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| number = ML16180A431
| number = ML16180A431
| issue date = 02/01/2016
| issue date = 02/01/2016
| title = Comanche Peak, Units 1 and 2 - FSAR Amendment 107, Text - Chapters 1 and 2
| title = FSAR Amendment 107, Text - Chapters 1 and 2
| author name =  
| author name =  
| author affiliation = Luminant Generation Co, LLC
| author affiliation = Luminant Generation Co, LLC
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=Text=
=Text=
{{#Wiki_filter:CPNPP/FSAR1-iAmendment No. 10
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==41.0  INTRODUCTION==
AND GENERAL DESCRIPTION OF THE PLANTTABLE OF CONTENTS SectionTitlePage
 
==1.1INTRODUCTION==
.........................................................................................................1.1-1 1.1.1STATION LOCATION...........................................................................................1.1-11.1.2NUCLEAR STEAM SUPPLY SYSTEM.................................................................1.1-11.1.3CONTAINMENT....................................................................................................1.1-11.1.4CORE THERMAL POWER LEVEL.......................................................................1.1-1 1.1.5SCHEDULE...........................................................................................................1.1-21.2GENERAL PLANT DESCRIPTION.............................................................................1.2-1 1.2.1SITE CHARACTERISTICS...................................................................................1.2-11.2.1.1Geology and Seismology................................................................................1.2-1 1.2.1.2Hydrology........................................................................................................1.2-2 1.2.1.3Meteorology.....................................................................................................1.2-21.2.1.4Environmental Radiation Monitoring...............................................................1.2-31.2.2PLANT DESCRIPTION.........................................................................................1.2-3 1.2.2.1Design Criteria.................................................................................................1.2-31.2.2.2Nuclear Steam Supply System........................................................................1.2-31.2.2.2.1Reactor Core...................................................................................................1.2-4 1.2.2.2.2Reactor Coolant System.................................................................................1.2-51.2.2.3Engineered Safety Features............................................................................1.2-51.2.2.3.1Containment....................................................................................................1.2-6 1.2.2.3.2Containment Spray System.............................................................................1.2-61.2.2.3.3Containment Spray Chemical Additive Subsystem.........................................1.2-71.2.2.3.4Containment Isolation System.........................................................................1.2-7 1.2.2.3.5Combustible Gas Control Systems.................................................................1.2-71.2.2.3.6Emergency Core Cooling System...................................................................1.2-81.2.2.3.7Control Room Habitability Systems.................................................................1.2-8 1.2.2.3.8Residual Heat Removal System......................................................................1.2-81.2.2.4Plant Instrumentation and Control System......................................................1.2-81.2.2.5Power Conversion and Electrical Systems......................................................1.2-9 1.2.2.6Fuel Handling and Storage System...............................................................1.2-101.2.2.7Cooling Water Systems.................................................................................1.2-101.2.2.8Auxiliary Systems..........................................................................................1.2-11 1.2.2.8.1Chemical and Volume Control System..........................................................1.2-121.2.2.8.2Sampling Systems.........................................................................................1.2-131.2.2.8.3Compressed Air Systems..............................................................................1.2-13 1.2.2.8.4Plant Ventilation System...............................................................................1.2-131.2.2.8.5Station Service Water System.......................................................................1.2-141.2.2.8.6Plant Fire Protection System.........................................................................1.2-14 1.2.2.8.7Spent Fuel Pool Cooling and Cleanup System.............................................1.2-171.2.2.9Waste Processing Systems...........................................................................1.2-171.2.2.10Safe Shutdown Impoundment.......................................................................1.2-18 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage1-iiAmendment No. 1041.2.2.11Shared Structures, Systems, and Components............................................1.2-191.2.2.11.1Shared Structures.........................................................................................1.2-191.2.2.11.2Shared Systems............................................................................................1.2-191.2.2.11.3Shared Components.....................................................................................1.2-20 1.2.2.12General Arrangements..................................................................................1.2-201.2.2.13References....................................................................................................1.2-201.2.3OLD STEAM GENERATOR STORAGE FACILITY............................................1.2-211.3COMPARISON TABLES.............................................................................................1.3-11.3.1DELETED..............................................................................................................1.3-11.3.2COMPARISON OF FINAL AND PRELIMINARY DESIGNS.................................1.3-11.4IDENTIFICATION OF AGENTS AND CONTRACTORS.............................................1.4-11.4.1OWNERS AND APPLICANTS - LUMINANT GENERATION COMPANY LLC (LUMINANT POWER)...........................................................................................1.4-11.4.2OPERATOR - LUMINANT POWER......................................................................1.4-11.4.3ENGINEERING ORGANIZATION - LUMINANT POWER.....................................1.4-21.4.4ARCHITECT-ENGINEER -....................................................................................1.4-2 1.4.5NUCLEAR STEAM SUPPLY SYSTEM MANUFACTURER - WESTINGHOUSE.................................................................................................1.4-31.4.6EARTH SCIENCES ENGINEER - DAMES & MOORE.........................................1.4-3 1.4.7CONSTRUCTOR - BROWN & ROOT, INC..........................................................1.4-41.4.8SUBSURFACE AND SOILS INVESTIGATION - MASON-JOHNSTON & ASSOCIATES.......................................................................................................1.4-41.4.9RESERVOIR DESIGN - FREESE AND NICHOLS...............................................1.4-41.4.10OPERATIONS QUALITY ASSURANCE AND ADMINISTRATIVE CONTROL - EDS NUCLEAR INCORPORATED...............................................................................1.4-51.4.11DIVISION OF RESPONSIBILITY..........................................................................1.4-51.4.11.1Design Stage...................................................................................................1.4-51.4.11.2Procurement of Safety-Related Equipment.....................................................1.4-5 1.4.11.2.1Westinghouse Scope of Supply......................................................................1.4-51.4.11.2.2Scope of Luminant Power's Services..............................................................1.4-51.4.11.3Construction....................................................................................................1.4-6 1.4.11.4Operation.........................................................................................................1.4-61.4.11.5Startup Assistance..........................................................................................1.4-61.5REQUIREMENTS FOR FURTHER TECHNICAL INFORMATION.............................1.5-11.5.1BLOWDOWN HEAT TRANSFER TESTING.........................................................1.5-11.5.1.1Objective.........................................................................................................1.5-11.5.1.2Program...........................................................................................................1.5-21.5.1.3Test Description..............................................................................................1.5-2 1.5.1.4Results............................................................................................................1.5-2 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage1-iiiAmendment No. 104REFERENCES......................................................................................................1.5-31.6MATERIAL INCORPORATED BY REFERENCE.......................................................1.6-11.7ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS.........................1.7-11A(N)DISCUSSION OF REGULATORY GUIDES...........................................................1A(N)-1REFERENCES................................................................................................1A(N)-461A(B)FDISCUSSION OF REGULATORY GUIDES.........................................................1A(B)-1 CPNPP/FSAR1-ivAmendment No. 104LIST OF TABLES NumberTitle1.3-1DELETED 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS1.5-1DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE I TEST PARAMETERS1.5-2DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE II TEST PARAMETERS1.6-1DOCUMENTS INCORPORATED BY REFERENCE1.6-2DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 11.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 21A(N)-1TUBULAR PRODUCTS WITHIN WESTINGHOUSE SCOPE RELATED TO REGULATORY GUIDE 1.66 CPNPP/FSAR1-vAmendment No. 104LIST OF FIGURES NumberTitle1.2-1Plot Plan 1.2-2West Elevation 1.2-3North Elevation1.2-4East Elevation1.2-5South and Part Elevations 1.2-6Building Cross-Sections 'A-A' & 'B-B'1.2-7Building Cross-Section 'C-C'1.2-8Building Cross-Section 'D-D'1.2-9Building Cross-Section 'E-E'1.2-10Primary Plant Unit No. 1 Containment and Safeguard Building Plans at El.773'-0" & 790'-6"1.2-11Primary Plant Unit No. 1 Containment and Safeguard Building Plans at El.808'-0" & 810'-6"1.2-12Primary Plant Unit No. 1 Containment and Safeguard Building Plans at El.831'-6" & 832'-6"1.2-13Primary Plant Unit No. 1 Containment and Safeguard Building Plans at El.852'-6" & 860'-0"1.2-14Primary Plant Unit No. 1 Containment and Safeguard Building Floor Plan at El. 873'-6"1.2-15Primary Plant Unit No. 1 Containment Building Plan at El. 905'-9" 1.2-16Primary Plant Unit No. 2 Containment and Safeguard Buildings Plans at El.773'-0" & 790'-6"1.2-17Primary Plant Unit No. 2 Containment and Safeguard Buildings Plans at El.808'-0" & 810'-6"1.2-18Primary Plant Unit No. 2 Containment and Safeguard Buildings Plans at El.831'-6" & 832'-6"1.2-19Primary Plant Unit No. 2 Containment and Safeguard Buildings Plans at El.852'-6" & 860'-0" CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle1-viAmendment No. 1041.2-20Primary Plant Unit No. 2 Containment and Safeguard Buildings Floor Plans at El. 873'-6"1.2-21Primary Plant Unit No. 2 Containment Building Plan at El. 905'-9" 1.2-22Turbine Building Unit No. 1 Basement Floor Plan El. 778'-0"1.2-23Turbine Building Unit No. 1 Mezzanine Floor Plan El. 803'-0" & 810'-6"1.2-24Turbine Building Unit No. 1 Oper. Floor Plan El. 830'-0" 1.2-25Turbine Building Unit No. 1 Misc. Plans and Details1.2-26Turbine Building Unit No. 1 & 2 Miscellaneous Plans1.2-27Turbine Building Unit No. 2 Basement Floor Plan El. 778'-0"1.2-28Turbine Building Unit No. 2 Mezzanine Floor Plan El. 803'-0" & 810'-6"1.2-29Turbine Building Unit No. 2 Operating Floor Plan El. 830'-0" 1.2-30Turbine Building Unit No. 2 Misc. Plans and Details1.2-31Primary Plant - Auxiliary & Electrical/Cont. Buildings Floor Plan at El.778'-0" & 790'-6"1.2-32Primary Plant - Auxiliary & Electrical/Cont. Buildings Floor Plan at El.807'-0" & 810'-6"1.2-33Primary Plant - Auxiliary & Electrical/Cont. Buildings Floor Plan at El.830'-0" & 831'-6"1.2-34Primary Plant - Auxiliary & Electrical/Cont. Buildings Floor Plan at El.852'-6" & 854'-4"1.2-35Primary Plant - Auxiliary Building Part Plans at El. 842'-0" & 873'-6"1.2-36Primary Plant - Electrical/Cont. Building Observation Floor Plan Section and Details El. 840'-6"1.2-37Electrical/Cont. Building Miscellaneous Plans & Details 1.2-38Primary Plant Fuel Building Floor Plan at El. 810'-6"1.2-39Primary Plant Fuel Building Floor Plan at El. 838'-9" & 841'-0" CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle1-viiAmendment No. 1041.2-40Primary Plant Fuel Building Plan at 860'-0" & 899'-6"1.2-41Circ. Water Intake Structure Lower Level Floor Plan1.2-42Circ. Water Intake Structure Plan at El. 779'-9"1.2-43Circ. Water Intake Structure Operating Level Floor Plan at El. 795'-9" 1.2-44Circ. Water Intake Structure Cross Sections1.2-45Service Water Intake Structure Floor and Roof Plans1.2-46Service Water Intake Structure Elevations, Sections, and Details 1A(N)-1Results of Westinghouse Capsule Irradiation Tests1A(N)-2Aluminum Corrosion in DBA Environment CPNPP/FSAR1.1-1Amendment No. 10
 
==61.1INTRODUCTION==
This updated Final Safety Analysis Report (FSAR) describes the design, construction and operation of a two-unit nuclear power plant designated as the Comanche Peak Nuclear Power
 
Plant (CPNPP), Operating Licenses NPF-87 and NPF-89 for Units 1 and 2, respectively. All future references to the Final Safety Analysis Report (or FSAR) contained in this document refer to the updated FSAR. This report follows the format recommended by Regulatory Guide 1.70, Revision 2, Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants. The design information provided herein reflects the design in sufficient detail to enable a definitive evaluation as to whether CPNPP can be constructed and operated without undue risk to the health and safety of the public.The Owner of CPNPP is Luminant Generation Company LLC, a subsidiary of TXU Energy Company LLC (Luminant Power) which is a subsidiary of TXU Corporation.
Luminant Power - has corporate responsibility for the design, engineering, construction, licensing, operation, procurement, quality assurance and fuel management support to CPNPP.1.1.1STATION LOCATIONLocated in Somervell County in North Central Texas, the CPNPP is about 65 miles southwest of the Dallas-Fort Worth Metropolitan Area. In addition, the Squaw Creek Reservoir (SCR), built for station cooling, extends northward into Hood County.1.1.2NUCLEAR STEAM SUPPLY SYSTEMThe Nuclear Steam Supply System (NSSS) for each unit is a pressurized water reactor, which along with the design and fabrication of the initial cores, is supplied by Westinghouse Electric Corporation.1.1.3CONTAINMENTThe containment for each unit is a steel-lined, reinforced concrete, cylindrical structure with a hemispherical dome designed by Gibbs & Hill, Inc. (Architect-Engineer).1.1.4CORE THERMAL POWER LEVELEach generating unit core was originally designed for a warranted power output of 3411 Megawatt thermal (MWt), which corresponds to a net electrical output of approximately 1150 Megawatt electric (MWe). This output, combin ed with the reactor coolant pump heat output of 14 MWt, gives a warranted NSSS output of 3425 MWt, which is the license application rating. A 4.5 percent increase in steam flow results in the maximum calculated NSSS output of 3579 MWt, and thus a maximum calculated core output of 3565 MWt. All safety systems, including the containment and engineered safety features, are designed for operation at the maximum
 
calculated power output.The thermal power output of Units 1 and 2 were subsequently increased to 3612 MWt.
CPNPP/FSAR1.1-2Amendment No. 1061.1.5SCHEDULE CPNPP Unit 1 was declared for commercial operation on August 13, 1990. Unit 2 was declared for commercial operation on August 3, 1993.
CPNPP/FSAR1.2-1Amendment No. 1071.2GENERAL PLANT DESCRIPTION1.2.1SITE CHARACTERISTICSThe site of the Comanche Peak Nuclear Power Plant (CPNPP) is in an area of low population (520 persons within four miles of site) having a rural farm-ranch community setting. There are no residents within one mile of the site, and only 75 persons reside within two miles. There are approximately 12,000 persons within 10 miles of the site. The nearest communities, Glen Rose and Granbury (combined 1970 population about 4,000 persons), are 4 1/4 and 10 miles from the site, respectively. Fort Worth (1970 population about 400,000), from 33 to 50 miles from site, is the nearest major population center.Land use in the site vicinity and surrounding area is predominantly agricultural. Dairy cattle are a minor portion of the total livestock with the closest commercial dairy herd nearly five (5) miles from the site. There is no commercial fishing in the site vicinity.Although local population is projected to increase, no land use characteristics are projected to be drastically altered during station life. The si te is well-suited for loc ating a nuclear generating installation because of a large exclusion area with a minimum boundary distance of 5,067 feet (1544 meters), a population center distance greater than 20 miles, a rock foundation for all seismic Category I structures, a lack of high surface water conditions, an available cooling water supply, and because of favorable hydrologic, geologic, seismic, and meteorologic conditions.1.2.1.1Geology and SeismologyThe CPNPP site is located on the Comanche Plateau, a subdivision of the Central Texas section of the Great Plains physiographic province.Gently dipping Lower Cretaceous limestone and sandstone directly underlie the site.Structurally, the site occupies the south flank of the Fort Worth basin, a sedimentary depositional trough filled with Pennsylvanian and Permian sediments formed in mid-Pennsylvanian time. A regional unconformity separates the Paleozoic sediments from the lower Cretaceous sediments underlying the site.Detailed investigation within five miles of the site has disclosed no evidence of surface faulting, thus eliminating the need for considering this factor as a design basis.With regard to the stability of subsurface materials, there is no evidence in the site region indicating actual or potential uplift or subsidence, cavernous or karst terrain, tectonic warping or deformational zones pertinent to the site. Also not in evidence are zones of alteration, significant
 
weathering, structural weakness, unrelieved re sidual stresses, or geologically hazardous materials.Two major fault systems, the Balcones and the Luling-Mexia-Talco fault zones occur within 200miles of the site. They are not regarded as active faults but are considered in establishing the Safe Shutdown Earthquake (SSE).Seventeen seismic events have been reported with epicenters within 200 miles of the site. The closest large event was a modified Mercalli Intensity VII which occurred in 1882 near Bonham, CPNPP/FSAR1.2-2Amendment No. 107Texas, 155 miles northeast of the CPNPP. The closest known event to the site occurred 90 miles to the north in 1950 and exhibited an intensity of IV. Two events occurred 90 and 100 miles to the southeast of the site in 1932 (V-VI) and 1970 (IV), respectively. For the purpose of establishing the Safe Shutdown Earthquake (SSE), it has been assumed that a Bonham type event could occur at the closest approach of the Wichita-Ouachita tectonic subprovince to the site (70 miles). Based on these considerations, a conservative safe shutdown earthquake of 0.12g has been selected for the site. An acceleration of 0.06g has been selected for the site operating basis
 
earthquake based on similar analysis.In conclusion, the site is acceptable from a geologic and seismic standpoint for the facility designed for the SSE.1.2.1.2Hydrology The CPNPP site is on Squaw Creek, a tributary of the Paluxy and thence Brazos rivers. Squaw Creek Reservoir (SCR) is impounded for station cooling by a dam constructed on Squaw Creek approximately 4 1/2 miles upstream of its confluence with the Paluxy and Brazos rivers.The site grade is at elevation 810 feet, which provides 20.3 feet of freeboard above the Probable Maximum Flood (PMF) and superimposed wave runup on Squaw Creek Reservoir. The site grade is well above the maximum water levels conceivable on the Brazos River. Hence, the site will be unaffected by river flooding of any kind and will not be affected by tsunami, seiche, or ice flooding.A continuous supply of service water is assured by means of a seismic Category I dam which encloses an arm of SCR. For the purpose of controlling the concentration of dissolved solids, SCR receives makeup water from Lake Granbury, on the Brazos River, and SCR blowdown is returned to Lake Granbury.Most of the groundwater in the site region occurs in bedrock, although some does exist in shallow flood plain alluvium in stream valleys, but is not withdrawn for use. Bedrock aquifers pertinent to the CPNPP vicinity include, in order of increasing age, the Paluxy, Glen Rose, and Twin Mountains formations. Locally, the CPNPP and SCR are on the Glen Rose outcrop, which in turn is underlain by the Twin Mountains Formation. The Paluxy Formation is absent at the CPNPP location and is not found within the limits of the reservoir; the Glen Rose Formation is the upper most stratigraphic unit exposed in these areas.In these formations, groundwater percolates slowly along bedrock joints and fractures, and through interstices in the rock fabric. The Twin Mountains Formation is the only moderately productive bedrock zone in the site vicinity. The Paluxy Formation has nominal pumpage near the site. The Glen Rose Formation yields very little water in the site area and is usually less productive than the other formations.The station's liquid waste processing system is designed so that radioactive liquid waste can be processed adequately prior to release to the environment as described in Section 11.2
. 1.2.1.3Meteorology Located approximately 290 miles to the northwest of the Gulf of Mexico, the CPNPP site usually experiences a continental climate with marked temperature extremes both diurnally and CPNPP/FSAR1.2-3Amendment No. 107seasonally. Maritime tropical air masses almost completely dominate the weather in summer. During the winter, outbreaks of polar continental air are the most common frontal activity, while pacific maritime cold fronts are more frequent in the spring and fall. Wide variations in precipitation amounts occur from year to year, including both drought and persistent rains (occasionally induced by land-weakened, but rain-filled tropical cyclones from the Gulf of Mexico).Tornado average return is about once in 320 years for the station site.The accident dilution factors at the site are similar to those specified by Regulatory Guide 1.4 for tentative use in site evaluations. The highest frequency of poorer diffusion conditions generally occur with winds blowing toward the northwest, north-north-west, and north sectors. Some amelioration of the conditions in these sectors will be provided by the warmed waters of the SCR and by reduced topographic variation. The routine dilution factors were evaluated according to Regulatory Guide 1.111.1.2.1.4Environmental Radiation MonitoringPre-operational baseline radiological monitoring has been performed to determine the average background radiation level.Conditions of radioactive releases are expected to be infrequent and thus contribute little dose to humans. Of primary concern are doses attributable to I-131 uptake and the submersion dose from noble gases. The primary emphasis of the operational environmental monitoring program will be to measure whole body dose from gaseous effluent and onsite sources, I-131 in air, and radionuclides (especially I-131) in milk. Radionuclides will also be measured in airborne particulate, surface water, well water, broadleaf vegetation, food products, fish, and milk. Frequency of data collection and location of measurements have been evaluated to maximize the data relating to the dose in humans.1.2.2PLANT DESCRIPTION1.2.2.1Design CriteriaThe design of the CPNPP complies with Appendix A of 10 CFR Part 50, General Design Criteria for Nuclear Power Plants.1.2.2.2Nuclear Steam Supply System The Nuclear Steam Supply system (NSSS) consists of a Westinghouse pressurized water reactor (PWR) and supporting auxiliary systems. The nuclear, mechanical, and thermal-hydraulic design of the reactor core is similar to the design of other Westinghouse units under construction. The rated thermal output of Unit 1 and Unit 2 is 3458 megawatt thermal (MWt). Heat balances, showing the major parameters of the plant for the original design rated power condition and maximum expected power condition and that provide bounding thermal/hydraulic conditions for the core power uprates to 3458 MWt, are shown in Section 10.1
.
CPNPP/FSAR1.2-4Amendment No. 107Nominal performance of the NSSS based on 0 percent makeup is as follows:1.2.2.2.1Reactor Core The reactor core is a multi-regions core composed of slightly enriched uranium dioxide pellets enclosed in pressurized, cold worked, sealed Zircaloy tubes. The fuel tubes are grouped and supported in fuel assemblies of the canless type. The basic fuel assembly consists of the control rod guide thimbles attached to the grids and the top and bottom nozzles. The fuel rods are held by the grids in the assembly to provide for very stiff support.
The initial loading of fuel into the core is designed so that fuel assemblies with the highest enrichment are placed in the outer region of the core while the two groups of fuel assemblies with lower enrichment are selectively arranged in the central region. During refueling operations, a portion of the fuel is discharged, and new fuel is loaded into the core. The fuel in the reactor core is arranged to achieve an acceptable power distribution. Control rod assemblies are inserted into the guide thimbles of the fuel assemblies. The absorber sections of the control rods are fabricated from silver-indium-cadmium and sealed in stainless steel tubes. Neutron control for slow transients is provided by means of boric acid in solution in
 
