9 of ANSI N509-1976:

1. Isolation dampers used in the supplementary leak collection and release system are neither designed nor constructed to the recommendations of ANSI B31.1. The system is designed to ensure that the leakage through the dampers is from the noncontaminated to the contaminated portion of the system and the flow is exhausted through the filters before being released to the atmosphere. Therefore, the uncontrolled release of radioactivity is precluded and the intent of Section 5.9 of ANSI N509-1976 is satisfied.
2. Butterfly valves used for control room isolation are in accordance with the ASME III code.
3. One Class B damper of each size will be tested for leakage rate instead of testing every damper.
4. Welding is controlled in accordance with the designers' specifications using visual acceptance criteria, which are based on AWS D1.1 in lieu of the standards recommended in paragraphs 5.9 and 7.3 of ANSI N509-1976.
5. The minimum diameter of damper shafts that are 24 inches and under in length shall be 1/2 inch. The minimum diameter of damper shafts that are greater than 24 inches in length through 48 inches in length shall be 3/4 inch.

Paragraph C.4.a Alternatives are taken to Section 2.3.8 of ERDA 76-21:

1. The control room filtration assembly, due to its size, does not require entry to the housing interior.

The SLCRS filtration assembly is of gasketless type, therefore handling of the charcoal adsorber trays inside the housing is eliminated. During replacement of HEPA filters, voice communication is sufficient.

The filter housing is provided with large doors allowing visual and voice communication between personnel inside and outside of the housing.

Therefore, no special communication system need be provided.

2. Decontamination, clothing change, and shower facilities for personnel involved in the filter service are incorporated into the overall plant

radiation protection program.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 29 of 91 3. Due to the large number of duct inlets (registers), it is not feasible to provide prefilters at each register. It should be noted that areas exhausted by filtration systems are not expected to contain significant amounts of dust. Inspection doors are provided at all dampers, reheat coils, and other similar items requiring inspection or maintenance. These doors can serve the functions specified in Section 2.3.8 of ERDA.

Paragraph C.4.d The ESF atmosphere cleanup systems are operated a minimum of 15 minutes per month.

Paragraph C.5.a A visual inspection of the ESF atmosphere cleanup system and all associated components is not planned to be made before each in-place airflow distribution test, DOP test, or activated carbon adsorber section leak test, but will be performed after initial installation and on an as-needed basis in accordance with the provisions of Section 5 of ANSI N510-1975.

Paragraph C.5.b The acceptance testing airflow capacity and distribution test procedure will be developed based on Section 8 of ANSI N510-1980 except for the following alternatives:

1. To avoid damage to system components an artificial resistance will be used in lieu of the recommendations of Paragraph 8.3.1.1.
2. Airflow measurements for the airflow capacity test will be performed in accordance with AABC National Standards for Total System Balance, Fourth Edition, 1982, instead of Section 9 of ACGIH, Industrial Ventilation, as recommended in Paragraph 8.3.1.3 and 8.3.1.4 of ANSI N510-1980. The above alternative will provide consistency with the airflow measurement

method for balancing of the plant ventilation systems.

3. The airflow test specified in Paragraph 8.3.1.6 will be performed with the filter bank at 100 percent of design dirty filter pressure drop. The system and equipment instrumentation and surveillance preclude inadvertent operation of the filter banks with the pressure or flow outside of the allowable limits.
4. The test specified in Paragraph 8.3.1.7 of ANSI N510-1980 cannot be performed because the system cannot operate at the flow associated with the pressure drop below clean component pressure drop. The pressure drop of about 50% of the design dirty filters is about equal to the pressure drop of clean components.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 30 of 91 5. Airflow distribution through prefilters and moisture separator banks is not specified. Therefore, the provisions of Paragraph 8.3.2.3 do not apply.

The surveillance test airflow measurements will be taken following maintenance when required by Technical

Specifications using installed instrumentation, when available, or the pitot tube velocity traverse method in accordance with an approved surveillance test procedure.

Paragraph C.5.c The in-place DOP test of HEPA filters will be performed in accordance with Section 10 of ANSI N510-1980 with the air-aerosol mixing uniformity test in accordance with

Section 9 of the above code.

Paragraph C.5.d The in-place test of the carbon adsorber will be performed in accordance with Section 12 of ANSI N510-1980.

Paragraph C.6.b Laboratory testing frequency for the activated carbon will meet the recommended minimum test frequency indicated in Table 1 of ANSI N510-1980.

The carbon samples not obtained from test canisters will be obtained with slotted-tube sampler in accordance with

ANSI N509-1980.

Table 2 Laboratory tests for methyl iodide penetration for the representative sample will allow a maximum penetration of

3 percent as stipulated in Table 5-1 of ANSI N509-1980.

RG No. 1.53, Rev. 0 UFSAR Reference Section 3.1.1, 7.1.2.6, 15.0.8

APPLICATION OF THE SINGLE-FAILURE CRITERION TO NUCLEAR POWER PLANT PROTECTION SYSTEMS (JUNE 1973)

Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.53 for application of the single failure criterion to protection systems with the following alternatives:

1. As stated in Paragraph C.1, departure from certain provisions may occur.
2. For certain Westinghouse supplied equipment, a fault tree analysis, rather than a failure mode and effects analysis, has been used.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 31 of 91 3. Final actuation devices are generally capable of periodic in-service testing. However, some devices by necessity can only be tested partially with the unit

on line and completely with the unit off line.

4. With regard to Paragraph C.3, single switches supplying signals to redundant channels will have a separation of at least 6 inches or a suitable barrier will be supplied.
5. Compliance with single failure criteria will be verified based on a collective analysis of both the protective system and the final actuation devices or actuators.

RG No. 1.54, Rev. 0 UFSAR Reference Sections 6.1.2, 17.1

QUALITY ASSURANCE REQUIREMENTS FOR PROTECTIVE COATINGS APPLIED TO WATER-COOLED NUCLEAR POWER PLANTS (JUNE 1973)

Quality assurance requirements for protective coatings at BVPS-2 meet the intent of this regulatory guide with the following

clarification and alternatives:

For the balance-of-plant, ANSI N101.4-1972 requirements for documentation are applied as follows to equipment located in the containment.

For large surface area components, the documents are submitted by the vendors as required by ANSI N101.4-1972. These components include such items as the polar crane,

structural steel, concrete, ductwork, uninsulated pipe, neutron shield tank, exteriors of uninsulated tanks and vessels, major equipment supports, and the containment

liner. For manufactured equipment such as pumps, motors, pipe

hangers, and supports, the documentation required by ANSI N101.4-1972 is maintained in the seller's files for the complete duration of the contract warranty-guarantee period. A certificate of compliance signed by responsible management personnel is furnished by the seller.

For balance of plant, in lieu of the inspection defined in Section 6.2.4 of ANSI 101.4-1972, inspection is performed in accordance with ANSI N5.12-1974, Section 10,

"Inspection for Shop and Field Work."

For nuclear steam supply equipment located in the

containment, the following acceptable alternate method is employed.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 32 of 91 For large surface area components, Westinghouse specifies stringent requirements through the use of a painting specification which includes the use of specific coating systems qualified to ANSI N101.2 and certifications of compliance from the vendors. The vendor's implementation of the specification requirements is monitored during the

quality assurance surveillance activities. These components include the reactor coolant system supports, reactor coolant pumps, accumulator tanks, and the

manipulator crane.

For intermediate surface area components, Westinghouse

employs another specification which also includes the use of coating systems which are qualified to ANSI N101.2. The vendor's compliance with the requirements is also checked during quality assurance surveillance activities. These components include the seismic platform and tie rods, reactor internals lifting rig, head lifting rig, and

electrical cabinets.

For both the nuclear steam supply system and the balance-of-plant, Regulatory Guide 1.54 guidelines are not invoked for items such as valve bodies, handwheels, certain electrical cabinets and control panels, loudspeakers,

emergency light cases, and small instruments. The total surface area of these items is very small in comparison with the total surface area for which the guidelines are

imposed.

The guidelines of this regulatory guide are not applied to

routine touch-up work.

No special QA requirements are imposed for the painting of

surfaces that will be insulated.

In general, stainless steel and corrosion-resistant alloys

are not painted.

RG No. 1.55, Rev. 0 UFSAR Reference Section 3.8.1.6.1

CONCRETE PLACEMENT IN CATEGORY I STRUCTURES (JUNE 1973)

Regulatory Guide 1.55 was, withdrawn (June 1981) and has been

superseded by Regulatory Guide 1.136, Rev. 2, June 1981, (Materials, Construction and Testing of Concrete Containments (Articles CC-1000, -2000, and -4000 through -6000 of the "Code for Concrete Reactor Vessels and Containments")). However, since a significant portion of Beaver Valley Power Station - Unit 2 (BVPS-2) design and construction was completed prior to the withdrawal of this regulatory guide, concrete placement in Category I structures at BVPS-2 meets or exceeds the intent of Regulatory Guide 1.55 with the following alternatives:

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 33 of 91 1. Shop detail drawings for the reactor containment mat, shell, dome, and internals are checked by the designer. All other reinforcing shop details are

checked by engineers at the job site.

2. Constituents and proportions for design mixes to be used for mass concrete are selected to minimize the effects of shrinkage and heat of hydration. The slump used for mass concrete is 3 inches, the slump used in

normal concrete is 4 inches, and a slump of 5 inches is allowed in congested areas of heavily reinforced structures and electrical duct lines to permit placing

concrete.

3. Curing and protection of freshly deposited concrete conforms to ACI-301, Chapter 12, except that curing compounds are not used on surfaces to which additional concrete is to be bonded, and where wood and/or metal forms are used and remain in place for curing, the forms are kept wet as required to prevent their opening at the joints and drying out of the concrete.
4. The ACI and ASTM specifications are supplemented as necessary with mandatory requirements relating to types and strengths of concrete, minimum concrete densities, proportioning of ingredients, reinforcing steel requirements, joint treatments, and testing

agency requirements.

RG No. 1.56, Rev. 1

MAINTENANCE OF WATER PURITY IN BOILING WATER REACTORS (JULY 1978)

This regulatory guide is not applicable to Beaver Valley Power

Station - Unit 2.

RG No. 1.57, Rev. 0 UFSAR Reference Section 3.8.2

DESIGN LIMITS AND LOADING COMBINATIONS FOR METAL PRIMARY REACTOR CONTAINMENT SYSTEM COMPONENTS (JUNE 1973)

The design limits and loading combinations for the Beaver Valley Power Station - Unit 2 metal primary reactor containment system components meet the intent of Regulatory Guide 1.57 with the following alternatives which apply only to those portions not backed by concrete:

1. The applicable edition of the ASME Boiler and Pressure Vessel Code for affected ASME III components is

identified in the ASME Code Baseline Document.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 34 of 91 2. The primary stresses, based on elastic analysis, meet the following limits in lieu of the limits specified in paragraph C.1.b(2):

General membrane...1.5 S m Local membrane...the greater of 1.8S m or 1.5Sm Bending plus local membrane...the greater of 1.8S m or 1.5Sm. 3. The bellows assemblies were designed, fabricated, tested, and installed to the following criteria in lieu of the requirements of paragraphs C.2.a and b.

The fuel transfer tube expansion bellows shall be in accordance with Code Case 1330-3 (special ruling) Special Equipment RequirementsSection III. An N-2 form in accordance with Code Case 1177 shall be furnished by the bellows vendor. A duplicate bellows shall be required for pressure and fatigue testing by the Contractor in accordance with ASME III, Winter 1974 Addendum, paragraph NE-3365.2(e)(2). The 15-percent maximum convolution pitch in accordance with paragraph NE-3365.2(c) for unreinforced bellows may be exceeded provided the bellows remain within the elastic range.

RG No. 1.58

UFSAR Reference Sections 17.1, 17.2 QUALIFICATION OF NUCLEAR POWER PLANT INSPECTION, EXAMINATION, AND TESTING PERSONNEL Application of Regulatory Guide 1.58 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual. RG No. 1.59, Rev. 2 UFSAR Reference Section 2.4.2.2 DESIGN BASIS FLOODS FOR NUCLEAR POWER PLANTS (AUGUST 1977)

The determination of the design basis flood and the design of Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 35 of 91 RG No. 1.60, Rev. 1 UFSAR Reference Section 3.7B.1.1

DESIGN RESPONSE SPECTRA FOR SEISMIC DESIGN OF NUCLEAR POWER PLANTS (DECEMBER 1973)

The design response spectra for the seismic design of Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.60 with the following alternatives:

The horizontal design response spectra used for seismic

analyses are shown on Figures 3.7B-1 and 3.7B-2. The spectra shown for the safe shutdown earthquake (SSE) correspond to a maximum ground acceleration of 0.125g and the spectra shown for the operating basis earthquake (OBE) correspond to a maximum ground acceleration of 0.06g. The vertical design response spectra are taken to be two-thirds of the horizontal design response spectra.

These response spectra are based upon the response spectra used for Beaver Valley Power Station - Unit 1 (Figures

2.5-1 and 2.5-2, BVPS-1 UFSAR, October 27, 1972 Docket 5O-33A) and as revised in response to USAEC Regulatory Position 3 of May 25, 1973 (Question 3.15, BVPS-2 PSAR,

Amendment 7, July 9, 1973).

RG No. 1.61, Rev. 0 UFSAR Reference Section 3.7.1

DAMPING VALUES FOR SEISMIC DESIGN OF NUCLEAR POWER PLANTS (OCTOBER 1973)

The determination of the damping values used for the design of Seismic Category I structures, systems, and components at Beaver Valley Power Station - Unit 2 follows the guidance of this

regulatory guide with the following clarifications:

A value of 4 percent of critical is employed for the primary coolant loop system components for the safe shutdown earthquake (SSE). For discussion and justification of this value, refer to WCAP-7921-AR and

WCAP-8288.

Values of 1/2 percent and 1 percent of critical are used for the design basis of piping and piping components for the l/2-SSE and SSE, respectively, except as indicated below. In addition; a value of 2 percent of critical is used for reinforced concrete structures for the l/2-SSE. These values are less than the values given in Table 1 of the regulatory guide and are therefore more conservative.

The higher, frequency dependent damping values provided in ASME III Code Case N-411 may be used for stress

reconciliation of piping systems and for support optimization.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 36 of 91 Values of 4 percent and 8 percent of critical are used for cable tray and conduit systems for 1/2 SSE and SSE, respectively. Existing analysis and testing of strut-supported cable tray and conduit systems constructed similar to the support configurations used at BVPS-2 demonstrate that damping values increase with increasing system response. Levels of damping have been measured in excess of 20 percent of critical. Use of 4 percent and 8 percent of critical for cable tray and conduit systems at

BVPS-2 is therefore conservative. For discussion of the analysis and testing, refer to:

Elsabee, F., Anagnostis, S., and Djordjevic, W., 1983. Seismic Evaluation of Electrical Raceway Systems.

American Society of Mechanical Engineers, Paper 83-PVP-18.

Koss, P., 1979. Seismic Testing of Electrical Cable Support Systems. 48th Annual Convention of Structural

Engineers Association of California, Paper.

RG No. 1.62, Rev. 0 UFSAR Reference Section 7.2.2.2, 7.3.2.2.7, 7.2.2.2.3

MANUAL INITIATION OF PROTECTIVE ACTIONS (OCTOBER 1973)

The design of manual initiation of protective actions at Beaver

Valley Power Station - Unit 2 follows the guidance of this regulatory guide with the following clarification:

Manual initiation of the semi-automatic switchover to recirculation following a LOCA is in general compliance with IEEE 279-1971. However, once safety injection is

initiated manually, all automatic functions follow except for the opening of the containment sump isolation valves. These valves remain closed until receipt of a low level

signal from the refueling water storage tank level instrumentation.

RG No. 1.63, Rev. 2 UFSAR Reference Section 8.3 ELECTRIC PENETRATION ASSEMBLIES IN CONTAINMENT STRUCTURES FOR LIGHT-WATER COOLED NUCLEAR POWER PLANTS (JULY 1978)

Since Beaver Valley Power Station - Unit 2 (BVPS-2) was docketed before August 31, 1978, the methods described in Regulatory Guide 1.63 were not required to be used in the evaluation of the BVPS-2 Construction Permit application. However, the design and construction of the electric penetration assemblies on BVPS-2

follow the guidance of this regulatory guide, except that a ASME Code data report, (ANI) third party inspection and ASME Code stamping of the penetrations are not required as the penetrations are an extension of the containment liner boundary which is not code stamped as discussed in Section 3.8.1.2.1.2.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 37 of 91 RG No. 1.64, Rev. 2 UFSAR Reference Section 17.2

QUALITY ASSURANCE REQUIREMENTS FOR THE DESIGN OF NUCLEAR POWER PLANTS (JUNE 1976)

Quality Assurance Programs in effect at the time of systems design were followed in the design of BVPS-2 and meet the intent of Regulatory Guide 1.64 with the following clarifications and

alternative:

Duquesne Light Company has developed a Quality Assurance Program which conforms to 10 CFR 50, Appendix B. The DLC Quality Assurance Department verifies, through the audit process, that Stone & Webster Engineering Corporation (SWEC) and Westinghouse Electric Corporation are regularly reviewing the status and adequacy of their own QA programs.

The original BVPS-2 Quality Assurance Program was described in Appendix A of the PSAR. This QA Program was

initially implemented in accordance with Regulatory Guide 1.64, Rev. 0, dated October 1973. Subsequent Revisions 1 and 2 of the guide required upgrading of the design

process, with the most significant changes being independent design verification by individuals not having immediate supervisory responsibility for the individual performing the design. Accordingly, SWEC Engineering Assurance Division issued a change to Engineering Assurance Procedure (EAP) 3.1, "Verification of Nuclear

Plant Designs," which requires the following:

All initial issues of key design documents issued after February 8, 1977, shall be subject to independent objective review.

Subsequent revisions to all key design documents, other than calculations, which contain a change in design concept shall be subject to independent objective review.

This review shall be limited to that portion of design being changed. Revisions that do not involve a change in design concept shall be reviewed, approved, and issued in

accordance with applicable EAPs.

For calculations, the applicable portions of this EAP and independent objective review requirements contained in EAP 5.3 shall be applied to initial issues and all subsequent revisions.

Westinghouse has also updated their Quality Assurance Program to reflect changes in the regulatory process and,

in particular, Regulatory Guide 1.64. Changes are described in Westinghouse Topical Reports WCAP-8370, "Westinghouse Quality Assurance Program," and WCAP-7800, BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 38 of 91 "Nuclear Fuel Division Quality Assurance Program." WCAP-8370 revisions applicable to activities for specific time periods are Rev. 7A (June 1, 1975 - Sept. 30, 1977), Rev.

8A (Oct. 1, 1977 - Oct. 31, 1979), and Rev. 9A (Nov. 1, 1979 - present). WCAP-7800, Rev. 5, is applicable to the activities for the entire time period.

Westinghouse has followed the alternative to Regulatory Guide 1.64 that the designer's immediate supervisor may

perform design verification in exceptional cases when the supervisor is the only qualified engineer available. For such a case, justification is documented and approved in

advance by the supervisor's management.

Application of Regulatory Guide 1.64 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.65, Rev. 0 UFSAR Reference Section 5.3.1.7 MATERIALS AND INSPECTIONS FOR REACTOR VESSEL CLOSURE STUDS (OCTOBER 1973)

Materials and inspection for reactor vessel closure studs meet the intent of Regulatory Guide 1.65 with the following

alternatives:

1. The use of modified SA-540, Grade B24, as specified in the ASME Code (Code Case 1605) is permitted by Westinghouse but is not listed in this regulatory guide. This alternative is based on ASME Code Case 1605 which has been found acceptable to the NRC for application in the construction of components for water-cooled nuclear power plants within the limitation discussed in Regulatory Guide 1.85, which are followed by the Westinghouse practice and one use of Code Case 1605 for reactor vessel closure stud materials is not precluded by this regulatory guide.
2. A maximum ultimate tensile strength of 170,000 psi is not specified by Westinghouse, as recommended by this regulatory guide.

The ASME Code requirement for toughness for reactor vessel bolting has precluded the regulatory guide's additional recommendation for tensile strength limitation, since to obtain the required toughness

levels, the tensile levels are reduced.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 39 of 91 Westinghouse has specified both 45 ft-lb and 25 mils lateral expansion for control of fracture toughness determined by Charpy-V testing, required by the ASME Code,Section III, and 10 CFR 50, Appendix G, "Fracture Toughness Requirements," (Paragraph IV.A.4).

These toughness requirements ensure optimization of the stud bolt material tempering operation with the accompanying reduction of the tensile strength level when compared with previous ASME Code requirements.

The specification of both impact and maximum tensile strength, as stated in the regulatory guide, results in unnecessary hardship in procurement of material without any additional improvement in quality.

The closure stud bolting material is procured to a minimum yield strength of 130,000 psi and a minimum tensile strength of 145,000 psi. This strength level is compatible with the fracture toughness requirement of 10 CFR 50, Appendix G (Paragraph I.C) although higher strength level bolting materials are permitted

by the ASME Code.

The primary concern of paragraph C.1.b(l) concerning a maximum tensile strength is to minimize the susceptibility of the bolting material to stress corrosion cracking. Stress corrosion has not been observed in reactor vessel closure stud bolting manufactured from material of this strength level. Accelerated stress corrosion test data do exist for materials of 170,000 psi minimum yield strength exposed to marine water environment stressed to 75 percent of the yield strength (given in Reference 2 of the regulatory guide). These data are not considered applicable to Westinghouse reactor vessel closure stud bolting because of the specified yield strength differences and a less severe environment; this has been demonstrated by years of satisfactory service experience.

Additional protection against the possibility of incurring corrosion effects is ensured by:

a. Decrease in level of tensile strength compatible with the requirement of fracture toughness as described previously.
b. Design of the reactor vessel studs, nuts, and washers, allowing them to be completely removed during each refueling permitting visual and/or nondestructive inspection in parallel with

refueling operations to assess protection against corrosion, as part of the inservice inspection described in Section 5.2.4.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 40 of 91 c. Design of the reactor vessel studs, nuts, and washers, providing protection against corrosion by allowing them to be completely removed during each refueling and placed in storage racks on the containment operating deck, as required by Westinghouse refueling procedures. The stud holes in the reactor vessel flange are sealed with special plugs before removing the reactor closure. Thus, the bolting materials and stud holes are

never exposed to the borated refueling cavity water. 3. Some studs cannot be removed from the vessel for surface examination per paragraph C.4.a. For these studs, it has been determined that a volumetric

examination (refer to Section 5.3.3.7) is sufficient.

4. The supplemental surface examination specified in paragraph C.4.a is not required. Improved volumetric (UT) techniques (per Appendix VIII of ASME XI) have rendered surface examinations on the studs unnecessary.

RG No. 1.66, Rev. 0

NONDESTRUCTIVE EXAMINATION OF TUBULAR PRODUCTS (OCTOBER 1973)

This regulatory guide was withdrawn October 1977.

RG No. 1.67, Rev. 0 INSTALLATION OF OVERPRESSURE PROTECTION DEVICES (OCTOBER 1973)

The design of piping for safety valve and relief valve stations,

which have open discharge systems with limited discharge pipes and which have inlet piping that neither contains a water seal nor is subject to slug flow of water upon discharge of the

valves, follows the guidance of this regulatory guide.

RG No. 1.68, Rev. 2 UFSAR Reference Section 14.2

INITIAL TEST PROGRAMS FOR WATER-COOLED NUCLEAR POWER PLANTS (AUGUST 1978)

Initial test program testing for BVPS-2 will be conducted in accordance with the intent of Regulatory Guide 1.68 for those structures, systems, and components designated by the General Design Criteria as discussed in UFSAR Section 3.1 and consistent with the extent of compliance noted in UFSAR Section 14.2.12. Compliance with the various referenced regulatory guides is

discussed in UFSAR Section 1.8.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 41 of 91 Initial test program testing for structures, systems, and components that are unrelated to functions designated in the General Design Criteria will be accomplished consistent with their importance to plant reliability and/or safety. For example, the condenser hotwell level control system at BVPS-2 serves no safety-related function, is not power dependent, and is clearly not governed by the regulatory bases cited in Regulatory Guide 1.68 (10CFR50 Appendices A and B). Testing performed on this system will be reasonable and prudent as determined by DLC, but is not appropriate for discussion or commitment in the UFSAR. Other examples of tests which fall into this category include the Normal AC Power Distribution System Test, Containment Instrument Air System Design Verification Test, Computer Input and Printout Data Test, Seismic Instrumentation Test, Computer Operability Test, Extraction Steam System Test, and Rod Cluster Control Assembly Bank and Boron Worth Measurement Test. Also, the plant performance following MSIV closure at power test will now be performed at 30 percent power rather than at 100 percent power. Performance of this test at 100 percent power is unacceptable because of the potential for damage to the plant with an MSIV

closure at this power level.

A graded approach to testing will be implemented to provide adequate assurance, considering the importance to safety of the item, that the item will perform satisfactorily while, at the same time, assuring the testing is accomplished in a cost

effective manner.

RG No. 1.68.1, Rev. 1

PREOPERATIONAL AND INITIAL STARTUP TESTING OF FEEDWATER AND CONDENSATE SYSTEMS FOR BOILING WATER REACTOR POWER PLANTS (JANUARY 1977)

This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

RG No. 1.68.2, Rev. 1 UFSAR Reference Section 14.2 INITIAL STARTUP TEST PROGRAM TO DEMONSTRATE REMOTE SHUTDOWN CAPABILITY FOR WATER-COOLED NUCLEAR POWER PLANTS (JULY 1978)

The initial start-up test program to demonstrate remote shutdown capability for BVPS-2 follows the guidance of Regulatory Guide

1.68.2 with the following clarification:

Paragraph C.3 The test does not require the turbine generator to be in operation since it would produce an unnecessary perturbation on the electrical distribution system. Steam can be bypassed to the main condenser with the reactor at a moderate power level.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 42 of 91 During the test, the only action necessary with regard to the turbine is the reactor trip which is initiated at the switchgear and results in a turbine trip signal. Under actual conditions, the trip would occur prior to evacuating the control room and no further actions regarding the turbine are necessary. Therefore, the

purposes specified in the Regulatory Guide (demonstration of design, procedures, procedural familiarity and sufficient numbers of personnel) are in no way dependent

on actual operation of the turbine.

RG No. 1.68.3, Rev. 0 UFSAR Reference Section 14.2

PREOPERATIONAL TESTING OF INSTRUMENT AND CONTROL AIR SYSTEMS (APRIL 1982)

Preoperational testing of instrument and control air systems for BVPS-2 will meet the intent of Regulatory Guide 1.68.3 with the following alternatives and clarifications:

Paragraph C.2 As an alternative to verifying the system relief/safety valve settings, credit will be taken for the purchase of specified code valves with documented set-points. Test results were provided with the valves, as specified in the purchase documents.

Paragraph C.3 A full regeneration cycle will be tested only on the station instrument air dryer since it is the only regenerative/desiccant-type dryer installed at BVPS-2. The refrigerant-type dryer installed in containment will be tested in accordance with the intended design attributes. The BVPS-2 position on testing the relief/safety valves is as stated above for Paragraph C.2.

Paragraph C.6 Both station and containment air compressors are oil-free by design. The station air compressors are the dry screw-type, and the containment air compressors are the water ring-type, Therefore, oil content in the product air would be negligible.

Regarding particulate matter in the product air, credit will be taken for vendor documented qualification of filter efficiency.

Paragraph C.8 As an alternative to testing the backup air supplies (accumulators), credit will be taken for the fail-as-is and fail-safe design that precludes the necessity of an excess stored air supply to effect safe shutdown.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 43 of 91 Paragraph C.9 Normal valve lineups are a prerequisite to the activation of any system or equipment or the performance of tests. The valve lineup completion/signoff sheets are verified by on-shift supervision, and system interface valves are

administratively controlled. This precludes the possibility of plant equipment designated by design to be supplied by the instrument and control air system being supplied by another compressed air system having less restrictive air quality requirements.

Paragraph C.10 BVPS-2 has no installed equipment being supplied by the instrument and control air system and having large air requirements. The largest air requirements is less than 1 percent of the capacity of a single compressor.

RG No. 1.69, Rev. 0 UFSAR Reference Section 12.3.2 CONCRETE RADIATION SHIELDS FOR NUCLEAR POWER PLANTS (DECEMBER 1973)

Regulatory Guide 1.69 invokes the requirements and recommended

practices contained in ANSI N101.6-1972, "Concrete Radiation Shields." The design and construction procedures for Beaver Valley Power Station - Unit 2 (BVPS-2) will meet or exceed the guidance of Regulatory Guide 1.69, with the following alternatives:

1. ANSI N101.6-1972 requires that shop drawings be prepared showing details and dimensions of formwork,

and then approved by the responsible engineer before fabrication of the formwork may begin. On BVPS-2, it is the responsibility of field personnel to visually check all formwork. Detail drawings are made only for

special applications.

2. Finishing and patching of concrete surfaces after removal of forms will conform to Chapter 9 of ACI-301 rather than Section 8.7.5 of ANSI N101.6. It is not necessary to complete this work within 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> after

the placing of concrete.

3. Section 8.2.4 of ANSI N101.6 lists the maximum vertical drop of concrete as 5 feet. The maximum vertical drop of concrete during placement operations is 6 feet. Experience has indicated that suitable

equipment and provisions are given to prevent segregation of the concrete.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 44 of 91 RG No. 1.70, Rev. 3 UFSAR Reference Section 1.1

STANDARD FORMAT AND CONTENT OF SAFETY ANALYSIS REPORTS FOR NUCLEAR POWER PLANTS (NOVEMBER 1978)

During construction of BVPS-2, Section 50.34 of 10 CFR Part 50 required that each application for a license to operate a nuclear reactor facility include a final safety analysis report (FSAR). Section 50.34 specified in general terms the information to be supplied in these safety analysis reports. The guidance of this regulatory guide was followed in

identifying information to be included in the FSAR, on which the NRC could base its findings requisite to the issuance of the license.

RG No. 1.71, Rev. 0 UFSAR Reference Sections 5.2.3, 5.3.1.4, 10.3.6.2 WELDER QUALIFICATION FOR AREAS OF LIMITED ACCESSIBILITY (DECEMBER 1973)

Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.71 with the following clarifications and alternatives:

Neither the nuclear steam supply system nor the balance of plant supplier requires qualification of welders for areas of limited accessibility for shop fabrication. Current

shop practices have produced high quality welds. In addition, the performance of required nondestructive evaluations provides further assurance of acceptable weld

quality.