the Reactor Coolant System (RCS).Each control rod cluster is attached to a spider connector and drive shaft. The drive mechanisms for the control rod assemblies are equipped with magnetic latches which are controlled by three magnetic coils and the latches are designed so that upon loss of power to the coils, the rod cluster control assembly (RCCA) is released and falls by gravity into the reactor core, effecting a shutdown of the reactor.The reactor core rated thermal power for Unit 1 prior to 1RF09 is 3411 MWt; this results in a NSSS thermal power of approximately 3427 MWt with the additional 16 Mwt (approximate) of energy input to the RCS by nonreactor sources such as pump heat.Unit 1(a)a)Based on nominal performance after 1RF12 [1 and 2].
Unit 21.Thermal output of NSSS, MWt347534742.Thermal output of reactor core, MWt345834583.Steam flow from NSSS, lb/hr15,334,48715,359,775 4.Steam pressure at a steam generator outlet, psia9679955.Maximum moisture content, percent0.100.25
 
6.Assumed feedwater temperature at steam generator inlet, °F 441.6 (HB)443 (BE)441.5 CPNPP/FSAR1.2-5Amendment No. 107The reactor core thermal power for Unit 1 (after 1RF09) and Unit 2 is 3458 Mwt; this results in a NSSS thermal power of approximately 3474 Mwt with the additional 16 Mwt (approximate) of energy input to the RCS by nonreactor sources such as pump heat.1.2.2.2.2Reactor Coolant SystemThe Reactor Coolant System (RCS) consists of four parallel, similar, heat transfer loops, each consisting of a reactor coolant pump and steam generator, connected to the reactor vessel. In addition, the system includes a pressurizer, pressurizer relief tank, connecting piping, and the instrumentation necessary for operat ional control and protection.The RCS transfers the heat developed in the reactor core to the steam generators, where steam is generated to drive the plant turbine- generator. Borated, demineralized light water is used as the heat transfer medium for the RCS and is circulated at a flow rate and temperature consistent with achieving the desired thermal-hydraulic performance for the reactor core. The water of the RCS also serves as neutron moderator, reflector, and solvent for the neutron absorber.The reactor coolant pumps are Westinghouse vertical, single stage, centrifugal pumps of the shaft-seal type. The power supply systems for the pumps are designed to provide for adequate coolant flow to the reactor core under all required conditions.The steam generators are Westinghouse vertical U-tube units containing Inconel tubes and equipped with integral moisture separation equipment to reduce the moisture content of the steam to 0.10 percent for Unit 1 and to 0.25 percent or less for Unit 2.All reactor coolant piping as well as all pressure-containing and heat transfer surfaces in contact with the reactor water is stainless steel clad expect for the fuel tubes and steam generator tubing which are Zircaloy and Inconel, respectively. The reactor core internals, including the control rod drive shafts, are primarily stainless steel.The electrically heated pressurizer, which is connected to one of the four parallel reactor coolant loops (RCLs), is designed to perform the following functions:1.To maintain the pressure of the RCS during normal operation2.To limit the pressure variations during plant loading transients3.To maintain the RCS pressure within the design limits during abnormal occurrences.
1.2.2.3Engineered Safety FeaturesThe engineered safety features (ESF) systems are designed to limit the potential radiation exposure to the public as well as to plant personnel in the event of a postulated accidental release of radioactive fission products from the reactor system, particularly as the result of a loss-of-coolant accident (LOCA). These ESF function to localize, control, mitigate, and terminate all such postulated accidents to ensure that the guidelines of 10 CFR Part 100 for exposure limits are not exceeded.
CPNPP/FSAR1.2-6Amendment No. 107The following is a list of ESF:1.Containment2.Containment Spray System3.Containment spray chemical additive subsystem 4.Containment Isolation System5.Combustible Gas Control Systems6.Emergency Core Cooling System (ECCS) 7.Control Room habitability systems8.Residual Heat Removal (RHR) SystemEach of the ESF systems is missile-protected and designed to withstand all normal and accident loads including the Safe Shutdown Earthquake (SSE).1.2.2.3.1ContainmentThe containment is a steel-lined, reinforced concrete structure which consists of a vertical cylinder with a hemispherical dome supported on a foundation mat with a reactor cavity pit. The interior steel liner is constructed with carbon steel plate for leaktightness.The Containment Building completely encloses the reactor and the RCS. An interior structure within the Containment Building supports and provid es shielding for the reactor and other components of the NSSS.The containment is designed to withstand the pressures and temperatures resulting from a spectrum of LOCAs and secondary system breaks.1.2.2.3.2Containment Spray System The Containment Spray System, including the containment spray chemical additive subsystem, is designed to meet the following criteria:1.To ensure that the containment pressure and temperature do not exceed the design parameters for all accidents including LOCAs2.To ensure that offsite radiological consequences are within the limits of 10 CFR Part 100 by reducing the fission product concentration with containmentThe Containment Spray System initially supplies the containment atmosphere with borated water drawn from the Refueling Water Storage Tank (RWST). When the water level in the RWST reach the low-level set point, water is drawn from the Containment sump and recirculated through the Containment spray heat exchangers to provide for the continued cooling of the containment atmosphere.
CPNPP/FSAR1.2-7Amendment No. 1071.2.2.3.3Containment Spray Chemical Additive SubsystemThe containment spray chemical additive subsystem is designed to insure that the concentration of the iodines within the Containment, following all postulated accidents, is reduced to limit the offsite radiological consequences.The desired reduction in containment iodine concentration is accomplished by the injection of sodium hydroxide from the containment spray chemical additive subsystem into the containment spray water; this chemically-treated water absorbs the fission product iodines from the containment atmosphere and retains them in solution in the containment sump.The containment spray chemical additive subsystem, together with the balance of the Containment Spray System, is designed as follows:1.To be fully redundant 2.To meet the single failure criterion3.To withstand all normal and accident loads4.To be fully missile-protected1.2.2.3.4Containment Isolation System In the event of postulated accidents, the Containment Isolation System is designed to minimize the leakage of radioactive materials through fluid lines penetrating Containment.This design objective is achieved by the use of double isolation barriers. The use of double isolation barriers ensures that no single failure of any active or passive component renders the Containment Isolation System partially or wholly inoperable. The isolation valves are checked regularly during normal unit operation and are designed to assume a fail-safe position.The Containment Isolation System ensures that the offsite radiological consequences of a main steam line rupture or LOCA are within the guidelines of 10 CFR Part 100.1.2.2.3.5Combustible Gas Control Systems Combustible gas control systems are not required to be Engineered Safety Feature Systems.The hydrogen purge system, a non-safety system, is designed to meet seismic category II requirements. This system purges the containment atmosphere through filters which reduce
 
radioactive releases. See Section 6.2.5 for details.1.2.2.3.6Emergency Core Cooling System The ECCS, with active and passive subsystems, is designed to perform the following functions:1.To inject borated water into the RCS following a LOCA to minimize core-damage, metal-water reactions, and fission-product releases CPNPP/FSAR1.2-8Amendment No. 1072.To ensure adequate shutdown margin regardless of temperature3.To provide for long-term postaccident cooling of the reactor core by recirculating borated water from the containment sump1.2.2.3.7Control Room Habitability SystemsThe Control Room habitability systems are designed to ensure that the Control Room is habitable for a period not less than 30 days following any LOCA.The Control Room air-conditioning system has a recirculation mode designed to maintain Control Room ambient conditions suitable for personnel occupancy during accident conditions. A set of emergency filtration units removes airborne activity from outside air during emergency pressurization and filtration modes of operation.Communication and domestic facilities are provided to meet personnel needs during an extended stay in the Control Room area.1.2.2.3.8Residual Heat Removal SystemThe RHR System serves as a part of the ECCS during both the low pressure injection and recirculation phases following a LOCA. The RHR System is designed to provide an adequate supply of water for cooling of the reactor core; this is accomplished by the RHR pumps delivering water from the RWST to the RCLs. When the supply of refueling water is depleted, recirculation of containment sump water through a heat exchanger is initiated and maintained to ensure continued core cooling.1.2.2.4Plant Instrumentation and Control SystemInstrumentation and controls are provided to monitor and maintain plant parameters within the prescribed operating ranges.Reactor control is provided by the following:1.Temperature coefficients of reactivity 2.Control rod cluster motion3.Injection of neutron absorbing chem ical shim in the form of boric acidThe control rod clusters provide for load-follow transients as well as for startup and shutdown requirements. The chemical shim is inserted during cold shutdown, partially removed during startup, and further adjusted during the lifetime of the core to compensate for such effects as fuel consumption and accumulation of fission products which act to decrease the excess reactivity of the core.The reactor control system permits the plant to accept 10 percent step-load increases and ramp load increases of 5 percent per minute over the load-range of 15 to 100 percent of full power. Step-and ramp-load reductions of the same magnitude are also possible over the range of 15 to 100 percent of full power.
CPNPP/FSAR1.2-9Amendment No. 107The non-nuclear-safety-related process and containment instrumentation measure temperatures, pressure, flows, and levels in the steam and auxiliary systems and in the Containment. Process variables required on a continuous basis for startup, operation, and shutdown of the unit are indicated, recorded, and controlled from the Control Room. The quantity and types of process instrumentation provided ensure safe and orderly operation of all systems and processes over the full operating range of the plant.The nuclear-safety-related instrumentation and control systems provide automatic protection and exercise proper control to ensure safe reac tor operation and to provide initiating signals to mitigate the consequences of design basis accidents (DBAs). Supervision of both nuclear and turbine generator plants is accomplished from the Control Room.1.2.2.5Power Conversion and Electrical Systems The electrical systems transmit the output of the generator units to the utility system and provide power for plant auxiliary loads. Independent and redundant Class 1E standby power systems function during a DBA to ensure operation of necessary safety-related systems.The main generator for each unit is rated 1410 MVA at 0.90 power factor, 22 kV, 60 Hz, three-phase, 1800 rpm. Power output from each generator is fed to its respective main step-up transformer bank through the isolated phase bus system. Generator voltage is stepped up to 345 kV and transmitted through overhead transmission lines to the 345 kV Switchyard where distribution to the utility system is accomplished
. Seven 345 kV transmission lines connect the Switchyard to other switching stations in the Transmission Operator's transmission system. The AC station power is distributed through the 6900 V, 480 V, and 118 V uninterruptible AC auxiliary bus systems to the unit loads. The DC load requirements are satisfied by 125-V, 125 250-V, and 2448-V systems.During normal operation, the main generators supply power to all the auxiliary loads except for the loads connected to the emergency buses.These loads are normally energized from the offsite power systems. Startup and shutdown power is derived from two independent offsite power circuits. One circuit is connected to the 345kV Switchyard, and the second feeder is connected to the 138 kV system. Each high voltage circuit is transformed through startup transformers to 6900 V.Under LOCA and loss-of-offsite power conditions, power to the safety-related loads is achieved through the standby diesel generator system. A total of four 100 percent diesel generators, two per unit, is provided. Each diesel generator is assigned to a specific safeguard bus. One diesel generator and its associated bus and loads can satisfy the safety load requirements for one unit.
There is no sharing of diesel generators.Each unit has two independent Class 1E 125-VDC systems to provide DC and uninterruptible AC power to essential plant instruments and controls. An independent 125/250-VDC system is provided for each unit to supply non-Class 1E power and control loads.1.2.2.6Fuel Handling and Storage System The Fuel Handling System is designed to permit the handling of spent fuel under water from the time it leaves the reactor vessel during refueling until it is placed in a cask for offsite shipment.
CPNPP/FSAR1.2-10Amendment No. 107 The transfer of spent fuel under water provides both a transparent radiation shield and a reliable cooling source for the removal of residual and decay heat.The Fuel Handling System is located in two separate areas. The first area is comprised of the refueling cavity inside the Containment Building, which is flooded during the refueling operations; the second area is the Fuel Building, which includes two spent fuel pools; a cask pit and connecting fuel transfer canal, and which is external to the Containment Building and accessible to authorized personnel. The two areas of the Fuel Handling System are connected by the Fuel Transfer System, which moves the fuel through an opening in the Containment. The Fuel Handling System provides for the safe handling of RCCA under all conditions and for the required assembly, disassembly, and storage of reactor internals. This system includes a refueling machine located inside the Containment above the refueling cavity Fuel Transfer System (which includes a fuel transfer tube), a fuel handling crane above the fuel storage racks area, the RCCA changing fixture, and lifting devices (which are us ed for handling the reactor vessel head and internals).The new fuel assemblies can be stored in racks in the new fuel pit, in racks in the spent fuels pools, or in the in-containment storage racks. In each of the locations, the new fuel is separated by sufficient distance to preclude criticality. Spent fuel is placed in storage racks in the spent fuel pools where it will remain for a sufficient decay and cooling period before shipment in a cask to a fuel reprocessing facility or a storage facility.1.2.2.7Cooling Water Systems Two separate closed-loop cooling water systems are provided to facilitate heat removal from ESF, safety-related, and non-safety- related equ ipment. These are the Component Cooling Water System (CCWS) and the Turbine Plant Cooling Water (TPCW) System. Cooling for the CCWS is provided by the Station Service Water System (SSWS) and the heat is ultimately rejected to the Safe Shutdown Impoundment (SSI). Cooling for the TPCW System is provided by the Circulating Water System and this resulting heat is ultimately rejected to the Squaw Creek Reservoir (SCR).The design criteria for the CCWS are as follows:1.To remove residual heat from the RCS by means of the RHR System during plant shutdown2.To cool the letdown flow to the CVCS during power operation 3.To dissipate waste heat from containment and auxiliary components4.To remove ESF heat loads after an accident The CCWS transfers heat to the SSWS via the component cooling water heat exchangers.
The CCWS consists of two separate and independent full capacity, safeguards-related, redundant trains of pumps and heat exchangers to remove heat from the engineering safeguards components and a nonredundant, safety-related loop with an ANS non-safety-class-related portion. Corrosion inhibiting demineralized water is circulated through the CCWS. The CCWS is maintained at a higher pressure than the SSWS to prevent inleakage of potentially corrosive CPNPP/FSAR1.2-11Amendment No. 107station service water fluids. The CCWS provides an intermediate barrier between the RCS and the service water system to preclude direct leakage of radioactive material to the SSI.An uninterrupted supply of water for the service water system is ensured by the SSI, a seismic Category I structure. Makeup water for the SSI is provided via a shallow canal connecting it with the SCR and can be provided via a bleed-off from the Circulating Water System.The design criterion for the TPCW System is to remove waste heat from various Turbine Building auxiliaries.The TPCW System passes its heat load via the TPCW heat exchanger to the Circulating Water System.Cooling water for the main condensers is provided by the Circulating Water System. The Circulating Water System Intake Structure is located north of the plant on the SCR. The heated water of the Circulating Water System is discharged to the SCR via a discharge tunnel at a point southeast of the plant.1.2.2.8Auxiliary SystemsThe auxiliary systems are designed to perform the following functions:1.To supply RCS water requirements 2.To purify reactor coolant water 3.To introduce chemicals to inhibit corrosion4.To introduce and remove chemicals for reactivity control 5.To cool system components6.To remove residual heat during a portion of the reactor cooling period and when the reactor is shut down7.To cool the spent fuel pool water8.To permit sampling of reactor coolant 9.To provide for safety injection10.To vent and drain the RCS and the auxiliary systems11.To provide containment ventilation and cooling 12.To provide plant fire protectionThe principal auxiliary systems are the following:1.Chemical and Volume Control System (CVCS)
CPNPP/FSAR1.2-12Amendment No. 1072.Sampling systems3.Compressed air systems4.Plant ventilation systems5.Station Service Water System (SSWS) 6.Plant Fire Protection System7.Spent Fuel Pool Cooling and Cleanup System1.2.2.8.1Chemical and Volume Control System Performance of the following functions will establish the design criteria of the CVCS:1.Purification of reactor coolant fluid2.Corrosion control3.Regulation of reactor coolant inventory4.Reactivity shim 5.Seal water injection for reactor coolant pumpsDuring power operation, a continuous feed-and-bleed system is maintained to and from the RCS. The bypassed fluid is depressurized, cooled, purified, and stored by a series of valves, heat exchangers, demineralizers, and tanks. Fu rthermore, the amount of reactor coolant is automatically adjusted to compensate for changes in volume as a result of coolant temperature changes. The CVCS provides reactivity control by varying the boron concentration in the reactor coolant.Water for the reactor coolant pump shaft seals is supplied from the charging pump.The centrifugal charging pumps associated with the CVCS also serve as the high-head pumps for the ECCS. In the event of a LOCA, the CVCS is isolated except for the charging pumps, which inject borated water into the reactor core.1.2.2.8.2Sampling Systems The CPNPP is equipped with three sampling systems:  the Primary Sampling System, the Secondary Sampling System and the Post Accident Sampling System (PASS). The Primary Sampling System serves the RCS and its auxiliary systems while the Secondary Sampling System serves the feedwater and main steam systems. The PASS no longer functions, as described in FSAR Section II.B.3. These systems provide a determination of both the chemical and radiological makeup of var ious plant fluids. Samples drawn from radioactive sources are passed through sample coolers or delay coils, or both, as required.
CPNPP/FSAR1.2-13Amendment No. 1071.2.2.8.3Compressed Air SystemsEach of the two CPNPP units are equipped with oil-free air compressors, which discharge filtered and dried compressed air into the Instrument Air System. There are two instrument air compressors for each unit and two common instrument air compressors which can be aligned to either unit. An oil-flooded common compressor supplies both units with unfiltered compressed air into a separate Service Air System.The Service Air System provides compressed air for routine maintenance at various stations throughout the plant.The Instrument Air System provides compressed air, which is dried and filtered, for all air-operated instruments and valves. 1.2.2.8.4Plant Ventilation SystemTo facilitate the independent control of the atmosphere in various plant areas, separate ventilation systems have been provided. The following major areas are served by separate ventilation system: 1.Containment Building.2.Auxiliary, Safeguards, and Fuel Building.
3.Turbine Building.4.Diesel Generator Building.5.Control Room.
6.Uninterruptible Power Supply and Distribution Room.In addition, a Containment Purge System and a Containment Preaccess Filtration System are provided for the containment atmosphere.1.2.2.8.5Station Service Water SystemThe SSWS removes heat from the CCWS to meet the cooling requirements of the plant as follows:1.During normal operations 2.Following shutdown3.During and after all postulated LOCAsThe SSWS is assured of a constant supply of water by the SSI Dam which is a seismic CategoryI structure founded on bedrock. The SSI maintains the necessary volume of water required by NRC Regulatory Guide 1.27. Makeup water is provided via a shallow canal to the SCR and can be provided via a bleed-off from the Circulating Water System.
CPNPP/FSAR1.2-14Amendment No. 107The SSWS of each of the units is completely independent and redundant. Each unit has two fully independent trains, either of which can supply the required cooling waterflow. The pumps and heat exchangers of each train can be aligned with the other train in the event of a component failure.1.2.2.8.6Plant Fire Protection SystemThe Fire Protection system provides means for detecting, alarming, and extinguishing fires. The system is divided into two basic subsystems: the Fire Detection System and the fire extinguishing system. The Fire Detection System is a plantwide instrumentation system provided to detect fires in various areas of the plant and to alert the Control Room operators of a fire and its location. The fire extinguishing system includes such fire fighting equipment as sprinkler systems (wet pipe, deluge and preaction), water spray, standpipe and hose stations, Halon Systems, and portable extinguishers. The Fire Protection System is not required to ensure the integrity of the reactor coolant pressure boundary (RCPB), the capability to shut down the reactor, and the capability to prevent or mitigate the consequences of accidents which could result in potential offsite exposures as detailed in 10 CFR Part 100.
All fire protection piping in Category I structures is classified Class 5 as described in Section3.2.2. The station fire main system, including the associated pumps, piping, and valves, is shared by the two CPNPP units.Noncombustible and fire-resistant materials are selected where practical for use throughout the CPNPP facility, particularly in controlled-access portions of the plant such as the Containment
 
and Control Room.1.Fire Detection SystemA Fire Detection System is provided throughout the plant. When a fire is detected, the respective zone and fire indication appears on the local zone panel and the main fire detection panel in the Control Room. An alarm indicating lamp illuminates in the base of the ionization detectors indicating the actuated detector, for other types of detectors a lamp illuminates at the local zone panel. The majority of detectors are placed overhead in their respective areas. Also, detectors located in areas protected by halon and automatic open head water spray systems actuate the fixed systems. Detectors sound an alarm condition via the Control Room fire detection panel.The Fire Detection System uses fire, smoke, and heat detection devices located throughout the entire plant; they include the following:a.Ionization smoke detectorsIonization detectors are of the two-chamber-type design. The first is a reference chamber to compensate against the sensit ivity changes due to temperature, barometric pressure, and humidity variations. The second chamber is a sensing chamber open to the outside elements through a protective screening which permits combustion products to enter while preventing insects and foreign matter from entering and causing false alarms.
CPNPP/FSAR1.2-15Amendment No. 107b.Thermal detectorsSpot-type thermal detectors are of the fixed-temperature, rate compensation type.Continuous strip thermistor heat detectors are used to monitor the temperature of charcoal adsorber beds of the atmosphere cleanup units, and other areas where accurate measurement of temperatures for fire detection is required. The strip thermistors are of the negative coefficient of resistance type.c.Flame detectors Flame detectors are of the ultraviolet (UV) radiation sensing type. The detectors respond to the UV frequency of radiation given off by a fire. The UV flame detectors are installed with high ceilings or specific pieces of equipment which contain highly flammable materials.
The detectors are strategically positioned throughout the facility to detect fires, annunciate alarms in the Control Room and indicate the location of the fire on the Control Room fire detection panel and local zone panel.The detection system is electrically supervised. Class A supervision is used in the cable spreading rooms. As a minimum, class B supervision is used in the remainder of the plant.2.Fire Extinguishing SystemThe fire extinguishing system uses portable extinguishers, in conjunction with hose stations and fixed suppression systems, as primary and secondary means of suppression. Water is supplied for the standpipes and suppression systems from two dedicated above ground storage tanks via an underground piping distribution system and water supply lines for each building and transformer branch from the underground loop; every branch has a post indicator gate valve fo r isolation of the branch or building. The main loop is divided into sections by post indicator valves to allow isolation of the loop in case of a line break. There are three 50 percent capacity fire pumps to supply water to the system. One is an electric motor driven pump and the other two pumps are diesel engine driven. Water is supplied to the underground fire loop by the lead pump, the electric motor-driven pump, when the jockey pump cannot maintain the system pressure above a predetermined set point.A siamese fire department connection is pr ovided for emergency fill of the system by a fire truck or a portable auxiliary pump. This fill is used as a backup to the pumps. As required by National Fire Protection Association (NFPA) No. 24, a check valve and a ball drip valve are provided for the connection of the siamese to the main loop. The siamese connection is located adjacent to the Service Water Intake Structure.The Safeguards, Fuel Handling, and Auxiliary buildings have internal loops to supply suppression and standpipes systems. These loops have multiple connections to the underground loop. Valves are available for isolation of sections of the loops as well as isolation of the internal loop from the underground loop. Each suppression and standpipe CPNPP/FSAR1.2-16Amendment No. 107system has a shutoff valve to facilitate work on the system. Approved control valves are located in the respective system in accordance with applicable NFPA standards.The Turbine Buildings have an internal loop to supply standpipes. This internal loop has multiple connections to the underground loop in Unit 1 and Unit 2. Crosstie lines are provided between Unit 1 and Unit 2 Turbine Buildings to facilitate isolation of sections of either loop. Valves are provided in accordance with NFPA No. 14 to control the waterflow and isolate the system. The water spray and automatic sprinkler systems are connected to the outside loop via isolation valves located in the fire protection valve rooms, which are accessible from inside and outside the Turbine Buildings, as required, to control the waterflow to the suppression systems. The suppression systems for the diesel generator day tanks are supplied from the main loop independent of each other. Each system has a deluge valve, a cutoff valve, and a detection system. Actuation of one system does not affect operation of the other diesel generator; each diesel generator compartment is provided with a watertight door to prevent flooding of the adjacent areas. The systems are actuated automatically based on detection of a fire or manually adjacent to the respective area. The systems can only be shut off manually at the valve.The fire pump house structure is protected by an automatic wet-pipe sprinkler system. Water flow and valve tamper alarms are provided at the pump house location and in the Control Room.The deluge water spray systems for the atmosphere cleanup units, except the containment preaccess units, are supplied by the interior building supply loop. The preaccess units are supplied by the Demineralized Water System. Should demineralized water be unavailable, the operator can manually route fire protecti on water through the demineralized water piping. Actuation of one system will not affect the operation of an adjacent atmosphere cleanup unit.The halon system for each cable spreading room consists of a detection system, storage cylinders, manifold and header assembly, control valves, piping, nozzles, and local control panel. Each system is designed with two charges of halon. Halon is released automatically after receipt of a fire signal from detectors located in the cable spreading room. The Unit computer rooms are each provided with a manually actuated halon system, and ionization smoke detection provides control room personnel notification of a fire. 1.2.2.8.7Spent Fuel Pool Cooling and Cleanup SystemThe Spent Fuel Pool Cooling and Cleanup System serves the spent fuel pools of both units.
The cooling portion of this system has two trains consisting of a pump, heat exchanger, and other associated equipment.The purification portion of this system consists of two trains containing a filter and a demineralizer which can be operated in parallel with either of the two cooling trains.The skimmer portion of this system consists of a single skimmer train and is shared between both pools.
CPNPP/FSAR1.2-17Amendment No. 1071.2.2.9Waste Processing SystemsThe waste processing systems (WPS) are designed to process liquid, gaseous, and solid waste while achieving the lowest reasonable radioactive release to the environment available through current technology. Liquid and gaseous wastes to be recycled within the plant are first segregated from those to be processed or shipped offsite.Segregation of wastes is consistently maintained in the subsystems to ensure proper handling.The Liquid Waste Processing System (LWPS) is designed to perform the following functions:
1.To collect reactor grade water2.To process reactor grade water3.To recycle reactor grade water 4.To collect floor drains and laundry waste5.To process floor drains and laundry waste6.To recycle or discharge processed floor drain and laundry waste7.To remove radioactive constituents8.To concentrate the removed radioactive constituents 9.To process concentrated radioactive constituents for solidification and shipment offsiteIn addition, all liquid wastes are sampled and activity levels recorded prior to release. All processed liquid effluents from the RCS are subjected to purification by the CVCS ion exchanger in addition to the components of the WPS. The limits established by 10 CFR Part 20 are met.The Gaseous Waste Processing System (GWPS) is designed to perform the following functions:1.To reduce fission product gas concentrations in the RCS during normal operation2.To contain indefinitely the fission product gases removed from the RCS 3.To collect gases generated by other systems4.To maintain a low level of hydrogen gas in the collected gases5.To discharge radioactive effluents after monitoring for radioactivity via a controlled path to ensure that the expected offsite doses are as low as reasonably achievable (ALARA)The waste gases generated during plant operations including anticipated operational occurrences are collected and processed and are stored in waste gas decay tanks.The Solid Waste Management System is designed:
CPNPP/FSAR1.2-18Amendment No. 1071.To provide a means of encapsulating or compacting radioactive solid wastes generated by reactor plant operations2.To provide adequate equipment and storage area shielding for the protection of operating personnel pending shipment of waste to disposal facilities3.To measure and record the radiation levels of the solid waste processed for shipment from the site to disposal facilities4.To provide a 3- to 6-month storage capacity for the processed wastes depending upon plant operation.Solid wastes are compacted into containers for offsite disposal.
The WPS, with the exception of the equipment associated with the reactor coolant drain tanks, are completely shared. The reactor coolant drain tanks and associated equipment are located inside their respective Containment structures.1.2.2.10Safe Shutdown ImpoundmentThe SSI is an enclosed body of water formed from a cove of the SCR and is retained by a seismic Category I dam. It is designed and constructed to withstand the most severe postulated natural phenomena. The water level of the SSI is maintained by a spillway between the SSI and the reservoir behind the Squaw Creek Dam.Since the Squaw Creek Dam is not a seismic Category I structure, it is assumed that ground motion from the SSE results in catastrophic, total, and instantaneous drawdown of the water level on the downstream side of the SSI Dam. The spillway limits the low water level in the SSI to 769ft 6 in, at which point the volume of water contained is approximately 300 acre-feet.The SSI is designed to serve as the ultimate heat sink of the CPNPP and acts to dissipate heat rejected by the SSWS during postaccident shutdown and normal cooldown conditions. It has been sized to provide adequate cooling capacity for the CPNPP in accordance with the requirements of NRC Regulatory Guide 1.27.The materials used in construction of the SSI Dam include limestone rock from excavation at the plant site, clay from a borrow area located upstream from the Squaw Creek embankment, and a granular filter zone material.1.2.2.11Shared Structures, Systems, and Components1.2.2.11.1Shared StructuresThe following structures are shared by both units of the CPNPP:
1.Auxiliary Building, including Control Room2.Fuel Building3.Service Water Intake Structure CPNPP/FSAR1.2-19Amendment No. 1074.Circulating Water Intake Structure5.Circulating Water Discharge Structure1.2.2.11.2Shared SystemsThe following systems are shared (or have shared components) by both units of the CPNPP:
1.Chemical and Volume Control Systems (CVCS)2.Boron Recycle System (BRS)3.Compressed Air Systems (CASs) 4.Station Service Water System (SSWS)5.Waste Processing Systems (WPS)6.Fire Protection Systems7.Hydrogen Purge System8.Turbine Building ventilation system 9.Control Room ventilation system10.Primary Plant ventilation system11.UPS and Distribution Room Ventilation System 1.2.2.11.3Shared ComponentsThe following components are shared by both units of the CPNPP:1.Fuel handling equipment (in Fuel Building only) 2.Startup transformers3.480-V motor control centers feeding to the common services systems (mechanical) load and lighting4.Control Room panels where common services controls are located1.2.2.12General Arrangements
 
Figure 1.2-1 through Figure 1.2-46 provide sufficient detail of major structures and equipment to give an understanding of the general layout of the plant. Plan and elevation drawings are provided for the following structures:1.Containment and Safeguards Buildings (Unit 1)
CPNPP/FSAR1.2-20Amendment No. 1072.Containment and Safeguards Buildings (Unit 2)3.Turbine Building (Unit 1)4.Turbine Building (Unit 2)5.Auxiliary and Electrical Control Building 6.Fuel Building7.Circulating Water Intake Structure8.Service Water Intake Structure These figures are based on plant plan and elevation drawings. As such, the figures provide additional detail beyond what is necessary for general arrangements. These figures will be updated as necessary to provide a reasonable understanding of the general arrangement of major plant structures and equipment. The additional detail on these drawings is not updated.1.2.2.13References1.TXU Letter CPSES-200401793, Transmittal of Contract Information - Best Estimate Feedwater Temperature, July 20, 2004.2.Design Specification No. 418A23, Revision 2, Comanche Peak Nuclear Power Plant Unit 1, Delta 76 Replacement Steam Generator, September 2006.1.2.3OLD STEAM GENERATOR STORAGE FACILITYThe Old Steam Generator Storage Facility (OSGSF), shown in Figure 1.2-1
, is a reinforced concrete structure supported on a reinforced concrete footing. The OSGSF consists of precast concrete wall closure panels and a reinforced concrete roof slab supported by structural steel beams. The OSGSF provides a secure long-term on-site storage facility for the four Unit 1 Old Steam Generators and Old Reactor Vessel Heads (and associated Control Rod Drive Mechanisms) for Units 1 and 2.1.2.4INDEPENDENT SPENT FUEL STORAGE INSTALLATIONThe CPSES site contains an Independent Spent Fuel Storage Installation (ISFSI) as shown on Figure 1.2-1. The ISFSI consists of a concrete pad with space for 84 natural convection air-cooled, HI-STORM shielded dry spent fuel storage casks, each capable of storing 32 spent nuclear fuel assemblies in a welded multiple purpose container. The ISFSI is inside a separate security protected area.1.2.5BEYOND DESIGN BASIS1.2.5.1NRC Order EA-12-049 Beyond Design Basis External Events On March 12, 2012, the NRC issued Order EA-12-049, "Order to Modify Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events."  Strategies, CPNPP/FSAR1.2-21Amendment No. 107details, and programmatic controls for mitigating beyond-design-basis external events are contained in site specific program documents. The CPNPP site contains a FLEX Storage Building as shown on Figure 1.2-1. The FLEX Storage Building protects equipment credited for NRC Order EA-12-049. Modifications to a Structure, System, or Component (SSC) required by the strategies of NRC Order EA-12-049 and are reflected in the FSAR flow diagrams as required.1.2.5.2NRC Order EA-12-051 - Spent Fuel Pool Instrumentation On March 12, 2012, the NRC issued Order EA-12-051, "Order to Modify Licenses with Regard to Reliable Spent Fuel Pool Instrumentation."  Details and programmatic controls are contained in site specific program documents. The instrument display for the wide range spent fuel pool instrumentation is installed in compliance with NRC Order EA-12-051 and is readily accessible during postulated events and a llows for SFP level information to be promptly available to decision makers. As appropriate, Sections 9.1.3.2 and 9.1.3.5 and Tables 17A-1 and 17A-2 refer to the wide range Spent Fuel Pool Instrumentation installed in accordance with the NRC Order.
CPNPP/FSAR1.3-1Amendment No. 1041.3COMPARISON TABLES1.3.1DELETED.1.3.2COMPARISON OF FINAL AND PRELIMINARY DESIGNSTable 1.3-2 details the significant design changes that have been made since the submittal of the PSAR.The FSAR is complete and does not rely on information contained in the PSAR. The original intent of this table was to provide a comparison with the PSAR when the FSAR was initially submitted for NRC Staff review. The information in this table is considered historical and will not be updated.
CPNPP/FSAR Amendment No. 104TABLE 1.3-1THIS TABLE HAS BEEN DELETED CPNPP/FSARAmendment No. 104TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 1 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChangesI.StructuresCategory I Structures (other than containment) 3.8Leak chase system behind liner of outdoor Category I tanks has been eliminated. The requirement for roof blow out panels above the main steam lines in the Safeguards Building has been deleted.Control Room3.11BLimiting environmental conditions have been reduced to 80°F and 60 percent relative humidity.
6.43.11BPositive pressure of 1/2 inch water gauge changed to 0.1 inch water gauge during an accident.Containment Systems 3.8The containment external pressure design has been changed from a 3 psi differential to a 5 psi differential pressure.The containment internal structure through liner anchors was eliminated.
The containment dome liner has been increased from 3/8 inch thickness to 1/2 inch.The containment liner paint has been changed.
CPNPP/FSARAmendment No. 104 3.9The break flow in the reactor cavity analysis is limited to 144 in 2 by pipe whip restraints instead of the previous 150 in
: 2.  (See Section 3.9N.1.4.6 for application of leak-before-break to GDC-4.)  Cathodic protection not required for containment liner, reinforced steel and other such steel encased in concrete.Containment penetration sleeves chan ged from A-333-70, Grade 6 to:1.SA-333, Grade 6 for sleeve sizes 20 in. and smaller 2.SA-516, Grade 70 or SA-537, Class 2 to sleeve sizes 20 in. and largerInside weld no longer utilized on cold pipe penetration.
Sleeve with inside weld and guard pipe on hot pipe penetration replaced with sleeve without inside welds or guard pipe.3.11BMaximum operational temperature increased to 120°F.
6.2.1The reactor cavity analysis was redone using new support criteria and restraint design.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 2 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104 6.2.4Changes in signals used to actuate the containment isolation system to reflect changes in WNES protection system. Addition of bellows expansion joints to the valve isolation tanks.
6.2.5The containment liner paint has been changed from a primer and top coat that was zinc free to inorganic zinc as a primer in phenolic topcoat.The use of aluminum and zinc inside containment is now permitted.
 