Limited accessibility qualification or requalification,

which is in excess of ASME Code,Section III and IX requirements, is believed to be an unduly restrictive requirement for component fabrication, where the welder's physical position relative to the welds is controlled and does not present any significant problems. In addition, shop welds of limited accessibility are repetitive due to

multiple production of similar components, and such welding is closely supervised.

For field fabrication and erection of ASME III piping, applicable welds are volumetrically inspected to the requirements and standards of ASME III, Class 1.

Volumetric nondestructive examination of the production welds made in areas of limited accessibility assures their acceptable quality.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 45 of 91 RG No. 1.72, Rev. 2 SPRAY POND PIPING MADE FROM FIBERGLASS-REINFORCED THERMOSETTING RESIN (NOVEMBER 1978)

This guide is not applicable to Beaver Valley Power Station -

Unit 2 because fiberglass pipe is not used for Quality Assurance Category I applications.

RG No. 1.73, Rev. 0 UFSAR Reference Section 3.11.2 QUALIFICATION TESTS OF ELECTRIC VALVE OPERATORS INSTALLED INSIDE THE CONTAINMENT OF NUCLEAR POWER PLANTS (JANUARY 1974)

Qualification tests of electric valve operators installed inside the containment at Beaver Valley Power Station - Unit 2 follow

the guidance of this regulatory guide.

RG No. 1.74 UFSAR Reference Section 17.2

QUALITY ASSURANCE TERMS AND DEFINITIONS

Application of Regulatory Guide 1.74 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.75, Rev. 2 UFSAR Reference Sections 7.1.2, 7.5.2, 8.3.1.4, 8.3.2.2 PHYSICAL INDEPENDENCE OF ELECTRIC SYSTEMS (SEPTEMBER 1978)

Beaver Valley Power Station - Unit 2 (BVPS-2) follows the guidance of Regulatory Guide 1.75 for physical independence of electrical systems with the following clarifications:

1. General For the purposes of electrical separation, equivalent protection is provided through enclosure by rigid aluminum conduit, rigid steel conduit, electro-metallic tubing (EMT), flexible aluminum conduit, and flexible steel conduit. Enclosures provided to meet the requirements of BTP CMEB 9.5-1 are considered

equivalent to enclosures provided for electrical separation and will have 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or longer fire rating.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 46 of 91 Metal clad cable, type MC, utilized in low energy, 120 V ac and 125 V dc nominal circuits and in low density applications is considered adequately

protected. As such, the minimum separation between these cables and other cables, or raceway (where required) is 1 in. These cables are further described

as follows:

a. Type MC cable is a factory assembly of conductors, each individually insulated, enclosed in a metallic sheath of interlocking type, or a smooth or corrugated tube.
b. Largest conductor size is No. 10 AWG.
c. No more than six conductors.
d. No more than three No. 10 AWG conductors with remaining conductors of smaller size.
e. Aluminum sheath cable (a Type MC cable in which the aluminum is continuously welded) and/or interlocked armor cable may have an overall jacket of neoprene or hypalon.

Type SO or SJO cords for lighting drops to fixtures are size 12 AWG or smaller and supply low energy, 120 V ac or

125 V dc, in low density applications. Adequate protection is provided by 1 inch or greater distance to Class lE raceways.

A raised floor panel can be used as a barrier. Panels are 1 in. thick particle board with 22 gauge steel top and

bottom sheets, and are fire rated Class A. These panels are considered a barrier when used in a configuration as shown in IEEE Standard 384-1974, Figures 2, 3, or 4.

The Cable Spreading Areas (CSA - Main Control Room, Cable Spreading room, and Computer Room) are protected areas and are not exposed to potential hazards such as high pressure piping, missiles, flammable material, flooding, or wiring that is not flame retardant. They do not contain high energy equipment such as switchgear, transformers, rotating equipment, or potential sources of missiles or pipe whip and are not used for storing flammable materials.

The General Plant Areas (GPA) have been analyzed for potential hazards and as such are categorized as areas where the damage potential is limited to failures of faults internal to the electrical equipment or circuits.

2. Paragraph C.6 Analyses of potential hazards in Section 5.1.1.1.1 of

IEEE Standard 384-1974 are accomplished as follows:

a. The high pressure piping and missile analyses are described in Sections 3.6 and 3.5, respectively.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 47 of 91

b. The fire protection analyses are outlined in Section 9.5.1 and the Fire Protection Evaluation Report (see Table 1.7-3).
c. Flame retardant characteristics of cable systems are described in Section 8.3.3.
d. The building design for external and internal flooding is described in Section 3.4 and 3.8, respectively. The environmental effects on safety-related components due to internal flooding

are described in Sections 3.6B, 3.4, and 3.11.

An extensive test program has been conducted at Wyle Labs in Huntsville, Alabama in accordance with Section 5.1.1.2 of IEEE Standard 384-1974, "IEEE Trial-Use Criteria for Separation of Class lE

Equipment and Circuits", to establish minimum separation distances for BVPS-2. A test report, "Test Report on Electrical Separation Verification Testing for Duquesne Light Company's Beaver Valley Power Station - Unit 2", including the Wyle test report has been submitted under separate submittal.

(See Table 1.7-3). The conclusions of this report are as follows:

a. In the General Plant Areas, the minimum horizontal spatial separation is reduced from 3 feet to 1

foot. b. Ventilated tray covers and cable bus enclosures are equivalent to solid tray covers.

c. Protective Wraps.

i) Lengths of cable enclosed in a protective wrap of woven silicon dioxide with a minimum of one inch free space protects adjacent

cables from electrically induced problems in the cables within the protective wrap.

ii) Length of cable enclosed in a protective wrap of woven silicon dioxide with a minimum of one inch free air space are protected from electrically induced problems in adjacent cables.

iii) Lengths of cable enclosed in a protective wrap of woven silicon dioxide are protected from electrically induced problems in adjacent cables when the adjacent cables are also enclosed in a protective wrap of woven silicon dioxide.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 48 of 91 iv) The protective wrap of woven silicon dioxide (Trade Name: SIL-TEMP) is normally 54 mils thick and is wrapped longitudinally around cable(s) with a 100 percent overlap (i.e. two thicknesses). The protective wrap of woven silicon dioxide may also be a tape,

nominally 125 mils thick, applied helically with a 50 percent lap (half-lapped). In either case an overall 50 percent lap (half-

lapped) of 3M No. 69 glass tape is required.

d. In plant areas (both GPA and CSA) where plant arrangement precludes minimum spatial separation between redundant Class 1E circuits or between Class lE and non-Class lE circuits separation is

achieved as follows:

i) Tray to Tray (Section 8.3.1.4.2 Items a.1 through a.20)

Vertical - One inch minimum free air space and a single tray cover Horizontal - One inch minimum free air space and a

tray cover top and

bottom on one tray.

ii) Tray to Conduit (Section 8.3.1.4.2 Items b.1 through b.18)

Vertical - One inch minimum free air space

Horizontal - One inch minimum free air space iii) Cable in Air to Cable in Air (Section 8.3.1.4.2 Items d.1 through d.12)

Vertical - One inch minimum free air space and enclosure of one circuit (group) in

conduit or a protective wrap.

or

Zero inch minimum free air space and enclosure of both circuits (groups) in

protective wraps.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 49 of 91 Horizontal - One inch minimum free air space and enclosure of one

circuit (group) in conduit or a protective wrap.

or Zero inch minimum free air space and

enclosure of both

circuits (groups) in protective wraps.

iv) Cable in Air to Tray (Section 8.3.1.4.2 Items e.1 through e.12)

Vertical - One inch minimum free air space and a

tray cover or Zero inch minimum free air space with both a tray cover and enclosure of the cable in a protective wrap.

Horizontal - One inch minimum free air space and enclosure of one circuit (group) in conduit or a

protective wrap.

or Zero inch minimum free air space and enclosure of both circuits (groups) in protective wraps.

v) Cable in Air to Conduit (Section 8.3.1.4.2 Items f.1 through f.6)

Vertical - One inch minimum free air space

Horizontal - One inch minimum free air space

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 50 of 91 e. Inside Control Switchboards and Instrument Cabinets separation between redundant Class lE or Class lE and non-Class lE wire (bundles) is

provided by one of the following:

i) A barrier.

ii) A minimum of one inch free air space.

iii) Enclosing each wire (bundles) in a protective wrap of woven silicon dioxide

(no overall glass type).

For justification refer to the test report.

3. Paragraph C.7 (Section 4.6 of IEEE Standard 384-1974 Minimum separation between Class lE and non-Class lE circuits is as specified in Sections 5.1.3, 5.1.4, or 5.6.2 of IEEE Standard 384-1974, except as discussed in the position under Paragraph C.6.
4. Paragraph C.9 Cable trays for control and instrumentation cables may be filled above the side rails where the overfill has been limited to a maximum of 1 1/2 in. above the top of the side rail and where solid hat covers with a 2 in. raised flat center section are used to enclose the top of the cable tray.

Cable splices in raceways are prohibited with the exception of the cables which are spliced in trays at penetration types IX and IX-A. The penetration manufacturers standard practice for these penetration types directs that the connection between the penetration conductor and field run cable be made by splicing. Due to the limited space at the penetrations and the size of these large power cables, installation of the termination boxes to enclose the splices is impractical. The cable trays will be enclosed by top and bottom tray covers per Section

8.3.1.4.

The cable splices are made according to the cable manufacturer's procedures. The resulting splice is as good as the cable and in no way degrades the performance of the cable.

5. Paragraph C.10 Class lE cable and raceways shall be marked at intervals not exceeding 15 feet and shall be plainly visible.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 51 of 91 6. Paragraph C.12

a. Power cables that supply power to the control, computer, or cable spreading room panels, limited to 120 V ac or 125 V dc, are enclosed in rigid metallic conduit or flexible conduit at the

entrance to panels.

b. Power cables serving facilities in or traversing the control, computer, or cable spreading rooms, limited to 480 V ac, 120 V ac, or 125 V dc, are enclosed in rigid metallic conduit or in flexible

conduit at the entrance to panels or equipment.

c. As noted above in items a and b, all power cables are totally enclosed in rigid metallic conduit or in flexible conduit or in enclosed raceways and are not exposed to free air. Any potential

electrical fires caused by fault current in the power cables are not considered to be a credible hazard, since fires resulting from fault current

would be contained in the conduit. In addition, these rooms are protected areas and are not subject to external energetic events such as

floods, high energy pipe breaks, and missiles.

d. The loss of the above cables, or the control, computer, or cable spreading rooms due to the design basis event fire, will not compromise the capability to achieve cold shutdown as outlined in Section 9.5.1 and in the Fire Protection Evaluation Report.
e. The Beaver Valley Power Station - Unit 2 design utilizes a single cable spreading room.
7. Paragraph C.16 (Section 5.6.2 of IEEE-Standard 384-1974) The minimum 6 in. separation (or a barrier) applies to spacing between exposed terminals, contacts, and equipment of redundant Class lE circuits or Class lE and non-Class lE circuits for testing and maintenance purposes. Separation between redundant Class lE or Class lE and non-Class lE wire (bundles) is as

discussed in the position in Paragraph C.6.

Separation requirements for Westinghouse NSSS

equipment are specifically addressed in Section 7.1.2.2.

BVPS-2 UFSAR Rev. 14 TABLE 1.8-1 (Cont) 52 of 91 8. Paragraph C.1 (IEEE Standard 384-1974 - Section 3, ISOLATION DEVICES)

The use of two independent Class lE overcurrent devices (breakers or fuses) in series, provides electrical separation between Class lE and non-Class

lE circuits under the following conditions:

1. Coordination is provided between each of the two series devices and the main Class 1E feeder breaker.
2. These devices are included in a surveillance program during normal plant operation.

RG No. 1.76, Rev. 0 UFSAR Reference Section 3.3.2.1

DESIGN BASIS TORNADO FOR NUCLEAR POWER PLANTS (APRIL 1974)

All applicable Beaver Valley Power Station - Unit 2 structures, systems, or components important to safety will be designed to withstand, or will be enclosed in structures which will withstand, the six descriptive parameters given in Table I of Regulatory Guide 1.76 for the Region I location.

RG No. 1.77, Rev. 0 UFSAR Reference Section 15.4.8 ASSUMPTIONS USED FOR EVALUATING A CONTROL ROD EJECTION ACCIDENT FOR PRESSURIZED WATER REACTORS (MAY 1974)

The assumptions used for evaluating the potential radiological consequences of a control rod ejection accident at Beaver Valley Power Station - Unit 2 are based on Regulatory Guide 1.183.

Refer to the position on Regulatory Guide 1.183, later in this table. This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

BVPS-2 UFSAR Rev. 18 TABLE 1.8-1 (Cont) 53 of 91 RG No. 1.78, Rev. 0 UFSAR Reference Sections 2.2.3, 6.4, 9.4

ASSUMPTIONS FOR EVALUATING THE HABITABILITY OF A NUCLEAR POWER PLANT CONTROL ROOM DURING A POSTULATED HAZARDOUS CHEMICAL RELEASE (JUNE 1974)

Assumptions for evaluating the habitability of the Beaver Valley Power Station - Unit 2 (BVPS-2) portion of the main control room during a postulated hazardous chemical release meet the intent of this regulatory guide with the following clarifications and

alternative:

1. Of the various evaluation methods available, BVPS-2 evaluation has been performed by the methodology outlined in NUREG-0570, published in June 1979, which is similar to that presented in Appendix B of Regulatory Guide 1.78 but at a much greater level of

detail and refinement.

2. Protection of the control room during a chlorine release is not required due to removal of on-site

chlorine storage.

Paragraph C.9

The control room emergency ventilation system is used to pressurize the control room envelope. Periodic control room envelope unfiltered air inleakage tests are performed to confirm that the control room envelope is operable.

RG No. 1.79, Rev. 1 UFSAR Reference Sections 6.3, 14.2

PREOPERATIONAL TESTING OF EMERGENCY CORE COOLING SYSTEMS FOR PRESSURIZED WATER REACTORS (SEPTEMBER 1975)

The program for preoperational testing of the Emergency Core Cooling Systems is performed by following the guidance of this

regulatory guide with the following clarification:

Paragraph C.1.c(2) recommends a test of the accumulator isolation valves with full accumulator pressure and zero RCS pressure. R.G. 1.79 clearly states the purpose for the subject test to be "to ensure that inadvertent valve closures do not prevent operation of the core flooding system if required." Administrative controls and technical specification requirements provide assurance that accumulator isolation valves will never be required to change position in performance of a safety function.

These controls include power removal upon opening the valve. Alarms which reflash at regular intervals are

provided to alert the operator when a valve is not fully

open. Technical specifications require periodic verification of valve position, periodic verification of power removal, and plant shutdown if any valve is not

opened.

BVPS-2 UFSAR Rev. 14 TABLE 1.8-1 (Cont) 54 of 91 Therefore, the "inadvertent valve closures" which are the source of concern for this test are eliminated unless multiple failures are postulated. These failures would

include combinations of the following:

1. Failure to open the valve per technical and operating procedures.
2. Failure of the power removal circuit or failure to remove valve power once the valve is open.
3. Failure of one or more operators to heed the alarm indicating a valve which is not fully open or failure of the alarm.
4. Failure of one or more operators to heed reflash of the alarm.
5. Incorrect verification of valve position on a periodic basis in violation of technical specifications.

Since combinations of these failures would be required to allow an inadvertent accumulator isolation valve closure to occur and not be noticed and corrected, the situation

would be highly unlikely. Protecting or testing for multiple failures is over and above philosophy and is not considered necessary. It should be noted that R.G. 1.79

was issued in 1975. This occurred prior to the initiation of the currently used "power removal techniques" found in the industry today.

RG No. 1.80, Rev. 0 UFSAR Reference Section 14.2

PREOPERATIONAL TESTING OF INSTRUMENT AIR SYSTEMS (JUNE 1974)

This regulatory guide has been withdrawn (April 1982). Regulatory Guide 1.68.3 ("Preoperational Testing of Instrument

and Control Air Systems," Rev. 0, April 1982) now applies.

RG No. 1.81, Rev. 1 UFSAR Reference Sections 8.1, 8.3.1, 8.3.2

SHARED EMERGENCY AND SHUTDOWN ELECTRIC SYSTEMS FOR MULTI-UNIT NUCLEAR POWER PLANTS (JANUARY 1975)

The design of the BVPS-2 onsite emergency and shutdown electric systems follows the guidance of this regulatory guide.

The safe shutdown basis for BVPS-2 is described in the conformance evaluation for Regulatory Guide 1.139 (UFSAR Section 1.8). None of the equipment required for compliance with this safe shutdown commitment for BVPS-2 is powered from electrical systems shared with BVPS-1.

BVPS-2 UFSAR Rev. 17 TABLE 1.8-1 (Cont) 55 of 91 RG No. 1.82, Rev. 0 UFSAR Reference Section 6.2.2.2

SUMPS FOR EMERGENCY CORE COOLING AND CONTAINMENT SPRAY SYSTEMS (JUNE 1974)

Design of the sumps for emergency core cooling and containment spray systems at Beaver Valley Power Station Unit 2 (BVPS-2) meets the intent of this regulatory guide with the following

alternatives:

Paragraphs C.1 and C.2 require two separate sumps in containment to supply the redundant halves of the emergency core cooling system (ECCS) and containment spray systems (CSS). Beaver Valley Power Station - Unit 2

provides a single sump with physical separation by

perforated plate between the two halves which supply the redundant ECCS and CSS.

Paragraphs C.3 and C.6 require an outer trash rack. The BVPS-2 strainer is constructed of perforated stainless steel plate. The strength of the plate plus the larger size and complex geometry of the strainer eliminate the need for a separate trash rack. Although the new design does include a trash rack, it simply protects the strainer elements as defense in depth, and is not credited with meeting RG 1.82.

Paragraph C.4 requires that the containment floor slope down away from the sump to minimize debris entering the sump. A portion of BVPS-2 containment floor slopes down

toward the sump but a raised lip is provided which directs normal floor drainage to the segmented section of the containment sump and will prevent small debris from being

swept directly into the sump due to the slope.

Paragraph C.7 requires a reactor coolant velocity through sump screens to be approximately 0.2 ft/sec which will

allow fine debris to settle out. The BVPS-2 sump screen velocity is approximately 0.2 ft/sec and is considered

satisfactory for the intent of Regulatory Guide 1.82.

RG No. 1.83, Rev. 1 UFSAR Reference Section 5.4.2.2.1

INSERVICE INSPECTION OF PRESSURIZED WATER REACTOR STEAM GENERATOR TUBES (JULY 1975)

The program for inservice inspection of steam generator tubes at Beaver Valley Power Station - Unit 2 meets the intent of this

regulatory guide with the following alternative:

Inservice inspection of steam generator tubes is performed

in accordance with a steam generator program required by

Technical Specifications. Required program provisions, such as for condition monitoring assessments and tube inspections, are specifically described in the Technical

Specifications.

BVPS-2 UFSAR Rev. 18 TABLE 1.8-1 (Cont) 56 of 91 RG No. 1.84, Rev. 24 UFSAR Reference Section 5.2.1.2

DESIGN AND FABRICATION CODE CASE ACCEPTABILITY ASME SECTION III DIVISION 1 (JUNE 1986)

Utilization of code cases for design and fabrication for BVPS-2

follows the guidance of this regulatory guide.

All applicable ASME III Code Cases utilized for BVPS-2 are

identified in the ASME Code Baseline Document.

RG No. 1.85, Rev. 24 UFSAR Reference Sections 4.5.1, 4.5.2, 5.2.1.2, 5.4.2.1

MATERIALS CODE CASE ACCEPTABILITY ASME SECTION III DIVISION 1 (JUNE 1986)

Utilization of materials code cases for BVPS-2 follows the

guidance of this regulatory guide.

All applicable ASME-III Code Cases utilized for BVPS-2 are

identified in the ASME Code Baseline Document.

RG No. 1.86, Rev. 0 UFSAR Reference Section 5.8 (ER-OLS)

TERMINATION OF OPERATING LICENSES FOR NUCLEAR REACTORS (JUNE 1974)

The guidance of this Regulatory Guide will be followed when termination of the Beaver Valley Power Station - Unit 2

operating license is desired.

RG No. 1.87, Rev. 1

GUIDANCE FOR CONSTRUCTION OF CLASS 1 COMPONENTS IN ELEVATED TEMPERATURE REACTORS (SUPPLEMENT TO ASME SECTION III CODE CASES 1592, 1593, 1594, 1595, AND 1596) (JUNE 1975)

This regulatory guide is not applicable to Beaver Valley Power

Station - Unit 2.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 57 of 91 RG No. 1.88 UFSAR Reference Sections 9.5.1, 17.2

COLLECTION, STORAGE, AND MAINTENANCE OF NUCLEAR POWER PLANT QUALITY ASSURANCE RECORDS

Application of Regulatory Guide 1.88 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.89, Rev. 1 UFSAR Reference Section 3.11 ENVIRONMENTAL QUALIFICATION OF CERTAIN ELECTRIC EQUIPMENT IMPORTANT TO SAFETY FOR NUCLEAR POWER PLANTS (JUNE 1984)

BVPS-2 electric equipment important to safety is qualified to meet or exceed the intent of IEEE Std. 323-1971 and Category II of NUREG 0588, Rev. 1. For BVPS-2, this includes both safety-related and certain post-accident equipment. When determined possible, the qualification of this equipment will be upgraded to meet the standards set forth in Category I of NUREG-0588, Rev. 1. In accordance with 10CFR50.49(k), BVPS-2 is not required to requalify electric equipment important to safety (except replacement equipment) in accordance with Regulatory Guide 1.89, Rev. 1. Replacement electric equipment important to

safety will be qualified in accordance with the guidance provided in Paragraph C.6 of this regulatory guide. Qualification records for replacement electric equipment will

meet the intent of Appendix E of this regulatory guide by meeting the applicable requirements of 10 CFR 50.49.

RG No. 1.90, Rev. 1 IN-SERVICE INSPECTION OF PRESTRESSED CONCRETE CONTAINMENT STRUCTURES WITH GROUTED TENDONS (AUGUST 1977)

This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

RG No. 1.91, Rev. 1 UFSAR Reference Section 2.2.3.1.1 EVALUATIONS OF EXPLOSIONS POSTULATED TO OCCUR ON TRANSPORTATION ROUTES NEAR NUCLEAR POWER PLANTS (FEBRUARY 1978)

Evaluation of the consequences of explosions postulated to occur on transportation routes near Beaver Valley Power Station -

Unit 2 follows the guidance of Regulatory Guide 1.91.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 58 of 91 RG No. 1.92, Rev. 1 UFSAR Reference 3.7B.2, 3.7N.2

COMBINING MODAL RESPONSES AND SPATIAL COMPONENTS IN SEISMIC RESPONSE ANALYSIS (FEBRUARY 1976)

The combining of modal responses in the seismic response analysis for Beaver Valley Power Station - Unit 2 follow the guidance of Regulatory Guide 1.92 with the following

clarifications:

If there are no closely spaced modes, the responses are combined by using the square root sum of the squares (SRSS) method. When there are closely spaced modes, the responses are combined by using either the grouping method, as discussed in Paragraph 1.2.1 of the regulatory guide or by using the double sum method, as discussed in Paragraph 1.2.3 of the regulatory guide or by using a method similar to the ten percent method as discussed in Paragraph 1.2.2 but with the inclusion of coupling factors as in the double sum method.

Responses from the orthogonal earthquake inputs are obtained by either the absolute addition of the worst horizontal plus vertical responses or the SRSS combination of the two horizontal direction responses and then the absolute addition of the vertical response.

RG No. 1.93, Rev. 0 UFSAR Reference Sections 8.1, 8.3 AVAILABILITY OF ELECTRIC POWER SOURCES (DECEMBER 1974)

BVPS-2 will follow the guidance of this regulatory guide for operation of the plant in the event of loss of electric power

sources.

RG No. 1.94, Rev. 1 UFSAR Reference Sections 3.8.1, 3.8.3, 3.8.4, 17.1, 17.2

QUALITY ASSURANCE REQUIREMENTS FOR INSTALLATION, INSPECTION, AND TESTING OF STRUCTURAL CONCRETE AND STRUCTURAL STEEL DURING THE CONSTRUCTION PHASE OF NUCLEAR POWER PLANTS (APRIL 1976)

Quality assurance requirements for installation, inspection, and testing of structural concrete and structural steel during the construction phase at BVPS-2 meet the intent of this Regulatory Guide with the following clarifications and alternatives:

The BVPS-2 Quality Assurance Program for structural concrete and steel follows WASH 1283, dated May 24, 1984, and WASH 1309, dated May 10, 1974.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 59 of 91 The provisions of Articles CC4334 and CC4330 of the "Code for Concrete Reactor Vessels and Containments" (ASME Boiler and Pressure Vessel Code,Section III, Division 2, 1975 Edition) were not applied to BVPS-2 since the BVPS-2 reactor containment purchase order had been placed prior to the 1975 edition of the Division 2 ASME Code.

Alternatives to ANSI N45.2.5-1974 are taken with respect to frequency of calibration of impact wrenches and bolt projection criteria. Impact and torque wrenches shall be checked at least once daily per shift, and at least one full thread of all bolts shall project beyond the nut of

all tightened connections. These criteria comply with the recommendations of the Research Council on Riveted and Bolted Structural Joints.

Application of Regulatory Guide 1.94 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual.

RG No. 1.95, Rev. 1 UFSAR Reference Sections 2.2.1, 2.2.3.1.2, 6.4.4.2, 9.4.1

PROTECTION OF NUCLEAR POWER PLANT CONTROL ROOM OPERATORS AGAINST AN ACCIDENTAL CHLORINE RELEASE (JANUARY 1977)

Protection of the Beaver Valley Power Station - Unit 2 control room operators against an accidental chlorine release is not required because there is no on-site chlorine storage.

RG No. 1.96, Rev. 1 DESIGN OF MAIN STEAM ISOLATION VALVE LEAKAGE CONTROL SYSTEMS FOR BOILING WATER REACTOR NUCLEAR POWER PLANTS (JUNE 1976)

This regulatory guide is not applicable to Beaver Valley Power Station - Unit 2.

RG No. 1.97, Rev. 2 UFSAR Reference Sections 6.2, 7.4, 7.5, 9.3.2, 11.5, 12.3 INSTRUMENTATION FOR LIGHT-WATER-COOLED NUCLEAR POWER PLANTS TO ASSESS PLANT AND ENVIRONS CONDITIONS DURING AND FOLLOWING AN ACCIDENT (DECEMBER 1980)

The instrumentation provided to monitor Beaver Valley Power Station - Unit 2 during and after postulated accident conditions meets the intent of this regulatory guide with the following clarifications and alternatives:

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 60 of 91 A plant-specific analysis has been conducted to identify the appropriate variables and to establish the appropriate design basis and qualification criteria in order to provide sufficient information to allow the operating staff to ascertain plant conditions during and following an accident. As a result of this analysis, the variables to be monitored have been selected and they have been included in one or more of five classifications (Types A through E) according to their usage and need, and they

have been assigned design and qualification Categories 1, 2, or 3. The selection of some of these plant-specific variables and their classifications and categories are

different than those of Regulatory Guide 1.97.

Type A variables are not all designated Category 1. Type A variables are designated Category 2 if they are employed in the emergency operating procedures for the sole purpose of providing preferred backup information.

Category 1 instrumentation information is not continuously displayed but it is immediately accessible to the operator. In addition, a historical record of at least one instrumentation channel for each process variable is maintained.

Since Category 3 instrumentation is not part of a safety-related system, it is not qualified so that it will provide information when exposed to a post-accident adverse environment. Category 3 instrumentation is subject to servicing, testing, and calibration programs that are specified to maintain their capability. However, these programs are not in accordance with

Regulatory Guide 1.118 which applies to safety-related systems.

RG No. 1.98, Rev. 0 ASSUMPTIONS USED FOR EVALUATING THE POTENTIAL RADIOLOGICAL CONSEQUENCES OF A RADIOACTIVE OFFGAS SYSTEM FAILURE IN A BOILING WATER REACTOR (MARCH 1976)

This regulatory guide is not applicable to Beaver Valley Power

Station - Unit 2.

RG No. 1.99, Rev. 1 UFSAR Reference Section 5.3.2.1

EFFECTS OF RESIDUAL ELEMENTS ON PREDICTED RADIATION DAMAGE TO REACTOR VESSEL MATERIALS (APRIL 1977)

The Beaver Valley Power Station - Unit 2 reactor vessel material meets the end-of-life reference criterion of Regulatory Guide 1.99. However, the procedures set forth in this regulatory guide are believed to be overconservative at the higher fluences, and the restriction of the end-of-life transition temperature to 200F is believed to be technically unnecessary.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 61 of 91 RG No. 1.100, Rev. 1 UFSAR Reference Section 3.10

SEISMIC QUALIFICATION OF ELECTRIC EQUIPMENT FOR NUCLEAR POWER PLANTS (AUGUST 1977)

Since the Beaver Valley Power Station - Unit 2 construction permit application was docketed before October 27, 1972, Class I electrical equipment are seismically qualified in accordance with IEEE Standard 344-1971. In addition, WCAP-8373, "Qualification of Westinghouse Seismic Testing Procedure for Electrical Equipment Tested Prior to May 1974," August 1974, and

letter NS-CE-692, dated July 10, 1975 from Westinghouse to D. B. Vassello (USNRC) provide justification and cover the test program that demonstrates that the tests meet the intent of IEEE

Standard 344-1975 and Regulatory Guide 1.100.

RG No. 1.101, Rev. 2 UFSAR Reference Section 13.3

EMERGENCY PLANNING AND PREPAREDNESS FOR NUCLEAR POWER REACTORS (OCTOBER 1981)

Beaver Valley Power Station - Unit 2 will follow the guidance of the regulatory guide for emergency planning and preparedness.

RG No. 1.102, Rev. 1 UFSAR Reference Sections 2.4.14, 3.4.1 FLOOD PROTECTION FOR NUCLEAR POWER PLANTS (SEPTEMBER 1976)

The Beaver Valley Power Station - Unit 2 design follows the flood protection guidance of this regulatory guide.

RG No. 1.103, Rev. 1 POST-TENSIONED PRESTRESSING SYSTEMS FOR CONCRETE REACTOR VESSELS AND CONTAINMENTS (OCTOBER 1976)

This regulatory guide, which has been withdrawn (June 1981), was

not applicable to Beaver Valley Power Station - Unit 2.