Remote thermal conductivity hydrogen analyzers are replaced by in-containment electrochemical sensors and microprocessor based analyzers located in the control room.The containment free volume has been changed from 2.9 x 10 6 cubic feet to 2.985 x 10 6 cubic feet 6.5Containment sump pH limits changed from 9.0 to 8.6 and 9.3 to 9.5.
Missile Shield 3.5The CRDM roll away missile shield is constructed of steel instead of reinforced concrete.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 3 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Safe Shutdown Impoundment 9.2.5The presence of fractures in the SSI limestone foundation material was determined to be acceptable if the fractures occur above elevation 769.5 (spillway level), and if the fractures would not cause piping of core material.
Clarification of the term "unweathered" to mean material that is firm, hard, and of appropriate strength parameters; the presence of slight oxidation resulting in some color change may not be an indication of weathering.
Shielding12.1Deleted the provisions for:1.Local alarms at entries to Zone IV areas 2.Local and remote alarms at entries to Zone V areas has been deleted.The minimum density for ordinary concrete has been changed from 2.33gcc to 2.26 g/ccThe secondary shield wall no longer surrounds the pressurizer and the thickness has been increased to 2 ft 9 in.Tornado Characteristics 3.5Tornado Missile Characteristics have been changed.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 4 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Piping Systems, Handling Equipment and Tornado Venting Components3.2 and Appendix 17APortions of systems or components are designed as Seismic Category II components.Non-nuclear Safety Piping Systems or Components3.2 andAppendix 17APortions of systems or components are designed as Class 5 components.Auxiliary Feedwater System3.6BThe system is identified as high energy fluid system.II.Reactor SystemsFuel4.2The reactors are fueled with 17 x 17 fuel assemblies in lieu of  15 x 15 fuel assemblies.
Reactor internals3.1, 7.7The use of part length control rods has been removed from the CPNPP design.4.5.2The reactor internals have been modified to accept 17 x 17 fuel assemblies.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 5 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104RCS pressure boundary 5.2Flux core welding on stainless steel piping components fabricated in the shop are permitted. The allowable heat input range is 15 to 100 KJ/in.The use of the following as valve materials is now permitted for valves 2.5 in. and larger:
bodies:SA 351 grade CF8 and CF8M bonnets:
SA 351 grade CF8M with nickel plating or stellite hardfacing closure bolting:SA 564 Type 630 and SA 193 grade B6closure nuts: SA 193 grade B6 and SA 194 grade 8MThe use of the following as valve materials is now permitted for valves 2.0in. and smaller:
bodies:SA-351 Gr. CF8MSA-182 F 316TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 6 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104bonnets:SA-182 F 316discs:A-567 Gr. 1 (Stellite 21) stems:SA-564 Type 416 (Non-pressure retaining applications)The lower heat input range limit for welding processes of austenitic stainless steel have been deleted, and the use of automatic gas tungsten arc-cold wire processes is allowed. The maximum allowable heat input for this process is 45 KJ/in.
7.6An RCS cold overpressure control system is employed to provide for the mitigation of potential cold overpressurization transients, utilizing existing power operated relief valves with modifications to their actuation logic.Steam Generators 5.4.3CPNPP utilizes model D5 steam generators in Unit 2. Thermal sleeves in reactor coolant loop branch nozzles have been deleted.
RHR systems 3.6The RHR system is no longer identified as a high-energy fluid system located outside the containment.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 7 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Safety Injection System 3.1Change in SIS signal from coincident low pressurizer pressure and water level to low pressurizer pressure.
Reactor Coolant and Whip Restraint 3.13.63.9N5.4The leak-before-break technology has been applied to exclude from the design basis the dynamic effects of postulate ruptures in the reactor coolant loop piping.III.Electrical Systems:Reactor Trip System 7.2The reactor trip on low feedwater fl ow has been replaced by a low-low steam generator level trip. The RTD bypass line T hot and T cold measurements have been replaced by an N-16 power monitor and an inline T cold measurement CPNPP utilities 4 section power range neutron detector assemblies.
Engineered Safety Feature Systems 7.3An improved steamline break protection system has been incorporated where safety injection and steamline isolation are initiated from low compensated steam line pressure.CCW, SSW7.3Recirculation valves are now flow controlled, rather than pressure controlledTABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 8 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104 Post-Accident Monitoring 7.5SSW and CCW system parameters are not considered post-accident monitorsHot Shutdown Panels 7.4Indicators on the hot shutdown panel are no longer considered "Post accident monitors" and are treated as non-Class IE.
Electrical systems 8.1Non-safety-related loads removed from Class 1E batteries and reassigned to +/- 125-V non-Class 1E batteries.A static switch has been added to the BOP static uninterrupt. Power supply system inverter to accommodate the 120 V supply.138 kV DeCordova line previously was directly fed from DeCordova substation. Now it is transferred through switching station located near DeCordova SES.Motor operated disconnect switch is added to the 138 kV line at CPNPP to isolate the startup transformer XST1 for maintenance.The condition of diesel generator trip on bus-fault is removed. Now diesel generator does not trip on bus fault condition. However, will trip on overspeed.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 9 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Some events which trip diesel genera tor excluding accident condition, are added and deleted as follows:1.Bus fault signal to trip the generator breaker is deleted and following signal are included to trip the diesel generator.2.Lube oil high temperature 3.Generator over current Diesel generator trips due to following events, during "no accident" conditions have been added 1.Generator Negative Sequence 2.Generator Ground 3.Generator Field Ground Trip
 
Diesel generator rating modified from a 2000 hour rating to a 2 hour short term ratingPlant computer removed from DC safeguards bus and added to 125/250 V bus. Both DC safeguard batteries are sized identically.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 10 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Back-up (Alternate) 120 V ac instrument power supply to the 118 V Class IE uninterruptible as bus is changed from 120 V single phase chassie emergency Lighting System to the 120 V ac supply from Class IE MCC via a 480/120 volt single phase Class 1E bypass transformer.Static switch is added in each BOP SUP system to allow automatic transfer from inverter to back-up (alternate) 120 V ac power source.The air circuit breakers are molded case type and fusible switches are provided on some switchboard feeders (instead of circuit breakers) for coordination purposes.Unit substation transformer was changed from 1500 kVA to 2000 1666kVA.The backup supply for the 120-V NSSS instrument buses was originally taken from the 120-V single-phase emergency lighting system. These buses are now fed from the Class 1E motor control centers via a 480/120V single-phase Class 1E bypass transformer.Electric penetration centerline spacing changed from 2 ft 6 in. to 2 ft 2 in.
Total integrated dose that electrical equipment is subjected to is increased to 2.0 x 10 8 rads (1.5 gamma and 0.5 beta).TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 11 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Added +/-24 volt dc system for the turbine generator systemsIV.Mechanical Water Systems:
Component Cooling 9.2The following equipment is no longer served by the CCWS:1.Safety injection pump seal cooler 2.Centrifugal charging pump seal cooler 3.SGBS heat exchanger The following equipment is now served by the CCWS:
1.Instrument air aftercoolers 2.Chilled water system condensers 3.Control room air-conditioning condensers 4.Pump added for component cooling water drain tank in safeguards building5.Control room alarm added if makeup water added to surge tankTABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 12 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104The CCWS heat exchangers will utilize Cu-Ni tubes instead of stainless steel.Component Cooling Water pump normal supply temperature is increased to 115oF.Condensate Storage Facility 9.2.6Storage capacity increased from 480,000 gallons to 500,000 gallons.Secondary system water storage decreased from 240,000 gallons to 224,000 gallons.Reserve auxiliary feedwater capacity increased from 240,000 gallons to 276,000 gallons.Containment Spray System 3.2Containment spray system nozzles will not bear an "N" stamp Change from one spray header to seven.
6.5Minimum spray fall height changed from 117 feet to 115 feet 9 inches.Eductor calibrated flow changed from 37.5 gpm to 45 gpm.
Containment spray delivery lag time changed from 40 seconds to 60seconds.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 13 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Containment sprayed volume changed from 2.528 x 10 6 cubic feet to 1.725x 10 6 cubic feet.  (From 87% to 57.8%)
Piping systems 3.6The pipe whip analyses are now performed by the ANSYS computer program of Swanson Analysis System, Inc.
3.9The addition of stress limits fo r seismic Category I piping.Potable and sanitary water system 9.2.4Sewage plant effluent is discharged to Squaw Creek Reservoir instead of the evaporation ponds.Domestic water storage tank is designed to ASME B&PV Code Section III Code Class 3 requirements.Capacity of the sewage treatment plant is increased from 5000 gpd (normal operation) to 10,000 gpd (normal operation) and to 30,000 gpd during the construction stage.Capacity of the hypochlorinator has been increased.Station Service Water System 9.2.1The following changes have been made:1.The SSI study resulted in an increase of the accident inlet temperature of the service water to 105°FTABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 14 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 1042.Revision of Service Water Intake structure3.Service water pump design temperature increased from 95°F to 120°F4.Traveling screen spray piping changed from carbon steel to copper alloy5.The SSWS no longer removes heat from the control room air-conditioning system6.The SSWS has been added as a backup water supply to the Auxiliary Feedwater System7.The non-safety-related train of the SSWS has been deleted 8.Automatic strainers have been deleted.
9.Piping is constructed of either stainless steel (or other corrosion resistant material) or is plasite 7122 lined carbon steel as indicated in the appropriate drawings and/or specifications.Valves:  Feedwater Isolation Valves 6.2.4The feedwater isolation valve will no longer fail closed upon loss of power. Closure will be upon energizing redundant solenoid valves.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 15 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Valves:  General 3.16.2.4Change from air-operated valves failing closed to air and solenoid-operated valves failing in the direction of greatest safety.
Materials6.1BThe control of delta ferrite to reduce the susceptibility of stainless steel welds to hot cracking is no longer considered for ANS Safety Class 3 components. The requirement that the total leachable chloride and fluoride content of clean elastomers and plastics placed over all openings in components fabricated from austenitic stainless steel be limited to 15 and 10 ppm, respectively, has been deleted.V.Fuel Storage and Handling Systems:Fuel storage and handling system 9.1The following changes were made to the spent fuel storage handling system system:1.An increase in total spent fuel storage space from 400 to 1166 spent fuel assemblies (1116 in spent fuel pools/25 in each Containment)2.A decrease in center-to-center spacing from 21 to 16 in.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 16 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 1043.An increase in Keff from 0.90 to 0.95 for spent fuel assemblies if immersed in unborated water.Purification loop was added to the refueling cavity.
The number of dry storage racks has been increased from 129 to 132.
An increase in Keff from 0.90 to 0.98 for new fuel assemblies if flooded with unborated water.
The dry cask loading co ncept is eliminated.The design of the spent fuel pool cooling heat exchangers is changed from horizontal to vertical.VI.Auxiliary Systems:Auxiliary Feedwater System 9.2.1The SSWS has been added as a backup water supply.10.4.9Manually controlled heating systems have been changed to automatic systemsThe Auxiliary Feedwater is supplied to the secondary side of the steam generator through a separate upper Auxiliary Feedwater nozzle.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 17 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Condensers10.4.1Design basis for auxiliary condensers was revised.Instrumentation for main condenser was modified to include high differential pressure alarm and temperature recorder in the control room.Isolation valves were added to the auxiliary condenser and turbine plant heat exchanger with change from a motor operator to a gear operator.The number of condensate pumps in the condenser hotwells has been changed from three to two half-capacity pumps.Vacuum pumps10.4.2The number of mechanical vacuum pumps was changed from two to three. During startup, discharge is to the atmosphere; during normal operation, discharge is through the charcoal filter system.
Circulating water system10.4.5Design basis was revised.Pressure-differential alarm on the screen is annunciated in control room.
Butterfly valves on the turbine plant cooling water heat exchangers were added.Circulating water pipes are made from coated carbon steel instead of concrete or plastic.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 18 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Condensate Cleanup System10.4.6Backwash recovery and powdered res in handling added to system designFeedwater heaters10.4.7Separate external drain coolers have been added to the 6A and 6B heaters.Steam Generator Blowdown System10.4.8Treatment capacity of the system has been increased from 50 to 640 gpm. Blowdown cooled by condensate of condensate/blowdown instead of component cooling waterBlowdown now recycled to heater drain tank at high temperature The processing of spent resin has been changed from regeneration to flushing into the storage tank prior to drumming.Change in bed processing as a result of elimination of the regeneration mode.SGBS heat exchanger has been changed from ANS Safety Class 3 to NNS.Fire Protection System 9.5.1The Fire Protection System has been completely upgraded to address current NRC Regulatory Positions.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 19 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104 Lighting systems 9.5.3Lighting system powered from localized motor control centers in lieu of a central power substation.
Instrument room and primary plant egre ss routes have been added to the list of areas provided with DC emergency lighting.The AC Essential Lighting System and DC Emergency Lighting System are reclassified as non-Class 1E.Diesel Generator Fuel Oil Day Tank 9.5.4Fuel oil supply increased to 2160 gallons from 3 hoursThe Diesel Generator Fuel Oil Storage and Transfer System 9.5.4The diesel fuel oil storage tank is equipped with: 1.A fill line with a shutoff valve. 2.A perforated fill line which runs to within 2 feet of the bottom of the tank. 3.A dirt and water collector.
4.Hold down straps embedded in a concrete foundation.
5.A return line from the fuel oil day tank.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 20 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Diesel Generator Combustion Air Intake and Exhaust System 9.5.8Exhaust relief valve discharge changed to vertical.Main Steam Supply System10.2Design temperature reduced to 541.5°F from 544.6°F.A vibration trip and alarm have been added.
 
A MSR high level trip and alarm have been added.10.3The main steam relief valves are relocated upstream from the safety valves to gain accessibility to these valves.The main steam isolation valve materials have been changed.
Each steam line of auxiliary feedwater pump turbine is provided with an air-operated stop valve instead of motorized stop check valve.Phosphate was deleted from use and condensate polishing added.
Design pressure changed to 1200 psig.
 
Safety class piping extended to the first moment restraint beyond the Main Steam Stop Valves.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 21 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Power operated relief valves now set to open at 1130 psia.The Main Steam Stop Valve integral bypass valve has been upgraded to code Class 1 from Code Class 2Lowest and highest safety valve set pressures changed to 1185 and 1235 psig.Steam Generators10.3Steam generator safety valves rated to pass 105 percent rather than 110 percent of flow.
Compressed Air System 9.3.1Air accumulators are upgraded to AN S Safety class 3 and designed to ASME B&PV Code Section III Class 3 Requirements.VII.Ventilation Systems:Containment Ventilation Systems 6.2.6The hydrogen purge system filter efficiencies have been increased from 90 to 95%.9.4CRDM cooling is accomplished by two 100-percent CRDM exhaust fans per containment instead of three 50-percent exhaust fans.The following changes have been made in the neutron detector well cooling system:TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 22 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 1041.Use of chilled water instead of component cooling water as the cooling medium of the neutron detector well cooling system2.A reduction in airflow from 24,000 ft 3 per containment to 13,100 ft 3 per containment for the neutron detector well cooling system due to the increase in the temperature gradient across the cooling coilsHeating, ventilating, and air-conditioning (HVAC) dampers are manufactured in accordance with ANS Safety Class 3, 10 CFR Part 50 Appendix B, and manufacturers' standards rather than ASME II.To provide for adequate cooling during accident conditions, centrifugal chillers are used for the emergency fan coil units instead of service water.Increase size of containment coolers to absorb heat load from the CRDM.
Only the containment purge exhaust ductwork is classified ANS Safety Class 3.Other ventilation systems 9.4.1Roof-mounted fans changed to in-duct fans for improved missile protectionReduction in outside air intake quantity for control roomTABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 23 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Control room pressurization capacity increased from 150 cfm to 800 cfm.Control room air-conditioning units in creased to 100 percent redundancy from 50 percent redundancy.Greater than 10 percent of the total air quantity is directed through the control room emergency filtration units.Four nuclear safety related vane-axial fans are utilized in each diesel generator room instead of one.
9.4.1The concept of lead system and standby system is deleted. Emergency recirculation will activate both Train A and Train B components.
9.4.2Auxiliary safeguards buildings ventilation supply distribution systems are now classified as seismic Category I 9.4.3Auxiliary building ventilation supply distribution system classified as seismic Category IElectrical area ventilation system contains only two 50-percent-capacity fans. TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 24 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Uncontrolled access area ventilation system contains two 50- percent-capacity fans.Battery rooms have in-duct fans instead of roof-mounted fans.
Office and service area ventilation systems have 50-percent redundancy; these systems are not required to satisfy the single-failure criterion and are nonessential to the safe shutdown of the reactor.GeneralAuxiliary, safeguards, fuel-handling, and containment purge supply and exhaust are incorporated into primary plant ventilation system.Summer design condition of diesel generator building changed from 104°F to 122°FFilter bed thickness increased from 2 inches to 4 inches.
Air inlet design temperature to the hydrogen purge exhaust unit changed from 120°F to 250°F.Instrument air accumulators are now provided for the control room HVAC system.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 25 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104VIII.Steam & Power Conversion Systems:
Component and sub-system design 5.4The steam generators for Unit 2 have been changed from D4's to D5'sSteam and power conversion system10.1The steam dump system to the condenser form the steam generator system is not a safety-related feature included in the steam and power conversion system.10.3The Main Steam Isolation Valve (MSIV) Bypass Valve were converted form automatic to manual. The hydraulic actuactors were deleted and handwheels installed. The valves are capable of being locked in position.Turbine-generator10.2Added Occupational Safety and Health Act (OSHA) to codes and standards.The worst case accident, a failure of the cast stage of the low pressure turbine rotor, is analyzed. The following have been added to the list of events that initiate a turbine trip:1.Reactor trip 2.Steam generator high-high levelTABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 26 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 1043.Safety injection4.Generator trip 5.Moisture separator high level (each MSR) 6.Excessive vibration during speed operation from 900 rpm until unit is synchronized.The following have been deleted from the list of events that initiate a turbine trip1.Low flow of stator coolant The following have been added to the list of events that initiate a generator trip:1.Loss of lube oil pressure 2.Low flow of stator coolantTABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 27 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104IX.Waste Processing Systems:Liquid Waste Processing System11.2The following equipment has been added to the LWPS:1.Laundry reverse osmosis system 2.Laundry holdup and monitor tanks 3.Laundry holdup and monitor tank pump 4.10,000 gallon floor drain tank 2 5.30,000 gallon floor drain tank 3Solid Waste Processing System (SWPS)11.4Utilizes an ATCOR proprietary cement solidification system per ATCOR Topical Report No. ATC-132A.X.Sampling & Monitoring Systems:Process Sampling System 9.3.2Phosphate analyzers replaced by sodium ion analyzers. System changed to non-nuclear safety related and non-seismic down-stream from the external containment isolation valves.9.3.2, II.B.3Inclusion of Post Accident Sampling System.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 28 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104Containment Hydrogen Monitoring System6.2.5Remote thermal conductivity analyzers replaced by in-containment electrochemical sensors and  microprocessor-based analyzers located in the control room.Steam generator liquid sample monitors11.5.2Steam generator liquid sample monitors reduced from four to one to simplify design Radiation Monitoring System11.5Changed from Analog to digital, microprocessor based system. Process monitors have been added to liquid waste processing and auxiliary condensate systems and to safeguards, auxiliary and fuel building vent ducts. Area monitors have been added to the fuel building to form a criticality alarm system.The auxiliary vent stack is no longer capable of being monitored by the containment air monitorRadiation monitors have been modified and have been added for accident monitoring.12.32Change from analog system to digital microprocessor based system Radiation monitors have been added for accident monitoring.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 29 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSARAmendment No. 104NOTE 1: The FSAR is complete and does not rely on information contained in the PSAR. The original intent of this table was to provide a comparison with the PSAR when the FSAR was initially submitted for NRC Staff review. The information in this table is consider ed historical and will not be updated.XI.Boron Recycle and Radioactive Waste Processing Systems1.Boron Recycle 3.2The code, code class, safety class, and seismic classification Table 17A-1 of system components were revised.2.Liquid Waste Processing System3.2 Table 17A-1 Appendix 1A(B)Same as for XI, item 1.3.Gaseous Waste Processing System3.2Table 17A-1 Appendix 1A(B)Same as for XI, item 1.TABLE 1.3-2DESIGN CHANGES SINCE PSAR SUBMITTAL(Sheet 30 of 30)
(See Note 1)
Systems or Components CPNPP/FSARSectionChanges CPNPP/FSAR1.4-1Amendment No. 1041.4IDENTIFICATION OF AGENTS AND CONTRACTORS1.4.1OWNERS AND APPLICANTS - TXU GENERATION COMPANY LP (TXU POWER)TXU Electric Generation Company LP, is a subsidiary of TXU Energy Company LLC (TXU Power) which is a subsidiary of TXU Corporation (TXU).TXU Power is a deregulated part of TXU Corporation and includes business activities engaged in power production. TXU Power is a top competitive generator of electricity in the U. S., with substantial electrical generating capacity in coal, natural gas and nuclear.The power generated at CPNPP is sold at market prices through power purchase and sale agreements coordinated with TXU Energy-Trading.TXU Power has over 55 years of experience in the design, construction and operation of electric generating plants.1.4.2OPERATOR - TXU POWERA charter was filed in the State of Texas, November 13, 1952, for the Industrial Generating Company "to manufacture and supply light, heat and electrical power, or either of them, in this state."  The name was changed in April of 1973 to Texas Utilities Generating Company (TUGCO). Effective January 1, 1984, TUCO reorganized several of its subsidiaries through the formation of a new corporate entity named Texas Utilities Electric Company (TUEC). The reorganization was effected through a consolidation of DP&L, TESCO and TP&L. Further, plant operation functions and personnel of TUGCO were transferred to TUEC. Effective January 16,
 
1987, TUEC adopted a new corporate signature "T U Electric" and discontinued the use of the acrynom "TUGCO" for its generating division. The TUGCO generating division became the Generating Division of TU Electric. Also in 1987, Texas Utilities Services, Inc. (TUSI) became known as TU Services.In a 1991 reorganization DP&L, TP&L, TESCO and the Generating Division were reorganized into six functional Divisions:  Operations; Operations Support and Marketing; Production; Engineering and Bulk Power; Finance, Accounting and Regulation; and Corporate Services. In a 1997 reorganization, TU Electric's six functional divisions were reorganized into Business Units: Generation; Transmission; and Distribution. In 1999, Texas Utilities Company was renamed TXU Corporation.
In a 2002 reorganization, TXU Electric, a subs idiary of TXU Corporation, was reorganized in order to comply with Texas law requiring the restructuring of the electric utility industry.Operations, engineering and construction activities for CPNPP are currently the responsibility of TXU Electric Generation Company LP, a subsidiary of TXU Energy Company LLC (TXU Power).TXU Power currently owns substantial generating capacity in coal, natural gas and nuclear.TXU Power has been designated by the Applicants as their Agent with the overall responsibility for the design, construction and operation of CPNPP.
CPNPP/FSAR1.4-2Amendment No. 1041.4.3ENGINEERING ORGANIZATION - TXU POWERTXU Power has been designated by the Applicants to coordinate the design and construction of CPNPP.TXU Power also furnishes engineering and other technical services at cost to the Applicants.The engineering functions of TXU Power for CPSES were in Texas Utilities Services Inc. (TUSI) prior to 1984. In January 1, 1984 all engineering functions in TUSI were reorganized into TUGCO. TUGCO/TUSI was given responsibility in 1969 to direct the design and construction activities of all lignite generating units in the TUGCO system. In 1972 an agreement to coordinate the design, quality assurance, and construction supervision of the TUCO system's nuclear generating units was made between Owners and TUGCO/TUSI.In October of 1991, engineering and construction activities for CPSES became the responsibility of the TU Electric Production Division. Within this division the Nuclear Production Group was delegated the responsibility for CPSES.In 1997 operation, engineering and construction activities for CPSES became the responsibility of the TU Electric Generation Business Unit, Generation Division. Within this division the Nuclear Generation Group has been delegated the responsibility for CPSES.In 1999, operation, engineering and construction activities for CPSES became the responsibility of the TXU Electric Generation Business Unit, Generation Division. Within this division the Nuclear Generation Group was delegated the responsibility for CPSES. In 2002, operation, engineering and construction activity for CPSES became the responsibility of TXU Electric Generation Company LP, a subsidiary of TXU Energy Company LLC (TXU Power).1.4.4ARCHITECT-ENGINEER -
Gibbs & Hill, Inc. was the original architect-engineer responsible for the design and engineering of CPSES.TXU Power gradually assumed more responsibility for the design and engineering of CPSES. This transition took place over several years and in an orderly and controlled manner. At the present time,  TXU Power - Nuclear Generation Group is the engineering organization ultimately responsible for the design and engineering of CPSES. Portions of this design and engineering
 
may be contracted to engineering services contractors working under a TXU Power approved Quality Assurance program.
Some of the engineering services contractors used at CPSES include:*Stone and Webster Engineering Corporation (SWEC) - provided engineering services including design and hardware validation in various technical disciplines such as mechanical, electrical, instrumentation and control, large and small bore pipe supports.*Impell - provided engineering services including design and hardware validation in selected areas such as fire protection, equipment qualification, safety-related cable tray hangers and non-safety related conduit supports.
CPNPP/FSAR1.4-3Amendment No. 104*Ebasco - provided engineering services including design and hardware validation in selected areas such as HVAC; safety-related conduit supports, cable tray and hangers and non-safety related conduit supports not within Impell scope; and the System Interaction Program.1.4.5NUCLEAR STEAM SUPPLY SYSTEM MANUFACTURER - WESTINGHOUSEWestinghouse Electric Corporation experience in nuclear plants for the  electric utility industry is demonstrated by the pressurized water reactor plants that Westinghouse has designed, developed and  manufactured. Table 1.4-1 lists all Westinghouse Pressurized Water Reactor plants to date, including those plants currently under construction or on order.Westinghouse Electric Corporation has long held a position of leadership in the electrical manufacturing industry. Traditionally, this leadership has been based on technological development of both standard and new products, reliability and product quality. Nowhere is this traditional leadership displayed more vividly than in nuclear power. Through early participation in basic research and basic engineering development, Westinghouse has established a broad technological foundation in nuclear power application. This has been followed by a continuing program of sound technological development which enables Westinghouse to offer to the electric utility industry a reliable and safe source of power from the atom.The experience of Westinghouse in nuclear activity is evident in  numerous Nuclear power projects - completed, soon to go into operation or being developed.1.4.6EARTH SCIENCES ENGINEER - DAMES & MOOREDames & Moore has been designated as the subcontractor responsible for  the earth sciences work at CPSES.The partnership of Dames & Moore was founded in 1938 in Los Angeles,  California. Since then, the firm has grown to more than 1500 employees in 42 offices in the United States and in 15 foreign countries. The varied experience and special knowledge of the firm's partners and technical employees enable them to solve earth science and environmental engineering problems.Their personnel have a diversified background in the fields of  meteorology, marine geology, oceanography, coastal and off-shore engineering, air and water pollution, ecology, engineering geology, soil and rock mechanics and dynamics, foundation engineering, geophysics, engineering seismology, engineering hydrology, mineral exploration, and systems management.Dames & Moore has served more than 8500 clients in over 100 countries,  with over 30,000 investigations of various types.Since 1965, Dames & Moore has made significant technical contributions to ER's and SAR's for more than 39 nuclear power stations, constructed, under construction, or planned in the United States. They have  provided expert testimony to the Nuclear Regulatory Commission, the Advisory Commission on Reac tor Safeguards, and various other regulatory agencies.
CPNPP/FSAR1.4-4Amendment No. 1041.4.7CONSTRUCTOR - BROWN & ROOT, INC.Brown & Root, Inc. has been designated as constructor of CPSES. Brown & Root is an engineering and construction company headquartered in Houston, Texas.The firm's operations are world-wide, with major engineering and construction offices in several nations, and project offices throughout the free world.The company was founded by Herman Brown in 1919 as a partnership with Dan Root. George Brown, the past Chairman of the Board, joined the firm in 1923, and in 1929 the firm was incorporated and restyled to its present form, Brown and Root, Inc. In 1962, the majority of the stock was purchased by Halliburton Company. The firm operates now as a wholly owned subsidiary of Halliburton Company, retaining its identity and autonomy as Brown & Root, Inc. Brown & Root, Inc. has more than 65,000 employees around the world, with a large percentage located in the Southwest.Brown & Root, Inc., has long been active in the field of power generation and to date has installed, or has under contract, central power stations with a combined capacity in excess of 40,000 MWe. Brown & Root, Inc. is currently constructing 2-1150 MWe PWR and has completed construction of 2-821 MWe BWR units. 1.4.8SUBSURFACE AND SOILS INVESTIGATION - MASON-JOHNSTON & ASSOCIATESMason-Johnston & Associates has been designated as subcontractor to perform soil mechanics and foundation engineering studies at CPSES.The firm of Mason-Johnston & Associates is primarily a professional service organization engaged in the fields of engineering geology, soil mechanics and foundation engineering. The firm provides field exploration, both land and ma rine, laboratory testing and soils and geological professional studies.Mason-Johnston & Associates has been engaged in the fields of soil mechanics, engineering geology, and foundation engineering in connection with multi-purpose projects varying from missile bases, dams, multi-story buildings, bridges, tunnels, pipelines and power plants. The activities of the firm also include subsurface ex ploration by vertical and multi-angle core borings; bore-holder color photography; resistivity and seismic traverses; laboratory determinations of the properties of earth materials; and engineering geology, soil mechanics, and foundation engineering studies. The firm's activities have included projects in most of the United States as well as in the countries of France, Surinam, Venezuela, and the Territory of Puerto Rico.1.4.9RESERVOIR DESIGN - FREESE AND NICHOLSFreese and Nichols was responsible for design of the Squaw Creek Reservoir system and the Safe Shutdown Impoundment at CPSES.Through a direct continuity of partnerships and subsequent incorporation, Freese and Nichols has been in professional engineering practice since 1894 and dams and water supply systems are among its primary areas of specialization. The firm now employs a staff of approximately 130 people.
CPNPP/FSAR1.4-5Amendment No. 104 Over 60 dams designed by Freese and Nichols have been constructed or are currently being built in Texas. Several of these projects are providing condenser cooling water for electric generating plants, including four plants in the TXU Power system.1.4.10OPERATIONS QUALITY ASSURANCE AND ADMINISTRATIVE CONTROL - EDS NUCLEAR INCORPORATEDEDS Nuclear Incorporated was retained as a consultant for QA services to assist in the development of QA programs and to provide operations administrative support services. Founded in 1969, with home offices in San Francisco, EDS Nuclear is engaged in providing specialized technical and management support services in connection with the design, construction and operation of nuclear power facilities. In 1984, EDS Nuclear Incorporated was
 
bought by Combustion Engineering and renamed Impell Corporation. The company provides analyses, reports, and services which assure safe operation of nuclear facilities to owners of such facilities and for their principal contractors and regulatory agencies involved. The clients of Impell include public utility companies, architec t-engineers, constructors, and equipment suppliers, who, in the aggregate, constitute all phases of a nuclear power plant project. 1.4.11DIVISION OF RESPONSIBILITY1.4.11.1Design StageAs indicated in Subsections 1.4.3 through 1.4.10, the design and construction of CPSES is coordinated and supervised by TXU Power. All parties (TXU Power, Gibbs & Hill, Westinghouse, Dames & Moore, Mason-Johnston, Freese and Nichols, EDS Nuclear and Brown & Root) have participated in the preliminary planning of CPSES as well as the preparation of the FSAR with TXU Power coordinating the effort. A review of the design bases and philosophies of the design for CPSES was conducted by all the above.1.4.11.2Procurement of Safety-Related Equipment1.4.11.2.1Westinghouse Scope of SupplyWestinghouse procures all items in their scope of supply. The equipment bidders' lists were approved by TXU Power. For further information, refer to Chapter 17
.1.4.11.2.2Scope of TXU Power's Services During design and construction TXU Power acts in procurement matters to insure that adequate information is provided to inform the bidders of all requirements for the requested equipment including but not limited to workmanship, material, documentation and shipping requirements. TXU Power is responsible for procurement of other safety-related equipment. TXU Power prepares the inquiries, sends them out for bids in accordance with the approved bidder's list, reviews the bids and prepares the requisition. After final approval by TXU Power, the purchase order is issued.
CPNPP/FSAR1.4-6Amendment No. 1041.4.11.3ConstructionAll construction activities at the site are under the supervision of TXU Power, with independent testing agencies contracted as necessary to perform special testing and to provide expertise in the interpretation of results.1.4.11.4Operation TXU Power has the responsibility for the operation of CPSES including the preoperational testing and initial startup. TXU Power procures both safety-related and non-safety related equipment, spare parts and supplies to insure the safe, efficient and reliable operation of CPSES. All safety-related procurement is accomplished per the requirements of the TXU Power Quality Assurance Program.1.4.11.5Startup AssistanceStartup assistance will be provided by Impell Corporation.
CPNPP/FSARAmendment No. 104TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 1 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of LoopsShippingportDuquesne Light Company; Energy Research &
Development AdministrationPennsylvania1957902Yankee-RoweYankee Atomic Electric CompanyMassachusetts19611752Trino Vercellese Enrico (Fermi)Ente Nazionale per L' Energia Elettrica (ENEL)Italy19652602Chooz (Ardennes)Societe d'Energie Nucleaire Franco-Belge des Ardennes (SENA)France19673052San Onofre No. 1Southern California Edison Co.; San Diego Gas and Electric Co.California19684502 Haddam Neck(Connecticut Yankee)Connecticut Yankee Atomic Power CompanyConnecticut19685752Jose Cabrera - ZoritaUnion Electrica, S. A. Spain19691531Beznau No. 1Nordostschweizerische Kraftwerke AG (NOK)Switzerland19693502 Robert Emmett GinnaRochester Gas and Electric CorporationNew York19704902 Mihama No. 1The Kansai Electric Power Company, Inc.Japan19703202 CPNPP/FSARAmendment No. 104Point Beach No. 1Wisconsin Electric Power Co.;Wisconsin Michigan Power Co.Wisconsin19704972H. B. Robinson No. 2Carolina Power and Light Co.South Carolina19717073Beznau No. 2Nordostschweizerische Kraftwerke AG (NOK)Switzerland19723502 Point Beach No. 2Wisconsin Electric Power Co.;Wisconsin Michigan Power Co.Wisconsin19724972Surry No. 1Virginia Electric and Power Co.Virginia19728223Turkey Point No. 3Florida Power and Light Co.Florida19727453 Indian Point No. 2Consolidated Edison Company of New York, Inc.New York19738734 Prairie Island No. 1Northern States Power CompanyMinnesota19735302 Turkey Point No. 4Florida Power and Light Co.Florida19737453 Surry No. 2Virginia Electric and Power Co.Virginia19738223 Zion No. 1Commonwealth Edison CompanyIllinois197310504TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 2 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104KewauneeWisconsin Public Service Corp.;
Wisconsin Power and Light Co.;
 
Madison Gas and Electric Co.Wisconsin19745602Prairie Island No. 2Northern States Power CompanyMinnesota19745302Takahama No. 1The Kansai Electric Power Company, Inc.Japan19747813 Zion No. 2Commonwealth Edison CompanyIllinois197410504 Doel No. 1Indivision DoelBelguim19753902 Doel No. 2Indivision DoelBelguim19753902 Donald C. Cook No. 1Indiana and Michigan Electric Company (AEP)Michigan197510904 Ringhals No. 2Statens Vattenfallsverk (SSPB)Sweden19758223 TrojanPortland General Electric Co.; Eugene Water and Electric Board; Pacific Power and Light CompanyOregon197511304Indian Point No. 3Power Authority of the State of New YorkNew York19769654TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 3 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Salem No. 1Public Service Electric and Gas Company;Philadelphia Electric Co.;
Atlantic Electric Co.;
Delmarva Power and Light Co.New Jersey197610904Almaraz No. 1Union Electrica, S. A.;Compania Sevillana de Electricidad, S. A.;
Hidroelectrica Espanola, S. A.Spain19779023Beaver Valley No. 1Duquesne Light Company; Ohio Edison Company;Pennsylvania Power CompanyPennsylvania19778523Diablo Canyon No. 1Pacific Gas and Electric Co.California197710844Joseph M. Farley No. 1Alabama Power CompanyAlabama19778293 Ko-Ri No. 1Korea Electric CompanyKorea19775642 North Anna No. 1Virginia Electric and Power Co.Virginia19778983Ringhals No. 3Statens Vattenfallsvert (SSPB)Sweden19779003 Lemoniz No. 1Iberduero, S. A.Spain19789023TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 4 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Almaraz No. 2Union Electrica, S. A.;Compania Sevillana de Electricidad, S. A.;
Hidroelectrica Espanola, S. A.Spain19789023Diablo Canyon No. 2Pacific Gas and Electric Co.California197811064North Anna No. 2Virginia Electric and Power Co.Virginia19788983 Ohi No. 1The Kansai Electric Power Company, Inc.Japan197811224 Ohi No. 2The Kansai Electric Power Company, Inc.Japan197811224 Sequoyah No. 1Tennessee Valley AuthorityTennessee197811484 Angra dos Reis No. 1Furnas-Centrais Eletricas, S. A.Brazil19786262 Donald C. Cook No. 2Indiana and Michigan Electric Company (AEP)Michigan197810604 Asco No. 1Fuerzas Electricas de Cataluna, S. A. (FECSA);Spain19799023 Asco No. 2Fuerzas 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.Spain19799023TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 5 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Lemoniz No. 2Iberduero, S. A.Spain19799023Sequoyah No. 2Tennessee Valley AuthorityTennessee197911484 Watts Bar No. 1Tennessee Valley AuthorityTennessee197911774 William B. McGuire No. 1Duke Power CompanyNorth Carolina197911804 Joseph M. Farley No. 2Alabama Power CompanyAlabama19798293 KrskoSavske Elektrarne, Ljubljana, Slovenia;Elektroprivreda, Zagreb, CroatiaYugoslavia19796152Ringhals No. 4Statens Vattenfallsvert (SSPB)Sweden19799003Salam No. 2Public Service Electric and Gas Company;Philadelphia Electric Co.;Atlantic Electric Co.;
Delmarva Power and Light Co.New Jersey197911154Virgil C. SummerSouth Carolina Electric and Gas CompanySouth Carolina19809003Watts Bar No. 2Tennessee Valley AuthorityTennessee198011774 William B. McGuireDuke Power CompanyNorth Carolina198011804TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 6 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Comanche Peak No. 1Texas Utilities Electric Co.Texas198511504  South Texas Project Unit No.1Houston Lighting and Power Co.;
Central Power and Light Co.;
 
City Public Service of San Antonio;City of Austin, TexasTexas198012504Byron No. 1Commonwealth Edison CompanyIllinois198111204Seabrook No. 1Public Service Company of New Hampshire;United Illuminating CompanyNew Hampshire198112004Braidwood No. 1Commonwealth Edison CompanyIllinois198111204Catawba No. 1Duke Power CompanySouth Carolina198111534 Beaver Valley No. 2Duquesne Light Company;Ohio Edison Company; Pennsylvania Power Co.;Cleveland Electric Illuminating Company; Toledo Edison CompanyPennsylvania19828523Callaway No. 1SNUPPS - Union Electric Co.Missouri198211504Ko-Ri No. 2Korea Electric CompanyKorea19826052TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 7 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Braidwood No. 2Commonwealth Edison CompanyIllinois198211204Byron No. 2Commonwealth Edison CompanyIllinois198211204 Comanche Peak No. 2Texas Utilities Electric Co.Texas198611504 Vandellos No. 2Fuerzas 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.Spain19829003Marble Hill No.1Public Service Company of Indiana, Inc.;Wabash Valley Power AssociationIndiana198211304Millstone No. 3Northeast Nuclear Energy Co.Connecticut198211564South Texas Project Unit No.2Houston Lighting and Power Co.;
Central Power and Light Co.;
City Public Service of San Antonio; City of Austin, TexasTexas198212504Wolf Creek Unit No. 1SNUPPS - Kansas Gas and Electric Company;Kansas City Power and Light CompanyKansas198211504TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 8 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Napot Point No. 1National Power CorporationPhilippines19826202Sayago No. 1Iberduero, S. A.Spain198210003 Catawba No. 2Duke Power CompanySouth Carolina198311534 Seabrook No. 2Public Service Company of New Hampshire;United Illuminating CompanyNew Hampshire198312004Maanshan No. 1Taiwan Power CompanyTaiwan19839073Alvin W. Vogtle No. 1Georgia Power Company; Oglethorpe Electric Membership Corp.;Municipal Electric Authority of Georgia; City of Dalton, GeorgiaGeorgia198311134Fort Calhoun No. 2Omaha Public Power District; Nebraska Public Power DistrictNebraska198311364Jamesport No. 1Long Island Lighting Company;New York State Electric and Gas Corp.New York198411504Maanshan No. 2Taiwan Power CompanyTaiwan19849073TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 9 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Alvin W. Vogtle No. 2Georgia Power Company; Oglethorpe Electric Membership Corp.;
Municipal Electric Authority of Georgia; City of Dalton, GeorgiaGeorgia198411134Marble Hill No. 2Public Service Company of Indiana, Inc.;Wabash Valley Power AssociationIndiana198411304Shearon Harris No. 1Carolina Power and Light Co.North Carolina19849003SterlingSNUPPS - Rochester Gas and Electric Corporation; Central Hudson Gas and Electric Corporation;Niagara Mohawk Power Corporation; Orange and Rockland Utilities, Inc.New York198411504Sundesert No. 1San Diego Gas and Electric Co.California19849503Tyrone No. 1SNUPPS - Northern States Power CompanyWisconsin198411504 NEP-1New England Power Company    -198411504 Atlantic No. 1 (O.P.S.)Public Service Electric and Gas Company;Atlantic Electric Co.;Jersey Central Power and Light CompanyNew Jersey198511504TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 10 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Jamesport No. 2Long Island Lighting Company;New York State Electric and Gas Corp.New York198611504NEP-2New England Power Company    -198611504Shearon Harris No. 2Carolina Power and Light Co.North Carolina1986 9003 Sundesert No. 2San Diego Gas and Electric Co.California1986 9503 Calloway No. 2SNUPPS - Union Electric CompanyMissouri198711504 Koshkonong No. 1Wisconsin Electric Power Co.;
Madison Gas and Electric Co.;
Wisconsin Power and Light Co.;
Wisconsin Public Service Corp.Wisconsin1987 9003Atlantic No. 2 (O.P.S.)Public Service Electric and Gas Company;Atlantic Electric Co.;Jersey Central Power and Light CompanyNew Jersey198711504Shearon Harris No. 4Carolina Power and Light Co.North Carolina1988 9003TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 11 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSARAmendment No. 104Koshkonong No. 2Wisconsin Electric Power Co.;
Madison Gas and Electric Co.;
 