RG No. 1.104, Rev. 0

OVERHEAD CRANE HANDLING SYSTEMS FOR NUCLEAR POWER PLANTS (FEBRUARY 1976)

This regulatory guide was withdrawn August 1979.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 62 of 91 RG No. 1.105, Rev. 1 UFSAR Reference Section 7.1.2.1.9, 7.5.2.3

INSTRUMENT SETPOINTS (NOVEMBER 1976)

The establishing of instrument setpoints in systems important to safety which monitor variables that have limiting safety system settings follows the guidance of this regulatory guide with the following alternative and clarification:

Paragraph C.5

Administrative procedures coupled with the present cabinet alarms and/or locks provide sufficient control over the setpoint adjustment mechanism such that no integral setpoint securing device is required. Integral setpoint locking devices will not be supplied.

Paragraphs C.1 and C.6 The assumptions used in selecting the setpoint values including instrument inaccuracy and calibration uncertainty and the minimum margin with respect to the technical specification limit will be documented by Westinghouse. Drift rates and their relationships to testing intervals will not be documented by Westinghouse.

RG No. 1.106, Rev. 1

THERMAL OVERLOAD PROTECTION FOR ELECTRIC MOTORS ON MOTOR-OPERATED VALVES (MARCH 1977)

Thermal overload protection for electric motors on motor-operated valves follows the guidance of this regulatory guide.

RG No. 1.107, Rev. 1 QUALIFICATIONS FOR CEMENT GROUTING FOR PRESTRESSING TENDONS IN CONTAINMENT STRUCTURES (FEBRUARY 1977)

This regulatory guide is not applicable to Beaver Valley Power

Station - Unit 2.

RG No. 1.108, Rev. 1 UFSAR Reference Sections 8.1, 8.3.1, 14.2.12.54, 14.2.12.55

PERIODIC TESTING OF DIESEL GENERATOR UNITS USED AS ONSITE ELECTRIC POWER SYSTEMS AT NUCLEAR POWER PLANTS (AUGUST 1977)

The periodic testing of diesel generator units used as on-site electric power systems at BVPS-2 will meet the intent of Regulatory Guide 1.108. All necessary periodic testing, testing frequencies, and reporting requirements are specified in the BVPS-2 Technical Specifications.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 63 of 91 Paragraph C.2.a(3) suggests a periodic 24-hour, full-load-carrying capability test consisting of 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> at the continuous diesel generator rating and 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> at the 2-hour rating. Such a test is appropriate only for initial qualification of the diesel generator by the vendor or during preoperational testing to demonstrate adequate design and construction. Since this test imposes more severe service than is required by plant design, periodic performance of this test would only serve to repeatedly demonstrate suitable design or

sizing of the units and is beyond what is necessary to demonstrate operability or reliability. Testing on a periodic basis is unnecessary and is inconsistent with the goals of

Generic Letter 84-15 by providing conditions which could increase diesel generator degradation and reduce reliability. The diesel generator may occasionally be run to demonstrate its capability to operate for prolonged periods (24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or longer) when it is determined that such operation is prudent.

The periodic complete loss of load test specified in Paragraph C.2.a(4) is intended to demonstrate that the diesel overspeed limits are not exceeded upon simultaneous loss of all loads which could be supplied by the diesel. Since it is not expected that all diesel loads would be operated simultaneously, such a test would not be representative of expected operating transients. Additionally, the safety analyses do not take credit for the ability of a diesel to assume its assigned load once it is lost for any reason. Therefore, if a full load rejection is assumed, any resulting consequences to the diesel itself have been considered in the safety analyses with acceptable results. A full loss of load test is performed initially by the vendor to demonstrate acceptable response, but subsequent periodic testing is not required.

Where applicable, during preoperational testing of diesel generator units, acceptable vendor testing may be substituted in whole or in part for operator testing listed in Regulatory Guide 1.108. Sufficient testing will be conducted during the operational life of the plant to demonstrate the operability, reliability, and functional capability of the diesel generator

units.

RG No. 1.109, Rev. 1

UFSAR Reference Sections 2.3.5, 11.3, Appendix 11A, 13.3

CALCULATION OF ANNUAL DOSES TO MAN FROM ROUTINE RELEASES OF REACTOR EFFLUENTS FOR THE PURPOSE OF EVALUATING COMPLIANCE WITH 10 CFR PART 50, APPENDIX I (OCTOBER 1977)

Calculation of annual doses to man from routine releases of

reactor effluents at Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 64 of 91 RG No. 1.110, Rev. 0 COST-BENEFIT ANALYSIS FOR RADWASTE SYSTEMS FOR LIGHT-WATER-COOLED NUCLEAR POWER REACTORS (MARCH 1976)

Since the Beaver Valley Power Station - Unit 2 (BVPS-2) application for a construction permit was docketed on October 20, 1972, the cost-benefit analysis is optional and will not be developed for BVPS-2.

RG No. 1.111, Rev. 1 UFSAR Reference Section 2.3.5 METHODS FOR ESTIMATING ATMOSPHERIC TRANSPORT AND DISPERSION OF GASEOUS EFFLUENTS IN ROUTINE RELEASES FROM LIGHT-WATER-COOLED REACTORS (JULY 1977)

The methods for estimating atmospheric transport and dispersion of gaseous effluents in routine releases from Beaver Valley Power Station - Unit 2 will follow the guidance of this

regulatory guide.

RG No. 1.112, Rev. 0-R UFSAR Reference Sections 2.3.5, 11.1, 11.3.3, 12.2, 15.7

CALCULATION OF RELEASES OF RADIOACTIVE MATERIALS IN GASEOUS AND LIQUID EFFLUENTS FROM LIGHT-WATER-COOLED POWER REACTORS (MAY 1977) The calculation of releases of radioactive materials in gaseous and liquid effluents at Beaver Valley Power Station - Unit 2

follows the guidance of this regulatory guide.

RG No. 1.113, Rev. 1 UFSAR Reference Section 2.4.12

ESTIMATING AQUATIC DISPERSION OF EFFLUENTS FROM ACCIDENTAL AND ROUTINE REACTOR RELEASES FOR THE PURPOSE OF IMPLEMENTING APPENDIX I (APRIL 1977)

The mathematical models and dispersion coefficients selected to calculate aquatic dispersion of effluents from accidental and

routine reactor releases at Beaver Valley Power Station - Unit 2 follows the guidance of Regulatory Guide 1.113.

RG No. 1.114, Rev. 1 UFSAR Reference Section 13.5.1 GUIDANCE ON BEING OPERATOR AT THE CONTROLS OF A NUCLEAR POWER PLANT (NOVEMBER 1976)

Operators at the controls of Beaver Valley Power Station - Unit 2 will carry out their responsibilities using the guidance of

this regulatory guide.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 65 of 91 RG No. 1.115, Rev. 1 UFSAR Reference Sections 3.5.1.3, 3.5.2, 9.1.2, 9.5.4, 9.5.8 PROTECTION AGAINST LOW-TRAJECTORY TURBINE MISSILES (JULY 1977)

Protection against low-trajectory turbine missiles at Beaver Valley Power Station - Unit 2 (BVPS-2) will meet the intent of this regulatory guide.

Paragraph C.4 and associated Standard Review Plan NUREG-0800, Section 3.5.1.3, Acceptance Criterion II.1 do not apply to the

BVPS-2 plant design arrangement.

As an alternative, the latest technical advances in the design

and analysis of Westinghouse low-pressure turbine rotors will be used to provide additional assurance of a low failure probability.

A not-to-be-exceeded ultrasonic inspection interval and inservice inspection program is provided in Section 10.2.3 to insure missile generation probability values well below the 10

-5 limit. This missile generation probability, in combination with the probability of resulting damage to safety-related equipment, maintains the total probability of turbine missile damage below the regulatory guide limit of 10

-7 per year.

RG No. 1.116 UFSAR Reference Section 17.2 QUALITY ASSURANCE REQUIREMENTS FOR INSTALLATION, INSPECTION, AND TESTING OF MECHANICAL EQUIPMENT AND SYSTEMS

Application of Regulatory Guide 1.116 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual

.

RG No. 1.117, Rev. 1 UFSAR Reference Sections 3.2, 3.5, 3.8

TORNADO DESIGN CLASSIFICATION (APRIL 1978)

The method used for identifying those structures, systems, and

components at Beaver Valley Power Station Unit 2 that should be designed to withstand the effects of the design basis tornado follows the guidance of this regulatory guide.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 66 of 91 RG No. 1.118, Rev. 2 UFSAR Reference Sections 7.5, 8.1, 8.3

PERIODIC TESTING OF ELECTRIC POWER AND PROTECTION SYSTEMS (JUNE 1978)

Periodic testing of electric power and protection systems at Beaver Valley Power Station - Unit 2 follows IEEE Standard 338-1977 and the guidance of Regulatory Guide 1.118 with the

following clarifications:

Equipment performing control functions, but activated from protection system sensors is not part of the safety system and is not tested for time response.

Status, annunciating, display, and monitoring functions, except those related to the safety parameter display system, are considered control functions, and reasonability checks, that is, comparison between or among similar such display functions, are made.

Response time testing of nuclear instrumentation system detectors is not required because they exhibit response times that are an insignificant fraction of the total system response

time (that is, less than 5 percent).

Protection system sensors are demonstrated to be adequate by vendor testing, analysis, operating experience, or by suitable type testing.

RG No. 1.119, Rev. 0 SURVEILLANCE PROGRAM FOR NEW FUEL ASSEMBLY DESIGNS (JUNE 1976)

This regulatory guide was withdrawn June 1977.

RG No. 1.120, Rev. 1 UFSAR Reference Section 9.5.1 FIRE PROTECTION GUIDELINES FOR NUCLEAR POWER PLANTS (NOVEMBER 1977)

This regulatory guide provides guidelines acceptable to the NRC for implementing General Design Criterion 3 (GDC 3) of 10CFR5O, Appendix A, in the development of a fire protection program. This guide is in an extended comment period and is not yet approved. Branch Technical Position (BTP) CMEB 9.5-1, which is part of the acceptance criteria of Standard Review Plan 9.5.1 (NUREG-0800), dated July 1981, also provides guidelines

acceptable to the NRC for implementing GDC 3 in the development of a fire protection program. Regulatory Guide 1.120, Rev. 1, is not listed among the SRP 9.5.1 acceptance criteria. However, the guidelines of this regulatory guide have been incorporated into BTP CMEB 9.5-1. Therefore, the BVPS-2 position on this regulatory guide is covered by the evaluation of the BVPS-2 Fire

Protection Program against the guidelines of BTP CMEB 9.5-1.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 67 of 91 This evaluation is provided in Section 9.5A.2.

RG No. 1.121, Rev. 0 UFSAR Reference Section 5.4.2

BASES FOR PLUGGING DEGRADED PWR STEAM GENERATOR TUBES (AUGUST 1976)

Bases for plugging degraded steam generator tubes at Beaver Valley Power Station - Unit 2 will meet the intent of this regulatory guide with the following alternatives:

Paragraph C.1 The term "Unacceptable defects" is interpreted to apply to those imperfections resulting from service induced mechanical or chemical degradation of the tube walls which have penetrated to a depth in excess of the plugging limit. Paragraphs C.2.a(2) and C.2.a(4)

A 200-percent margin of safety will be used based on the following definition of tube failure. Tube failure is defined as plastic deformation of a crack to the extent that the sides of the crack open to a nonparallel,

elliptical configuration.

Paragraph C.2.b In cases where sufficient inspection data exist to establish degradation allowance, the rate used will be an average time-rate determined from the mean of the test data.

Where requirements for minimum wall are markedly different for different areas of the tube bundle, (for example, U-bend area versus straight length in Westinghouse designs), two plugging limits may be established to address the varying requirements in a manner which will not require unnecessary plugging of tubes.

Paragraphs C.3.d(l) and C.3.d(3)

The combined effect of these requirements would be to establish a maximum permissible primary-to-secondary leak rate which may be below the threshold of detection with current methods of measurement. The maximum acceptable length of a through-wall crack has been determined based on secondary pipe break accident loadings which are typically twice the magnitude of normal operating pressure loads. Westinghouse will use a leak rate associated with the crack size determined on the basis of accident

loadings.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 68 of 91 Paragraph C.3.e(6)

Computer code names and references will be supplied rather than the actual codes.

Paragraph C.3.f(l)

A minimum acceptable tube wall thickness (plugging limit) will be established based on structural requirements and

consideration of loadings, measurement accuracy, and, where applicable, a degradation allowance as discussed in this position and in accordance with the general intent of this regulatory guide. Analyses to determine the maximum acceptable number of tube failures during a postulated condition are normally done to entirely different bases and criteria and are not within the scope of this regulatory guide.

RG No. 1.122, Rev. 1 UFSAR Reference Section 3.7B.2.5 DEVELOPMENT OF FLOOR DESIGN RESPONSE SPECTRA FOR SEISMIC DESIGN OF FLOOR-SUPPORTED EQUIPMENT OR COMPONENTS (FEBRUARY 1978)

The development of floor design response spectra for seismic design of floor-supported equipment or components at Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide with the following alternative and clarification:

The response spectra peak resonant period values are broadened +25 percent and -20 percent with vertical sides

for use in the design basis.

When ASME III Code Case N-411 damping values are applied for piping analysis peak resonant period values are broadened plus and minus 15 percent with parallel sides.

The use of this code case is limited to pipe stress

reconciliation and support optimization.

RG No. 1.123, Rev. 1 UFSAR Reference Section 17.2

QUALITY ASSURANCE REQUIREMENTS FOR CONTROL OF PROCUREMENT OF ITEMS AND SERVICES FOR NUCLEAR POWER PLANTS (JULY 1977)

The original BVPS-2 Quality Assurance Program was described in Appendix A of the PSAR. This Quality Assurance Program followed the guidance of Regulatory Guide 1.123, Rev. 0. During

procurement activities, the Quality Assurance program was upgraded to reflect changes in regulatory requirements, including Regulatory Guide 1.123, Rev. 1.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 69 of 91 Westinghouse topical reports applicable to specific time periods are WCAP-8370, "Westinghouse Quality Assurance Program," Rev. 7A (June 1, 1975 - September 30, 1977), Rev. 8A (October 1, 1977 -

October 31, 1979), Rev. 9A (November 1, 1979 - present) and WCAP-7800, "Nuclear Fuel Division Quality Assurance Program Plan," Rev. 5 (applicable to the entire time period).

Application of Regulatory Guide 1.123 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual

.

RG No. 1.124, Rev. 1 UFSAR Reference Sections 3.9B.3.4.1, 5.4.14

SERVICE LIMITS AND LOADING COMBINATIONS FOR CLASS 1 LINEAR-TYPE COMPONENT SUPPORTS (JANUARY 1978)

The design limits and appropriate loading combinations associated with normal operation, postulated accidents and specified seismic events for the design of Class 1 linear-type component supports, as defined in Subsection NF of Section III of the ASME code, are not applicable to Beaver Valley Power Station - Unit 2 since the design and placement of the purchase

order for these supports precedes the first issue of ASME III, Subsection NF. The only exception is the reactor pressure vessel leveling devices which were procured after July 1974.

The design rules for the leveling devices follow ASME III, Subsection NF, as a guide and meet the intent of Regulatory Guide 1.124 with the following alternative:

Paragraph C.8 Supports for the "active" components that are required only during an emergency or faulted plant condition and that are subjected to loading combinations described in Regulatory Positions C.6 and C.7 should be designed within the design limits described in Regulatory Position C.5 or other justifiable design limits. These limits should be defined by the design specification and stated in the PSAR, such that the function of the supported system will be maintained when they are subjected to the loading

combinations described in Regulatory Positions 6 and 7.

The design limits and loading combinations for the

component supports are presented in Section 5.4.14.

RG No. 1.125, Rev. 1 UFSAR Reference Section 2.4

PHYSICAL MODELS FOR DESIGN AND OPERATION OF HYDRAULIC STRUCTURES AND SYSTEMS FOR NUCLEAR POWER PLANTS (OCTOBER 1978)

The use of physical models for design and operation of hydraulic structures and systems for Beaver Valley Power Station - Unit 2 follows the guidance of this regulatory guide.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 70 of 91 RG No. 1.126, Rev. 1 UFSAR Reference Section 4.2

AN ACCEPTABLE MODEL AND RELATED STATISTICAL METHODS FOR THE ANALYSIS OF FUEL DENSIFICATION (MARCH 1978)

The analysis of fuel densification for Beaver Valley Power Station - Unit 2 meets the intent of this regulatory guide with the following clarification:

The regulatory guide states clearly that, "The model presented in . . . this guide is not intended to supersede

NRC-approved vendor models." Beaver Valley Power Station

- Unit 2 uses the Westinghouse densification model presented in WCAP-8218 (Proprietary) which has been approved by the USNRC. Westinghouse's reports WCAP-8219 (Non-proprietary) and WCAP-8264, (Customer Version) are companions to the approved versions.

RG No. 1.127, Rev. 1 UFSAR Reference Section 2.4 INSPECTION OF WATER-CONTROL STRUCTURES ASSOCIATED WITH NUCLEAR POWER PLANTS (MARCH 1978)

BVPS-2 does not use water-control structures, such as those described in this regulatory guide. Water-control structures along the Ohio River are operated and maintained by the responsible governmental authorities, such as the U.S. Army

Corps of Engineers.

RG No. 1.128, Rev. 1 UFSAR Reference Sections 8.1.6, 8.3.2

INSTALLATION DESIGN AND INSTALLATION OF LARGE LEAD STORAGE BATTERIES FOR NUCLEAR POWER PLANTS (OCTOBER 1978)

The installation design and installation of large lead storage batteries at Beaver Valley Power Station Unit 2 follows IEEE Standard 484-1975 and the guidance of Regulatory Guide 1.128,

with the following clarification:

Hydrogen detectors are not required because proper ventilation has been provided in the battery rooms to ensure a sufficient air exchange rate. In addition, instrumentation exists so that a lack of sufficient flow

will be indicated in the control room by an alarm system.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 71 of 91 RG No. 1.129, Rev. 1 UFSAR Reference Section 8.3.2

MAINTENANCE, TESTING, AND REPLACEMENT OF LARGE LEAD STORAGE BATTERIES FOR NUCLEAR POWER PLANTS (FEBRUARY 1978)

Maintenance, testing, and replacement of large lead storage batteries at Beaver Valley Power Station Unit 2 will follow the guidance of this regulatory guide with the following

alternatives:

Periodic testing will follow the guidance of IEEE Standard 450-1980.

The initial battery service test will be held within 2 years, the customary interval for the first outage; thereafter, the service tests will be held within intervals at 18 months.

RG No. 1.130, Rev. 1 UFSAR Reference Sections 3.9B.3.4.1, 5.4.14

SERVICE LIMITS AND LOADING COMBINATIONS FOR CLASS 1 PLATE-AND-SHELL-TYPE COMPONENT SUPPORTS (OCTOBER 1978)

The service limits and loading combinations for Class 1 plate-and-shell type component supports meet the intent of Regulatory Guide 1.130 with the following alternatives:

Paragraph C.3 Service limits for component supports designed by linear

elastic analysis are limited by the critical buckling strength. The critical buckling strength is calculated using material properties at temperature. Conservative factors of safety for flat plates and for shells are maintained for each design and service limit. The allowable stress for Service Limit D does not exceed two-

thirds of the critical buckling stress.

The safety margins of 3 for shells and 2 for flat plates required by Paragraph C.3 of Regulatory Guide 1.130 are unnecessarily conservative. The margins have been arbitrarily selected by the USNRC; they were influenced by

the precedent set in Subsection NE of the ASME Code for shells (F.S. = 3), and by the AISC column factors in the case of plates (F.S. varies from 1.67 to 1.92). The USNRC has authorized a study of generic buckling criteria by a group of consultants. Initial reports indicate they are proposing establishment of critical buckling stresses based on lower bound values of test data from the aerospace industry (thin shells) without specific tolerance requirements on construction.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 72 of 91 Paragraph C.7 Support for active components that are required only during an emergency or faulted plant condition and that are subjected to loading combinations described in Paragraphs C.5 and C.6 are designed within the limits described in

Paragraph C.4 or other justifiable design limits. These limits are defined in UFSAR Section 5.4.14. The function of the supported system is maintained when they are subjected to the loading combinations described in Paragraphs C.5 and C.6.

Paragraph C.7 implies that the lower stress limits associated with Levels A and B Service Limits must be used for any component support that serves a safety-related function during an emergency or faulted (LOCA) plant condition. This would seem to imply that a main coolant pump support, which is a passive element in the main

coolant loop, would have to be designed to meet the Level A and B Limits during an emergency or faulted plant condition. This would require that a snubber providing

restraint on a residual heat removal line would have to be designed to the Level A and B Service Limits during an emergency or faulted plant condition. If this is the intent, it is a severe departure from current practice. Only active components, such as valves, whose operation is required for safe shutdown during an emergency or faulted conditions have been required to meet design stress limits for these plant conditions. Level C and D Service Limits have been considered adequate to assure pressure boundary

integrity under the more severe operating conditions.

RG No. 1.131, Rev. 0 UFSAR Reference Sections 3.11 and 8.3.3

QUALIFICATION TESTS OF ELECTRIC CABLES, FIELD SPLICES, AND CONNECTIONS FOR LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (AUGUST 1977)

Qualification tests of electric cables, field splices, and connections for Beaver Valley Power Station - Unit 2 meet the

intent of this regulatory guide, with the following alternatives and clarification:

a. All cables installed in trays at BVPS-2, either:
1. have passed the vertical cable tray gas burner flame test delineated in Section 2.5.4.4 of IEEE-383-1974 or,
2. additionally, the flame testing for cables specified after January 1978 was modified in

accordance with Reg. Guide 1.131-77 or,

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 73 of 91 3. for non-safety applications, are flame retardant and have passed equivalent industry flame testing as approved by engineering evaluation.

b. Single conductor 600 V control, coaxial, and triaxial cables installed after December 5, 2000, meet the vertical flame testing listed in item a above. Single conductor 600 V control, coaxial, and triaxial cables installed prior to December 5, 2000, are flame resistant and meet the vertical flame test provisions of the appropriate ICEA standards. These cables were not subjected to the gas burner vertical cable tray flame test of IEEE-383-1974, and as such, are restricted to installation in conduit and electrical enclosures (i.e., panels and junction boxes).

RG No. 1.132, Rev. 1 UFSAR Reference Section 2.5.4 SITE INVESTIGATIONS FOR FOUNDATIONS OF NUCLEAR POWER PLANTS (MARCH 1979)

Site investigations for foundations at Beaver Valley Power Station - Unit 2 meet the intent of Regulatory Guide 1.132 with the following alternatives and clarifications:

Paragraph B.5 Surveys of horizontal deviation are made in all boreholes

that are used for crosshole seismic tests. This must be done in order to determine the true distance between the energy source and receiver. The suggestion that surveys

of vertical deviation be performed appears to be an error.

Paragraph C.1 (Item 5)

Only typical time-distance plots are included on the geologic profiles. A typical time-distance plot is more appropriate since time-distance plots are not usually included on geologic profiles.

Paragraph C.2 Since boring logs do not typically include field and laboratory test results, the results of field permeability tests and borehole logging are presented in tables and figures especially designed for these tests.

Paragraph C.3 Measurement of water or drilling mud levels in borings is not required in all cases since water or drilling mud levels in some materials, such as clays, may give false information about ground-water levels. A sufficient number of observation wells are installed to monitor ground-water levels.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 74 of 91 Paragraph C.6 Continuous undisturbed samples will be taken in compressible or normally consolidated clays only if required for geotechnical analysis. The need for continuous undisturbed samples is a matter of engineering

judgment and is evaluated for each case.

Appendix C

1. Earth Dams, Dikes, Levees, and Embankments Boring criteria for rock sites will be developed for each case since penetration to d max at a rock site is excessive.
2. Deep Cuts and Canals Boring criteria for rock sites will be developed for each case. Detailed mapping is used for rock sites, supplemented by borings where appropriate.
3. Pipelines Boring spacing criteria for rock sites will be developed for each case since the suggested spacing would require an excessive number of borings for rock

sites. The boring depth criteria for soil and rock sites will

be developed for each case since a minimum depth of 5 diameters may be excessive, depending upon the site geology and pipe diameter.

4. Tunnels

Boring spacing and depth criteria will be developed for each case. The suggested spacing would require an excessive number of borings if applied to rock sites

and a minimum depth of 5 times the tunnel diameter may be excessive, depending upon the site geology.

RG No. 1.133, Rev. 1 UFSAR Reference Section 4.4, 14.2

LOOSE-PART DETECTION PROGRAM FOR THE PRIMARY SYSTEM OF LIGHT-WATER-COOLED REACTORS (MAY 1981)

The original design of Beaver Valley Power Station Unit 2 included a loose-part monitoring system that was intended to meet the intent of Regulatory Guide 1.133. Subsequent evaluation has determined that this system was not required.

Therefore, various features may be eliminated, modified or

maintained as an operating convenience.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 75 of 91 RG No. 1.134, Rev. 1 MEDICAL EVALUATION OF NUCLEAR POWER PLANT PERSONNEL REQUIRING OPERATOR LICENSES (MARCH 1979)

Medical evaluation of Beaver Valley Power Station Unit 2 (BVPS-2) personnel requiring operator licenses meets the intent of Regulatory Guide 1.134 by following acceptable alternative criteria. These alternative criteria meet the requirement of 10 CFR 55.10, "Contents of Applications," and 10 CFR 55.33, "Renewal of Licenses," that each initial or renewal operator or senior operator license application contain a report of medical examination by a licensed medical practitioner on the form prescribed in 10 CFR 55.60, "Examination Form." BVPS-2 also demonstrates compliance with the requirement of 10 CFR 55.11, "Requirements for the Approval of Applications," and 10 CFR 55.33 that the physical condition and general health of BVPS-2 operator applicants are not such as might cause operational

errors endangering public health and safety.

RG No. 1.135, Rev. 0 UFSAR Reference Section 2.4

NORMAL WATER LEVEL AND DISCHARGE AT NUCLEAR POWER PLANTS (SEPTEMBER 1977)

This regulatory guide pertains to those facilities whose construction permit application was docketed after May 1, 1978. Because Beaver Valley Power Station - Unit 2 (BVPS-2) received

its docket prior to this date, the regulatory guide is not applicable. However, the methods used for determining normal water levels and surface water discharges for BVPS-2 follows the

guidance of this regulatory guide.

RG No. 1.136, Rev. 2 UFSAR Reference Section 3.8.1

MATERIALS, CONSTRUCTION, AND TESTING OF CONCRETE CONTAINMENTS (ARTICLES CC-1000, -2000, AND -4000 THROUGH -6000 OF THE "CODE FOR CONCRETE REACTOR VESSELS AND CONTAINMENTS") (JUNE 1981)

Regulatory Guide 1.136, Revision 2, June 1981, is not applicable to the Beaver Valley Power Station - Unit 2 (BVPS-2) design and

construction since Revision 2 criteria are to be used in the evaluation of construction permit applications docketed after May 1981. However, materials, construction, and testing of the concrete containment for BVPS-2 meet the intent of Regulatory Guide 1.136, Revision 1, October 1978, with the following alternative:

In Paragraph C.3, the chloride content for grout should not exceed 200 ppm. Reduced chloride content for grout

with pH from 11.6 to 12.0 is unnecessary and will require continuous testing of pH value. All normal Portland cement grout has a pH in excess of 12.0. Therefore, up to

200 ppm of chloride should be acceptable.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 76 of 91 Regulatory Guide 1.136, Revision 2, refers to adoption of articles cc-1000, -2000, and -4000 through -6000 of the

ASME Boiler and Pressure Vessel Code,Section III, Division 2, 1980 edition. Revision 2 of Regulatory Guide 1.136 replaces the following regulatory guides:

Regulatory Guide 1.10, Revision 1 - Mechanical (Cadweld)

Splices in Reinforcing Bars of Category I Concrete

Structures.

Regulatory Guide 1.15, Revision 1 - Testing of Reinforcing

Bars for Category I Concrete Structures.

Regulatory Guide 1.18, Revision 1 - Structural Acceptance

Test for Concrete Primary Reactor Containments.

Regulatory Guide 1.19, Revision 1 - Nondestructive

Examination of Primary Containment Liner Welds.

Regulatory Guide 1.55, Revision 0 - Concrete Placement in

Category I Structures.

Regulatory Guide 1.103, Revision 1 - Post-tensioned Prestressing Systems for Concrete Reactor Vessels and Containments.

The applicability of the preceding regulatory guides to BVPS-2 is as stated in the respective positions on these regulatory guides.

RG No. 1.137, Rev. 1 UFSAR Reference Section 9.5.4

FUEL-OIL SYSTEMS FOR STANDBY DIESEL GENERATORS REV. 1 (OCTOBER 1979)

Beaver Valley Power Station - Unit 2 (BVPS-2) meets the intent of the guidelines of Regulatory Guide 1.137 for fuel-oil systems for standby diesel generators with the following alternatives:

ANSI-N195-1976, which is the basis for Regulatory Guide 1.137, recommends the use of duplex strainers to allow continued operation of the system if a strainer becomes

plugged. BVPS-2 meets the intent of this recommendation by providing redundant pumps with a simplex wye-type strainer in the discharge line of each pump.

Fuel specifications and periodic tests to verify fuel oil quality will be in accordance with the BVPS-2 technical

specifications.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 77 of 91 RG No. 1.138, Rev. 0 UFSAR Reference Section 2.5.4

LABORATORY INVESTIGATIONS OF SOILS FOR ENGINEERING ANALYSIS AND DESIGN OF NUCLEAR POWER PLANTS (APRIL 1978)

Laboratory investigations of soils and rocks for engineering analysis and design of Beaver Valley Power Station - Unit 2 meets the intent of Regulatory Guide 1.138, with the following alternatives. Most of these were noted in a letter from S. B. Jacobs, Stone & Webster Engineering Corporation, to the Secretary of the USNRC, dated July 6, 1978:

Paragraph C.1.c Standards used to calibrate laboratory test equipment are of a known higher accuracy than the test equipment, rather than four times more accurate than the working instrument.

Calibration of the architect engineer's geotechnical laboratory equipment to higher standards than currently in use is not justified since soils and rocks are material whose properties vary widely within the same deposit or formation. In addition, certain physical properties of soils and rocks are greatly affected by sampling and by preparation for testing in the laboratory. The geotechnical engineer takes these natural variations and sampling/preparation effects into account, and exercises considerable judgment in assigning the material properties to be used in an analysis. (This is different from the case of manufactured materials, where dimensions and physical properties are maintained within a narrow range by the manufacturing process.)

Paragraph C.1.d Index and classification tests are not performed on all soil and rock samples. Classification of soil and rock samples is performed by visual-manual techniques. Index and classification tests are performed on representative

samples to confirm the visual-manual classifications.

Paragraph C.2 Moisture seals are not periodically checked and renewed as needed. Tube samples are inspected for obvious leakage when a tube has been selected for testing. Each sample is examined when it is extruded, and any evidence of drying in the tube is noted on the sample description log. This procedure is sufficient to evaluate whether drying has occurred. Samples that appear to have dried are not tested. Periodic inspection and replacement of moisture seals would not provide any better protection against testing samples whose water content has changed than the method used.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 78 of 91 The duration of storage is not specifically recorded for each test since this can be calculated from the boring logs, where the sampling date is given, and the laboratory test data sheets, where the date of testing is recorded. Therefore, it is unnecessary to make a separate record of storage time.

Paragraph C.3.a Classification tests are not performed on every undisturbed test specimen of soil or rock. Visual-manual techniques are the primary means of classifying soil and rock samples. Classification tests are performed on representative samples as necessary to confirm the results of the visual-manual classifications.

Measurements and control tests are not performed to determine whether undisturbed samples have changed during

shipment, storage, and handling. Undisturbed samples are visually inspected as they are opened and extruded, to determine whether there has been any change in sample length within the tube or if there are any signs of sample disturbance. Results of these inspections are reported on the sample description log. This procedure and examination of the laboratory test results for possible indications of sample disturbance, is sufficient to determine whether sample disturbance has occurred.

Paragraph C.3.b A discussion of the validity of test results on scalped materials is not presented as part of the laboratory test data. The laboratory test results indicate which portion of the sample has been scalped, and a competent reviewer of the test results would understand the effect of scalping on the results of specific tests.

Paragraph C.4.a(2)

Results of tests with B-values less than 0.95 may be used for analysis in certain cases. For very stiff or hard clays, it may not be possible to achieve a B-value of 0.95. If results of such a test are used, the B-value is reported and the probable effect on results of the test could be evaluated by a competent reviewer.

Paragraph C.5.a All soil and rock identifications and descriptions are not documented. The current practice of recording sample descriptions and determining index properties of representative samples is consistent with good engineering practice.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 79 of 91 Anomalous test data are not reported if they are caused by sample disturbance or equipment malfunction because such data do not reflect the true properties of the material in the field. However, records of such tests are maintained as part of the laboratory records.

Appendix B, Relative Density Test The frequency of the vibratory table cannot be adjusted, because it depends upon the fixed frequency of the input current.

RG No. 1.139, Rev. 0 UFSAR Reference Sections 3.1.2.34, 5.4.7, Appendix 5A, 10.3, 10.4.9, 14.2 GUIDANCE FOR RESIDUAL HEAT REMOVAL (MAY 1978)

While the safe shutdown basis for Beaver Valley Power Station -

Unit 2 (BVPS-2) is hot standby, the cold shutdown capability of

the plant meets the intent of Regulatory Guide 1.139 and the Branch Technical Position RSB 5-1 design guidelines for Class 2 plants with the following clarifications:

Following a safe shutdown earthquake, assuming loss of onsite or offsite power and the most limiting single failure, the plant is capable of achieving residual heat removal (RHR) system initiation conditions (approximately 350F and 400 psia) within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

BVPS-2 designers employed an approach to safety grade cold

shutdown by upgrading to safety grade, wherever feasible. It is recognized that achievement of cold shutdown, utilizing normally available non-safety grade systems and components, is desirable with postulation of loss-of-offsite power as the initiating event.

In order to provide adequate cooldown within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> to initiate the RHR system, the steam generator power operated relief valves (PORVS) are qualified to full safety-grade design and an adequate supply of auxiliary feedwater is established.

The primary plant demineralized water storage tank initially establishes the supply of auxiliary feedwater and is provided with backup from the demineralized water storage tank.

Combined, these tanks have adequate storage capacity to remove residual heat for more than three days. Additionally, supply connections from the service water system are available should they be required.

Further upgrades for BVPS-2 include the addition of a safety grade atmospheric dump valve which provides backup to the steam generator PORVS and the upgrading of the pressurizer PORVS to

safety grade.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 80 of 91 The RHR system is provided with two separate and independent systems. This redundancy provides the system with the capability to maintain its heat removal function even with a

major single failure. Each RHR system train is isolated from the reactor coolant system (RCS) on the suction side by two motor operated valves (MOVs) in series. The suction isolation valves are independently interlocked to prevent the valves from being opened unless the RCS pressure is below the RHR system design pressure. Each MOV receives power via a separate motor

control center and the two valves in series in each train receive their power from a different vital bus. The suction isolation valves are also independently interlocked so that any open valve will automatically close if RCS pressure increases above the RHR system design pressure.

Refer to the positions on Regulatory Guides 1.22 and 1.68 for testing and the position on Regulatory Guide 1.33 for operational procedures.

RG No. 1.140, Rev. 1 UFSAR Reference Sections 9.4, 11.1, 11.3, 14.2.12 DESIGN, TESTING, AND MAINTENANCE CRITERIA FOR NORMAL VENTILATION EXHAUST SYSTEM AIR FILTRATION AND ADSORPTION UNITS OF LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (OCTOBER 1979)

Design, testing, and maintenance criteria for normal ventilation exhaust system air filtration and adsorption units for Beaver Valley Power Station - Unit 2 meet the intent of Regulatory

Guide 1.140 with the following alternatives:

Paragraph C.2.a

1. Where a very small amount of dust is anticipated, prefilters instead of upstream HEPA filters are provided.
2. Heating coils are provided only where the relative humidity is expected to exceed 70 percent.

Paragraph C.2.f

1. The ductwork leak tests are performed in accordance with ANSI N510-1975 with the alternative that ASME

Performance Test Code 19.5-1971 will be used in lieu of paragraph 6.3.1. The equipment and equipment arrangement based on the above ASME performance test

code will provide test results equivalent to results obtained by equipment specified in paragraph 6.3.1 of ANSI N510-1975.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 81 of 91 2. The air leakage rate for ductwork will be established based on the air cleaning effectiveness provisions defined in paragraph 4.12.1 of ANSI N509-1980.

Because the ductwork carrying contaminated air upstream of filters is under negative pressure and there is no leakage from the ductwork to surrounding space, and because any air leak from the ductwork under positive pressure is on the downstream side of filters (filtered air), the leakage for ductwork upstream of filters and downstream of fans is limited to 5 percent of rated flow at internal design pressure (leakage Class II, Table 4-3 of ANSI N509-1980).

3. For ductwork between the outlet of filters and the inlet of fans, the leakage is limited to 0.5 percent of rated flow at internal design pressure (leakage Class I, Table 4-3 of ANSI N509-1980).
4. The filter housing leak test will be performed in accordance with paragraph 4.12 of ANSI N509-1976 with the alternative that the housing maximum allowable leakage will be as specified in Table 4-3 of ANSI N509-1980. The leakage test procedure will be developed based on Section 6 of ANSI N510-1980.

Paragraph C.3.c The component mounting frames meet the recommendations of ANSI N509-1976, paragraph 5.6.3, with an alternative for the tolerance provisions. The tolerances for mounting frames are sufficient to pass the bank leak test of paragraphs C.5.c and C.5.d of this Regulatory Guide.

Paragraph C.3.e

1. Stainless steel materials for filter housings are procured to ASTM material specifications such as A167 Type 304 and A267 Type 304 in addition to those listed in paragraph 4.3 of NSIC-65/ERDA 76-21.
2. Welding is performed in accordance with AWS D1.1 or ASME IX; therefore, the workmanship samples recommended in paragraph 7.3 of ANSI N509-1976 are not used to demonstrate welders' qualifications to perform production work.

Paragraph C.3.f

1. Welding procedures, welders, and welding operators are qualified in accordance with designer's welding specifications. These specifications are in general

conformance with AWS D1.1 and ASME Section IX, which are recommended in paragraph 7.3 of ANSI N509-1976. Production weld visual acceptance criteria, which are based on AWS D1.1, are used in lieu of workmanship samples recommended in ANSI N509-1976 paragraph 7.3.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 82 of 91 2. Materials for ductwork are procured to ASTM material specifications, such as A276 Type 304, A500 Gr B, A575 Gr N1020, and A576 Gr 1020, in addition to those

listed in paragraph 5.10.6 of ANSI N509-1976.

3. An alternative is taken to paragraph 5.10.3.5 of ANSI N509-1976. While ductwork, as a structure, has a resonant frequency above 25 Hz, this may not be true for the unsupported plate or sheet sections. ANSI N509-1980, which has been issued since the issuance of this Regulatory Guide, has deleted this provision. Tympanic vibration modes of the duct are not considered in design because the loads will be small, and minimum thickness of duct material is 20 gauge.

This is more conservative then SMACNA provisions.

Paragraph C.3.g The qualification of impregnated carbon will be in accordance with Table 5-1 of ANSI N509-1980. The test will be performed as specified in ASTM D3803-1979,

paragraph 4.1, Method A.

Paragraph C.3.i

1. The type and application of protective coatings on internal surfaces is controlled in accordance with the designer's specifications, which specify high quality materials and application methods in accordance with the coating manufacturer's instructions. These

practices are used in lieu of the recommendations in paragraphs 5.6.4 and 5.7.1 of ANSI N509-1976.

2. An alternative is taken to paragraph 5.7.2 of ANSI N509-1976. Copies of fan rating or test reports are not provided. However, certified fan performance

curves are furnished.

3. An alternative is taken to balancing techniques defined in paragraph 5.7.3 of ANSI N509-1976. Displacement criteria following normal industrial practice are used.
4. The fan drawings follow the recommendations of paragraph 5.7.4 of ANSI N509-1976 with the alternative that all information about lubricants and lubrication is contained in operation and instruction manuals.
5. Where AMCA certified ratings are submitted, documentation developed in conjunction with the

certification of fans is not furnished in accordance

with paragraph 5.7.5 of ANSI N509-1976.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 83 of 91 Paragraph C.3.1 The following alternatives are taken to paragraph 5.9 of ANSI N509-1976:

1. Isolation dampers used in the contaminated air streams are neither designed nor constructed to the recommendations of ANSI B31.1. The system is designed to ensure that the leakage through the dampers is from the noncontaminated to contaminated portion of the system, and the flow is exhausted through the filters before being released to the atmosphere. Therefore,

the uncontrolled release of radioactivity is precluded and the intent of Section 5.9 of ANSI N509-1976 is satisfied.

2. Butterfly valves, where used, are in accordance with the ASME III code.
3. One Class B damper of each size will be tested for leakage rate instead of testing every damper.
4. Welding is controlled in accordance with the designer's specifications using visual acceptance criteria, which are based on AWS D1.1 in lieu of the standards recommended in paragraphs 5.9 and 7.3 of ANSI N509-1976.
5. The minimum diameter of damper shafts that are 24 inches and under in length shall be 1/2 inch. The minimum diameter of damper shafts that are greater than 24 inches in length through 48 inches in length shall be 3/4 inch.

Paragraph C.5.a A visual inspection of the atmosphere cleanup system and all associated components is not planned to be made before each in-place air flow distribution test, DOP test, or

activated carbon adsorber section leak test, but will be performed after initial installation and on an as-needed basis in accordance with the provisions of Section 5 of

ANSI N510-1975.

Paragraph C.5.b The airflow capacity and distribution test procedure will

be developed based on Section 8 of ANSI N510-1980 with the

following alternatives:

1. To avoid damage to system components, an artificial resistance will be used in lieu of the provision of paragraph 8.3.1.1.

BVPS-2 UFSAR Rev. 17 TABLE 1.8-1 (Cont) 84 of 91 2. Airflow measurements for the airflow capacity test will be performed in accordance with AABC National Standards for total system balance, Fourth Edition, 1982, instead of Section 9 of ACGIH, Industrial Ventilation, as specified in paragraph 8.3.1(3) of ANSI N510-1975. The above alternative will provide

consistency with the airflow measurement method for balancing of the plant ventilation systems.

3. The airflow test will be performed in accordance with paragraphs 8.3.1.1 and 8.3.1.6 only. The test

specified in paragraph 8.3.1.7 of ANSI N510-1980 duplicates the test under paragraph 8.3.1.1, because the actual values for pressure drop for both tests are approximately equal. The airflow test specified in paragraph 8.3.1.6 will be performed with the filter bank at 100 percent of design dirty-pressure drop.

The system and equipment instrumentation and

surveillance preclude inadvertent operation of the filter banks with the pressure or flow outside of the allowable limits.

4. Airflow distribution through prefilters and moisture separator banks is not specified, therefore, the provisions of paragraph 8.3.2.3 do not apply.

Paragraph C.5.c Sealant is used in ductwork field repairs, in addition to rivets, by applying the sealant between the ductwork and a

riveted patch. This method of repair is allowed only on non-seismic SMACNA Class ductwork.

The in-place DOP Test of HEPA filters will be performed in accordance with Section 10 of ANSI N510-1980. The air-aerosol mixing uniformity test will be performed in

accordance with Section 9 of the above code.

In-place DOP testing will be performed on the Filtration Units initially and after an entire or partial bank changeout.

Paragraph C.5.d The in-place test of the carbon adsorber will be performed in accordance with Section 12 of ANSI N510-1980.

In place testing of the carbon absorber units will be performed initially and after an entire or partial bank changeout.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 85 of 91 Paragraph C.6.b Laboratory testing frequency for the activated carbon will coincide with scheduled reactor shutdowns for refueling.

The carbon samples not obtained from test cannisters will be obtained with slotted-tube sampler in accordance with ANSI N509-1980.

RG No. 1.141, Rev. 0 UFSAR Reference Section 6.2.4

CONTAINMENT ISOLATION PROVISIONS FOR FLUID SYSTEMS (APRIL 1978)

Containment isolation provisions for fluid systems at Beaver Valley Power Station - Unit 2 follow the guidance of this regulatory guide.

RG No. 1.142, Rev. 1 UFSAR Reference Sections 3.8.3, 3.8.4 SAFETY-RELATED CONCRETE STRUCTURES FOR NUCLEAR POWER PLANTS (OTHER THAN REACTOR VESSELS AND CONTAINMENT (OCTOBER 1981)

The design and analysis procedures for the Beaver Valley Power Station - Unit 2 safety-related concrete structures other than the reactor vessel and containment meet the intent of Regulatory Guide 1.142 with the following alternative:

The load combinations considered conform to the requirements of ACI Standard 318-7 and meet the general intent of ACI Standard 349-76. These combinations are shown in Sections 3.8.3.3 and 3.8.4.3.

RG No. 1.143, Rev. 1 UFSAR Reference Sections 3.8.4, 10.4.8, 11.2, 11.3, 11.4, 11.5

DESIGN GUIDANCE FOR RADIOACTIVE WASTE MANAGEMENT SYSTEMS, STRUCTURES, AND COMPONENTS INSTALLED IN LIGHT-WATER-COOLED NUCLEAR POWER PLANTS (OCTOBER 1979)

The Beaver Valley Power Station - Unit 2 design of radioactive waste management systems, structures, and components meets the intent of Regulatory Guide 1.143 with the following clarifications and alternatives:

Paragraph C.1.1.3 The steam generator blowdown flash tank, the steam generator blowdown demineralizers, and the steam generator blowdown demineralizer heat exchangers are located in the

turbine building, a nonseismic structure.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 86 of 91 Leakage from steam generator blowdown system components located in the turbine building is collected in the turbine building sumps and monitored via grab samples prior to release to the

environment. The turbine building drain release will be isolated from the storm drainage system and transferred to the liquid waste system when the activity concentration exceeds

established site limits.

Paragraph C.1.2.3 The steam generator blowdown evaporator test tanks, the steam generator blowdown demineralizers, and the steam generator blowdown flash tank do not have curbs or elevated thresholds.

Test tanks receive distillate from the steam generator blowdown evaporators and provide facilities for storage and sampling prior to release to the environment.

Calculations show that the tanks do not require shielding due to the low activity level of water expected in these tanks. A floor drain is provided in the general area of the test tanks to collect leakage and overflow in the auxiliary building sump for pumping to the liquid waste system. Refer to paragraph C.1.1.3 for the steam

generator blowdown flash tank.

Paragraph C.1.2.5 The refueling water storage tank is not provided with a

dike or retention pond. Tank overflow is directed to the

liquid waste system via piping.

The refueling water storage tank is fabricated in accordance with the requirements of ASME III, Class 2.

The atmospheric tank is tested full of water to ensure that there are no leaks, and undergoes 100-percent

radiographic examination on the shell. Tank overflow is directed to the liquid waste system via the safeguards building sump piping. The radionuclide concentrations of the refueling water storage tank liquid will be determined following each refueling.

Paragraph C.2.1.1 The gaseous waste system equipment meets or exceeds the

codes in Table 1. The gaseous waste delay beds, gaseous waste surge tank, waste gas chiller, overhead gas compressors and piping are designed and fabricated to ASME III. The valves are designed and fabricated to ANSI B31.1. The gaseous waste storage tanks are designed and fabricated to ASME VIII, Division 1.

All equipment manufacturing codes exceed those specified by Table 1 of Regulatory Guide 1.143.

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 87 of 91 Paragraph C.2.1.3 The gaseous waste system piping within the gaseous waste storage tank vault structure is designated non-seismic and has been analyzed for dead-load and thermal stresses only.

Failure of the gaseous waste system piping within the gaseous waste storage tank vault will not adversely affect any other systems or components because the storage tank vault contains only gaseous waste system piping. The Offsite Dose Calculation Manual (ODCM) provides a limit on the quantity of radioactivity contained in each group of gaseous waste storage tanks. The basis of this requirement is to restrict the quantity of radioactivity so any release due to a leak or failure will not exceed the requirements of NRC Branch Technical Position ETSB 11-5, Rev. 0, dated July 1981, of 0.5 Rem at the exclusion area boundary. This accident is described in Section

15.7.1. The storage tank system is used to store all the gas

generated by either BVPS-1 or BVPS-2 when going to a cold shutdown condition. The system uses seven tanks, each of which has individual solenoid operated isolation valves, a pressure indicator, a high pressure alarm, and overpressure protection. The storage tanks were purchased and constructed to ASME VIII requirements and subsequently were seismically mounted in the gaseous waste storage tank vault structure. The seven tanks may all be in service at one time, or be operated in smaller groupings.

Paragraph C.4.3 The piping downstream of the overhead gas compressors is one-half inch.

The discharge piping for the overhead gas compressors is designed to not impose any unnecessary pressure loss in that portion of the gaseous waste system.

The steam generator blowdown heat exchanger condensate flow sensing lines are one-half inch. These sensing lines are sized to accommodate instrument requirements. Standard 300# orifice flanges are tapped with 1/2" ports. There is no concern for clogging the smaller diameter pipe

because there are no resins present in this portion of the system. Paragraph C.5.1.1

Beaver Valley Power Station - Unit 2 (BVPS-2) does not apply the Regulatory Guide 1.60 design ground response spectra. Instead, a BVPS spectrum is applied as described in Section 3.7B.1

BVPS-2 UFSAR Rev. 13 TABLE 1.8-1 (Cont) 88 of 91 Paragraph C.5.2.1 Beaver Valley Power Station - Unit 2 does not use Regulatory Guide 1.60 spectra nor Regulatory Guide 1.61 damping values. Instead, refer to Sections 3.7B.1.1 and 3.7B.1.3.

Paragraph C.5.2.2 Beaver Valley Power Station - Unit 2 complies with this section, except that the spectra described in Sections 3.7B.1 and 3.7B.2 are used.

Paragraph C.5.2.3 Beaver Valley Power Station - Unit 2 uses the modal time-history technique to generate floor response spectra.

Refer to Section 3.7B.2.

Paragraph C.5.2.4 Beaver Valley Power Station - Unit 2 uses ACI-318-71. This was the code in effect at the time of design. The differences between this code and ACI-318-77 are

insignificant.

Paragraph C.6 Quality assurance programs used for the design, manufacture, construction, and inspection of the equipment used in the radwaste management systems are in accordance with a QA Category II classification and the codes and standards specified in the equipment purchase

specifications.

RG No. 1.144 UFSAR Reference Section 17.2

AUDITING OF QUALITY ASSURANCE PROGRAMS FOR NUCLEAR POWER PLANTS

Application of Regulatory Guide 1.144 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance Program Manual

.

RG No. 1.145, Rev. 1 UFSAR Reference Sections 2.3, 13.3

ATMOSPHERIC DISPERSION MODELS FOR POTENTIAL ACCIDENT CONSEQUENCE ASSESSMENTS AT NUCLEAR POWER PLANTS (NOVEMBER 1982)

Atmospheric dispersion models used for potential accident consequence assessments at Beaver Valley Power Station - Unit 2

follow the guidance of this regulatory guide.

BVPS-2 UFSAR Rev. 18 TABLE 1.8-1 (Cont) 89 of 91 RG No. 1.146 UFSAR Reference Section 17.2

QUALIFICATION OF QUALITY ASSURANCE PROGRAM AUDIT PERSONNEL FOR NUCLEAR POWER PLANTS

Application of Regulatory Guide 1.146 during the operations phase of BVPS-2 is described in the FENOC Quality Assurance

Program Manual.

RG No. 1.147, Rev. 5 UFSAR Reference Section 6.6

INSERVICE INSPECTION CODE CASE ACCEPTABILITY ASME SECTION XI DIVISION 1 (AUGUST 1986)

Utilization of inservice inspection code cases for BVPS-2

follows the guidance of this regulatory guide.

All applicable ASME XI Code Cases utilized for BVPS-2 are

identified in the ASME Code Baseline Document.

RG No. 1.148, Rev. 0 UFSAR Reference Section 3.11

FUNCTIONAL SPECIFICATION FOR ACTIVE VALVE ASSEMBLIES IN SYSTEMS IMPORTANT TO SAFETY IN NUCLEAR POWER PLANTS (MARCH 1981)

BVPS-2 meets the intent of Regulatory Guide 1.148 for ensuring the operability of active valve assemblies in systems important

to safety with the following clarifications and alternatives:

Active valves are defined as those relied upon to perform a safety function (as well as a reactor shutdown function) during the transients or events considered in the

respective operating condition categories.

Active valves are subjected to analysis and tests to verify operability during a seismic event as described in UFSAR Section 3.9N.3.2 and 3.9B.3.2.2. Active valves also

undergo pre-installation operational tests and periodic in-service operational tests to verify and assure their

functional ability.

The overall design process includes systems design, valve specifications, and quality assurance procedures. Many of the functional requirements are included in the systems design which dictates the type of valve required for the system application. Inclusion of all requirements in a

specification to a valve manufacturer would provide information that is not required to manufacture the valves. Since the requirements are all integrated into the design process, a consolidation of all the requirements into a single document is considered

unnecessary.

BVPS-2 UFSAR Rev. 14 TABLE 1.8-1 (Cont) 90 of 91 RG No. 1.149, Rev. 0 UFSAR Reference Section 13.2 NUCLEAR POWER PLANT SIMULATORS FOR USE IN OPERATOR TRAINING (APRIL 1981)

The guidance of this regulatory guide is followed for simulators used in operator training for Beaver Valley Power Station -

Unit 2.

RG No. 1.150, Rev. 1 UFSAR Reference Section 5.3.1, 5.3.3

ULTRASONIC TESTING OF REACTOR VESSEL WELDS DURING PRESERVICE AND INSERVICE EXAMINATIONS (FEBRUARY 1983)

Ultrasonic testing of the reactor vessel welds during preservice and inservice examinations at BVPS-2 will follow the guidance of this regulatory guide as described in the Preservice Inspection Program, which was submitted to the NRC in Letter 2NRC-5-154, dated December 26, 1985, and the Inservice Inspection Program, which is scheduled to be submitted to the NRC in the last

quarter of 1986.

RG No. 1.155, June 1988 UFSAR Reference Section 8.3.1.1.19

STATION BLACKOUT

BVPS utilizes the emergency diesel generators at each unit as an alternate AC (AAC) power source to operate systems necessary for coping with a station blackout. The design of the cross-tie circuit between BVPS-1 and BVPS-2 AAC power sources conforms

with guidance provided by RG No. 1.155.

RG No. 1.163, September 1995 UFSAR Reference Section 6.2.6

PERFORMANCE-BASED CONTAINMENT LEAK TEST PROGRAM

The Containment Leakage Rate Testing Program is in accordance with the guidelines contained in RG No. 1.163 except as noted in the Technical Specifications. This regulatory guide provides guidance on an acceptable performance based leak test program, leakage rate test methods, procedures, and analyses that may be used to comply with the performance based Option B in Appendix J of 10 CFR 50.

BVPS-2 UFSAR Rev. 16 TABLE 1.8-1 (Cont) 91 of 91 RG No. 1.183, Rev. 0 ALTERNATIVE RADIOLOGICAL SOURCE TERMS FOR EVALUATING DESIGN BASIS ACCIDENTS AT NUCLEAR POWER REACTORS (JULY 2000)

This regulatory guide provides assumptions, methods and acceptance criteria that are acceptable to the NRC staff for performing design basis radiological analyses using an alternate

source term. With the exception of the Waste Gas System Rupture, this regulatory guide is utilized to evaluate the potential radiological consequences of all of the BVPS-2 design basis accidents.

RG No. 1.194, Rev. 0 ATMOSPHERIC RELATIVE CONCENTRATIONS FOR CONTROL ROOM RADIOLOGICAL HABITABILITY ASSESSMENTS AT NUCLEAR POWER PLANTS Control Room X/Q values were calculated using the NRC-sponsored ARCON96 computer code (NUREG/CR-6331, Revision 1, "Atmospheric Relative Concentrations in Building Wakes") and in a manner consistent with RG 1.194.

BVPS-2 UFSAR Rev. 16 1.9-1 1.9 STANDARD REVIEW PLAN CONFORMANCE EVALUATION In accordance with 10 CFR 50.34(g), this section provided an evaluation of Beaver Valley Power Station - Unit 2 (BVPS-2) against the USNRC Standard Review Plan [NUREG-0800], dated July 1981. Therefore, this section is being retained for historical perspectives. Submission of new material in this section is not required since design changes are incorporated in the text throughout the Updated FSAR.

The evaluation of BVPS-2 against each Standard Review Plan (SRP) includes an identification and description of all differences in design features, analytical techniques, and procedural measures proposed for BVPS-2 and those corresponding features, techniques, and measures given in the SRP acceptance criteria. Where such a difference exists, an evaluation is provided which discusses how the proposed alternative provided an acceptable method of complying with those USNRC rules or regulations, or portions thereof, that underlie the corresponding SRP acceptance

criteria.

Table 1.9-1 identifies each SRP against which BVPS-2 was evaluated. For those SRPs against which exceptions were taken, SRP conformance statements, which discuss and justify such alternatives to the SRP acceptance criteria, are provided in

Table 1.9-2.

BVPS-2 UFSAR Tables for Section 1.9

(Tables in Section 1.9 are historical)

BVPS-2 UFSAR Rev. 16 1 of 12 TABLE 1.9-1 STANDARD REVIEW PLAN CONFORMANCE (HISTORICAL)

CHAPTER 1: INTRODUCTION AND GENERAL DESCRIPTION OF PLANT Rev. Conform Exception 1.8 Interfaces for Standard Design...................................................................................... 1 N/A CHAPTER 2: SITE CHARACTERISTICS 2.1.1 Site Location a nd Description................................................................................. 2 X 2.1.2 Exclusion Area Authority and Control..................................................................... 2 X 2.1.3 Population Distribution........................................................................................... 2 X 2.2.1 - 2.2.2 Identification of Potential Hazards in Site Vicinity................................................... 2 X 2.2.3 Evaluation of Potential Accidents........................................................................... 2 X

2.3.1 Regional

Climatology............................................................................................. 2 X 2.3.2 Local Meteorology.................................................................................................. 2 X 2.3.3 Onsite Meteorological Measurements Programs................................................... 2 X

Appendix A.................................................................................................... 2 X 2.3.4 Short-Term Diffusion Estimates............................................................................. 1 X 2.3.5 Long-Term Diffusion Estimates.............................................................................. 2 X 2.4.1 Hydrologic Description........................................................................................... 2 X

Appendix A.................................................................................................... 2 X 2.4.2 Floods.................................................................................................................... 2 X 2.4.3 Probable Maximum Flood (PMF) on Streams and Rivers...................................... 2 X 2.4.4 Potential Dam Failures (Seismically-Induced)........................................................ 2 X 2.4.5 Probable Maximum Surge and Seiche Flooding.................................................... 2 X 2.4.6 Probable Maximum Ts unami Flooding................................................................... 2 X 2.4.7 Ice Effects.............................................................................................................. 2 X 2.4.8 Cooling Water Canals and Reservoirs................................................................... 2 X 2.4.9 Channel Diversions................................................................................................ 2 X 2.4.10 Flood Protection Requirements.............................................................................. 2 X 2.4.11 Cooling Water Supply............................................................................................

2 X 2.4.12 Ground Water......................................................................................................... BTP HGEB 1.......................................................................................................

2 2 X X 2.4.13 Accidental Releases of Liquid Effluents in Gr ound and Surface Waters................ 2 X 2.4.14 Technical Specifications and Emergency Operation Requirements....................... 2 X 2.5.1 Basic Geologic and Seismic Information................................................................ 2 X 2.5.2 Vibratory Ground Motion........................................................................................ 1 X 2.5.3 Surface Faulting..................................................................................................... 2 X BVPS-2 UFSAR Rev. 0 2 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 2.5.4 Stability of Subsurface Ma terials and Foundations....................................................... 2 X 2.5.5 Stability of Slopes.......................................................................................................... 2 X CHAPTER 3: DESIGN OF STRUCTURES, COMPONENTS, EQUIPMENT, AND SYSTEMS 3.2.1 Seismic Classification................................................................................................... 1 X 3.2.2 System Quality Group Classification............................................................................. 1 X Appendix A (formerly BTP RSB 3-1).................................................................... 1 X Appendix B (formerly BTP RSB 3-2).................................................................... 1 X Appendix C .......................................................................................................... 0 X Appendix D........................................................................................................... 0 X 3.3.1 Wind Loadings.............................................................................................................. 2 X 3.3.2 Tor nado Loadings......................................................................................................... 2 X 3.4.1 Flood Protection............................................................................................................ 2 X 3.4.2 Analysis Procedures..................................................................................................... 1 X 3.5.1.1 Internally Generated Missi les (Outside Containment)................................................... 2 X 3.5.1.2 Internally Generated Missi les (Inside Containment)...................................................... 2 X 3.5.1.3 Turbi ne Missiles............................................................................................................ 2 X 3.5.1.4 Missiles Generated by Natural Phenomena.................................................................. 2 X BTP AAB 3-2..............................................................................................................

1 X BTP ASB 3-2..............................................................................................................