Wisconsin Power and Light Co.;
Wisconsin Public Service Corp.Wisconsin1989 9003Unit No. 4 Iberduero, S. A.Spain1980's10003Shearon Harris No. 3Carolina Power and Light Co.North Carolina1990 9003 Unassigned No. 1 (O.P.S.) Public Service Electric and Gas Company;Atlantic Electric CompanyNew Jersey199011504Unassigned No. 2 (O.P.S.) Public Service Electric and Gas Company;Atlantic Electric CompanyNew Jersey199211504NORCOPuerto Rico Water Resources AuthorityPuerto Rico  - 5832Unit No. 1Central Maine Power CompanyMaine  -12004 South Dade No. 1Florida Power and Light Co.Florida  -11504 South Dade No. 2Florida Power and Light Co.Florida  -11504TABLE 1.4-1WESTINGHOUSE PRESSURIZED WATER REACTOR NUCLEAR POWER PLANTS(Sheet 12 of 12)PlantOwner UtilityLocation Scheduled Commercial OperationMWe NetNumber of Loops CPNPP/FSAR1.5-1Amendment No. 1041.5REQUIREMENTS FOR FURTHER TECHNICAL INFORMATIONThe activities described in Section 1.5 will be maintained as historical information and will not be updated.Reference [1] presents descriptions of the safety-related research and development programs which are being carried out for, or 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, followed, where appropriate, by background information. There is, then, a description of the program which relates the program objectives to the problem and presents pertinent recent results. Finally, a back up position may be given for programs (generally experimental rather than analytical) which have not yet reached a stage where it is reasonably certain that the results confirm the  expectation. The back up position is one that might be used if the results are unfavorable; it is not necessarily the only course that  might be taken.The term "research and development", as used in this report, is the same as that used by the NRC in 10CFR50.2, that is:(n) 'Research and development' means (1) theoretical analysis, exploration or experimentation; or (2) the extension of  investigative findings and theories of a scientific nature into  practical application for experimental and demonstration purposes including the experimental production and testing of models,  devices, equipment, materials, 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 will lead to design improvements.1.5.1BLOWDOWN HEAT TRANSFER TESTINGThe Nuclear Regulatory Commission (NRC) acceptance criteria for Emergency Core Cooling Systems (ECCS) for light-water power reactors was issued in Section 50.46 of 10CFR50 on December 28, 1973. It  defines the basis and conservative assumptions to be used in the  evaluation of the performance of the ECCS. 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 (CREST) indicated that the time to DNB can be delayed under transient conditions. To demonstrate the conservatism of the ECCS evaluation models, Westinghouse 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 early in 1976. Testing was completed in 1979. A DNB  correlation will be developed by Westinghouse from these test results for use in the ECCS
 
analyses.1.5.1.1Objective The objective of the Blowdown Heat Transfer Test was to determine the  time that DNB occurs under LOCA conditions. This information will be used to confirm the existing, or develop a new CPNPP/FSAR1.5-2Amendment No. 104Westinghouse transient  DNB correlation. The steady state DNB data obtained from 15 x 15 and  17 x 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.1.5.1.2ProgramThe program was divided into two phases. The 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 and flows, and at 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 shown in Table 1.5-1
.Phase II simulates PWR behavior during a LOCA to permit definition of the time delay associated with onset of DNB. Tests in this phase covered the large double ended guillotine cold leg break. All tests in Phase II were also started after establishment of typical steady state operating
 
conditions. The fluid transient was then initiated, and the rod power decay programmed in such a manner as to simulate the actual heat input of fuel rods. The test was terminated when the heater rod temperatures reach a predetermined limit.Typical parameters used for Phase II testing are shown in Table 1.5-2
.1.5.1.3Test Description The experimental program was conducted in the J-Loop at the Westinghouse Forest Hills Facility with a full length 5 x 5 rod bundle simulating a section of a 15 x 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.1.5.1.4Results The experiments in the DDNB Facility resulted in cladding temperature and 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 and plans were made for a new test bundle and further testing during 1978-79. These tests were completed in December of 1979. A DNB correlation will be developed from these test results for use in the Westinghouse ECCS analyses.
CPNPP/FSAR1.5-3Amendment No. 104REFERENCES1.Eggleston, F. T., "Safety-Related Research and Development for  Westinghouse Pressurized Water Reactors, Program Summaries,"  WCAP-8768, latest revision.
CPNPP/FSAR Amendment No. 104TABLE 1.5-1DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE I TEST PARAMETERSParametersNominal ValueInitial Steady State ConditionsPressure1250 to 2250 psiaTest section mass velocity12 to 2.5 x 10 6 lb/hr-ft 2Core inlet temperature550 to 600°F Maximum heat flux306,000 to 531,000 Btu/hr-ft 2Transient Ramp ConditionsPressure decrease 0 to 350 psi/sec and subcooled depressurization from 2250 psiaFlow decrease 0 to 100%/sec Inlet enthalpyConstant CPNPP/FSAR Amendment No. 104TABLE 1.5-2DELAYED DEPARTURE FROM NUCLEATE BOILING PHASE II TEST PARAMETERSParametersNominal ValueInitial Steady State ConditionsPressure2250 psiaTest section mass velocity2.5 x 10 6 lb/hr-ft 2Inlet temperature545°F Maximum heat flux531,000 Btu/hr-ft 2Transient ConditionsSimulated breakDouble ended cold leg guillotine breaks CPNPP/FSAR1.6-1Amendment No. 1041.6MATERIAL INCORPORATED BY REFERENCETable 1.6-1 lists documents which provide information additional to that provided in this FSAR and have been filed separately with the Nuclear Regulatory Commission (NRC) in support of the CPNPP operating licenses. A change to any of the documents listed in this table is considered to be a change to the FSAR and is subject to the same processing requirements. It should be noted, however, that for documents with revisions and/or dates, only the specific revisions and/or dates listed are considered to be part of the FSAR. Later revisions to these documents are not part of the FSAR unless they are incorporated into this table (except for the Technical Requirements Manual (including TRM Bases) and Technical Specifications Bases).Table 1.6-2 lists many of the topical reports and other licensing documents which were provided to the NRC in support of the CPNPP operating licenses as additional background and/or reference material for the FSAR. Material in this table is not considered to be "incorporated by reference" and changes to these documents are not considered to changes to the FSAR. Table1.6-2 is historical and is not updated.Documents listed in Table 1.6-2 (or are referenced elsewhere in the FSAR but are not listed in Table 1.6-1) are provided for information (e.g., references listed at the end of each FSAR section) or are documents to which CPNPP is committed (e.g., Regulatory Guides, Codes and Standards). Compliance with committed documents is required but the documents are not considered to be part of the FSAR.
CPNPP/FSAR Amendment No. 105TABLE 1.6-1DOCUMENTS INCORPORATED BY REFERENCE(Sheet 1 of 5)ReportReference Section(s)"An Evaluation of the Rod Ejection Accident in Westinghouse Pressurized Water Reactors Using Spatial Kinetics Methods," WCAP-7588, Revision 1-A, January 197515.4"Overpressure Protection for Westinghouse Pressurized Water Reactors," WCAP-7769, October 1971 5.2"Pipe Breaks for the LOCA Analysis of the Westinghouse Primary Coolant Loop," WCAP-8082-P-A (Proprietary) and WCAP-8172-A (Non-Proprietary), January 1975 (Non-Proprietary), January 1975 3.6BWCAP-10698-P-A, "SGTR Analysis Methodology to Determine the Margin to Steam Generator Overfill," August 1987.WCAP-14882-P-A, "RETRAN-02 Modeling and Qualification for Westinghouse Pressurized Water
 
Reactor Non-LOCA Safety Analyses," April 1999.5.2, 6.2, 15.1, 15.2, 15.3, 15.4, 15.5, 15.6 "VIPRE-01 Modeling and Qualification for Pressurized Water Reactor Non-LOCA Thermal-Hydraulic Safety Analysis," WCAP-14565-P-A, October 1999.
4.4, 15.1, 15.3, 15.4"Fuel Densification Experimental Results and Model for Reactor Application," WCAP-8218-P-A (Proprietary) and WCAP-8219-A (Non-Proprietary), March 1975.
4.1, 4.2, 4.3, 4.4"Westinghouse Mass and Energy Release Data For Containment Design," WCAP-8264-P-A, Rev. 1 July 2004 (Proprietary) and WCAP-8312-A, Revision 2, August 1975 (Non-Proprietary).
6.2 "Westinghouse Anticipated Transients Without Trip Analysis," WCAP-8330, August 1974 4.3, 4.6 15.1, 15.2 15.8"Environmental Qualification of Westinghouse Class 1E Equipment," WCAP-8587, Rev. 6, March 1983 3.10N, 3.11N CPNPP/FSAR Amendment No. 105"General Method of Developing Multi-frequency Biaxial Test Inputs for Bistables," WCAP-8624 (Proprietary) September 1975 and WCAP-8695 (Non-Proprietary)
August 1975.3.10N    Response to Station Blackout Rule", TXX-92447 October1, 1992 8BTP-03143, "Missile Analysis Methodology for GE Nuclear Steam Turbine Rotors by the SWPC," July 31, 2003.
3.5, 10.2Technical Requirements Manual (TRM) for Comanche Peak Nuclear Power Plant Units 1 and 2 All Sections Technical Specification Bases for Comanche Peak Nuclear Power Plant Units 1 and 2 All Sections Foster, J.P., et. al., "Westinghouse Improved Performance Analysis and Design Model (PAD 4.0)," WCAP-15063-P-A, Revision 1, with Errata (Proprietary) and WCAP-15064-NP-A, Revision 1, with Errata (Non-Proprietary), July 2000.4.2, 4.3, 4.4, 15.1Davidson, S.L., Ryan, T. L., "VANTAGE+ Fuel Assembly Reference Core Report," WCAP-12610-P-A and Appendices, April 1995.4.2, 4.3, 4.4, 15.1Weiner, R. A., et. al., "Improved Fuel Performance Models for Westinghouse Fuel Rod Design and Safety Evaluations," WCAP-10851-P-A (Proprietary) and
 
WCAP-11873-A (Non-Proprietary), August 1988.
4.2Kersting, P. J., et. al., "Assessment of Clad Flattening and Densification Power Spike Factor Elimination in Westinghouse Nuclear Fuel," WCAP-13589-A, March 1995.4.2WCAP-13060-P-A, "Westinghouse Fuel Assembly Reconstitution Methodology," July 1993 (Technical Specification 5.6.5b Item 18).
4TABLE 1.6-1DOCUMENTS INCORPORATED BY REFERENCE(Sheet 2 of 5)ReportReference Section(s)
CPNPP/FSAR Amendment No. 105 WCAP-10444-P-A, "Reference Core Report VANTAGE 5, Fuel Assembly," September 1985 (Technical Specification 5.6.5b Item 16).4.2, 4.3, 4.4, 15.1Scherder, W. J. (ed.), et al. "Reactor Core Response to Excessive Secondary Steam Releases," WCAP-9226-P-A, Revision 1, February 1998.4.4, 15.1"Addendum 1 to WCAP-12488-A, Revision to Design Criteria," WCAP-12488-A, Addendum 1-A, Revision 1,
 
January 2002.
4.2Davidson, S. L. (ed.), et al., "Extended Burnup Evaluation of Westinghouse Fuel," WCAP-10125-P-A, December 1985.4.2WCAP-14040-NP-A, "Methodology used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves."5.2.2.11Design Basis Document, DBD-ME-006, "Control of Heavy Loads at Nuclear Plants"9.1.4"RETRAN-02 Modeling and Qualification for Westinghouse Pressurized Water Reactor Non-LOCA
 
Safety Analyses," WCAP-14882-P-A, April 1999. 5.2, 15.1, 15.2, 15.3, 15.4, 15.5, 15.6"Revised Thermal Design Procedure," WCAP-11397-P-A, April 1989. 4.2, 4.3, 4.4, 15.0, 15.1, 15.2, 15.3, 15.4, 15.6 "TWINKLE - A Multi-dim ensional Neutron Kinetics Computer Code," WCAP-7979-P-A, January 1975. 15.0, 15.1, 15.4 "FACTRAN - A FORTRAN-IV Code for Thermal Transients in a UO2 Fuel Rod," WCAP-7908-A, December 1989. 15.4 "LOFTRAN Code Description," WCAP-7907-P-A, April 1984. 15.4 "Methodology for the Analysis of the Dropped Rod Event," WCAP-11394-P-A, January 1990. 4.2, 4.3, 4.4, 15.1, 15.4 TABLE 1.6-1DOCUMENTS INCORPORATED BY REFERENCE(Sheet 3 of 5)ReportReference Section(s)
CPNPP/FSAR Amendment No. 105"ANC:  A Westinghouse Advanced Nodal Computer Code," WCAP-10965-P-A, September 1986. 15.4 WCAP-10079-P-A (Proprietary) and WCAP-10080-A (Non-proprietary), 1985. Meyer, P. E., "NOTRUMP, A
 
Nodal Transient Small Break and General Network Code."15.6 Report Reference Section(s) WCAP-10054-P-A, Addendum 2, Revision 1 (Proprietary), 1995. Thompson, C.M., et al, "Addendum to the Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code:
Safety Injection into the Broken Loop and COSI Condensation Model." 15.6 WCAP-10054-P-A (Proprietary) and WCAP-10081-A (Non-proprietary), 1985. Lee, N. Rupprecht, S. D., Schwarz, W. R, and Tauche, W. D., "Westinghouse Small ECCS Evaluation Model Using the NOTRUMP
 
Code." 15.6 Bajorek, S.M., et. al., 1998, "Code Qualification Document for Best-Estimate LOCA Analysis," WCAP-12945-P-A, Volume 1, Revision 2 and Volumes 2 through 5, Revision 1. 15.6 WCAP-16009-P-A, "Realistic Large-Break LOCA Evaluation Methodology Using th e Automated Statistical Treatment of Uncertainty Method (ASTRUM)",
(Proprietary), January 2005.
15.6WCAP-8745, "Design Bases for the Thermal Overpower T Trip Functions," September 1986.
15.1WCAP-10325-P-A, (Proprietary) and WCAP-10326-A, (Nonproprietary), "Westinghouse LOCA Mass and Energy Release Model for Containment Design, March 1979 Version," May 1983.
6.2 WCAP-8264, Rev. 1, August 1975 and WCAP-8312, Rev. 2, "Topical Report Westinghouse Mass and Energy
 
Release Data Containment Design."
6.2 TABLE 1.6-1DOCUMENTS INCORPORATED BY REFERENCE(Sheet 4 of 5)ReportReference Section(s)
CPNPP/FSAR Amendment No. 105 WCAP-8822 and WCAP-8860, "Mass and Energy Releases Following a Steam Line Rupture," September 1976; WCAP-8822 and WCAP-8860, "Supplement 1 -
Calculations of Steam Superheat in Mass/Energy Releases Following a Steam Line Rupture," September 1986; WCAP-8822 and WCAP-8860, "Supplement 2 -
Impact of Steam Superheat in Mass/Energy Releases Following a Steam Line Rupture for Dry and Subatmospheric Containment Designs," September 1986.6.2WCAP-9272, "Westinghouse Reload Safety Evaluation Methodology," July 1985.4.2, 4.3, 4.4, 15.1RXE-94-001-A, "Safety Analysis of the Postulated Inadvertent Boron Dilution Event in Modes 3, 4, and 5,"
February 1994.
15.1Skaritka, J., (ed.), "Fuel Rod Bow Evaluation," WCAP-8691, Rev. 1 (Proprietary) and WCAP-8692, Rev. 1 (Non-Proprietary), July 1979.TABLE 1.6-1DOCUMENTS INCORPORATED BY REFERENCE(Sheet 5 of 5)ReportReference Section(s)
CPNPP/FSAR Amendment No. 104TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 1 of 12)
ReportReference Section(s)"The Doppler Effect for a Non-Uniform Temperature Distribution in Reactor Fuel Elements,"  WCAP-2048, July19624.3"Single Phase Local Boiling and Bulk Boiling Pressure Drop Correlations," WCAP-2850 (Proprietary), April 1966 and WCAP-7916 (Non-Proprietary), June 19724.4"In-Pile Measurement of UO 2 Thermal Conductivity,"
WCAP-2923, 19664.4"Hydraulic Tests of the San Onofre Reactor Model," WCAP-3269-8, June 19644.4"LEOPARD - A Spectrum Dependent Non-Spatial Depletion Code for the IBM - 7094," WCAP-3269-26, September 19634.3, 15.0, 15.4"Saxton Core II Fuel Performance Evaluation,"
WCAP-3385-56, Part II, "Evaluation of Mass Spectrometric and Radio-chemical Analyses of Irradiated
 
Saxton Plutonium Fuel," July 19704.3, 4.4 "Xenon-Induced Spatial Instabilities in Large PWRs," WCAP-3680-20, (EURAEC-1974) March 1968 4.3"Control Procedures for Xenon-Induced X-Y Instabilities in Large PWR's" WCAP-3680-21, (EURAEC-2111)
February19694.3"Xenon-Induced Spatial Instabilities in Three-Dimensions," WCAP-3680-22, (EURAEC-2116) September 19694.3"Pressurized Water Reactor pH - Reactivity Effect Final Report," WCAP-3696-8, (EURAEC-2074) October 19684.3"PUO2 - UO2 Fueled Critical Experiments," WCAP-3726-1, July 19674.3"Melting Point of Irradiated UO 2," WCAP-6065, February19654.2, 4.4 CPNPP/FSAR Amendment No. 104 "Burnup Physics of Heterogeneous Reactor Lattices," WCAP-6069, June 19654.4"LASER - A depletion Program for Lattice Calculations Based on MUFT and THERMOS," WCAP-6073, April19664.3"Supplementary Report on Evaluation of Mass Spectrometric and Radio-chemical Analyses of Yankee Core I Spent Fuel, Including Isotopes of Elements Thorium Through Curium," WCAP-6086, August 19694.3"Subchannel Thermal Anaylsis of Rod Bundle Cores,"
WCAP-7015, Revision 1, January 19694.4"The PANDA Code," WCAP-7048-P-A (Proprietary) and WCAP-7757-A (Non-Proprietary), January 19754.3"Evaluation of Protective Coatings for use in Reactor Containment," WCAP-7198-L (Proprietary), April 1969 and WCAP-7825 (Non-Proprietary), December 19716.1N"The TURTLE 24.0 Diffusion Depletion Code," WCAP-7213-P-A (Proprietary) and WCAP-7758-A (Non-Proprietary), January 19754.3, 15.0 15.4"Evaluation of Nuclear Hot Channel Factor Uncertainties," WCAP-7308-L (Proprietary) and WCAP-7810 (Non-Proprietary), December 19714.3"Application of the THINC Program to PWR Design," WCAP-7359-L (Proprietary), August 1969 and WCAP-7838 (Non-Proprietary), January 19724.4"Sensitized Stainless Steel in Westinghouse PWR Nuclear Steam Supply Systems," WCAP-7477-L (Proprietary), March 1970 and WCAP-7735 (Non-Proprietary), August 19715.2"Solid State Logic Protection System Description," WCAP-7488-L (Proprietary), March 1971 and WCAP-7672 (Non-Proprietary), May 1971.7.2, 7.3TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 2 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104 "Radiological Consequences of a Fuel Handling Accident," WCAP-7518-L (Proprietary) and WCAP-7828 (Non-Proprietary), June 197015.7"Seismic Vibration Testing with Sine Beats," WCAP-7558, October 19713.10N"Dynamic Fracture Toughness Properties of Heavy Section A533 Grade B Class 1 Steel Plate," WCAP-7623,
 