2 X 3.5.1.5 Site Proximity Missiles (Except Aircraft)........................................................................ 1 X 3.5.1.6 Aircra ft Hazards............................................................................................................ 1 X 3.5.2 Structures, Systems, and Components to be Protected from Externally Generated Missiles....................................................................................

2 X 3.5.3 Barrier Design Procedures............................................................................................ 1 X Appendix A................................................................................................................. 0 X 3.6.1 Plant Design for Protection Against Postulated Piping Failures in Fluid Systems Outs ide Containment...................................................................................

1 X BTP ASB 3-1..............................................................................................................

1 X 3.6.2 Determination of Rupture Locations and Dynamic Effects Associated with the Postulated Rupture of Piping........................................................................

1 X BTP MEB 3-1............................................................................................................. 1 X 3.7.1 Seismic Design Parameters.......................................................................................... 1 X 3.7.2 Seismic System Analysis.............................................................................................. 1 X 3.7.3 Seismic Subsystem Analysis......................................................................................... 1 X 3.7.4 Seismic Instrumentation................................................................................................ 1 X BVPS-2 UFSAR Rev. 0 3 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 3.8.1 Concrete Containment.................................................................................................. 1 X 3.8.2 Steel Containment......................................................................................................... 1 X 3.8.3 Concrete and Steel Internal Structures of Steel or Concrete Containments................. 1 X 3.8.4 Other Seismic Category I Structures.............................................................................

1 X 3.8.5 Found ations.................................................................................................................. 1 X 3.9.1 Special Topics for Mec hanical Components................................................................. 2 X 3.9.2 Dynamic Testing and Analysis of Systems, Components, and Equipment................... 2 X 3.9.3 ASME Code Class 1, 2 and 3 Components, Component Supports, and Core Support Structures.............................................................................................

1 X Appendix A........................................................................................................... 0 X 3.9.4 Control Rod Drive Systems........................................................................................... 1 X 3.9.6 Inservice Testing of Pumps and Valves........................................................................ 2 X 3.10 Seismic Qualification of Category I Instru mentation and Electrical Equipment.............

2 X 3.11 Environmental Design of Mechanical a nd Electrical Eq uipment.................................... 2 X CHAPTER 4: REACTOR 4.2 Fuel System Design......................................................................................................

2 X 4.3 Nuclear Design.............................................................................................................. 2 X BTP CPB 4.3-1........................................................................................................... 2 X 4.4 Thermal and Hydraulic Design...................................................................................... 1 X Appendix.............................................................................................................. 1 X 4.5.1 Control Rod Drive Structural Ma terials.......................................................................... 2 X 4.5.2 Reactor Internal and Core Support Materials................................................................ 2 X 4.6 Functional Design of Control Rod Drive System........................................................... 1 X CHAPTER 5: REACTOR COOLANT SYSTEM AND CONNECTED SYSTEMS 5.2.1.1 Compliance with Codes and Standard Rule 10 CF R 50.55a......................................... 2 X 5.2.1.2 Applicable Codes Cases............................................................................................... 2 X 5.2.2 Overpressure Protection............................................................................................... 1 X BTP RSB 5-2..............................................................................................................

0 X 5.2.3 Reactor Coolant Pressure Boundary Materials............................................................. 2 X BTP MTEB 5-7........................................................................................................... 2 X BVPS-2 UFSAR Rev. 0 4 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 5.2.4 Reactor Coolant Pressure Boundary Inservic e Inspection and Testing........................ 1 X 5.2.5 Reactor Coolant Pressure Boundary Leakage Detection.............................................. 1 X 5.3.1 Reactor Vessel Materials.............................................................................................. 1 X 5.3.2 Pressure-Temperat ure Limits........................................................................................ 1 X BTP MTEB 5-2........................................................................................................... 1 X 5.3.3 Reactor Vessel Integrity................................................................................................ 1 X 5.4 Preface.......................................................................................................................... 1 X 5.4.1.1 Pump Flywheel Integrity (PWR).................................................................................... 1 X 5.4.2.1 Steam Generat or Materials........................................................................................... 2 X BTP MTEB 5-3........................................................................................................... 2 X 5.4.2.2 Steam Generator Tube In service Inspection................................................................. 1 X 5.4.6 Reactor Core Isolation Cooling System (BWR)............................................................. 2 N/A 5.4.7 Residual Heat Removal (RHR) System........................................................................ 2 X BTP RSB 5-1..............................................................................................................

2 X 5.4.8 Reactor Water Cleanup System (BWR)........................................................................ 2 N/A 5.4.11 Pressurize r Relief Tank................................................................................................. 2 X 5.4.12 Reactor Coolant System High Point Vents.................................................................... 0 X CHAPTER 6: ENGINEERED SAFETY FEATURES 6.1.1 Engineered Safety Features Materials.......................................................................... 2 X BTP MTEB 6-1........................................................................................................... 2 X 6.1.2 Protective Coating Systems (Pai nts) - Organic Materials.............................................. 2 X 6.2.1 Containment Functional Design.................................................................................... 2 X 6.2.1.1A PWR Dry Containments, Including Sub-atmospheric Containments............................. 2 X 6.2.1.1B Ice C ondenser Containments........................................................................................ 2 N

/A 6.2.1.1C Pressure-Suppression Ty pe BWR Containments......................................................... 4 N/A Appendix I............................................................................................................ 1 N/A 6.2.1.2 Subcompartment Analysis............................................................................................. 2 X 6.2.1.3 Mass and Energy Release Analysis for Postulated Loss-of-Coolant Accidents 1 X 6.2.1.4 Mass and Energy Release Analysis for Postulated Secondary System Pipe Ruptures............................................................................................................

1 X BVPS-2 UFSAR Rev. 0 5 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 6.2.1.5 Minimum Containment Pressure Analysis for Emergency Core Cooling System Performance Capability Studies....................................................................

2 X BTP CSB 6-1..............................................................................................................

2 X 6.2.2 Containment Heat Removal Systems........................................................................... 3 X 6.2.3 Secondary Containment Functiona l Design.................................................................. 2 X BTP CSB 6-3..............................................................................................................

2 X 6.2.4 Containment Isolation System....................................................................................... 2 X BTP CSB 6-4..............................................................................................................

2 X 6.2.5 Combustible Gas Contro l in Containment..................................................................... 2 X Appendix A........................................................................................................... 2 X 6.2.6 Containment Leakage Testing...................................................................................... 2 X 6.2.7 Fracture Prevention of Contai nment Pressure Boundary.............................................. 5 6.3 Emergency Core Cooling System................................................................................. 1 X BTP RSB 6-1..............................................................................................................

1 X 6.4 Control Room Habitability Systems............................................................................... 2 X Appendix A........................................................................................................... 2 X 6.5.1 ESF Atmosphere Cleanup Systems.............................................................................. 2 X 6.5.2 Containment Spray as a Fissi on Product Cleanup System........................................... 1 X 6.5.3 Fission Product Control Sy stems and Structures.......................................................... 2 X 6.5.4 Ice Condenser as a Fission Product Cleanup System.................................................. 2 X 6.6 Inservice Inspection of Class 2 and 3 Components...................................................... 1 X 6.7 Main Steam Isol ation Valve Leakage Control System (BWR)....................................... 2 N/A CHAPTER 7: INSTRUMENTATION AND CONTROLS

7.1 Instrumentatio

n and Controls - In troduction.................................................................. 2 X Table 7-1 Acceptance Criteria and Guidelines for Instrumentation and Controls Sy stems Important to Safety..................................................................

2 X 7.2 Reactor Trip System..................................................................................................... 2 X Appendix A........................................................................................................... 2 X 7.3 Engineered Safety Features Systems........................................................................... 2 X Appendix A........................................................................................................... 2 X 7.4 Safe Shutdown Systems............................................................................................... 2 X 7.5 Information Systems Impor tant to Safety...................................................................... 2 X BVPS-2 UFSAR Rev. 0 6 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 7.6 Interlock Systems Impor tant to Safety........................................................................... 2 X 7.7 Control Systems............................................................................................................ 2 X Appendix 7A Branch Technica l Positions (ICSB)............................................................................... 2 X BTP ICSB 1 (DOR).................................................................................................... 2 X BTP ICSB 3................................................................................................................ 2 X BTP ICSB 4 (PSB)..................................................................................................... 2 X BTP ICSB 5................................................................................................................ 2 X BTP ICSB 9................................................................................................................ 2 X BTP ICSB 12.............................................................................................................. 2 X BTP ICSB 13.............................................................................................................. 2 X BTP ICSB 14.............................................................................................................. 2 X BTP ICSB 16.............................................................................................................. 2 X BTP ICSB 19.............................................................................................................. 2 X BTP ICSB 20.............................................................................................................. 2 X BTP ICSB 21.............................................................................................................. 2 X BTP ICSB 22.............................................................................................................. 2 X BTP ICSB 25.............................................................................................................. 2 X BTP ICSB 26.............................................................................................................. 2 X Appendix 7B General Agenda, Station Site Visits.............................................................................. 1 X CHAPTER 8: ELECTRIC POWER 8.1 Electric Power - Introduction......................................................................................... 2 X Table 8-1 Acceptance Criteria and Guidelines for Electric Power Systems....................................................................................................

2 X 8.2 Offsite Power System....................................................................................................

2 X 8.3.1 AC Power System s (Onsite).......................................................................................... 2 X 8.3.2 DC Power System s (Onsite)......................................................................................... 2 X Appendix 8A Branch Techni cal Positions (PSB)................................................................................

2 X BTP ICSB 2 (PSB)..................................................................................................... 2 X BTP ICSB 4 (PSB)..................................................................................................... 2 X BTP ICSB 8 (PSB)..................................................................................................... 2 X BTP ICSB 11 (PSB)................................................................................................... 2 X BTP ICSB 15 (PSB)................................................................................................... 2 N/A BTP ICSB 17 (PSB)................................................................................................... 2 X BTP ICSB 18 (PSB)................................................................................................... 2 X BTP ICSB 21 (PSB)................................................................................................... 2 X BTP PSB 1................................................................................................................. 0 X BTP PSB 2................................................................................................................. 0 X Appendix 8B General Agenda, Station Site Visits.............................................................................. 0 X CHAPTER 9: AUXILIARY SYSTEMS 9.1.1 New Fuel Storage......................................................................................................... 2 X BVPS-2 UFSAR Rev. 0 7 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 9.1.2 Spent Fuel Storage....................................................................................................... 3 X 9.1.3 Spent Fuel Pool Cooling and Cleanup System............................................................. 1 X 9.1.4 Light Load Handling System (Related to Ref ueling)...................................................... 2 X BTP ASB 9-1..............................................................................................................

2 X 9.1.5 Overhead Heavy Load Handling Systems.................................................................... 0 X 9.2.1 Station Service Water System....................................................................................... 2 X 9.2.2 Reactor Auxiliary Cooling Water Systems..................................................................... 1 X 9.2.3 Demineralized Water Makeup Systems........................................................................ 2 X 9.2.4 Potable and Sanitary Water System............................................................................. 2 X 9.2.5 Ultimate Heat Sink........................................................................................................ 2 X BTP ASB 9-2..............................................................................................................

2 X 9.2.6 Condensate Storage Facilities...................................................................................... 2 X 9.3.1 Compressed Air System................................................................................................

1 X 9.3.2 Process and Po st-Accident Sampling Systems............................................................. 2 X 9.3.3 Equipment and Floor Drainage System........................................................................ 2 X 9.3.4 Chemical and Volume Control System (PWR) (Including Boron Recovery System)......................................................................................................

2 X 9.3.5 Standby Liquid Control System (BWR)......................................................................... 2 N/A 9.4.1 Control Room Area Ventilation System......................................................................... 2 X 9.4.2 Spent Fuel Pool Area Ventilation System..................................................................... 2 X 9.4.3 Auxiliary and Radwaste Area Ventilation System.......................................................... 2 X 9.4.4 Turbine Area Ventilation System................................................................................... 2 N/A 9.4.5 Engineered Safety Feature Ventilation System.............................................................

2 X 9.5.1 Fire Protection Program................................................................................................ 3 X BTP CMEB 9.5-1........................................................................................................ 2 X 9.5.2 Communications Systems............................................................................................. 2 X 9.5.3 Lighting Systems........................................................................................................... 2 X 9.5.4 Emergency Diesel Engine Fuel Oil Storage and Transfer System................................ 2 X 9.5.5 Emergency Diesel Engine Cooling Water System........................................................ 2 X

9.5.6 Emergenc

y Diesel Engine Starting System................................................................... 2 X 9.5.7 Emergency Diesel Engine Lubrication System..............................................................

2 X 9.5.8 Emergency Diesel Engine Combustion Air Intake and Exhaust System....................... 2 X BVPS-2 UFSAR Rev. 0 8 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception CHAPTER 10: STEAM AND POWER CONVERSION SYSTEM 10.2 Turbine Generator......................................................................................................... 2 X 10.2.3 Turbine Disk Integrity.................................................................................................... 1 X 10.3 Main Steam Supply System..........................................................................................

2 X 10.3.6 Steam and Feedwater Sy stem Materials....................................................................... 2 X 10.4.1 Main Condensers.......................................................................................................... 2 X 10.4.2 Main Condenser Evacuation System............................................................................ 2 X 10.4.3 Turbine Gland Sealing System...................................................................................... 2 X 10.4.4 Turbine Bypass System................................................................................................

2 X 10.4.5 Circulating Water System..............................................................................................

2 X 10.4.6 Condensate Cleanup System........................................................................................ 2 X 10.4.7 Condensate and Feedwater System............................................................................. 2 X BTP ASB 10-2............................................................................................................ 2 X 10.4.8 Steam Generator Blowdown System (PWR)................................................................. 2 X 10.4.9 Auxiliary Feedwater System (PWR).............................................................................. 2 X BTP ASB 10-1............................................................................................................ 2 X CHAPTER 11: RADIOACTIVE WASTE MANAGEMENT 11.1 Source Terms................................................................................................................ 2 X 11.2 Liquid Waste Management Systems............................................................................. 2 X 11.3 Gaseous Waste Management Systems........................................................................ 2 X BTP ETSB 11-5.......................................................................................................... 0 X 11.4 Solid Waste Management Systems..............................................................................

2 X BTP ETSB 11-3.......................................................................................................... 2 X Appendix 11.4-A................................................................................................... 0 X 11.5 Process and Effluent Radiological Monitoring Instrumentation and Sampling Systems.....................................................................................................

3 X Appendix 11.5-A 1 X CHAPTER 12: RADIATION PROTECTION 12.1 Assuring That Occupational Radiation Exposures are as Low as is Reasonably Achievable..............................................................................................

2 X 12.2 Radiatio n Sources......................................................................................................... 2 X 12.3-12.4 Radiation Protecti on Design Features........................................................................... 2 X 12.5 Operational Radiation Protection Program.................................................................... 2 X CHAPTER 13: CONDUCT OF OPERATIONS 13.1.1 Management and Technical Support Organization....................................................... 2 X BVPS-2 UFSAR Rev. 0 9 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 1.3.1.2- 13.1.3 Operating Organization................................................................................................. 2 X 13.2.1 Reactor Operating Training........................................................................................... 0 X 13.2.2 Training for Non-Licensed Plant Staff...........................................................................

0 X 13.3 Emergency Planning..................................................................................................... 2 X 13.4 Operational Review....................................................................................................... 2 X 13.5.1 Administrati on Procedures............................................................................................ 0 X 13.5.2 Operating and Maintenance Pr ocedures....................................................................... 0 X 13.6 Physical Security........................................................................................................... 2 X CHAPTER 14: INITIAL TEST PROGRAM 14.1 Initial Plant Test Programs - PSAR............................................................................... 2 N/A 14.2 Initial Plant Test Programs - FSAR............................................................................... 2 X 14.3 Standard Plant Designs, Initial Test Program Final Design Approval (FDA)................. 1 N/A CHAPTER 15: ACCIDENT ANALYSIS 15.0 Intr oduction................................................................................................................... 2 N/A 15.1 INCREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM 15.1.1-15.1.4 Decrease in Feedwater Temperature, Increase in Feedwater Flow, Increase in Steam Flow, and Inadvertent Opening of a Steam Generator Relief or Safety Valve...........................................................................................................

1 X 15.1.5 Steam System Piping Fail ures Inside and Outside of Containment (PWR)..................

2 X Appendix A................................................................................................................. 2 X 15.2 DECREASE IN HEAT REMOVAL BY THE SECONDARY SYSTEM 15.2.1-15.2.5 Loss of External Load, Turbine Trip, Loss of Condenser Vacuum, Closure of Main Steam Isolation Valve (BWR), and Steam Pressure Regulatory

Failure (Closed)..........................................................................................................

1 X 15.2.6 Loss of Nonemergency AC Power to the Station Auxiliaries......................................... 1 X 15.2.7 Loss of Normal Feedwater Flow.................................................................................... 1 X 15.2.8 Feedwater System Pipe Breaks Inside and Outside Containment (PWR)....................

1 X BVPS-2 UFSAR Rev. 0 10 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 15.3 DECREASE IN REACTOR COOLANT SYSTEM FLOW RATE 15.3.1-15.3.2 Loss of Forced Reactor Coolant Flow Including Trip of Pump and Flow Controller Malfunctions...............................................................................................

1 X 15.3.3-15.3.4 Reactor Coolant Pump Rotor Seizure and Reactor Coolant Pump Shaft Break................................................................................................................

2 X 15.4 REACTIVITY AND POWER DISTRIBUTION ANOMALIES 15.4.1 Uncontrolled Control Rod Assembly Withdrawal from a Subcritical or Low Power Startu p Condition............................................................................................

2 X 15.4.2 Uncontrolled Control Rod Assembly Withdrawal at Power............................................

2 X 15.4.3 Control Rod Misoperation (System Malfunction or Operator Error)............................... 2 X 15.4.4-15.4.5 Startup of an Inactive Loop or Recirculation Loop at an Incorrect Temperature, and Flow Controller Malfunction Causing an Increase in BWR Core Flow Rate.................................................................................................

1 X 15.4.6 Chemical and Volume Control System Malfunction That Results in a Decrease in the Boro n Concentration in the R eactor Coolant (PWR)........................

1 X 15.4.7 Inadvertent Loading and Operation of a Fuel Assembly in an Improper Position...................................................................................................................... 1 X 15.4.8 Spectrum of Rod Ejecti on Accidents (PWR)................................................................. 2 X Appendix A........................................................................................................... 1 X 15.4.9 Spectrum of Rod Drop Accidents (BWR)...................................................................... 2 N/A Appendix A........................................................................................................... 2 N/A 15.5 INCREASE IN REACTOR COOLANT INVENTORY 15.5.1-15.5.2 Inadvertent Operation of ECCS and Chemical and Volume Control System Malfunction that Increases Reactor Coolant Inventory...............................................

1 X BVPS-2 UFSAR Rev. 0 11 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception 15.6 DECREASE IN REACTOR COOLANT INVENTORY 15.6.1 Inadvertent Opening of a PWR Pressurizer Safety/Relief Valve or a BWR Safety/Rel ief Valve.....................................................................................................

1 X 15.6.2 Radiological Consequences of the Failure of Small Lines Carrying Primary Coolant Outside Cont ainment.......................................................................

2 X 15.6.3 Radiological Consequences of Steam Generator Tube Failure (PWR)......................... 2 X 15.6.4 Radiological Consequences of Main Steam Line Failure Outside Containment (BWR)...................................................................................................

2 N/A 15.6.5 Loss-of-Coolant Accidents Resulting from Spectrum of Postulated Piping Breaks Within the Reactor Coolant Pressure Boundary.............................................

2 X Appendix A........................................................................................................... 1 X Appendix B........................................................................................................... 1 X Appendix C........................................................................................................... 2 X Appendix D........................................................................................................... 1 X 15.7 RADIOACTIVE RELEASE FROM A SUBSYSTEM OR COMPONENT 15.7.1 Waste Gas Syst em Failure............................................................................................ 1 X 15.7.2 Radioactive Liquid Waste System Leak or Failure (Release to Atmosphere)...............................................................................................................

1 N/A 15.7.3 Postulated Radioactive Release Due to Liquid-Containing Tank Failures.................... 2 X 15.7.4 Radiological Consequences of Fuel H andling Accidents.............................................. 1 X 15.7.5 Spent Fuel Cask Dr op Accidents.................................................................................. 2 X 15.8 ANTICIPATED TRANSIENTS WITHOUT SCRAM 15.8 Anticipated Transients Without Scram.......................................................................... 1 X Appendix.............................................................................................................. 1 X CHAPTER 16: TECHNICAL SPECIFICATIONS 16.0 Technical Specifications................................................................................................ 1 X CHAPTER 17: QUALITY ASSURANCE 17.1 Quality Assurance During the Desi gn and Constructi on Phases................................... 2 X 17.2 Quality Assurance During th e Operations Phase.......................................................... 2 X BVPS-2 UFSAR Rev. 0 12 of 12 TABLE 1.9-1 (Cont)

Rev. Conform Exception CHAPTER 18: HUMAN FACTORS ENGINEERING 18.0 Human Factors Engineering/Standard Review Plan Development............................... 0 N/A X

BVPS-2 SRP Rev. 16 1 of 93 TABLE 1.9-2 SRP CONFORMANCE STATEMENTS (HISTORICAL)

SRP NO. 2.3.2

TITLE: LOCAL METEOROLOGY DIFFERENCES FROM THE SRP:

5- and 50-mile detailed topographic maps are not provided.

REMARKS:

During a telephone communication between S. A. Vigeant (SWEC) and J. Levine (USNRC) on January 13, 1982, the USNRC indicated that topographic cross sections are sufficient for USNRC review and detailed maps do not necessarily need to be provided.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 2 of 93 SRP NO. 2.4.11

TITLE: COOLING WATER SUPPLY DIFFERENCES FROM THE SRP:

A means of assuring that sediment accumulation is adequately controlled is not discussed in FSAR Section 2.4.11.

REMARKS:

Administrative controls assure that sediment is removed periodically.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 3 of 93 SRP NO. 2.4.12

TITLE: GROUND WATER DIFFERENCES FROM THE SRP:

The information requested by SRP 2.4.12 is provided in FSAR Section 2.4.13. A discussion of accident effects on ground

water is also provided.

REMARKS:

The discussion of ground water presented in FSAR Section 2.4.13 is in accordance with the content requirements of Regulatory Guide 1.70, Rev. 3. The discussion of ground water in FSAR Section 2.4.13 is in full conformance with SRPs 2.4.12 and 2.4.13.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 4 of 93 SRP NO. 2.4.13

TITLE: ACCIDENTAL RELEASES OF LIQUID EFFLUENTS IN GROUND AND SURFACE WATERS

DIFFERENCES FROM THE SRP:

The information requested by SRP 2.4.13 on dilution and travel times of accidental releases in surface waters is provided in FSAR Section 2.4.12.

REMARKS:

The discussion of accidental releases of liquid effluents in ground and surface waters is in accordance with the content requirements of Regulatory Guide 1.70, Rev. 3. The discussions of accidental releases to ground water in FSAR Section 2.4.13 and accidental releases to surface water in FSAR Section 2.4.12 are in full conformance with SRP 2.4.13.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 5 of 93 SRP NO. 2.5.1

TITLE: BASIC GEOLOGIC AND SEISMIC INFORMATION DIFFERENCES FROM THE SRP:

Gravity and aeromagnetic maps are not provided.

REMARKS:

At the present time a gravity map of Pennsylvania that includes

the site region is not available.

Aeromagnetic maps are available but show only broad regional

trends which provide no additional site-specific information.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 6 of 93 SRP NO. 2.5.2

TITLE: VIBRATORY GROUND MOTION DIFFERENCES FROM THE SRP:

SRP 2.5.2 suggests that a calculation to determine the probability of exceeding the accelerating level of the OBE during the life of the plant may be helpful. Regulatory Guide 1.70 requires the calculation. This determination is not provided.

REMARKS:

A determination of the probability of exceeding the OBE during the operating life of the plant was not considered necessary because the OBE acceleration level was taken as one-half the SSE

in accordance with Appendix A to 10 CFR 100.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 7 of 93 SRP NO. 2.5.4

TITLE: STABILITY OF SUBSURFACE MATERIALS AND FOUNDATIONS DIFFERENCES FROM THE SRP:

The SRP suggests that static and dynamic properties of in situ and backfill materials be supported by laboratory test data.

Laboratory testing was not performed on samples of the in situ sands and gravels within the main plant area since it was not possible to obtain undisturbed samples from the boring investigations due to the gravel content of the soils.

Grain size analyses, in-place density tests, and compaction tests were performed on compacted backfill material as part of the site quality assurance program. However, laboratory

determinations of engineering strength properties were not made.

REMARKS:

Since suitable undisturbed soil samples could not be obtained, the static and dynamic properties of the in situ sands and gravels at the site were determined from accepted, conservative empirical correlations of engineering properties to subsurface conditions determined by test borings, geophysical testing, and

field testing. For instance, shear modulus was evaluated by the equation presented by Hardin and Drenevich (1972) and was compared with that computed from in situ measurements of shear

wave velocity. The permeability of the in situ sands was determined from field permeability tests. Soil unit weights were evaluated from the results of in-place density tests made at the foundation level of the reactor containment. The friction angle was based upon correlations with relative density determined from standard penetration test blow count data

obtained from test borings. The susceptibility of the soils at the site was based upon the observed behavior of similar sites during previous earthquakes (DLC 1976) and by using test data from dynamic laboratory tests performed to be more susceptible to liquefaction than the soils at the site (DLC 1972).

Similar methods were used to evaluate the engineering properties of the material used for compacted structural or select granular fill.

Liquefaction analyses are generally performed with the ground-water level assumed coincident with that corresponding to the 25-year flood, which for BVPS-2 is at el 690. With the exception of an area beneath the reactor containment (FSAR Figure 2.5.4-19), structural or select granular fill was placed above el 690 and as such would not be subject to liquefaction. Consequently, tests to evaluate its susceptibility to liquefaction were not performed.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 8 of 93

REFERENCES:

Duquesne Light Company (DLC) 1972. Preliminary Safety Analysis Report - Beaver Valley Power Station - Unit 2, Section 2.6.5.2.

Prepared by SWEC, Boston, Mass.

Duquesne Light Company (DLC) 1976. Report on the Soil Densification Program - Beaver Valley Power Station - Unit 2.

Harding, B.O. and Drenevich, V.P. 1972. Shear Modulus and Damping in Soils, Design Equations. Journal of Soil Mechanics

and Foundation Division, Vol. 98, SM-7. ASCE.

BVPS-2 SRP Rev. 18 TABLE 1.9-2 (Cont)

9 of 93 SRP NO. 3.2.2

TITLE: SYSTEM QUALITY GROUP CLASSIFICATION

DIFFERENCES FROM THE SRP:

BVPS-2 uses the safety classification system provided in ANSI N18.2 as an acceptable alternative to the Regulatory Guide 1.26 quality group classification system. FSAR Section 3.2.2 provides a cross reference between the ANS safety classifications end the quality groups defined in Regulatory

Guide 1.26.

REMARKS:

The ANS classification system implemented for BVPS-2 has been

endorsed by industry as an alternative accepted by the USNRC for many other plants and meets the requirements of GDC 1 and 10 CFR

50.55a.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 10 of 93 SRP NO. 3.3.1

TITLE: WIND LOADINGS DIFFERENCES FROM THE SRP:

ANSI A58.1, "Building Code Requirements for Minimum Design Loads in Buildings and Other Structures," was not used as a basis for

developing wind loads.

REMARKS:

ASCE Paper No. 3269, "Wind Force on Structures," was used as a basis for developing wind loads; this provides sufficient

guidance for satisfying the requirements of GDC 2.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 11 of 93 SRP NO. 3.5.1.3

TITLE: TURBINE MISSILES DIFFERENCES FROM THE SRP:

Acceptance Criterion II.1 does not apply to the BVPS-2 plant design arrangement. However, protection against low-trajectory

turbine missiles at Beaver Valley Power Station - Unit 2 (BVPS-2) does meet the overall risk acceptance guidelines recommended by this SRP.

REMARKS:

The latest technical advances in the design and analysis of Westinghouse low-pressure turbine rotors is used to provide assurance of turbine disc integrity. Improved disc integrity,

overspeed protection, and a comprehensive inspection program provides sufficient missile protection to meet the overall risk acceptance guidelines and maintain acceptably low probabilities.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 12 of 93 SRP NO. 3.6.1

TITLE: PLANT DESIGN FOR PROTECTION AGAINST POSTULATED PIPING FAILURES IN FLUID SYSTEMS OUTSIDE CONTAINMENT

DIFFERENCES FROM THE SRP (BRANCH TECHNICAL POSITION ASB 3-l):

1. BTP ASB-1, paragraph B.1.a(l) suggests that essential equipment be separated from the main steam and feedwater piping and be protected from the effects of a one square foot break of these lines, even though these lines are designed to the "break exclusion" criteria of MEB 3-1. BVPS-2 has determined the resultant environment (pressure, temperature, and humidity) due to the one square foot break and has evaluated the effects on safety-related equipment. Dynamic effects (e.g. pipe whip, jet impingement, and pressurization), structural effects, and flooding have not been considered for the arbitrary one square foot break. Additionally, essential components are not enclosed within structures or compartments as suggested in BTP ASB-1,

paragraph B.1.b.

2. Item B.2.c recommends that high energy piping between the containment isolation valves be designed to meet the "break exclusion" criteria of MEB 3-1. On BVPS-2, the only high energy piping in containment penetration areas designed for "break exclusion" are the main steam and feedwater lines as well as the high energy branch lines contained within the main steam valve house. In addition, non-nuclear safety

class piping is contained within the break exclusion zone.

3. Item B.2.d requires the break excluded piping outboard of the isolation valves to the first restraint be maintained as the same piping classification as the inboard piping. On BVPS-2, the piping class outboard of the isolation valve is

designated non-nuclear safety, QA Category II.

4. Item B.3.b(3) limits the exclusion of single active component failures to certain dual-purpose moderate energy essential systems. However, BVPS-2 employs this criterion to dual-purpose systems in general (i.e., high and moderate energy systems). For example, after a postulated pipe rupture in a CVCS pump discharge line, a single active failure of the idle pump in the redundant train to start is

not postulated.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 12a of 93 REMARKS:

1. These differences are due to the addition of later NRC criteria than were utilized during the plant design stage,

i.e.; the arbitrary one square foot break. BVPS-2 has met

the intent of BTP-ASB 3-1, B.la. and lb., by evaluating the environmental effects of the arbitrary break on safety-related equipment. This degree of conformance is allowed by

BTP-ASB 3-1, paragraph B.lc.

2. The only other high energy piping systems which penetrate the reactor containment are the steam generator blowdown and chemical and volume control systems. It is not necessary to break exclude either of these two systems in containment

penetration areas because:

1. Containment isolation capability is not required to mitigate the effects of a break in either system.
2. These pipe breaks can all be isolated in consideration of single active failures.

Refer to Difference and Remark 3 for an explanation of the

NNS piping.

3. The piping outboard of the isolation valve, although QA Category II, is analyzed to Seismic Category I criteria from the isolation valve to the terminal anchor (6-way restraint) which is located outside the break exclusion area. The

actual break excluded piping is the Class 2 portion from the penetration to the isolation valve and then the non-nuclear safety class high energy piping and branch lines to the main steam valve house wall. Although non-nuclear safety class piping which consists of ANSI B31.1 material has been included in the break exclusion zone, it has been analyzed

in accordance with the criteria of MB 3-1, Item B1.b for ASME III Class 2 material. All piping within the extended break exclusion zone is subjected to the augmented ISI criteria of MEB 3-1, Item B1.b.(7). Also refer to differences from SRP Section 3.6.2.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 12b of 93 4. The BVPS-2 position is in accordance with current industry practice as defined in American National Standard ANSI/ANS 51.1 - 1983 (Appendix B, Section B5 "Application of the Single Failure Criterion"), and ANSI/ANS 58.9 - 1981 (Section 4.5) which makes no distinction between high and

moderate energy dual purpose safety-related fluid systems.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 12c of 93 SRP NO. 3.6.2

TITLE: DETERMINATION OF RUPTURE LOCATIONS AND DYNAMIC EFFECTS ASSOCIATED WITH THE POSTULATED RUPTURE OF PIPING

DIFFERENCES FROM THE SRP:

1. BTP MEB 3-1, paragraph B.1.b, states that breaks need not be postulated in those portions of Class 2 piping from the containment wall to and including the inboard or outboard isolation valve.

The BVPS-2 criteria state that breaks need not be postulated in those portions of high energy lines designated as break

exclusion zones:

a. Between the containment penetration and the outboard isolation valve. These portions of Class 2 piping are designed to ASME III, Subarticle NE-1120.
b. Between the containment isolation valves and the Main Steam Valve House (MSVH)/Service Building wall. This includes all MSS high-energy branch lines within the MSVH. All non-nuclear safety (NNS) portions of the break excluded piping are designed in accordance with ANSI B31.1.
2. BTP MEB 3-1, paragraph B.1.c(l), states that breaks should be postulated...at intermediate locations where the maximum

stress range as calculated by Eq. (10) and either Eq. (12) or (13) exceeds 2.4 Sm.

The BVPS-2 criteria states that breaks should be postulated at any intermediate location where the maximum stress range as calculated by Eq. (10) and either Eq. (12) or (13)

exceeds 3.0 Sm.

3. SRP 3.6.2 paragraph III.2.C.(4) states that for the jet thrust force T=KpA to be acceptable, K values should not be

less than 1.26 for steam, saturated water, or steam-water mixtures, or 2.0 for subcooled, nonflashing water. The

BVPS-2 criteria states that values of K or K for jet impingement evaluation may be reduced below the 1.26 and 2.00 limits where justified by consideration of pressure

drop due to frictional effects.

4. BTP MB 3-1, paragraph B.1.c(l)(d), states that if stresses and usage factors at two intermediate locations in a Class 1 piping or branch run do not exceed the threshold values for postulating

BVPS-2 SRP Rev. 13 TABLE 1.9-2 (Cont) 12d of 93 break then the...two highest stress locations based on

Equation (10) should be selected.

The BVPS-2 criteria states that intermediate breaks are postulated only at those locations where the stresses and/or usage factors exceed the threshold values specified in BTP MEB 3-1, paragraph B.l.c(l)(b) and B.1.c(l)(c).

5. BTP MEB 3-1, paragraph B.1.c(2)(b)(ii), states that if the stresses in a Class 2 or 3 piping or branch run do not exceed the threshold value for postulating breaks then intermediate breaks are postulated...at not less than two separated locations chosen on the basis of highest stress.

The BVPS-2 criteria states that intermediate breaks are postulated only at those locations where the stresses exceed the threshold values specified in paragraph B.1.c(2)(b)(ii) for the following system:

1. Reactor Coolant System (not including the primary loop)
2. Hydrogenated Drain System
3. Residual Heat Removal System
4. Safety Injection System
5. Main Steam System
6. Main Feedwater System
7. Auxiliary Feedwater System
8. Steam Generator Blowdown System
9. Chemical and Volume Control System
10. Gaseous Nitrogen System
11. Auxiliary Steam System
6. SRP 3.6.2,Section III.3(c) states that "...the jet (from a ruptured high energy pipe) is time and distance

invarient...".

The BVPS-2 criteria allows the use of a 10 diameter limit for certain piping systems in establishing the range of jet

effects.

7. SRP 3.6.2 and associated sections of BTP MEB 3-1 specify criteria for postulation of piping ruptures.

BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 12e of 93 BVPS-2 has invoked the current GDC-4 and an earlier schedular exemption granted to delete these pipe ruptures

from the design basis.

8. SRP 3.6.2 and associated sections of BTP MEB 3-1 specify criteria for postulation of high energy line piping

ruptures.

BVPS-2 has submitted analyses under NUREG-1061 (Vol. 3) qualifying certain ASME III Class 1 and 2 lines for exemption from pipe rupture postulation.

REMARKS:

1. The BVPS-2 criteria provide an acceptable alternative method of complying with GDC 4 by following the guidance of NUREG-

75/087 (November 1975). In addition:

a. The NNS piping has been seismically designed as described in Section 3.2.1.2.
b. The NNS piping has been designed to the additional design criteria per paragraphs B.1.b(l)(d), B.1.b(l)(e) and B.1.b(2) - B.1.b(7).
c. The NNS piping except for the 32" main steam piping is of seamless construction.
d. The 32" NNS main steam piping is electric fusion welded pipe manufactured to ASTM A-155, KC-70. Class 1 requirements. In addition, the plate used in this manufacturing process was ultrasonically examined in

accordance with ASTM A-577-69.

e. The weld material used in NNS pipe spool fabrication and installation conforms and is certified to ASME Code,Section II requirements.
2. BVPS-2 Code Class 1 piping has been designed to the requirements of the ASME Code,Section III (ASME III), 1971 Edition through the Winter 1972 Addenda. In this version of ASME III (ref. paragraph NB-3653) Equation 10 includes a stress term for a linear through wall temperature gradient referred to as 1T.1. This stress term is not included in Equation 10 specified in versions of ASME III later than the 1977 Edition through Summer 1979 Addenda. Applying 2.4 Sm as the threshold level in determining intermediate break

locations is not considered appropriate when stress intensity ranges are calculated using the more conservative version of Equation 10 specified in the ASME III edition and Addenda applicable for BVPS-2 Code Class 1 piping. When using this more conservative version of Equation 10 it is more appropriate to apply 3.0 Sm as the threshold level.

3. American National Standard ANSI/ANS-58.2-1980, titled "Design Basis for Protection of Light Water Nuclear Power Plants Against Effects of Postulated Pipe Rupture" provide an acceptable alternative method for BVPS-2 SRP Rev. 0 TABLE 1.9-2 (Cont) 12f of 93 the calculation of jet force (Appendix D) and fluid thrust

force (Appendix B) based upon inclusion of the effects of

pipe friction.

4. The deviations were requested by DLC in DLC letter no. 2NRC-5-042, docket no. 50-412 and granted in NRC letter dated

May 27, 1985 for Docket No. 50-412

5. Same as Remark 4.
6. NUREG/CR-2913, 1983 establishes that piping containing steam or subcooled, flashing water at pressures between 870 and 2,465 psia and with no greater than 70C subcooling may be evaluated for a jet impingement effective range equal to ten times the nominal pipe diameter.
7. SRP 3.6.2, paragraph II.1 and associated sections of Branch Technical Position MEB 3-1 require conformance with the previous version of General Design Criterion 4. The current version of GDC-4 (Federal Register, Volume 51, No. 70, Friday, April 11, 1986) permits exclusion of such breaks from the design basis "when analysis demonstrates the probability of rupturing such piping is extremely low under design basis conditions." Prior to the formal revision of GDC-4, BVPS-2 was granted a schedular exemption (Reference NRC letter dated October 11, 1985, Knighton to Carey) based upon review of such analyses. This exemption is maintained under the current GDC-4.
8. A combination of conventional methodology (Standard Review Plan Section 3.6.2) along with an alternative leak-before-break (WHIPJET) approach is used for the provision of protection from the mechanistic effects of postulated pipe rupture. WHIPJET demonstrates that the fluid leakage from a postulated defect at the highest stress location (in terms of normal plus safe shutdown earthquake loads) concurrent with minimum material properties in a high energy piping line can be detected well before the rupture of the pipe.

WHIPJET is consistent with the procedural recommendations and analytical criteria found in NUREG-1061, Volume 3.

Portions of the reactor coolant system (RCS), residual heat removal system (RHR), and safety injection system (SIS) have

been exempted from consideration of pipe whip and jet impingement effects by the application of WHIPJET. Specific lines covered by this alternative approach are listed by

line number in Table 3.6B-4.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 13 of 93 SRP NO. 3.7.1

TITLE: SEISMIC DESIGN PARAMETERS DIFFERENCES FROM THE SRP:

1. Design response spectra were not derived using Regulatory Guide 1.60 guidelines.

REMARKS:

1. The design response spectra are unique to BVPS-2 and were derived in accordance with Section 2.5 and question 3.15 of the BVPS-2 PSAR. That is, the shape and the magnitude of values in the design response spectra were specified by the USNRC in question 3.15.
2. Refer to Table 1.8-1 for conformance to Regulatory Guide 1.61.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 14 of 93 SRP NO. 3.7.2

TITLE: SEISMIC SYSTEM ANALYSIS DIFFERENCES FROM THE SRP:

1. The BVPS-2 design is based on two-dimensional earthquake effects.
2. BVPS-2 design floor response spectra are developed considering one component of earthquake motion at a time.
3. BVPS-2 design responses are not developed by enveloping the results from a half-space analysis and a finite element analysis for soil-structure interaction.

REMARKS:

1. The guidelines to base designs on three dimensional earthquake effects were not in effect when BVPS-2 was designed and its construction permit issued. The BVPS-2 PSAR commits to using the two dimensional earthquake criteria.
2. Design response spectra are developed based on the response only in the direction of input motion. Coupling between three-directions of input motion is not a BVPS-2 design requirement; BVPS-2 uses a two-direction of input-motion criterion with no consideration of statistical independence between the different input time histories. Coupling between orthogonal directions of response is not considered since the structures are reasonably symmetric, and BVPS-2 is a soil site for which the structural responses are due largely to soil response and not to actual structural distortion responses.
3. The BVPS-2 design is in accordance with the previous SRP (NUREG-75/087, SRP 3.7.2). BVPS-2 was designed using a half-space approach and justified by using a finite element approach to demonstrate the conservatism of the half-space method for soil-structure interaction (refer to FSAR Section

3.7B-2 for further discussion of this issue).

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 15 of 93 SRP NO. 3.7.3

TITLE: SEISMIC SUBSYSTEM ANALYSIS DIFFERENCES FROM THE SRP:

1. SRP 3.7.3, paragraph II.2.g, suggests that closely spaced modes be combined in accordance with Regulatory Guide 1.92. Westinghouse combines closely spaced modes in accordance with the methods described in FSAR Section 3.7N.2.7.
2. Paragraph II.2.h requires adjacent Non-Category I systems to be analyzed according to the same seismic criteria as

applicable to the Category I system, if it is not feasible

or practical to isolate the Category I system. Such non-Category I piping, which is not attached to Category I piping systems, is not qualified for the seismic event

associated with the upset plant condition.

3. Paragraph II.2.1 addresses buried conduit and tunnels. The FSAR does not address the issue in this section.

REMARKS:

1. The Westinghouse methods for combining closely spaced modes represents an alternative accepted by the USNRC for recent plants and meets the requirements of GDC 2 and Appendix A to 10 CFR 100.
2. For Non-Category I piping which is not attached to Category I piping systems, the Non-Category piping is qualified only for the seismic event associated with the faulted plant condition. This will ensure the structural integrity of the Non-Category I piping, thus precluding damage to Category I components/systems and is in agreement with the BVPS-2

position on Regulatory Guide 1.29.

3. Tunnels are addressed in FSAR Section 3.7.2. Conduit will be addressed later via an FSAR amendment to show compliance.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 16 of 93 SRP NO. 3.8.1

TITLE: CONCRETE CONTAINMENT DIFFERENCES FROM THE SRP:

1. BVPS-2 does not use the ACI/ASME (ACI 359) Code as a basis for load equations, design allowables, materials, quality control, or special construction techniques.
2. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.19, 1.55, and 1.94.

REMARKS:

1. The BVPS-2 design uses ACI 318-71, with the alternative noted in Section 3.8.1.2.1.1, as a basis for the concrete portions of the containment and ASME Section III, Division I (1971 edition with Addenda through winter 1972) as a guide for liner portions instead of the ACI/ASME (ACI 359) Code.

The ACI/ASME Code was not in effect at the time BVPS-2 was designed and its construction permit issued.

2. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 17 of 93 SRP NO. 3.8.2

TITLE: STEEL CONTAINMENT DIFFERENCES FROM THE SRP:

The structural acceptance criteria used for BVPS-2 differ from that in this SRP and Regulatory Guide 1.57.

REMARKS:

The structural acceptance criteria (that is, design limits and loading combinations) used for BVPS-2 is consistent with NUREG-

75/087, which satisfies the requirements of the GDC. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.57.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 18 of 93 SRP NO. 3.8.3

TITLE: CONCRETE AND STEEL INTERNAL STRUCTURES OF STEEL OR CONCRETE CONTAINMENTS

DIFFERENCES FROM THE SRP:

1. The ACI-349 Code was not used for BVPS-2.
2. The ASME Boiler and Pressure Vessel Code,Section III, was not used for BVPS-2.
3. BVPS-2 takes exception to one of the requirements of the AISC Specification for the Design, Fabrication, and Erection of Structural Steel for Buildings.
4. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.15, 1.55, 1.94 and 1.142.

REMARKS:

1. The BVPS-2 design uses ACI 318-71, with the alternative noted in Section 3.8.1.2.1.1, as a basis for the concrete internal structures; the ACI 349 Code was not in effect at the time BVPS-2 was designed and its construction permit issued. 2. The ASME Boiler and Pressure Vessel Code is not applicable to the internal structures of BVPS-2.
3. Refer to Section 3.8.1.2.1.3 for this exception.
4. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 20 TABLE 1.9-2 (Cont)

19 of 93 SRP NO. 3.8.4

TITLE: OTHER SEISMIC CATEGORY I STRUCTURES

DIFFERENCES FROM THE SRP:

1. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.55, 1.69, 1.94, 1.115, 1.142, and 1.143.
2. BVPS-2 does not use the ACI 349 Code as a basis for reinforced concrete design and analysis procedures.
3. BVPS-2 takes exception to one of the requirements of the AISC Specification for the Design, Fabrication, and Erection

of Structural Steel for Buildings.

4. Loads, load combinations, and structural acceptance criteria are not in complete agreement with SRP 3.8.4.
5. Appendices A, B, C, and D to SRP 3.8.4 are not addressed in Section 3.8.4.

REMARKS:

1. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
2. Reinforced concrete design and analysis procedures conform to the ACI 318-71 Code, with the alternative noted in Section 3.8.1.2.1.1. The ACI 349 Code was not issued at the

time the BVPS-2 Construction Permit was issued nor by the

time the majority of the reinforced concrete was designed.

3. Refer to Section 3.8.1.2.1.3 for this exception.
4. Certain load combinations have not been postulated. These combinations would not govern the design of the structures.
5. Appendix A: BVPS-2 has no safety-related concrete masonry walls. Appendix B: The Appendix, "Structural Design Audits,"

contains no specific acceptance criteria.

Appendix C: Items comprising "The Design Report" were

discussed during the NRC Structural Design Audit.

Appendix D: The spent fuel racks are addressed in Section

9.1.2.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 20 of 93 SRP NO. 3.8.5

TITLE: FOUNDATIONS DIFFERENCES FROM THE SRP:

1. BVPS-2 takes some alternatives to Regulatory Guides 1.10, 1.19, 1.55, 1.94, 1.136, and 1.142.
2. BVPS-2 does not use the ACI 349 Code as a basis for reinforced concrete design and analysis procedures.
3. Overturning moments do not consider the combination of the three components of the earthquake.

REMARKS:

1. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
2. Reinforced concrete design and analysis procedures conform to the ACI 318-71 Code, with the alternative noted in Section 3.8.1.2.1.1. The ACI 349 Code was not issued at

the time the BVPS-2 construction permit was issued nor by the time the majority of the reinforced concrete was designed.

3. BVPS-2 is committed to two-dimension earthquake criteria. Refer to Section 3.7B.2 for a description of the analytical techniques used to determine earthquake forces.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 21 of 93 SRP NO. 3.9.1

TITLE: SPECIAL TOPICS FOR MECHANICAL COMPONENTS DIFFERENCES FROM THE SRP:

SRP 3.9.1, paragraph II.2, requests a considerable amount of information for all the computer codes used in the design and analysis of seismic Category I components. Westinghouse only provides a brief description of the computer codes used by Westinghouse for component design and analysis in FSAR Section 3.9N.1.2. Additional information required by this SRP for the computer codes referred to in FSAR Section 3.9N.1.2 is provided by reference to WCAP-8252 and -8929. Computer codes used by

Westinghouse vendors are not included in the FSAR.

REMARKS:

The information requested by the SRP for referenced Westinghouse computer codes is provided in WCAP-8252 and -8929 and meets the relevant requirements of GDC 1 and Appendix B to 10 CFR 50.

Both of these documents have been submitted to the USNRC for review.

Vendor computer codes are not included in the FSAR because of the large number of codes used and the proprietary nature of this vendor information. Westinghouse ensures the acceptability of vendor computer codes through quality assurance audits at vendor facilities and the technical review of various design

documents submitted by vendors to Westinghouse.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 22 of 93 SRP NO. 3.9.2

TITLE: DYNAMIC TESTING AND ANALYSIS OF SYSTEMS, COMPONENTS, AND EQUIPMENT

DIFFERENCES FROM THE SRP:

1. SRP 3.9N.2, paragraph II.2.e, defines criteria for combining closely spaced modes. The Westinghouse method for combining closely spaced modes is provided in FSAR Section 3.7N.2.7.
2. Differences in methods exist of combining individual orthogonal stresses resulting from the dynamic responses of

the equipment and the modeling techniques employed in the

seismic qualification of mechanical and electrical equipment.

3. BVPS-2 employs alternatives to Regulatory Guides 1.20, 1.61.

1.68, and 1.92.

REMARKS:

1. Refer to the justification provided for SRP 3.7.3.
2. FSAR Section 3.9B.2.2 was written to a previous revision of the SRP. Based on previous successfully submitted SARs the general intent should be satisfied by the present 3.9.2.2 and other referenced sections. Technically acceptable alternate methods are identified in FSAR Section 3.7B.3.
3. Refer to Section 1.8 of the FSAR for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 23 of 93 SRP NO. 3.9.3

TITLE: ASME CODE CLASS 1, 2, AND 3 COMPONENTS, COMPONENT SUPPORTS, AND CORE SUPPORT STRUCTURES

DIFFERENCES FROM THE SRP:

1. Design of ASME Code Class 1, 2, and 3 Components do not include specific provisions for addressing functional capability as outlined in SRP 3.9.3.
2. SRP 3.9.3, Appendix A.1.3.3, defines the design basis pipe break (DBPB) as an emergency condition. For ASME Code Class 1, 2, and 3 components and component supports, the DBPB is a faulted condition. (Refer to the loading combination tables in Section 3.9.)
3. SRP 3.9.3, paragraph II.3, requests deformation limits to be included in the FSAR for component supports when the support affects the operability of the component. This requirement

would only apply to active pump supports. Active valves are supported in the piping system. No information on deformation limits is provided in the FSAR for supports of

active pumps.

4. BVPS-2 provides acceptable alternatives to various portions of Regulatory Guides 1.48, 1.67, 1.124, and 1.130.
5. A fatigue evaluation of shock arrestors is requested by SRP 3.9.3, paragraph II.3.b.l unless it can be demonstrated that the number of load cycles which the snubber will experience during normal plant operating conditions is small (less than 2500), or motion during normal plant operating conditions does not exceed snubber dead band. This fatigue evaluation is not done.
6. SRP 3.9.3, paragraph II.3.b.2 discusses the need to consider snubber end fitting clearance and lost motion when calculating snubber reaction loads and stress which are based on a linear analysis of the system or component. Piping analysis and component analysis do not consider

snubber end fitting clearance and lost motion.

7. BVPS-2 does not use service stress limits A, B, C, and D as described in Appendix A to SRP 3.9.3.

REMARKS:

1. Conformance with ASME III requirements and experience with components experiencing significant earthquakes and fluid transient loads (NUREGs/CR-2137 and CR-1665) provides adequate assurance of functional capability.

BVPS-2 UFSAR Rev. 18 TABLE 1.9-2 (Cont)

24 of 93 2. The DBPB is a faulted condition event consistent with the criteria defined in ANSI N18.2. Additionally, the stress limits and analysis methods for faulted conditions defined

in the ASME Code and Section 3.9N of the FSAR are

sufficiently conservative to ensure the structural integrity and operability of components when subjected to faulted

condition loads including the DBPB.

3. BVPS-2 is committed to a pump operability program which does not permit permanent deformation of component supports for active pumps. Although specific deformation limits are not

quantified, they are addressed in a qualitative manner in

FSAR Sections 3.9N.3.2 and 3.9B.3.2.

4. Refer to Section 1.8 for BVPS-2 positions on regulatory guides.
5. Normal plant surveillance of snubbers will detect and report any lack of function or deterioration of performance due to

system vibration. Any defective snubbers will be replaced.

6. Snubber end fitting clearance and lost motion are not considered significant in piping analysis or component

analysis.

7. The ASME III Code editions applicable to BVPS-2 components (refer to the ASME Code Baseline Document) do not include the use of service stress limits A, B, C, and D.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 25 of 93 SRP NO. 3.10

TITLE: SEISMIC QUALIFICATION OF CATEGORY I INSTRUMENTATION AND ELECTRICAL EQUIPMENT

DIFFERENCES FROM THE SRP:

1. The SRP requests that acceptable load combination and methods for defining dynamic responses for mechanical and electrical equipment be defined in SRP Section 3.9.3. There are differences in the SRP guidelines and the Westinghouse and balance of plant (BOP) methods of load combination and methods for combining dynamic responses for mechanical equipment (refer to Section 3.9.3 remarks). For electrical equipment, the only dynamic loads considered in testing are seismic loads. These seismic loads are not combined by test with other dynamic loads.
2. BVPS-2 takes some alternatives to Regulatory Guides 1.61, 1.89, 1.92, 1.100, and 1.122.
3. Seismic qualification of mechanical equipment is not addressed in FSAR Section 3.10.
4. Section 3.10 of the FSAR does not cover operability of active pumps and valves.
5. Paragraph II.l.a.(2) of the SRP suggests that equipment should be tested in the operational condition and that loadings simulating normal plant conditions should be superimposed on seismic and dynamic loads. This includes flow induced loads and degraded flow conditions. For the tests performed, operational conditions are included where practical, simulated in some manner, or addressed by analysis. Flow loads are not superimposed on seismic loads

for valve operability tests.

6. Paragraph II.l.a.(8) suggests that fixture design for seismic tests should simulate actual service mounting and should not cause any extraneous dynamic coupling to the test

item. 7. If the dynamic testing of a pump or valve is impractical, static testing of the assembly can be performed in accordance with paragraph II.1.a(l0). End loadings are not applied, and all dynamic amplification effects are not included in the static deflection tests for active valves.

8. Paragraph 3.10.II.l.a.(14)(b)iii requires that an analysis be performed to determine the pressure differential and impact energy on a valve disc during a LOCA, and to verify the design adequacy of the disc. Westinghouse specified the loading conditions applicable to each valve. Westinghouse performs design verification on vendor supplied valves to assure that the valves are designed properly and meet the

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 26 of 93 stress acceptance criteria specified both in the Equipment Specifications and the ASME Code Standards. The valve suppliers use the guidance provided in NB-3552(C) of the ASME Code to determine if any analysis is warranted.

9. Paragraph II.1.a.(14)(b)viii suggests the use of Regulatory Guide 1.92 for combination of multimodal and multidirectional responses in analyses. Westinghouse uses

the methods defined in FSAR Section 3.7 for combining closely spaced modes.

10. Paragraph II.5.b suggests that a list of systems necessary to perform the functions outlined in the SRP Section 3.10 be

included in the FSAR Section 3.10. This list is not

included in FSAR Section 3.10N.

11. Paragraph II.5.b(2) suggests that a description of the results of any in-plant tests used to confirm qualification of equipment be included in the FSAR.
12. Paragraph II.5.c suggests a Seismic Qualification Report.

Westinghouse does not maintain such a report for BVPS-2.

REMARKS:

1. Seismic loads are the only dynamic loads considered for electrical equipment. Interface requirements dictate that electrical equipment be protected from such dynamic loads as jet impingement and pipe whip. The exceptions to the above statement are line mounted electrical components (such as RTDs and valve accessories) in ASME Class 1 systems. This line mounted equipment is subjected to blowdown loads from a

LOCA. However, these blowdown loads are enveloped by the seismic loads and are not combined with the seismic loads because of the low probability of the simultaneous

occurrence of the two events. The second exception is the electrically operated pressurizer PORV which is subject to transient flow loads. These loads are not combined with seismic loads during test. However, the design load combination includes consideration of transient flow load effects (pressure loads resulting from LOCA) combined with seismic loads. This combined effect is evaluated by analysis for the pressurizer PORVS. In addition, seismic testing in accordance with WCAP-8587 has been conducted on

this device.

2. In accordance with the SRP, since the BVPS-2 construction permit application was docketed before October 27, 1972, Class I electrical equipment will be seismically qualified in accordance with IEEE 344-1971. Although not required (due to Beaver Valley's docket date being before October 27, 1972), IEEE 344-1975 was employed for seismic qualification of Seismic Category I electrical equipment when feasible.

Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 27 of 93 3. Seismic qualification of mechanical equipment is addressed in FSAR Sections 3.7 and 3.9 in accordance with SRPS 3.7 and

3.9. 4. The BVPS-2 operability program is covered in FSAR Sections 3.9N.3.2. and 3.9B.3.2. The latest version of the SRP has included operability under Section 3.10 and has deleted it from Section 3.9. 5. Full operational testing conditions are not included in testing because performing such a test is impractical. For example, when static deflection tests on valves are performed, the P across the valve disc is simulated.

However, the test is not performed with the valve in a flow loop. As stated above, operational conditions are addressed other than by test.

The active valve operability program defined in FSAR Sections 3.9N.3.2 and 3.9B.3.2 outlines the program for demonstrating operability under all required plant

conditions. This program of conservative design, analysis, and test provides adequate assurance that safety related equipment will perform the required safety functions under

the appropriate plant conditions. 6. Seismic qualification testing configurations are designed to represent the typical plant installation for the tested component. Interface requirements are defined based on the test configuration and other design requirements.

Installation is then completed in accordance with the component interface requirements. Any dynamic coupling effects that result from mounting the component in accordance with these interface criteria would have been

adequately considered during the test program. 7. Conservative restrictions are placed on the allowable piping loads transmitted to the valve or pump body such that these loads cannot cause detrimental deflections of the active component. This restriction of allowable piping loads combined with the static deflection testing performed on active valves provides adequate assurance of valve performance and obviates the need to apply end loadings during the static deflection tests for active valves.

The operability program for active valves addresses dynamic amplification effects by increasing the g loadings utilized in static deflection tests and analyses when dynamic equipment response is a concern. In most cases the equipment is rigid and does not display dynamic amplification characteristics. 8. In conformance with NA-3254 of the ASME Code Section III, Westinghouse utilizes the mechanism of Equipment Design Specifications to address the equipment boundaries of jurisdiction. All loading conditions which are expected to be applicable to the hardware are therefore covered explicitly in the Equipment Specifications. By so doing, Westinghouse conforms to NA-3254. In most cases, the vendor invokes NB-3552(c) of BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 28 of 93 the ASME Code states that any transient effects due to maloperation or accident whose number of occurrences does

not exceed 5 need not be considered.

9. The Westinghouse methods for combining closely spaced modes has been previously justified and accepted by the USNRC.
10. The information requested is included in FSAR Chapters 6 and 7, Safety Related Mechanical and Electrical Systems.
11. The test results for Westinghouse supplied equipment are referenced in the FSAR. Actual test results are not included in the FSAR.
12. Seismic qualification of equipment is documented in test reports, analysis reports, and calculation notes contained in Westinghouse files. The documentation maintained by

Westinghouse satisfies existing regulatory requirements and, therefore, it is not considered necessary to prepare an additional Seismic Qualification Report.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 29 of 93 SRP NO. 3.11

TITLE: ENVIRONMENTAL DESIGN OF MECHANICAL AND ELECTRICAL EQUIPMENT

DIFFERENCES FROM THE SRP:

1. SRP 3.11 suggests that all mechanical and electrical systems and equipment necessary to perform the functions listed in paragraph 1 of Section I of the SRP 3.11 should be listed in Section 3.11 of the FSAR. Section 3.11 does not include the

entire list.

2. BVPS-2 meets or exceeds the guidelines of NUREG-0588, Rev. 1, for a Category II plant in lieu of IEEE Standard 323-1974 which is endorsed by Regulatory Guide 1.89.
3. Qualification of safety related mechanical equipment consists of seismic and operability type programs as

addressed in FSAR Sections 3.7 and 3.9.

REMARKS:

1. The information requested by SRP 3.11 is located in different parts of the FSAR as listed below:
a. Safety related Mechanical and Electrical Systems - FSAR Chapters 6 and 7.
b. Active Pumps and Valves - FSAR Tables 3.9N-9 and 3.9N-10.
c. Plant Specific Class 1E components list - FSAR Table 3.11-1.
d. Other safety related mechanical components - FSAR Sections 3.2N and 3.9N.
2. The environmental qualification of Class I electrical equipment is in accordance with the USNRC Commissioners'

memorandum and order CLI-80-21.

3. Preparation and submittal of information pertaining to environmental qualification of mechanical equipment is pending USNRC rule making.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 30 of 93 SRP NO. 4.5.1

TITLE: CONTROL ROD DRIVE STRUCTURAL MATERIALS DIFFERENCES FROM THE SRP:

Cleaning and cleanliness controls differ slightly from SRP 4.5.1. Alternatives are also taken to Regulatory Guides 1.31

and 1.44.