December 19705.4"Interchannel Thermal Mixing with Mixing Vane Grids," WCAP-7667-P-A (Proprietary) and WCAP-7755-A (Non-Proprietary), January 19754.4"DNB Tests Results for New Mixing Vane Grids (R)," WCAP-7695-P-A (Proprietary) and WCAP-7958-A (Non-Proprietary), January 19754.4"DNB Test Results for R Grid Thimble Cold Wall Cells," WCAP-7695-Addendum 1-P-A (Proprietary) and WCAP-7958-Addendum 1-A (Non-Proprietary),
January19754.4"Testing of Engineering Safety Features Actuation System," WCAP-7705, Revision 2, January 1976.7.3"An Evaluation of Solid State Logic Reactor Protection in Anticipated Transients," WCAP-7706-L (Proprietary) and WCAP-7706 (Non-Proprietary), February 19734.6, 7.1, 7.2"Electric Hydrogen Recombiner for PWR Containments," WCAP-7709-L, Supplements 1 through 7 (Proprietary) and WCAP-7820, Supplements 1 through 7 (Non-Proprietary), 1971 through 19773.11N, 6.2"A Comprehensive Space-Time Dependent Anaylsis of Loss of Coolant (SATAN-IV Digital Code)," WCAP-7750, August 19713.6BTABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 3 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"Behavior of Austenitic Stainless Steel in Post Hyporthetical Loss of Coolant Accident Environment,"
WCAP-7798-L (Proprietary) and WCAP-7803 (Non-Proprietary), January 19726.1N"Nuclear Fuel Division Quality Assurance Program Plan,"
WCAP-7800, Revision 4-A, April 19754.2, 17"Nuclear Design of Westinghouse Pressurized Water Reactors with Burnable Poison Rods," WCAP-7806, December 19714.3"Power Distribution Control of Westinghouse Pressurized Water Reactors," WCAP-7811, December 19714.3"Evaluation of Steam Generator Tube, Tubesheet and Divider Plate Under Combined LOCA Plus SSE Conditions," WCAP-7832, December 19735.4"Inlet Orificing of Open PWR Cores," WCAP-7836, January 19724.4"Methods of Determining the Probability of a Turbine Missile Hitting a Particular Plant Region," Topical Report WCAP-7861, February 1972.3.5"Neutron Shielding Pads," WCAP-7870, May 19723.9N"LOFTRAN Code Description," WCAP-7907, June 19725.2, 15.015.1, 15.215.3, 15.415.5, 15.6"FACTRAN - A FORTRAN-IV Code for Thermal Transients in a UO 2 Fuel Rod," WCAP-7908, June 197215.0, 15.2 15.3, 15.4"MARVEL, A Digital Computer Code for Transient Analysis of a Multiloop PWR System," WCAP-7909, June19726.2"Power Peaking Factors," WCAP-7912-P-A (Proprietary) and WCAP-7912-A (Non-Proprietary), January 19754.3, 4.4TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 4 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"Process Instrumentation for Westinghouse Nuclear Steam Supply Systems," WCAP-7913, January 1973.7.2, 7.3"Damping Values of Nuclear Power Plant Components,"
WCAP-7921-AR, May 19741A(N), 3.7N"Basis for Heatup and Cooldown Limit Curves," WCAP-7924-A, April 19755.3"Effect of Axial Spacing on Interchannel Thermal Mixing with the R Mixing Vane Grid," WCAP-7941-P-A (Proprietary) and WCAP-7959-A (Non-Proprietary),
 
January 19754.4"THINC-IV An Improved Program for Thermal- Hydraulic Analysis of Rod Bundle Cores," WCAP-7956, June 19734.4"Axial Xenon Transient Tests at the Rochester Gas and Electric Reactor," WCAP-7964, June 19714.3"TWINKLE - A Multi-Dimensional Neutron Kinetics Computer Code," WCAP-7979-P-A (Proprietary) and WCAP-8028-A (Non-Proprietary), January 197515.0, 15.4 "Application of the THINC-IV Program to PWR Design," WCAP-8054 (Proprietary) and WCAP-8195 (Non-Proprietary), October 19734.4A Summary Analysis of the April 30 Incident at the San Onofre Nuclear Generating Station Unit 1," WCAP-8099, April 19733.9N"Reactor Coolant Pump Integrity in LOCA," WCAP-8163, September 19731A(N), 5.4 "Calculation Model for Core Reflooding After a Loss of Coolant Accident (WREFLOOD Code)," WCAP-8170 (Proprietary) and WCAP-8171 (Non-Proprietary),
June197415.6"Operational Experience with Westinghouse Cores,"
WCAP-8183, Revision 6, June 19774.2, 11.1 TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 5 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"WFLASH, A FORTRAN-IV Computer Program for Simulation of Transients in a Multi-Loop PWR,"
WCAP-8200, Revision 2 (Proprietary) and WCAP-8261, Revision 1 (Non-Proprietary), July 197415.6"Safety Analysis of the 17x17 Fuel Assembly for Combined Seismic and Loss of Coolant Accident,"
WCAP-8236 (Proprietary), December 1973 and WCAP-8288 (Non-Proprietary), January 19743.7N, 4.2"Safety Analysis of the 8-Grid 17x17 Fuel Assembly for Combined Seismic and Loss of Coolant Accident,"
WCAP-8236, Addendum 1(Proprietary), March 1974 and WCAP-8288, Addendum 1 (Non-Proprietary), April 19743.7N"Documentation of Selected Westinghouse Structural Analysis Computer Codes," WCAP-8252, Revision 1, July19773.6B, 3.9N"Source Term Data for Westinghouse Pressurized Water Reactors," WCAP-8253, Amendment 1, July 197511.1, 12.3"Nuclear Instrumentation System," WCAP-8255 January1974.7.2, 7.7"Hydraulic Flow Test of the 17x17 Fuel Assembly," WCAP-8278 (Proprietary) and WCAP-8279 (Non-Proprietary), February 19744.2, 4.4 "The Effect of 17x17 Fuel Assembly Geometry on Interchannel Thermal Mixing," WCAP-8298-P-A (Proprietary) and WCAP-8299-A (Non-Proprietary),
 
January 19754.4"LOCTA-IV Program" Loss of Coolant Transient Analysis," WCAP-8301 (Proprietary) and WCAP-8305 (Non-Proprietary), June 197415.0, 15.6 "SATAN-IV Program: Comprehensive Space-Time Dependent Analysis of Lo ss of Coolant," WCAP-8302 (Proprietary) and WCAP-8306 (Non-Proprietary), June197415.0, 15.6 TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 6 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"Prediction of the Flow-Induced Vibration of Reactor Internals by Scale Model Tests," WCAP-8303-P-A (Proprietary) and WCAP-8317-A (Non-Proprietary), July19753.9N"Control of Delta Ferrite in Austenitic Stainless Steel Weldments," WCAP-8324-A, June 19751A(N), 5.2"Containment Pressure Analysis Code (COCO)," WCAP-8327 (Proprietary) and WCAP-8326 (Non-Proprietary), June 197415.6"Westinghouse ECCS Evaluation Model- Summary,"
WCAP-8339, July 19746.2, 15.6"Westinghouse ECCS - Plant Sensitivity Studies," WCAP-8340 (Proprietary) and WCAP-8356 (Non-Proprietary), July 197415.6"Westinghouse ECCS Evaluation Model Sensitivity Studies," WCAP-8341 (Proprietary) and WCAP-8342 (Non-Proprietary), July 197415.6"Effects of Fuel Densification Power Spikes on Clad Thermal Transients," WCAP-8359, July 19744.3"Westinghouse Nuclear Energy Systems Division Quality Assurance Plan," WCAP-8370, Revision 8A, September19771A(N), 17"Revised Clad Flattening Model," WCAP-8377 (Proprietary) and WCAP-8381 (Non-Proprietary), July19744.2"Power Distribution Control and Load Follow Procedures," WCAP-8385 (Proprietary) and WCAP-8403 (Non-Proprietary), September 19744.3, 4.4 "An Evaluation of Loss of Flow Accidents Caused by Power System Frequency Transients in Westinghouse PWRs," WCAP-8424, Revision 1, June 197515.3TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 7 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"17x17 Drive Line Components Tests - Phase IB, II, III, D-Loop Drop and Deflection," WCAP-8446 (Proprietary) and WCAP-8449 (Non-Proprietary), December 19743.9N"Analysis of Data from the Zion (Unit 1) THINC Verification Test," WCAP-8453-A, May 19764.4"Westinghouse ECCS Evaluation Model - Supplementary Information," WCAP-8471 (Proprietary) and WCAP-8472 (Non-Proprietary), April 197515.6"Incore Power Distribution Determination in Westinghouse Pressurized Water Reactors,"
WCAP-8498, July 19754.3"UHI Plant Internals Vibration Measurement Program and Pre and Post Hot Functional Examinations,"
WCAP-8516-P (Proprietary) and WCAP-8517 (Non-Proprietary), April 19753.9N"Critical Heat Flux Testing of 17x17 Fuel Assembly Geometry with 22 Inch Grid Spacing," WCAP-8536 (Proprietary) and WCAP-8537 (Non-Proprietary), May19754.4"The Application of Preheat Temperatures after Welding Pressure Vessel Steels," WCAP-8577, February 19761A(N)"Failure Mode and Effects Anaylsis (FMEA) of the Engineered Safeguard Features Actuation System," WCAP-8584 (Proprietary) and WCAP-8760 (Non-Proprietary), Revision 1, February 1980.4.6, 7.3"Westinghouse ECCS Evaluation Model - October 1975 Version," WCAP-8622 (Proprietary) and WCAP-8623 (Non-Proprietary), November 197515.6"Experimental Verification of West Fuel Storage Criticality Analyses," WCAP-8682 (Proprietary) and WCAP-8683 (Non-Proprietary), December 19754.3TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 8 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"Fuel Rod Bowing," WCAP-8691 (Proprietary) and WCAP-8692 (Non-Proprietary), Revision 1, July 1979 as
 
supplemented by NS-EPR-2515, October 9, 1981 and NS-EPR-2572, March 16, 19824.2"Delta Ferrite in Production Austenitic Stainless Steel Weldments," WCAP-8693, January 1976 1A(N), 5.2"MULTIFLEX - A FORTRAN-IV Computer Program for Analyzing Thermal-Hydraulic-Structure System Dynamics," WCAP-8708 (Proprietary) and WCAP-8709 (Non-Proprietary), February 19763.9N"Improved Analytical Models Used in Westinghouse Fuel Rod Design Computations," WCAP-8720 (Proprietary) and WCAP-8785 (Non-Proprietary), October 19764.2"Safety-Related Research and Development for Westinghouse Pressurized Water Reactors, Program Summaries," WCAP-8768, latest revision1.5, 4.24.3"Verification of Neutron Pad and 17x17 Guide Tube Designs by Preoperational Tests on the Trojan 1 Power Plant," WCAP-8780, May 19763.9N"Mass and Energy Releases Following a Steam Line Rupture," WCAP-8822 (Proprietary) and WCAP-8860 (Non-Proprietary), September 1976.6.2"Hybrid B 4C Absorber Control Rod Evaluation Report,"
WCAP-8846-A, October 19774.2, 15.3"7300 Series Process Control System Noise Tests," WCAP-8892-A, April 19777.1"Bench March Problem Solutions Employed for Verification of WECAN Computer Program," WCAP-8929, June 1977.3.9NTABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 9 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"Safety Analysis for the Revised Fuel Rod Internal Pressure Design Basis," WCAP-8963 (Proprietary),
November 1976 and WCAP-8964 (Non-Proprietary), August 19774.2"Dropped Rod Methodology for Negative Flux Rate Trip Plants", WCAP-10297-A (Proprietary)15.4"Evaluation of Mispositioned ECCS Valves," WCAP-8966 (Proprietary), September, 19776.3"Westinghouse Emergency Core Cooling System Small Break October 1975 Model," WCAP-8970 (Proprietary) and WCAP-8971 (Non-Proprietary), April, 1977.15.6"Failure Mode and Effects Analysis (FMEA) of the Solid State full Length Rod Control System," WCAP-8976, September 19774.6"Westinghouse Emergency Core Cooling System Evaluation Model for Analyzing Large LOCA's During Operation with One Loop Out of Service for Plants Without Loop Isolation Valves," WCAP-9166, February197815.6"Properties of Fuel and Cor e Component Materials," WCAP-9179 (Proprietary), September 19774.2"N-16 Power Measuring System," WCAP-9190 (Proprietary) and WCAP-9191 (Non-Proprietary),
December 19777.2"Westinghouse ECCS Evaluation Model, February 1978 Version," WCAP-9220-P-A (Proprietary Version),
WCAP-9221-P-A (Non-Proprietary Version), February 197815.6"Westinghouse Emergency Core Cooling System Evaluation Model" - Modified October 1975 Version, WCAP-9168 (Proprietary) and WCAP-9169 (Non-Proprietary), September 1977TABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 10 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104"Combination of Safe Shutdown Earthquake Loss of Coolant Accident Responses for Faulted Condition Evaluation of Nuclear Power Plants," WCAP-9279 (Non-Proprietary), March 19783.9N"Integrity of the Primary Piping Systems of Westinghouse Nuclear Power Plants During Postulated Seismic Events,"
WCAP-9283 (Non-Proprietary), March 19783.9N"Technical Bases for Eliminating Large Primary Loop Pipe Ruptures as the Structural Design Bases for Comanche Peak Units 1 and 2" WCAP-10527 (Proprietary) and WCAP-10528 (Non-Proprietary), April 19843.6B"Evaluation Of Surveillance Frequencies And Out Of Service Times For The Reactor Protection Instrumentation System" WCAP-10271-P-A, May 198616.2"Evaluation Of Surveillance Frequencies And Out Of Service Times For The Reactor Protection Instrumentation System" Supplement 1 WCAP-10271, Supplement 1-P-A, May 198616.2"Evaluation Of Surveillance Frequencies And Out Of Service Times For The Engineered Safety Features Actuation System" WCAP-10271, Supplement 2, Revision 1, March 198716.2"Reactor Trip Breaker Maintenance/Surveillance Optimization Program" WCAP-11312, April 198716.2WCAP-8708-PA (Proprietary), WCAP-8709 (Non-Proprietary), "MULTIFLEX A FORTRAN Computer Program for Analyzing Thermal-Hydraulic Structure System Dynamics, "Takeuchi, K., et al., September 1977.3.6B, 3.9NWCAP-15029-P-A (Proprietary), WCAP-15030-NP-A, (Non-Proprietary) "Westinghouse Methodology for Evaluating the Acceptability of Baffle-Former-Barrel Bolting Distribution Under Faulted Load Conditions," E.R.
 
Schwirian, et al., January 1999.3.6B, 3.9NTABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 11 of 12)
ReportReference Section(s)
CPNPP/FSAR Amendment No. 104WCAP-15245 (Proprietary), WCAP-15246 (Non-Proprietary), "Control Rod Insertion Following a Cold Leg LBLOCA, D.C. Cook Units 1 and 2," J.A. Barsic, et al.,
February 28, 1999.3.6B, 3.9NWCAP-11004-P (Proprietary), WCAP-11005 (Non-Proprietary), "Comparison of Data for Beaver Valley Power Station Unit 2 with WCAP-9735 Data, Prepared for NRC Review in Conjunction with Review of WCAP-9735, Docket No. 50-412," D.R. Bhandari, et al., November 1985.3.6B, 3.9NWCAP-11522 (Proprietary), WCAP-11523 (Non-Proprietary), "Response to NRC Questions on the LOCA Hydraulic Forces Analysis of the Beaver Valley Power Station Unit 2, Prepared for NRC Review in Conjunction with Review of WCAP-9735, Docket No. 50-412," D.C. Garner, et al., June 1987.3.6B, 3.9NTABLE 1.6-2 (HISTORICAL)DOCUMENTS PROVIDED AS ADDITIONAL REFERENCE INFORMATION(Sheet 12 of 12)
ReportReference Section(s)
CPNPP/FSAR1.7-1Amendment No. 1041.7ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGSA list of electrical, instrumentation, and control drawings is presented in Tables 1.7-1 and 1.7-2 for Unit 1 and Unit 2, respectively. These drawings include safety-related systems and non-safety-related systems which interact with the safety-related systems.The fifth digit letter of the drawing number indicates type of drawing. E indicates Electrical drawing and M indicates Mechanical Instrumentation and Control (I&C) drawing.The sixth digit numeral indicates Unit number. 1 indicates Unit 1 and 2 indicates Unit 2.
The revision and date indicated identify the drawing issue submitted to the NRC staff for review.
Additional drawings or later revisions of th ese drawings will be provide d upon request and the latest revision of all drawings are available for review on site.
CPNPP/FSARAmendment No. 104TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 1 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks Schematics (Electrical)Main steam Reheat & Steam Dump System2323-E1-00400 (a)00, 1-4, 17-28,44-71, 92-95, 97 H(b)  01/08/80(b)  Aux. & Main Steam System2323-E1-00390 (a)00, 41-48, 58-61,63, 64J(b) 01/08/80(b)
Steam generator feedwater2323-E1-00380 (a)00, 3-11, 13, 15,17, 19-30, 50,51, 54-62, 64-99 M(b) 03/15/80(b)
Auxiliary feedwater2323-E1-00370 (a)00, 1-16, 19-22,24-38, 40, 41, 42,46, 48, 60-68 S(b)  10/07/80(b) Compressed air (Instrument Air)2323-E1-00480 (a)00, 1, 4, 5, 7, 9,12, 14, 16 I(b)  03/13/80(b)
CPNPP/FSARAmendment No. 104Process sampling2323-E1-00450 (a)01-14, 16, 17 E(b)01/07/80(b)Component cooling water2323-E1-00502323_E1_0050  0 (a)00, 1, 3, 4, 6_19,23, 26-29, 34-41, 43,44, 47, 49, 50, 51, 53-55 M(b) 03/19/80(b)
Containment spray2323-E1-00490 (a)00, 01-14, 18, 21 H(a)02/07/80(b)Reactor Building Safeguard Building sump pumps2323-E1-00550 (a)00, 7, 8, 16-19 K(a)01/28/80(b)Demineralized water and reactor plant makeup2323-E1-00440 (a)00, 6-9, 11, 12, 14,16, 19M(b)  07/15/80(b)  Containment ventilation2323-E1-00590 (a)00, 1, 2, 13-16,19-54, 58, 59, 62-70 85, 86, 89 L(b) 03/19/80(b)
TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 2 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104 Safeguard and electrical area ventilation2323-E1-00530 (a)12, 13, 14, 16-55,62, 63, 65-76, 90,
 