REMARKS:

FSAR Section 1.8 provides a discussion of cleaning and cleanliness controls used at BVPS-2. Although these controls differ from Regulatory Guide 1.37 guidelines, they are in accordance with the requirements of GDC 1.

For the BVPS-2 position on Regulatory Guides 1.31 and 1.44, refer to FSAR Section 1.8.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 30a of 93 SRP No. 4.5.2

TITLE: REACTOR INTERNAL AND CORE SUPPORT MATERIALS

DIFFERENCE FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.31 and 1.44.

REMARKS:

For the BVPS-2 position on these Regulatory Guides, refer to

FSAR Section 1.8.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 31 of 93 SRP NO. 5.2.1.1

TITLE: COMPLIANCE WITH THE CODES AND STANDARD RULE, 10 CFR 50.55a DIFFERENCES FROM THE SRP:

BVPS-2 uses the safety classification system provided in ANSI N18.2 as an acceptable alternative to the Regulatory Guide 1.26 quality group classification system.

REMARKS:

The ANS classification system implemented for BVPS-2 has been

endorsed by industry as an alternative accepted by the USNRC for many other plants. This classification system meets the relevant requirements of GDC 1 and 10 CFR 50.55a.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 32 of 93 SRP NO. 5.2.1.2

TITLE: APPLICABLE CODE CASES DIFFERENCES FROM THE SRP:

Code cases other than those endorsed by Regulatory Guides 1.84, 1.85, and 1.147 may be used at BVPS-2.

REMARKS:

Code cases not endorsed by the regulatory guides will be limited to those for which USNRC acceptance has been obtained, otherwise assured, or as discussed in FSAR Section 1.8.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 33 of 93 SRP NO. 5.2.2

TITLE: OVERPRESSURE PROTECTION DIFFERENCES FROM THE SRP:

NUREG-0737, Items II.D.1 and II.D.3, are not discussed in FSAR Section 5.2.2.

REMARKS:

This material is discussed in Section 1.10.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 34 of 93 SRP NO. 5.2.3

TITLE: REACTOR COOLANT PRESSURE BOUNDARY MATERIALS

DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.31, 1.36, 1.37, 1.43, 1.44, 1.50 and 1.71.

REMARKS:

The BVPS-2 position on these Regulatory Guides is discussed in FSAR Section 1.8.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 34a of 93 SRP NO. 5.2.5

TITLE: REACTOR COOLANT PRESSURE BOUNDARY LEAKAGE DETECTION DIFFERENCES FROM THE SRP:

BVPS-2 does not fully follow the guidelines of Regulatory Guide 1.45, Position C.6 in that the containment sump level detection systems, which meet the detection sensitivity requirements of normal plant operation (that is, 1 gpm in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />), are not designed to meet seismic requirements.

REMARKS:

Seismically qualified redundant level instrumentation, powered from Class lE electrical buses, is provided to monitor the containment sump level for excessive leakage following seismic events. The instrumentation is qualified for seismic loads up to SSE loads. Although a sensitivity of 1 gpm in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is not achieved, narrow range instruments are provided with an accuracy of 1.7 inches. The airborne particulate radiation monitoring system is seismically designed for SSE loads and detects a leakage rate of one gpm in less than one hour. The combination of these two types of instruments satisfies the relevant requirements of GDCS 2 and 30.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 35 of 93 SRP NO. 5.3.1

TITLE: REACTOR VESSEL MATERIALS DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.31, 1.37, 1.43, 1.44, 1.50, and 1.65.

REMARKS:

The BVPS-2 positions on these regulatory guides are discussed in FSAR Section 1.8.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 36 of 93 SRP NO. 5.4.1.1

TITLE: PUMP FLYWHEEL INTEGRITY (PWR)

DIFFERENCES FROM THE SRP:

The reactor coolant pump flywheel integrity is not completely addressed in FSAR Section 5.4.1.1.

REMARKS:

The pump flywheel integrity is addressed in FSAR Sections 5.4.11 through 5.4.1.5 and Section 1.8.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 37 of 93 SRP NO. 5.4.2.1

TITLE: STEAM GENERATOR MATERIALS DIFFERENCES FROM THE SRP:

1. Specific details of the secondary side chemistry program are not discussed in FSAR Section 5.4.2.1.
2. The SRP states that the steam generators should be visually inspected to be in a "metal clean" surface condition before start-up.
3. The SRP states that access for tooling to remove sludge by lancing from the tube support plates should be provided.

REMARKS:

1. The secondary side water chemistry program at BVPS-2 will follow the guidance of Westinghouse document SIP 5-4.
2. The lay-up procedure for steam generators during the time after removal from site storage for installation in containment and after installation is described in the Westinghouse document "NSSS Component Receiving and Storage Guidelines" specifically procedure SGE-32001, "Environmental

Protection of Steam Generators During Site Installation and the Period Initially Preceding Water Fill." (During on-site storage the steam generator is sealed and pressurized

in a nitrogen atmosphere to inhibit corrosion.)

Procedure SGE-32001 states that "light rust film may be present and shall not, by itself, be cause for further cleaning." Adherence to SGE-32001 will minimize the potential for a significant amount of corrosion to occur in the steam generator during the remainder of site construction. Procedure SGE-32001 is stringent enough to provide adequate protection from significant corrosion during this layup period. A small amount of corrosion product (oxide) retards further corrosion by acting as a barrier to continued corrosion attack.

3. Historically, tube lancing from tube support plates has not been performed. Sludge filters down through flow slots and flow holes in the support plates to accumulate at low flow areas on the top of the tube sheet. There are two techniques used to remove sludge from the top of the tube

sheet. During normal operation, utilization of the steam generator blowdown system will remove a portion of the accumulating sludge. During shutdowns, sludge lancing can be employed to remove sludge not removed by normal blowdown. Removal of sludge from the tubesheet is therefore more efficient than sludge removal from the tube support plates

would be.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 38 of 93 SRP NO. 5.4.7

TITLE: RESIDUAL HEAT REMOVAL (RHR) SYSTEM DIFFERENCES FROM THE SRP:

1. Task action plan items II.E.3.2 and II.E.3.3 of NUREG-0660 are not discussed.
2. Task action plan item III.D.1.1 of NUREG-0737 is not discussed in FSAR Section 5.4.7.

REMARKS:

1. Since Office of Nuclear Reactor Regulation (NRR) studies regarding these items are incomplete, they need not be

addressed.

2. Item III.D.1.1 has no basis in the requirements specified in this SRP. It is, however, discussed in FSAR Section 1.10.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 39 of 93 SRP NO. 5.4.12

TITLE: REACTOR COOLANT SYSTEM HIGH POINT VENTS DIFFERENCES FROM THE SRP:

1. The reactor coolant system high point vents are not discussed in FSAR Section 5.4.12.
2. The one-inch pipe LOCA is larger than a leak.

REMARKS:

1. The vents are discussed in FSAR Section 5.4.15, in accordance with the format of Regulatory Guide 1.70.
2. This line is necessary for letdown in the cold shutdown scenario, as discussed in FSAR Appendix 5A.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 40 of 93 SRP NO. 6.1.1

TITLE: ENGINEERED SAFETY FEATURES MATERIALS DIFFERENCES FROM THE SRP:

1. The recommendations of ASME Section III, Appendix D, Article D-1000 was not required.
2. Moisture control on low hy drogen welding materials used for shop welding fabrication was not required to conform to both ASME Section III and AWSD1.1.
3. BVPS-2 takes some alternatives to Regulatory Guides 1.44, 1.54, and 1.71.

REMARKS:

1. Welding preheat was specified in accordance with ASME Sections III and IX with the additional provisions of Regulatory Guide 1.50 as discussed in FSAR Section 1.8.

It was determined that either subsequent post-weld heat treatment or final nondestructive examination in accordance with ASME Section III provides adequate assurance of weld quality.

2. The requirements of either ASME,Section III, or AWSD.1.1, and the applicable code,Section II, SFA filler material

specifications were met for shop fabrications.

3. Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 41 of 93 SRP NO. 6.2.1.1.A

TITLE: PWR DRY CONTAINMENTS, INCLUDING SUBATMOSPHERIC CONTAINMENTS

DIFFERENCES FROM THE SRP:

1. SRP 6.2.1.1.A, paragraph II.g, states that instrumentation capable of operating in the post-accident environment should be provided to monitor containment atmosphere temperature and sump water temperature.
2. SRP 6.2.1.1.A, paragraph II.F states, that adequate margin above the maximum expected external pressure should be provided. This margin was not addressed in the FSAR.

REMARKS:

1. These two types of post-accident monitors are not required in order to perform a diagnosis as specified by the emergency response guidelines. Attachments 4 and 5 of NUREG-0737, Item II.F.1 are not addressed in FSAR Section 6.2.1.1; they are addressed in Section 7.5.
2. Conservatism in the analysis provides for this margin.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 42 of 93 SRP NO. 6.2.1.3

TITLE: MASS AND ENERGY RELEASE ANALYSIS FOR POSTULATED LOSS-OF-COOLANT ACCIDENTS

DIFFERENCES FROM THE SRP:

SRP 6.2.1.3, paragraph II.B.3e, identifies an acceptable Westinghouse mass and energy release model (Ref. 18 of SRP 6.2.1) which was not used for BVPS-2.

REMARKS:

The Westinghouse mass and energy release model for containment

design is described in FSAR Sections 6.2.1.3.3, 6.2.1.3.4, 6.2.1.3.5, and 6.2.1.3.6. This model provides sufficient conservatism and satisfies GDC 50 requirements.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 43 of 93 SRP NO. 6.2.1.5

TITLE: MINIMUM CONTAINMENT PRESSURE ANALYSIS FOR EMERGENCY CORE COOLING SYSTEM PERFORMANCE CAPABILITY STUDIES

DIFFERENCES FROM THE SRP:

BTP 6-1, Section B.3b, recommends conservative condensing heat

transfer coefficients which differ from the Westinghouse model.

REMARKS:

The Westinghouse evaluation model for ECCS minimum containment pressure as presented in Appendix A of WCAP-8339 (1974) satisfies the governing requirements and has been approved by the USNRC staff.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 44 of 93 This page is intentionally left blank

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 45 of 93 SRP No. 6.2.4

TITLE: CONTAINMENT ISOLATION SYSTEM DIFFERENCES FROM THE SRP:

Containment isolation arrangements which differ from the arrangements specified in the General Design Criteria of SRP

6.2.4 are found in the following:

1. Emergency core cooling system safety injection lines.
2. Recirculation spray pump suction lines.
3. Containment vacuum pump and hydrogen recombine suction and discharge lines.
4. Containment depressurization.
5. Containment leakage monitoring.
6. Fuel transfer tube.
7. Main steam, steam generator blowdown, and feedwater penetrations.
8. Auxiliary feedwater.
9. Personnel air lock and equipment hatch.
10. Reactor coolant pump seal injection.

REMARKS:

The containment isolation system (CIS) meets the intent of NUREG-0737, Item II.E.4.2 with regard to containment isolation dependability. The CIS is activated automatically when monitored system variables exceed pre-established set points.

It is neither necessary nor desirable that every containment isolation valve close simultaneously upon a containment isolation signal. The plant design allows selected valves in the engineered safety features systems, which are essential to mitigate the effects of an accident, to remain in or move to their open position. These pre-selected valves are remote and

manually-operated from the main control room. Containment isolation arrangements which differ in some manner from the specific arrangements allowed by GDC 54, 55, 56, and 57 are

described in Section 6.2.4.2.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 46 of 93 This page is intentionally left blank.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 47 of 93 SRP NO. 6.3

TITLE: EMERGENCY CORE COOLING SYSTEM DIFFERENCES FROM THE SRP:

1. Task action plan item III.D.1.1 of NUREG-0737 is not discussed in FSAR Section 6.3.
2. Item II.K.3.10 of NUREG-0737 is not discussed in FSAR Section 6.3.

REMARKS:

1. Item III.D.1.1 has no basis in the underlying requirements for this SRP. It is, however, discussed in FSAR Section

1.10. 2. Item II.K.3.10 is addressed in Section 7.2

BVPS-2 UFSAR Rev. 5 TABLE 1.9-2 (Cont) 48 of 93 SRP NO. 6.4

TITLE: CONTROL ROOM HABITABILITY SYSTEMS DIFFERENCES FROM THE SRP:

1. BVPS-2 takes some alternatives to Regulatory Guides 1.78 and 1.95.
2. BVPS-2 takes some alternatives to Regulatory Guide 1.52.
3. BVPS-2 takes some alternatives to the x/Q methodology referenced in SRP 6.4.

REMARKS:

1. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.78 and 1.95. The only toxic gas BVPS-2 will monitor is chlorine, based upon the results of the Control Room Habitability Study, described in FSAR Section

2.2.3.1.2.

2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.52.
3. Refer to UFSAR Section 2.3.4.3 for the x/Q methodology used in analyses performed after 1991.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 49 of 93 SRP NO. 6.5.1

TITLE: ESF ATMOSPHERE CLEANUP SYSTEMS DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guide 1.52.

REMARKS:

Refer to FSAR Section 1.8 for the BVPS-2 position of Regulatory

Guide 1.52.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 50 of 93 SRP NO. 7.2

TITLE: REACTOR TRIP SYSTEM DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.

REMARKS:

Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 51 of 93 SRP NO. 7.3

TITLE: ENGINEERED SAFETY FEATURES SYSTEMS DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.

REMARKS:

Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 52 of 93 SRP NO. 7.4

TITLE: SAFE SHUTDOWN SYSTEMS DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.

REMARKS:

Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 53 of 93 SRP NO. 7.5

TITLE: INFORMATION SYSTEMS IMPORTANT TO SAFETY DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.75, 1.97, and 1.118.

REMARKS:

Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 54 of 93 SRP NO. 7.6

TITLE: INTERLOCK SYSTEMS IMPORTANT TO SAFETY DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.53, 1.62, 1.75, 1.105, and 1.118.

REMARKS:

Refer to FSAR Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 55 of 93 SRP NO. 8A

TITLE: BRANCH TECHNICAL POSITIONS (PSB)

DIFFERENCES FROM THE SRP:

Branch Technical Position PSB-1, paragraph B.1:

Two separate time delays for the second level of undervoltage protection are not provided. The Class lE distribution system is not separated from offsite on safety injection signal and the load shedding feature is not reinstated once the transfer onto the diesel generator units has occurred.

REMARKS:

Two levels of undervoltage protection are provided. The first level detects the loss of power, isolates the emergency system from the normal system, starts the diesel generator, and begins load sequencing. The second level undervoltage scheme detects a

degraded voltage condition and, if this condition does not improve within one minute, isolates the emergency system from the normal system, starts the diesel generator, and begins

sequencing.

Both of these levels of protection utilize sequential logic from different potential transformers and relays at both the 480 volt and 4,160 volt systems.

The two schemes described satisfy all the safety functions required to assure the protection and safe shutdown of the station.

Branch Technical Position, ICSB 18:

Redundant position indication in the main control room is not provided for the hydrogen recombiner isolation valves 2HCS*MOV110A, B, 2HCS*MOV113A, B. All of these valves have their power supplies normally disconnected to avoid spurious opening during conditions when it is essential that they remain closed.

REMARKS:

The hydrogen control system (HCS) valves are controlled from remote electrical control stations in the plant and are closed during normal and post-accident operation. The only time these

valves are intended to be open are for testing purposes during normal plant operation or if both hydrogen recombiners were to fail post-accident after the recombiners have been placed in operation. To ensure that spurious opening of the subject valves does not cause failure of the hydrogen

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 56 of 93 control system to perform its safety function in a post-accident condition, an administrative procedure will be implemented to require that the valve breakers are maintained de-energized during normal and post-accident modes of operation.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 56a of 93 SRP NO. 9.1.1

TITLE: NEW FUEL STORAGE DIFFERENCES FROM THE SRP:

The BVPS-2 design does not follow all the recommendations of ANS 57.1 and ANS 57.3.

REMARKS:

The ANS standards had not been issued at the time the BVPS-2 design was established.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 56b of 93 SRP No. 9.1.2

TITLE: SPENT FUEL STORAGE

DIFFERENCES FROM THE SRP:

The BVPS-2 design does not follow all the recommendations of ANS 57.2.

REMARKS:

The ANS standard had not been issued at the time the BVPS-2

design was established.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 57 of 93 SRP NO. 9.1.4

TITLE: LIGHT LOAD HANDLING SYSTEM (RELATED TO REFUELING)

DIFFERENCES FROM THE SRP:

1. Regulatory Guide 1.13, paragraph C.3, states that an interlock should be provided to prevent cranes from passing over stored spent fuel when fuel handling is not in progress. The BVPS-2 motor-driven platform crane has, instead, an adjustable interlock which will stop hoist motion if a preset weight, based on the weight of a single fuel assembly, is exceeded.
2. The maximum potential kinetic energy capable of being developed by any load handled above stored spent fuel may, if dropped, exceed the kinetic energy of one fuel assembly and its associated handling tool when dropped from the height at which it is normally handled above the spent fuel storage racks.
3. The BVPS-2 design does not follow all the recommendations of ANS-57.1.

REMARKS:

1. Refer to Section 1.8 for the BVPS-2 position on Regulatory Guide 1.13.
2. An analysis has been performed to demonstrate that although the kinetic energy of a dropped tool exceeds that of a fuel assembly and its associated handling tool, there is no

adverse safety impact.

3. The ANS standard had not been issued at the time the BVPS-2 design was established.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 58 of 93 SRP NO. 9.1.5

TITLE: OVERHEAD HEAVY LOAD HANDLING SYSTEMS DIFFERENCES FROM THE SRP:

1. SRP 9.1.5 suggests using NUREG-0554, "Single Failure Proof Cranes." None of the cranes or monorails at BVPS-2 were designed to be single failure proof.
2. FSAR Section 9.1.5 does not follow the guidance of NUREG-0612 in the following areas.
a. The design of special lifting devices at BVPS-2 did not follow ANSI N14.6-1978.
b. Lifting devices of standard industry design should meet the ANSI B30.9-1971 standard.
c. NUREG-0612 calls for safe load paths to be marked on floors and for safe load paths to follow structural floor members.
d. NUREG-0612 states that if physical separation of safe shutdown equipment or a load drop analysis for a load falling through a floor is not provided, then cranes

must be upgraded to single failure proof.

3. The BVPS-2 design does not follow all the recommendations of ANS-57.1 and ANS-57.2

REMARKS:

1. NUREG-0554 was issued in 1979, which is after all BVPS-2 cranes and monorails were designed. Also, the NUREG does not make any specific references to being applicable to General Design Criteria 2, 4, 5, or 61. Duquesne Light Company (DLC) submitted a report, "Control of Heavy Loads,"

to the USNRC in 1982, which addresses the design criteria and operating procedures for the load handling systems at BVPS-2, which are two major concerns of NUREG-0554.

2. Administrative procedures to limit crane operations within the safe load paths are utilized to address items 2c and 2d. NUREG-0612 was issued in 1980, which is after all BVPS-2 cranes and monorails were designed. Also, the NUREG does not make any specific references to being applicable to General Design Criteria 2, 4, 5 or 61. The DLC, "Control of Heavy Loads," report examined BVPS-2 compliance with NUREG-0612. 3. The ANS standards had not been issued at the time the BVPS-2 design was established.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 59 of 93 SRP NO. 9.2.2

TITLE: REACTOR AUXILIARY COOLING WATER SYSTEMS DIFFERENCES FROM THE SRP:

1. BVPS-2 Reactor coolant pumps have not been demonstrated by testing to withstand a 20-minute loss of cooling water.
2. Primary component cooling water flow to the reactor coolant pumps is monitored by instrumentation which was designed and procured to standards other than IEEE 279.

REMARKS:

1. GDC 44 is cited by the SRP as a basis for the 20-minute acceptance criterion. GDC 44 is concerned with Provisions for transfer of heat from structures, systems and components important to safety to an ultimate heat sink and is unrelated to the length of time a reactor coolant pump can operate following loss of cooling water. Pumps similar to those used at BVPS-2 have been demonstrated to function for at least 10 minutes without cooling water.
2. Flow instrumentation is described in FSAR Section 9.2.2.1 and is normally supplied with power from an emergency bus.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 60 of 93 SRP NO. 9.3.4

TITLE: CHEMICAL AND VOLUME CONTROL SYSTEM (PWR) (INCLUDING BORON RECOVERY SYSTEM)

DIFFERENCES FROM THE SRP:

Task action plan item III.D.1.1 of NUREG-0737 is not discussed

in FSAR Section 9.3.4.

REMARKS:

Item III.D.1.1 has no basis in the requirements specified in this SRP. It is, however, discussed in FSAR Section 1.10.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 61 of 93 SRP NO. 9.4.1

TITLE: CONTROL ROOM AREA VENTILATION SYSTEM DIFFERENCES FROM THE SRP:

1. BVPS-2 takes some alternatives to Regulatory Guides 1.78 and 1.95.
2. BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140. REMARKS:
1. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.78 and 1.95. The only toxic gas BVPS-2 will monitor is chlorine, based upon the results of the Control Room Habitability Study, described in FSAR Section 2.2.3.1.2.
2. Refer to FSAR Section 1.8 for BVPS-2 positions on Regulatory Guides 1.52 and 1.140.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 62 of 93 SRP NO. 9.4.2

TITLE: SPENT FUEL POOL AREA VENTILATION SYSTEM DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140.

REMARKS:

Refer to regulatory guide positions in Section 1.8 of the FSAR.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 63 of 93 SRP NO. 9.4.3

TITLE: AUXILIARY AND RADWASTE AREA VENTILATION SYSTEM DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guide 1.140.

REMARKS:

Refer to regulatory guide positions in Section 1.8 of the FSAR.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 64 of 93 SRP NO. 9.4.5

TITLE: ENGINEERED SAFETY FEATURE VENTILATION SYSTEM DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guides 1.52 and 1.140.

REMARKS:

Refer to regulatory guide positions in Section 1.8 of the FSAR.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 65 of 93 SRP NO. 9.5.1

TITLE: FIRE PROTECTION PROGRAM DIFFERENCES FROM THE SRP:

BVPS-2 takes alternatives to the guidance provided in Branch Technical Position CMEB 9.5-1. These alternatives and the associated justifications are provided in Appendix 9.5A (Section 9.5A.2).

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 66 of 93 SRP 9.5.4

TITLE: EMERGENCY DIESEL ENGINE FUEL OIL STORAGE AND TRANSFER SYSTEM DIFFERENCES FROM THE SRP:

1. BVPS-2 takes an alternative to Regulatory Guide 1.137.
2. The fill lines to the diesel generator fuel oil tanks are not tornado protected.
3. There are no tank design features which minimize the creation of turbulence of the accumulated residual sediments.

REMARKS:

1. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.137.
2. Alternate methods of filling the fuel oil tank are provided through the sample connection or the vent flame arrestor connection which are located in a missile protected area.
3. The admission of deleterious material is prohibited by strainers in the fuel oil tank fill line. Strainers are also provided on the fuel oil transfer pump discharge, and a duplex filter is provided on the emergency diesel generator

set.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 67 of 93 SRP NO. 9.5.6

TITLE: EMERGENCY DIESEL ENGINE STARTING SYSTEM DIFFERENCES FROM THE SRP:

BVPS-2 does not rely on air dryers in the diesel generator air starting system to assure adequate dehydration.

REMARKS:

Accumulated moisture will be removed from the starting system by blowdown of the air receivers at regular intervals. Blowdown will be ensured by implementing administrative controls such as

operating surveillance tests and will satisfy the relevant requirements of GDC 17.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 68 of 93 SRP NO. 10.4.3

TITLE: TURBINE GLAND SEALING SYSTEM DIFFERENCES FROM THE SRP:

BVPS-2 takes some alternatives to Regulatory Guide 1.26.

REMARKS:

Refer to Section 1.8 for BVPS-2 positions on regulatory guides.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 69 of 93 SRP NO. 10.4.6

TITLE: CONDENSATE CLEANUP SYSTEM DIFFERENCES FROM THE SRP:

Specific details of the secondary side chemistry program are not discussed in FSAR Section 10.4.6.

REMARKS:

The secondary side water chemistry program at BVPS-2 will follow the guidance of Westinghouse document SIP 5-4.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 70 of 93 SRP NO. 10.4.7

TITLE: CONDENSATE AND FEEDWATER SYSTEM DIFFERENCES FROM THE SRP:

FSAR Section 10.4.7 does not specify provisions for start-up feedwater hammer testing per BTB ASB 10-2, Item 3.

REMARKS:

The system is adequately protected against damaging feedwater hammer by the feeding J-tube design, coupled with the elbow arrangement at the feedwater piping connection. Therefore, no

testing is necessary.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 71 of 93 SRP NO. 10.4.8

TITLE: STEAM GENERATOR BLOWDOWN SYSTEM (PWR)

DIFFERENCES FROM THE SRP:

The system does not follow the guidance of Regulatory Guide 1.143, paragraph C.1 with respect to the turbine building

seismic criteria.

REMARKS:

Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.143. Although the system differs from the SRP acceptance criteria, its design meets the requirements of GDC 1, 2, and 14.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 72 of 93 SRP NO. 11.1

TITLE: SOURCE TERMS DIFFERENCES FROM THE SRP:

1. SRP 11.1, paragraph II.a suggests that a cost-benefit analysis be performed in accordance with Regulatory Guide 1.110 for the radioactive waste management systems and equipment.
2. BVPS-2 takes some alternatives to Regulatory Guide 1.140.

REMARKS:

1. BVPS-2 received a construction permit prior to June 4, 1976, the effective date of the cost-benefit analysis requirement. The radwaste systems and equipment described in the FSAR satisfy the regulatory position in Docket RM-50-2, which is reproduced in the Annex to Appendix I to 10 CFR 50.
2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.140.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 73 of 93 SRP NO. 11.2

TITLE: LIQUID WASTE MANAGEMENT SYSTEMS DIFFERENCES FROM THE SRP:

1. BVPS-2 systems that contain provisions to control leakage and facilitate operation and maintenance meet Regulatory Guide 1.143 with some alternatives.

2a. SRP 11.2, paragraph II.1.a, provides only the "per unit" limits for determining compliance with 10 CFR 50, Appendix I. 2b. SRP 11.2, paragraph II.1.b, suggests that the applicant consider refinements to liquid radwaste treatment systems and performed a cost-benefit analysis in accordance with

Regulatory Guide 1.110: liquid radwaste treatment systems should include all items of the system sequentially and in order of diminishing cost-benefit return, which can (for a favorable cost-benefit ratio) effect reductions in dose to the population reasonably expected to be within 50 miles of the reactor. This cost-benefit analysis has not been

performed.

REMARKS:

1. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.143.

2a. Analysis for BVPS-2 has been performed on a "per site" basis and resultant doses are within the RM-50-2 design limits and, therefore, is in compliance with 10 CFR 50, Appendix I.

2b. The cost-benefit analysis is not applicable for applicants for construction permits which were docketed on or after January 2, 1971, and prior to June 4, 1976, if the radwaste systems and equipment described in the preliminary or final safety analysis report and amendments thereto satisfy the Guides on Design Objectives for Light-Water-Cooled Nuclear Power Reactors proposed in the Concluding Statement of Position of the Regulatory Staff in Docket-RM-50-2 dated February 20, 1974, pp. 25-30.

BVPS-2 received its construction permit prior to the requirement for cost-benefit analyses of radwaste treatment systems. Duquesne Light Company was given the option by the USNRC of performing the cost-benefit analyses, but chose not to perform the analyses due to the stage of system design.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 74 of 93 SRP NO. 11.3

TITLE: GASEOUS WASTE MANAGEMENT SYSTEMS DIFFERENCES FROM THE SRP:

1. SRP 11.3, paragraph II.B.1.c, requires the gaseous radwaste treatment systems to include all items of reasonably demonstrated technology that when added to the system sequentially and in order of diminishing cost-benefit return, can (for a favorable cost-benefit ratio) effect reductions in dose to the population reasonably expected to be within 50 miles of the reactor. This cost-benefit analysis has not been performed.
2. SRP 11.3, paragraph II.B.4, requires system designs that contain provisions to control leakage and to facilitate operation and maintenance in accordance with the guidelines of Regulatory Guide 1.143. BVPS-2 meets Regulatory Guide 1.143 with the following exceptions:
a. Paragraph C.2.1.1

The gaseous waste system meets or exceeds the codes in Table 1. The gaseous waste delay beds, gaseous waste surge tank, and the overhead compressors have been purchased as ASME III. The waste gas chillers, piping, and valves are ANSI B31.1.

b. Paragraph C.4.3 The piping downstream of the overhead gas compressor discharge lines are 1/2 inch, whereas the guide suggests that process lines should not be less than 3/4 inch (nominal).
3. SRP 11.3, paragraph II.B.6.b, requires two independent gas analyzers continuously operating and providing two

independent measurements verifying that hydrogen and/or oxygen are not present in potentially explosive concentrations. The two oxygen analyzers do not measure

independent locations.

4. The SRP provides only the "per unit" limits for determining compliance with 10 CFR 50, Appendix I.
5. The design case concentrations for gaseous effluents from the ventilation vent exceed the limits of 10 CFR 20, Appendix B, Table II, Column 1, for five nuclides assuming the design basis ventilation rate is used.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 75 of 93 REMARKS:

1. BVPS-2 received a construction permit prior to June 4, 1976, the date that the requirement for the cost-benefit analysis became effective. The radwaste systems and equipment described in the FSAR satisfy the regulatory position in Docket RM-50-2 which is reproduced in the Annex to Appendix I. 2. The FSAR addresses ETSB 11-1.
a. The waste gas chillers are a pipe-within-a-pipe heat exchanger designed and fabricated in accordance with ANSI B.31.1. The charcoal delay bed vessels and the gaseous waste surge tank are designed and fabricated to ASME III, a design which is superior to the specified ASME VIII. The overhead gas compressors are designed and fabricated to ASME III, a design which is superior to the specified manufacturer's standard.
b. The overhead gas compressor prefilters provide a clean gas downstream where the lines are 1/2 inch. Pressure

drop is not a problem in the 1/2 inch lines downstream

of the overhead gas compressors.

3. The two oxygen analyzers are downstream of the overhead gas compressors with the most likely leakage point being the suction of the compressors.
4. Analysis for BVPS-2 has been performed on a "per site" basis and resultant doses are within the RM-50-2 design limits.

It is, therefore, in compliance with 10 CFR 50, Appendix I.

5. Controlled releases will be imposed so as not to exceed the concentration limits of 10 CFR 20, Appendix B, Table II, Column 1.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 76 of 93 SRP NO. 11.4

TITLE: SOLID WASTE MANAGEMENT SYSTEMS DIFFERENCES FROM THE SRP:

1. SRP 11.4, paragraphs II.2 and II.3, suggest a description of the methods for solidification, the solidifying agent used, and a process control program to ensure a solid matrix. A process control program has not been submitted by the system vendor but has been discussed for BVPS-2.
2. Regulatory Guide 1.143 suggest 0-15 psig tanks to be designed and fabricated to ASME III, Class 3 or, API 650. The spent resin holding tank and the decanting tank are designed and fabricated to ASME VIII, Division 1.

REMARKS:

1. The FSAR states that a process control program is needed to verify the absence of free liquid in the containers. The required program will be written prior to the completion of the environmental radiological Technical Specification.
2. The deviation of the design and fabrication of the spent resin holding tank and the decanting tank from the requirements of Regulatory Guide 1.143 is due to the geometry of the two tanks. The fabrication codes specified (ASME III, Class 3 or API 650) do not specifically cover tanks of this type, that is, vessel-type nonflat bottom atmospheric tanks. As such, these tanks have been constructed in accordance with ASME VIII, Division 1, which

is more stringent than API 650, thus indicating that the SRP requirements are more than adequately addressed. Exception to ASME VIII, Division 1 requirements are:

a. The vessels are not stamped.
b. Radiography of welds is not required.
c. A water fill leak test in accordance with API-650 is substituted for a hydrostatic test at 1.5 times design pressure.

These tanks were designed and fabricated prior to issuance of NUREG-0800.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 77 of 93 SRP NO. 11.5

TITLE: PROCESS AND EFFLUENT RADIOLOGICAL MONITORING INSTRUMENTATION AND SAMPLING SYSTEMS

DIFFERENCES FROM THE SRP:

1. Regulatory Guide 1.97 suggests post-accident sampling for primary coolant activity. There are no plans to install equipment to continuously monitor reactor coolant following an accident.
2. BVPS-2 takes some alternatives to Regulatory Guide 1.21.
3. Table 2 of the SRP requires continuous monitoring of the turbine building drain effluents. BVPS-2 does not

continuously monitor these effluents.

REMARKS:

1. To meet the intent of Regulatory Guide 1.97, reactor coolant can be analyzed by obtaining a grab sample via the post-

accident sampling facility (PASS). The PASS does not

operate at all times after an accident.

Information provided by this Regulatory Guide 1.97 variable

would not be vital to the control room operator for safe shutdown of the plant.

2. Refer to FSAR Section 1.8 for the BVPS-2 position on Regulatory Guide 1.21.
3. To obtain gross activity of turbine building drain effluents, grab sampling will be performed as explained in

Section 11.2.2

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 78 of 93 SRP NO. 12.1

TITLE: ASSURING THAT OCCUPATIONAL RADIATION EXPOSURES ARE AS LOW AS IS REASONABLY ACHIEVABLE

DIFFERENCES FROM THE SRP:

1. 10 CFR 19.12 is not discussed.
2. NUREG-0761 guidelines are not specifically discussed.

REMARKS:

1. The SRP specifies in part that the FSAR is acceptable if sufficient information identified in Section 12.1 of Regulatory Guide 1.70 is provided to meet the relevant requirements of 10 CFR 19 and 20. Regulatory Guide 1.70 does not identify any necessary discussion of 10 CFR 19. The FSAR does, however, discuss 10 CFR 19.12 in Section 13.2.2.1.
2. The Radiation Protection Plan for BVPS-2 will be an extension of the plan currently in effect for the operation of BVPS-1. Having been developed prior to the current guidance (draft NUREG-0761, March 1981), the plan was not designed to follow this guidance document. The plan does

meet the intent of draft NUREG-0761 by satisfying the requirements of 10 CFR 20 as described in FSAR Sections 12.5, 13.1, and 13.2.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 79 of 93

This page has been intentionally deleted from the FSAR.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 80 of 93 SRP NO. 12.3 - 12.4

TITLE: RADIATION PROTECTION DESIGN FEATURES DIFFERENCES FROM THE SRP:

FSAR Sections 12.3 and 12.4 do not include:

1. A description of the radiation instrumentation that will be used to meet the criticality accident monitoring

requirements of 70.24(b) of 10 CFR Part 70 and Regulatory

Guide 8.12 for the new fuel storage area.

2. A description of intermediate range area monitors used to measure radiation exposure rates in locations contiguous to containment building penetrations and hatches, and in vital access areas as described in Regulatory Guide 1.97, Rev. 2.

REMARKS:

1. An application will be filed for an exemption from the installation of the criticality monitor required in

accordance with 10 CFR Part 70.24(b) and Regulatory Guide

8.12.

2. General Design Criterion 19 is the only underlying requirement of Regulatory Guide 1.97 which is specified in SRP 12.3-12.4, and is unrelated to the area radiation monitors. However, Regulatory Guide 1.97 indicates that the function of the radiation monitors in areas adjacent to containment penetrations is to indicate a breach of the primary containment building. Because of the high radiation levels due to radiation streaming through containment penetration and systems carrying post-LOCA fluid outside containment, these radiation monitors are not expected to

perform the intended function.

To ensure that personnel exposures do not exceed the

guidelines of NUREG-0737, administrative controls require the use of a two-person team. One person performs the vital post-LOCA function and the other surveys the area with portable survey instruments. Additionally, the area monitors listed in FSAR Table 12.3-10 are mounted in selected areas of the plant to provide an indication of the

radiation levels up to 10 Rem/hr.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 81 of 93 SRP NO. 12.5

TITLE: OPERATIONAL RADIATION PROTECTION PROGRAM DIFFERENCES FROM THE SRP:

1. NUREG-0761 guidelines are not specifically discussed.
2. Regulatory Guide 8.28 is not discussed
3. Regulatory Guide 8.3 is not discussed.

REMARKS:

1. Refer to the SRP 12.1 conformance statement.
2. Regulatory Guide 8.28, "Audible Alarm Dosimeters," is not applicable to BVPS-2. The established Radiation Protection Program does not rely upon the use of audible alarm dosimeters to satisfy regulatory requirements.
3. Regulatory Guide 8.3, "Film Badge Performance Criteria," is not applicable to BVPS-2. The established Radiation Protection Program does not rely upon the use of film badges to satisfy regulatory requirements.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 82 of 93 SRP NO. 13.2.2

TITLE: TRAINING FOR NON-LICENSED PLANT STAFF DIFFERENCES FROM THE SRP:

An annual evacuation drill for all employees is not discussed.

REMARKS:

The BVPS-2 Station Orientation Training Program, which is discussed in FSAR Section 13.2.2.1.1, meets the relevant requirements of 10 CFR 50.34(b) and 10 CFR 50, Appendix E, by providing all employees with adequate training to ensure that

they are familiar with their emergency response duties.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 83 of 93 SRP NO. 13.4

TITLE: OPERATIONAL REVIEW DIFFERENCES FROM THE SRP:

ANSI/ANS-3.l-1978 and Regulatory Guide 1.8 are not addressed with respect to the qualification requirements of personnel

assigned to the Offsite Review Committee (ORC).

REMARKS:

The independent operational review of BVPS-2 will be performed by the same ORC that has been performing this review for BVPS-1.

Qualification requirements of personnel assigned to the ORC meet those described in ANSI N18.1-1971. Meeting these qualification requirements satisfies the relevant requirements of 10 CFR 50.40(b) by ensuring that the ORC personnel are technically qualified to perform an operational review.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 84 of 93

SRP NO. 15.1.5

TITLE: STEAM SYSTEM PIPING FAILURES INSIDE AND OUTSIDE OF CONTAINMENT (PWR)

DIFFERENCES FROM THE SRP:

Items II.E.1.2, II.K.3.5, and II.K.3.25 of NUREG-0737 are not discussed in FSAR Section 15.1.5.

REMARKS:

Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3, Item II.K.3.5 is addressed in Section 1.10, and Item II.K.3.25 is addressed in Section 5.4.1.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 85 of 93 SRP NO. 15.2.6

TITLE: LOSS OF NONEMERGENCY AC POWER TO THE STATION AUXILIARIES DIFFERENCES FROM THE SRP:

Items II.E.1.1 and II.E.1.2 of NUREG-0737 are not discussed in FSAR Section 15.2.6.

REMARKS:

Item II.E.1.1 is addressed in Section 10.4.9; Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 86 of 93 SRP NO. 15.2.7

TITLE: LOSS OF NORMAL FEEDWATER FLOW DIFFERENCES FROM THE SRP:

Items II.E.1.1 and II.E.1.2 of NUREG-0737 are not discussed in FSAR Section 15.2.7.

REMARKS:

Items II.E.1.1 and II.E.1.2 are addressed in Section 10.4.9.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 87 of 93 SRP NO. 15.2.8

TITLE: FEEDWATER SYSTEM PIPE BREAKS INSIDE AND OUTSIDE CONTAINMENT (PWR)

DIFFERENCES FROM THE SRP:

Items II.E.1.1, II.E.1.2, II.K.3.5, and II.K.3.25 of NUREG-0737

are not discussed in FSAR Section 15.2.8.

REMARKS:

Item II.E.1.1 is addressed in Section 10.4.9, Item II.E.1.2 is addressed in Sections 10.4.9 and 7.3, Item II.K.3.5 is addressed in Section 1.10, and Item II.K.3.25 is addressed in Section 5.4.1.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 88 of 93 SRP NO. 15.3.3 - 15.3.4

TITLE: REACTOR COOLANT PUMP ROTOR SEIZURE AND REACTOR COOLANT PUMP SHAFT BREAK

DIFFERENCES FROM THE SRP:

Item II.K.3.5 of NUREG-0737 is not discussed in FSAR Section

15.3. REMARKS:

Item II.K.3.5 is addressed in Section 1.10.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 89 of 93 SRP NO. 15.4.8

TITLE: SPECTRUM OF ROD EJECTION ACCIDENTS (PWR)

DIFFERENCES FROM THE SRP:

The SRP implies that the stresses should be evaluated to emergency conditions defined in ASME III. Westinghouse considers this a faulted condition as stated in ANSI N18.2.

Faulted condition stress limits are applied for this accident.

REMARKS:

System overpressurization due to a rod ejection transient was evaluated in WCAP-7588 Rev. 1-A and received USNRC acceptance in the Topical Report Evaluation.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 90 of 93 SRP NO. 15.6.1

TITLE: INADVERTENT OPENING OF A PWR PRESSURIZER RELIEF VALVE OR A BWR RELIEF VALVE

DIFFERENCES FROM THE SRP:

Items II.K.3.1, II.K.3.5, and II.K.3.25 of NUREG-0737 are not

discussed in FSAR Section 15.6.1.

REMARKS:

Items II.K.3.1 and II.K.3.5 are addressed in Section 1.10 and Item II.K.3.25 is addressed in Section 5.4.1.

BVPS-2 UFSAR Rev. 16 TABLE 1.9-2 (Cont) 91 of 93 SRP NO. 15.6.5

TITLE: LOSS-OF-COOLANT ACCIDENTS RESULTING FROM SPECTRUM OF POSTULATED PIPING BREAKS WITHIN THE REACTOR COOLANT

PRESSURE BOUNDARY DIFFERENCES FROM THE SRP:

1. The parameters presented below were used to calculate the radiological consequences. These values are consistent with

NUREG-75/087 and Regulatory Guide 1.4, Revision 2.

Iodine available for release from containment 25%

Iodine composition Elemental 9l%

Particulate 5%

Methyl 4%

Iodine spray removal 10 hr-1 Maximum elemental iodine decontamination factor (NaOH) 100

2. No modifications have been made to the small break model in accordance with Items II.K.3.30 and II.K.3.31 of NUREG-0737.
3. The value assumed for ECCS leakage in radiological calculations (i.e., 2.0X10

-2 gpm) is twice the expected leakage. The expected leakage was used as a basis since the

BVPS-2 Technical Specifications (like the BVPS-1 version)

contains no limit on ECCS leakage.

REMARKS:

1. The radiological consequences calculated using the model which is consistent with NUREG-75/087 and Regulatory Guide 1.4, Revision 2, are within the requirements of 10 CFR 100.
2. The BVPS-2 positions on the PWR applicable items from the U.S. Nuclear Regulatory Commission's Clarification of TMI Action Plan Requirements for applicants for an operating license, NUREG-0737, Enclosure 2, dated November 1980 are discussed in FSAR Section 1.10.
3. The BVPS-2 Technical Specifications are modeled after the BVPS-1 Technical Specifications in accordance with NRC letter dated September 18, 1984.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 92 of 93 SRP NO. 16.0, Rev. 1

TITLE: TECHNICAL SPECIFICATIONS DIFFERENCES FROM THE SRP:

Technical Specifications are not provided.

REMARKS:

BVPS-2 Technical Specifications are currently being developed

and will be provided within the schedule suggested by the USNRC staff. A working copy of the Technical Specifications is continuously available for the USNRC Resident Inspector's use.

BVPS-2 UFSAR Rev. 0 TABLE 1.9-2 (Cont) 93 of 93 SRP NO. 17.2

TITLE: QUALITY ASSURANCE DURING THE OPERATIONS PHASE DIFFERENCES FROM THE SRP:

The description of the Duquesne Light Company Operations Quality Assurance (QA) program does not provide discussions of those

areas which are considered to be excessively detailed and, therefore, not appropriate as input to the FSAR.

REMARKS:

FSAR Section 17.2 follows the format and content guidelines of Regulatory Guide 1.70 in describing the operations QA program. Although the description does not address the more detailed SRP acceptance criteria, it provides sufficient information to conclude that the program satisfies the requirements of 10 CFR 50, Appendix B. Many of the SRP criteria are of a detailed nature not suitable for discussion in the FSAR. Methods of meeting these criteria or acceptable alternatives are documented in the Operations QA Program, Operations Quality Control Procedures, Quality Assurance Instructions, and detailed implementing procedures, all of which have been successfully implemented since early 1976 for BVPS-1.

BVPS-2 UFSAR Rev. 0 1.10-1 1.10 NUREG 0737 ACTION ITEMS Table 1.10-1 presents the BVPS-2 positions on the PWR applicable items from the U.S. Nuclear Regulatory Commission's

Clarification of TMI Action Plan Requirements for applicants for an operating license, NUREG-0737, Enclosure 2, dated November 1980. In addition, this table identifies the location of each

individual item addressed in the UFSAR.

BVPS-2 UFSAR Tables for Section 1.10

BVPS-2 UFSAR Rev. 14 1 of 6 TABLE 1.10-1 NUREG 0737 CONFORMANCE Item and Title Position UFSAR Reference I.A.1.1 Shift Technical Advisor BVPS-2 will meet the intent of this item.

13.2.2.5 I.A.1.2 Shift Supervisor Administrative Duties BVPS-2 will meet the intent of this item.

13.5.1 I.A.1.3 Shift Manning BVPS-2 meets the intent of this item. Minimum shift crew composition is specified by 10 CFR 50.54. Controls on working hours are specified by technical specifications.

13.5.1 I.A.2.1 Immediate Upgrade of RO and SRO Training and Qualifications

BVPS-2 will meet the intent of this item.

I.A.2.3 Administration of Training Programs

BVPS-2 will meet the item by having licensed operation instructors enrolled in the operator's retraining program.

I.A.3.1 Revise Scope and Criteria for Licensing Examinations BVPS is building its own simulator and once complete will make it available for the simulator examination portion of NRC licensing examination.

I.B.1.2 Evaluation of Organization and Management BVPS-2 will meet the intent of this item.

13.4.4 I.C.1 Short-Term Accident Analysis and Procedures Revision Following USNRC review and approval of the Westinghouse Owners Group revised emergency procedure guidelines, BVPS-2 will revise its emergency procedures, as necessary, to incorporate these recommendations.

13.5.2 I.C.2 Shift and Relief Turnover Procedures

BVPS-2 Administrative Procedures will meet the intent of this item.

13.5.1 I.C.3 Shift Supervisor Responsibility

BVPS-2 Administrative Procedures will comply with the intent of this item.

13.5.1 I.C.4 Control Room Access

BVPS-2 Administrative Procedures will comply with the intent of this item.

13.5.1 BVPS-2 UFSAR Rev. 0 2 of 6 TABLE 1.10-1 (Cont)

Item and Title Position UFSAR Reference I.C.5 Procedures for Feedback of Operating Experience

BVPS-2 Administrative Procedures will comply with the intent of this item.

13.5.1 I.C.6 Procedures for Verification of Correct Performance of Operating Activities BVPS-2 Administrative Procedures will comply with the intent of this item.

13.5.1 I.C.7 NSSS Vendor Review of Procedures BVPS-2 remains available to correct any deficiencies found in it s low-power, power ascension, and emergency procedures, as necessary, if the NRC opts to require a NSSS vendor review. However, it may not be necessary cons idering BVPS-2 response to I.C.1.

  • I.C.8 Pilot Monitoring of Selected Emergency Procedures for NTOLS BVPS-2 remains available to correct any deficiencies found in its em ergency pr ocedures if the USNRC opts to conduct a pilot monitoring program. The PMP may not be necessary considering the BVPS-2 response to Item I.C.1.
  • I.D.1 Control Room Design Review A control room design review has been performed for BVPS-2 to meet this item. 18.0 I.D.2 Plant Safety Parameter Display Console BVPS-2 will install a safety parameter display system.

7.5.6 I.G.1 Training During Low-Power Testing The training objectives required by NUREG-0737, Item I.G.1 will be satisfied and operator training will be provided on a simulator which adequately represents BVPS-2 performance with regard to natural circulation.

Test data which could be used to update existing simulator training will be obtained using the approved guidelines of the revised Westinghouse Low Power Test Program (W NS-EPR-2465 dated July 8, 1981) as indicated below:

1. During hot functional testing with the reactor coolant pumps supplying heat input to the secondary side, a loss of AC power will be simulated to the auxiliary feed pumps, controls and area ventilation. This will demonstrate that the plant can be stabilized

utilizing manual control and the steam driven auxilia ry feedwater pump. Informational data will be taken for simulator update as necessary, with no acceptance criteria applied.

2. The existing initial startup test, (Section 14.2.12.8.13), "Pressurizer Heater and Spray Capability" test will be revised to include a section with one RCP in operation

BVPS-2 UFSAR Rev. 14 2a of 6 TABLE 1.10-1 (Cont)

Item and Title Position UFSAR Reference (not to be in loops with pressurizer surge line or spray line). Pre ssure will be reduced by turning off pressurizer heaters and noting depressurization rate. The heaters will then be re-established and pressure further reduced by use of auxiliary spray. The effects of changes in charging flow and steam flow on margin to saturation temperature will be observed. Test data will be recorded and will be available for simulator update as necessary, with no acceptance criteria applied.

3. BVPS-2 does not plan to conduct this natural circulation test since results of testing previously performed at North Anna-2 are sufficient to demonstrate the adequacy of BVPS-2 design features related to natural circulation. BVPS-1 has experienced loss of AC power and has satisfactorily demonstrated natural circulation during this transient.
4. The existing initial startup test (Section 14.2.12.6.5), "Verification of Plant Performance Following Turbine Trip Coincident with Loss of Offsite Power at Load" is satisfactory for obtaining the necessary plant conditions. Us ing this test, the plant will be brought to stable conditions using batteries and emergency diesels.

II.B.1 Reactor Coolant System Vents BVPS-2 meets the intent of this item.

5.4.13 5.4.15 II.B.2 Plant Shielding BVPS-2 will meet the intent of this item.

12.3.2 II.B.3 Post-Accident Sampling The requirement for a post-accident sampling system was eliminated by License Amendment No. 123.

II.B.4 Training for Mitigating Core Damage BVPS-2 will meet the intent of this item.

13.2.2.6 BVPS-2 UFSAR Rev. 0 3 of 6 TABLE 1.10-1 (Cont)

Item and Title Position UFSAR Reference II.D.1 Testing Requirements for Reactor Coolant System Relief and Safety Valves BVPS-2 meets the intent of this item with the exception of ATWS testing.

3.9N.3 5.4.13 II.D.3 Direct Indication of Relief and Safety Valve Position BVPS-2 meets the intent of this item.

7.5 II.E.1.1 Auxiliary Feedwater System Evaluation BVPS-2 meets the intent of this item.

10.4.9.3 10A.1 II.E.1.2 Auxiliary Feedwater System Automatic Initiation and Flow Indication

BVPS-2 meets the intent of this item.

7.3 10.4.9 II.E.3.1 Emergency Power Supply for Pressurizer Heaters BVPS-2 meets the intent of this item.

8.3.1.1.3 8.3.2 II.E.4.1 Dedicated Hydrogen Penetrations (Containment Design)

BVPS-2 meets the intent of this item.

6.2.5.1 II.E.4.2 Containment Isolation Dependability BVPS-2 meets the intent of this item.

6.2.4 7.3 II.F.1 Additional Accident Monitoring Instrumentation

Attachment (1) BVPS-2 will meet the intent of this item.

11.5.1 11.5.2.4.2 Attachment (2) BVPS-2 will meet the intent of this item.

11.5.2.4.2 11.5.1 Attachment (3) BVPS-2 will meet the intent of this item 12.3 Attachment (4) BVPS-2 meets the intent of this item.

7.5 Attachment (5) BVPS-2 meets the intent of this item.

7.5 Attachment (6) BVPS-2 meets the intent of this item.

  • BVPS-2 UFSAR Rev. 16 4 of 6 TABLE 1.10-1 (Cont)

Item and Title Position UFSAR Reference II.F.2 Identification of and Recovery from Conditions Leading to Inadequate Core Cooling BVPS-2 will meet the intent of this item. A detailed description of plant design satisfying this item will be provided in an amendment to BVPS-2 UFSAR.

7.5 7.7.2 II.G.1 Power Supplies for Pressurizer Relief Valves, Block Valves, and Level Indicators BVPS-2 meets the intent of this item.

8.3.1.1.3 8.3.1.2 II.K.1.5 Review ESF Valves BVPS-2 plant operating procedures will meet the intent of this item.

13.5.2.1 II.K.1.10 Operability Status BVPS-2 meets the intent of this item.

13.5.2.1 II.K.1.17 Trip per Low-Level B/S BVPS-2 meets the intent of this item.

7.1 7.2 II.K.2.13 Thermal Mechanical Report Westinghouse (in support of the Westinghouse Owners Group) has developed methods and performed analyses for a spectrum of small LOCAs. The methods employed the NOTRUMP computer program to generate the thermal/hydraulic transients. The results of the analyses are provided in WCAP-10019.

  • II.K.2.17

Potential for Voiding in the Reactor Coolant System During Transients BVPS-2 meets the intent of this item.

5.4.7.2.3 II.K.2.19 Sequential Auxiliary Feedwater Flow Analysis This item is not applicable to BVPS-2. The concerns expressed in this item do not apply to NSSS with inverted U-tubes such as the one utilized in BVPS-2.

  • II.K.3.1 Installation and Testing of Automatic Power-Operated Relief Valve Isolation System As a result of the evaluation documented in WCAP-9804, February 1981, it has been determined that an automatic pressurizer power-operated relief valve isolation system is not required for BVPS-2.
  • BVPS-2 UFSAR Rev. 16 5 of 6 TABLE 1.10-1 (Cont)

Item and Title Position UFSAR Reference II.K.3.2 Report on Overall Safety Effects of Power-Operated Relief Valve Isolation System A generic report was submitted by the Westinghouse Owners Group which responds to this item (WCAP-9804). This report identifies a significant reduction in the PORV LOCA probability as a result of post-TMI modifications and the calculations compare favorably with the operational data for Westinghouse plants (included as an appendix to the report).

II.K.3.3 Reporting SV and RV Failures and Challenges Failures of PORVs or safety valves to close when required will be reported as appropriate in accordance with 10 CFR 50.72 and 10 CFR 50.73.

16 II.K.3.5 Automatic Trip of Reactor Coolant Pumps During Loss-of-Coolant Accident Westinghouse has performed an analysis of delayed reactor coolant pump trip during small-break LOCAs. This analysis is documented in WCAP-9584 and WCAP-9585, August 1979. In addition, Westinghouse has performed test predictions of LOFT experiments L3-1 and L3-6. The results of these predictions are documented in letters OG-49, dated, March 3, 1981; OG-50, dated March 23, 1981; and OG-60, dated, June 15, 1981. Based on: 1) the Westinghouse analysis, 2) the excellent prediction of the LOFT experiment L3-6 results using the Westinghouse analytical model, and 3) Westinghouse simulator data related to operator response time, the Westinghouse & BVPS-2 position is that the automatic reactor coolant pump trip is not necessary, since sufficient time is available for manual tripping of all the pumps.

  • II.K.3.7 Evaluation of PORV Opening Probability This item is applicable to B&W plants only and therefore, does not apply to BVPS-2.
  • II.K.3.9 Proportional Integral Derivative Controller Modification

BVPS-2 controller (PID) derivative action setting is zero, thereby eliminating it from consideration. Therefore, II.K.3.9 is not applicable to BVPS-2.

  • II.K.3.10 Proposed Anticipatory Trip Modification

BVPS-2 meets the intent of this item.

7.2.1.1.2 II.K.3.12

Confirm Anticipatory Trip

BVPS-2 design meets the intent of this item.

7.2.1.1.2 II.K.3.17 Report on Outages of Emergency Core Cooling Systems Licensee Report and Proposed Technical Specification Changes BVPS-2 will meet the intent of this item.

13.5.2.1 BVPS-2 UFSAR Rev. 0 6 of 6 TABLE 1.10-1 (Cont)

Item and Title Position UFSAR Reference II.K.3.25 Effect of Loss of Alternating Current Power on Pump Seals BVPS-2 meets the intent of this item.

5.4.1.3.1 II.K.3.30 Revised Small Break Loss-of-Coolant Accident Methods to Show Compliance with 10CFR Part 50, App. K

BVPS-2 position on the small-break LOCA analysis model currently approved by the NRC for use on BVPS-2 is conservative and in confor mance with Appendix K to 10CFR Part 50. However (as documented in Anderson 1980), Westinghouse believes that improvement in the realism of small-break calculations is a worth-while effort and is currently developing a revised small-break LOCA analysis model to address NRC concerns (e.g. NUREG-0611, NUREG-0623, etc). Review and approval of the revised W small-break model by the NRC is scheduled for December 1, 1983.

15.6.5 II.K.3.31 Plant Specific Calculations to Show Compliance with 10 CFR Part 50.46 A small-break loss-of-coolant accident analysis specific to BVPS-2 is provided using the present Westinghouse small-break evaluation model. This is in conformance with 10CFR Part 50, Appendix K.

15.6.5 III.A.1.1 Emergency Preparedness, Short Term BVPS Emergency Preparedness Plan (EPP) is in compliance with standards of 10CFR50 Appendix E and meets the intent of this item.

13.3 III.A.1.2 Upgrade Emergency Support Facilities BVPS-2 will meet the intent of this item.

13.3 III.A.2 Emergency Preparedness BVPS-2 Emergency Preparedness Plan will comply with the intent of this item.

13.3 III.D.1.1 Primary Coolant Sources Outside Containment BVPS-2 plant operating procedures will meet the intent of this item.

13.5.2.1 III.D.3.3 Inplant I Radiation Monitoring BVPS-2 will meet the intent of this item.

12.3 III.D.3.4 Control Room Habilitability BVPS-2 meets the intent of this item.

6.4 NOTE:

  • Statement stands alone, no UFSAR Section reference

.

BVPS-2 UFSAR Rev. 2B 1.11-1 1.11 ASME CODE CASES Table 1.11-1 is provided as a convenient means for locating discussions of code cases located in the FSAR or other docketed licensing basis

documents.

BVPS-2 UFSAR Tables for Section 1.11

BVPS-2 UFSAR Rev. 14 1 of 1 TABLE 1.11-1 ASME CODE CASE REFERENCES Code Case Location of Reference to Code Case General UFSAR Table 1.8, Regulatory Guides 1.84, 1.85 and 1.147 UFSAR Section 5.4.2.1.1 1177 UFSAR Table 1.8, Regulatory Guide 1.57 UFSAR Section 3.8.1.2.3 1330-3 UFSAR Table 1.8, Regulatory Guide 1.57 UFSAR Sections 3.8.1.2.3 and 3.8.2.7 1332-6 UFSAR Table 3.8-8 1355 Response to NRC question 210.44 1401-1 Response to NRC question 210.44 1423-2 UFSAR Table 5.2-2 Response to NRC question 210.44 1484 Response to NRC question 210.44 1493-1 Response to NRC question 210.44 1501 Response to NRC question 210.44 1526 Response to NRC question 210.44 1528 UFSAR Section 5.2.1.2 Response to NRC question 210.44 1552 Response to NRC question 210.44 1553-1 Response to NRC question 210.44 1605 UFSAR Table 1.8, Regulatory Guide 1.65 1606 UFSAR Table 3.9B-10 1607 UFSAR Table 3.9B-10 1618 UFSAR Table 5.2-4 1635 UFSAR Table 3.9B-10 1636 UFSAR Table 3.9B-10 1644 Response to NRC question 210.35 1649 Response to NRC question 210.44 N-3-10 (1335-10)

Response to NRC question 210.44 N-242-1 Response to NRC question 210.44 N-318 UFSAR Sections 3A.3, 3A.3.22.1, 3A.3.23.1 and 3A.3.25 N-392 UFSAR Sections 3A.3, 3A.3.21.1, 3A.3.24.1 and 3A.3.25 N-411 UFSAR Table 1.8, Regulatory Guides 1.61 and 1.122 UFSAR Section 3.7B.3.1.2

UFSAR Table 3.7B-1 BVPS-2 UFSAR Rev. 14 1.12-1 1.12 EQUIVALENT MATERIALS Materials listed in the UFSAR that are qualified with an "or equivalent" statement may be replaced with an evaluated alternative material. Prior to the replacement of an existing material for a component part, an engineering technical evaluation is performed to determine suitability and acceptability for the application. These technical evaluations are performed utilizing approved procedures which meet the design control requirements of the FENOC Quality Assurance Program. The Site Design Control program under which the acceptability of alternate materials is evaluated addresses many material properties and their interactions with the system environment. In a typical evaluation, material properties

such as tensile strength, yield strength, ductility, fracture toughness, corrosion resistance, surface conditions, hardness, thermal conductivity, heat treatment, and electro-chemical potential are evaluated as appropriate for the application. The term "equivalent,"

however, does not apply to materials specified in the UFSAR that are required by a legally binding commitment described in the license or NRC Safety Evaluation Report (SER).

Retrieved from "https://kanterella.com/w/index.php?title=ML14339A414&oldid=785202"