91K(b) 03/10/80(b)
Auxiliary building and fuel handling area ventilation2323-E1-00560 (a)00, 1, 2, 7-11,14-53, 55-62, 64-67 I(b)  02/20/80(b)  Turbine Gen. Aux. & Misc. Syst.2323-E1-00600 (a)59N(b)03/06/80(b)Chilled water ventilation2323-E1-00540 (a)00, 2-5, 7-23 G(b)03/19/80(b)Primary plant ventilation2323-E1-00360 (a)1-32, 49, 50, 58,59, 71-96 I(b)  03/19/80(b)  Service water and intake structure ventilation2323-E1-00430 (a)00,1-23, 25-27, 40 41L(b)  02/08/80(b)  TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 3 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104CVCS2323-E1-00610 (a)00,1-6, 9, 10,14-20, 26-31, 36-41, 43-46, 65-69, 74-77, 80, 86 L(b) 03/18/80(b) 6.9 kV 3-line Normal Buses2323-E1-00261, 2212/13/796.9 kV 3-line Safeguard Buses2323-E1-00271, 2310/15/79Safeguard 6.9-kV switchgear breakers2323-E1-00310 (a)1-66AA(b)02/01/80(b)Normal 6.9-kV switchgear breakers2323-E1-00320 (a)1-72AF(b)02/28/80(b)Safeguard 480-V switchgear breaker2323-E1-00330 (a)1-42, 47-70 L(b)01/30/80(b)Normal 480-V switchgear breakers2323-E1-00340 (a)1-43, 45-49, 51-57 K(b)11/12/79(b)Control Room and office Facil. HVAC2323-E1-00350 (a)00, 1-30, 35-43, 46-53, 58-67, 69, 70, 71, 72-79, 88, 89, 92-97 S(b) 09/29/80(b)
TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 4 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104BOP Misc. System (Part of 2323-E1-0035)2323-E1-00690 (a)1-7B(b)09/12/80(b)BOP & NSSS Misc. Systems2323-E1-00710 (a)14, 15, 24, 46-6567, 68L(b)  03/20/80(b)  Safety injection2323-E1-00620 (a)00, 1, 2, 5-75 H(b)03/13/80(b)RHR2323-E1-00630 (a)00, 1-9G(b)03/27/80(b)RCS2323-E1-00640 (a)00, 1, 2, 9-12, 16,21-25, 40-43 H(b) 02/26/80(b)  Waste Processing2323-E1-00650 (a)00, 13-16 Q(b)03/03/80(b)6.9-kV Switchgear Miscellaneous2323-E1-00300 (a)9, 10, 19, 21, 22, 24, 26, 30, 35-37, 39, 43, 45, 47, 49, 51-54, 75, 58, 59, 60, 62, 63AD(b)  08/12/80(b)  TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 5 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104BOP Misc. Systems DC Switchboard Battery Charger Inverter2323-E1-00660 (a)00, 22, 23, 24-29,66, 78-81, 84, 87 Z(b) 10/03/80(b)
Diesel Generator and Monitor Lights2323-E1-00670 (a)1-36, 39, 40,41-50, 52-65, 77-90 L(b) 09/05/80(b)
NSSS Misc. System2323-E1-00700 (a)1-6, 8, 9, 21-26 F(b)08/05/80(b)Annunciator2323-E1-00761, 2, 3-7, 9, 10,13-20, 28-40, 42 (b) (b) Ventilation System2323-E1-00570 (a)00, 12-23 F(b)01/11/80(b)Radiation Monitoring System2323-E1-00460 (a)62-65G(b)04/03/80(b)Main 3-Line Meter Diagram2323-E1-00251, 2201/22/80Instrumentation and Control Diagram (ICD)Legend2323-M1-2200-01206/08/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 6 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M1-2200-02410/16/792323-M1-2200-03206/08/79 2323-M1-2200-04206/08/79 2323-M1-2200-05206/08/79Main Steam Reheat and Steam Dump2323-M1-2202-01304/26/792323-M1-2202-02412/14/79 2323-M1-2202-06304/26/79 2323-M1-2202-07304/26/79 2323-M1-2202-08412/14/79 2323-M1-2202-10304/26/79Steam Generator Feedwater2323-M1-2203-02307/03/792323-M1-2203-04407/03/79 2323-M1-2203-05307/03/79 2323-M1-2203-07207/03/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 7 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M1-2203-08207/03/79Auxiliary feedwater2323-M1-2206-01308/27/792323-M1-2206-02404/22/80 2323-M1-2206-03308/27/79 2323-M1-2206-04308/27/79 2323-M1-2206-05308/27/79 2323-M1-2206-06308/27/79 2323-M1-2206-07308/27/79 2323-M1-2206-08308/27/79 2323-M1-2206-09308/27/79 2323-M1-2206-10208/27/79Diesel Generator Auxiliary2323-M1-2215-01409/11/792323-M1-2215-02305/18/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 8 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Compressed air2323-M1-2216-03411/06/792323-M1-2216-01411/06/79Fire Protection2323-M1-2225-01307/13/79Not Class 1 Process Sampling2323-M1-2228-01410/25/792323-M1-2228-02410/25/79Component cooling water2323-M1-2229-01304/10/792323-M1-2229-02304/10/79 2323-M1-2229-03410/04/79 2323-M1-2229-04304/10/79 2323-M1-2229-05304/10/79 2323-M1-2229-06403/17/80 2323-M1-2230-01403/17/80 2323-M1-2230-02503/17/80 2323-M1-2231-02304/10/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 9 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M1-2231-03304/10/792323-M1-2231-05304/10/79 2323-M1-2231-07304/10/79Containment spray2323-M1-2232-01304/12/792323-M1-2232-02304/12/79 2323-M1-2232-03412/13/79 2323-M1-2232-04304/12/79 2323-M1-2232-05304/12/79 2323-M1-2232-06304/12/79Station Service Water2323-M1-2233-01305/02/792323-M1-2233-02305/02/79 2323-M1-2233-04412/27/79Not Class 1 2323-M1-2233-05305/02/79 2323-M1-2233-06305/02/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 10 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M1-2233-07412/27/792323-M1-2233-08412/27/79 2323-M1-2233-09305/02/79 2323-M1-2234-01305/02/79Not Class 1 2323-M1-2234-02305/02/79Spent Fuel Pool Cooling and Cleanup2323-M1-2235-012323-M1-2235-04 3302/09/7902/09/79Not Class 1Vents & Drains System2323-M1-2236-01302/01/79Safeguards and Auxiliary Building2323-M1-2236-02302/01/79 Vents & Drains System Turbine and Fuel Handling Building2323-M1-2237-02302/26/79Not Class 1Vents & Drains System Containment Building2323-M1-2238-02402/08/79Steam Generator Blowdown Cleanup2323-M1-2239-01406/01/79Not Class 1TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1(Sheet 11 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104 Demineralized and reactor makeup water2323-M1-2241-032323-M1-2242-01 3402/08/7904/08/80Turbine Generator2323-M1-2249-06205/16/79 Ventilation Containment2323-M1-2300-04302/07/792323-M1-2300-02302/07/79 2323-M1-2300-01302/07/79 2323-M1-2301-01305/04/79 2323-M1-2301-02405/04/79 2323-M1-2301-03305/04/79 2323-M1-2301-04305/04/79 2323-M1-2301-05305/04/79 2323-M1-2301-06305/04/79 2323-M1-2301-07305/04/79 2323-M1-2301-08405/04/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 12 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M1-2301-09305/04/792323-M1-2301-10305/04/79 2323-M1-2301-11205/04/79Ventilation safeguards and electrical area2323-M1-2302-05301/26/792323-M1-2302-06301/26/792323-M1-2302-07301/26/79 2323-M1-2302-08301/26/79 2323-M1-2302-09301/26/79 2323-M1-2302-10201/26/79Ventilation Auxiliary building and fuel handling area2323-M1-2303-01301/26/792323-M1-2303-05301/26/792323-M1-2303-05A101/26/79 2323-M1-2303-06301/26/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 13 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Control room air conditioning2323-M1-2304-01507/13/792323-M1-2304-02507/13/79 2323-M1-2304-03507/13/79 2323-M1-2304-04507/13/79 2323-M1-2304-05507/13-79 2323-M1-2304-06507/13/79 2323-M1-2304-07507/13/79 2323-M1-2304-08507/13/79 2323-M1-2304-12507/13/79 2323-M1-2304-13507/13/79 2323-M1-2304-14507/13/79Ventilation uncontrolled and miscellaneous areas2323-M1-2305-04303/09/79Ventilation chilled water2323-M1-2307-01302/09/792323-M1-2307-02302/09/79TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 14 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M1-2307-03302/09/79Not Class 12323-M1-2307-04302/09/79 2323-M1-2307-05302/09/79 2323-M1-2307-06302/09/79Ventilation equipment primary plant2323-M1-2309-02405/21/792323-M1-2309-04405/21/79 2323-M1-2309-01205/21/79 2323-M1-2309-05405/21/79Not Class 1Ventilation safety chilled water2323-M1-2311-01302/07/792323-M1-2311-02302/07/79 2323-M1-2311-03202/07/79Ventilation service water intake structure and misc. buildings2323-M1-2312-01305/16/79Ventilation UPS & Distribution Room2323-M1-2313-01CP107/20/84Reactor Coolant2323-M1-2250-03112/28/79Not Class 1TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 15 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M1-2251-07108/11/812323-M1-2250-07A108/11/81Boron Recycle2323-M1-2259-02111/19/79Not Class 12323-M1-2259-03111/19/79Not Class 1Liquid Waste Processing Drain Channel A2323-M1-2265-03210/15/79Not Class 1Liquid Waste Processing Drain Channel B2323-M1-2266-03210/15/79Not Class 12323-M1-2266-04210/15/79Not Class 12323-M1-2266-05110/15/79Not Class 1Liquid Waste Processing Drain Channel C2323-M1-2267-02210/15/79Not Class 12323-M1-2267-03210/15/79Not Class 12323-M1-2267-04210/15/79Not Class 1 2323-M1-2267-05210/15/79Not Class 1TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 16 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Liquid Waste Processing Disposal System2323-M1-2268-03210/15/79Not Class 12323-M1-2268-04210/15/79Not Class 12323-M1-2268-05210/15/79Not Class 1 2323-M1-2268-06210/15/79Not Class 1Waste Processing System(gas)2323-M1-2270-05110/15/79Not Class 1
 
Others (Equipment Supplier Drawings)Process Control Block Diagram8758D39 1(a)2-143(b) --NIS Source Range Functional Block Diagram5655D49--8--NIS Intermediate Range Functional Block Diagram5655D50--6--
NIS Power Range Functional Block Diagram5655D51--9--
NIS Auxiliary Channels Functional Block Diagram5655D52--6--TABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 17 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Solid State Protection System Functional Diagram7247D051-16 (b)--Pressurizer Heater Controller413918--6--Upgrade System Block Diagrams95540851, 21--a)Index Sheetb)For Revision and Date see Individual SheetTABLE 1.7-1CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 1 (Sheet 18 of 18)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 1 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks Schematics (Electrical)Main steam2323-E2-00400 (a)01-04, 18-2844-47, 53-63 B(b)  03/15/80(b)  Steam generator feedwater2323-E2-0038LaterLaterLater  Auxiliary feedwater2323-E2-0037LaterLaterLater Compressed air (Instrument air)2323-E2-0048LaterLaterLater  Process sampling2323-E2-00450 (a)01-14, 16, 17 A05/13/80(b)Component cooling water2323-E2-00500 (a)01, 03, 04, 06-19, 23, 26-29, 34-41, 43, 44, 47, 49-51, 53-55 C(b) 09/2/80(b)
Containment spray2323-E2-00490 (a)01-14, 18, 21 B(b)10/31/80(b)Extraction steam2323-E2-0051LaterLaterLater CPNPP/FSARAmendment No. 104Auxiliary & main steam2323-E2-00390 (a)41-48, 58-60, 63, 64B(b)  07/16/80(b)  Safeguards and reactor building sump pumps2323-E2-00550 (a)07, 08, 16-19 B(b)03/17/80(b)Demineralized water and and reactor plant makeup2323-E2-00440 (a)06, 08, 09, 11, 14 A(b)06/17/80(b)Containment ventilation2323-E2-0059LaterLaterLater Safeguard and electrical area ventilation2323-E2-00530 (a)65-76, 90, 91 B(b)09/09/80 (b)Auxiliary building and fuel handling area ventilation2323-E2-00560 (a)55-59A(b)07/28/80 (b)Turbine generator aux. and misc.
system2323-E2-00600 (a)59D(b)05/28/80 (b)Chilled water ventilation2323-E2-0054LaterLaterLater  6.9-kV 3-line normal buses2323-E2-0026LaterLaterLater  TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 2 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Service water and intake structure ventilation2323-E2-00430 (a)01, 02, 05, 06,13-20, 25-27 C(b)  09/15/80(b)  Diesel generator and monitor lights2323-E2-0067LaterLaterLater  Vent system2323-E2-00570 (a)12-23A(b)09/15/80(b)Annunciator2323-E2-0076LaterLaterLater  Radiation monitoring2323-E2-0046LaterLaterLater  CVCS2323-E2-00610 (a)01-06, 9, 10, 14-20, 26-31, 36-41, 43-46, 65-69, 74-77, 80, 86 B(b) 10/06/80(b)  Safety injection2323-E2-0062LaterLaterLater  RHR2323-E2-00630 (a)01-09A(b)11/10/80(b)RCS2323-E2-00640 (a)01, 02, 09-12, 16, 21-25 C(b)  10/01/80(b)  TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 3 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Waste processing2323-E2-00650 (a)13-16B(b)07/10/80(b)6.9-kV switchgear miscellaneous2323-E2-0030LaterLaterLater  Safeguard 6.9-kV switchgear breakers2323-E2-0031LaterLaterLater  Normal 6.9-kV switchgear breakers2323-E2-00320 (a)05-38, 41-62, 67-72 B(b)09/03/80(b)480-V Safeguard switchgear breakers2323-E2-00330 (a)01-40, 47-70 A(b)12/08/80(b)480-V Normal switchgear breakers2323-E2-0034LaterLaterLater  6.9-kV 3-line Safeguard buses2323-E2-0027LaterLaterLater BOP NSS Misc. Systems2323-E2-0071LaterLaterLater BOP Misc. System DC Switchboard Battery Charger and Inverter2323-E2-0066LaterLaterLater NSSS Misc. System2323-E2-0070LaterLaterLater  Main 3-Line Metering Diagram2323-E1-0025LaterLaterLater  TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 4 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Instrumentation and Control Diagrams (ICD)Legend2323-M2-2200-01107/20/792323-M2-2200-02310/16/79 2323-M2-2200-03107/20/79 2323-M2-2200-04107/20/79 2323-M2-2200-05107/20/79Main Steam Reheat and Steam Dump2323-M2-2202-01212/21/792323-M2-2202-02212/21/792323-M2-2202-06212/21/79 2323-M2-2202-07212/21/79 2323-M2-2202-08212/21/79 2323-M2-2202-10212/21/79Steam generator feedwater2323-M2-2203-02112/28/792323-M2-2203-04112/28/79TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 5 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M2-2203-05112/28/792323-M2-2203-07112/28/79 2323-M2-2203-08112/28/79Auxiliary feedwater2323-M2-2206-01108/27/792323-M2-2206-02204/22/80 2323-M2-2206-03108/27/79 2323-M2-2206-04108/27/79 2323-M2-2206-05108/27/79 2323-M2-2206-06108/27/79 2323-M2-2206-07108/27/79 2323-M2-2206-08108/27/79 2323-M2-2206-09108/27/79 2323-M2-2206-10108/27/79TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 6 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Compressed air2323-M2-2216-03211/06/792323-M2-2216-01211/06/79Condenser Vacuum and Waterbox Priming2323-M2-2211-02102/28/79Not Class 1Auxiliary Steam2323-M2-2213-01101/25/79Not Class 1 Diesel Generator Auxiliary2323-M2-2215-01209/11/792323-M2-2215-02105/18/79Fire protection2323-M2-2225-01108/30/79Not Class 12323-M2-2225-02108/30/79Not Class 1Process sampling2323-M2-2228-01210/25/792323-M2-2228-02210/25/79Spent fuel pool cooling and cleanup2323-M2-2235-01102/09/79Not Class 1 Component cooling water2323-M2-2229-01104/10/792323-M2-2229-02104/10/79 2323-M2-2229-03210/04/79TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 7 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M2-2229-04104/10/792323-M2-2229-05104/10/79 2323-M2-2229-06203/17/80 2323-M2-2229-07212/10/79Not Class 1 2323-M2-2230-01203/17/80 2323-M2-2230-02303/17/80 2323-M2-2231-01104/10/79Not Class 1 2323-M2-2231-02104/10/79 2323-M2-2231-03104/10/79 2323-M2-2231-04104/10/79Not Class 1 2323-M2-2231-05104/10/79 2323-M2-2231-06104/10/79Not Class 1 2323-M2-2231-07104/10/79TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 8 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Containment spray2323-M2-2232-01104/12/792323-M2-2232-02104/12/79 2323-M2-2232-03212/13/79 2323-M2-2232-04104/12/79 2323-M2-2232-05104/12/79 2323-M2-2232-06104/12/79 2323-M2-2232-07207/24/79Not Class 1Station Service water2323-M2-2233-01105/02/792323-M2-2233-02105/02/79 2323-M2-2233-03105/02/79Not Class 1 2323-M2-2233-04212/27/79 2323-M2-2233-05105/02/79 2323-M2-2233-06105/02/79Not Class 1 2323-M2-2233-07105/02/79TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 9 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M2-2234-02105/02/79Vents and Drains System Safeguards and Auxiliary building2323-M2-2236-01102/01/792323-M2-2236-02102/01/79Vents and Drains System Turbine and Fuel Handling Buildings2323-M2-2237-02203/26/80Not Class 1Vents and Drains System Containment building2323-M2-2238-02102/08/79Steam Generator Blowdown Cleanup2323-M2-2239-01206/01/79Not Class 1 Demineralized and reactor makeup water2323-M2-2241-01102/08/792323-M2-2242-01204/08/80Turbine Generator2323-M2-2249-06203/26/80 Ventilation Containment2323-M2-2300-01102/07/792323-M2-2300-02102/07/79 2323-M2-2300-04102/07/79TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 10 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 1042323-M2-2301-01105/04/792323-M2-2301-02105/04/79 2323-M2-2301-03105/04/79 2323-M2-2301-04105/04/79 2323-M2-2301-05105/04/79 2323-M2-2301-06105/04/79 2323-M2-2301-07105/04/79 2323-M2-2301-08105/04/79Ventilation Safeguards and electrical area2323-M2-2302-05101/26/792323-M2-2302-06101/26/792323-M2-2302-07101/26/79 2323-M2-2302-08101/26/79 2323-M2-2302-09101/26/79 2323-M2-2302-10101/26/79TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 11 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104Ventilation Auxiliary Building and fuel handling area2323-M2-2303-01101/26/79Ventilation Uncontrolled and miscellaneous areas2323-M2-2305-02103/09/79Ventilation Chilled water2323-M2-2307-01102/09/792323-M2-2307-02102/09/79 2323-M2-2307-03102/09/79Ventilation Equipment Primary plant2323-M2-2309-01105/21/79Not Class 1 Ventilation Safety chilled water2323-M2-2311-01102/07/792323-M2-2311-02102/07/79 2323-M2-2311-03102/07/79 Others (Equipment Supplier Drawings)Process Control Block Diagram8758D391 (a)2-413(b)--NIS Source Range Functional Block Diagram5655D49--8--TABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 12 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSARAmendment No. 104NIS Intermediate Range Functional Block Diagram5655D50--6--
NIS Power Range Functional Block Diagram5655D51--9--
NIS Auxiliary Channels Functional Block Diagram5655D52--6--Solid State Protection System Functional Diagram7247D051-16 (b)--Pressurizer Heater Controller413918--6--Upgrade System Block Diagrams9554D851, 21--a)Index Sheetb)For Revision and Date See Individual SheetTABLE 1.7-2CPNPP ELECTRICAL, INSTRUMENTATION, AND CONTROL DRAWINGS LIST FOR UNIT 2(Sheet 13 of 13)System or TitleDrawing No.Sheet No.RevisionDateRemarks CPNPP/FSAR1A(N)-1Amendment No. 104APPENDIX 1A(N) - DISCUSSION OF REGULATORY GUIDESThis appendix discusses the CPNPP positions on, and compliance with, Division 1 regulatory guides as they apply to the Nuclear Steam Supply System scope of equipment and services.
Appendix 1A(B) is provided separately for the balance of plant information.Identification of specific issues of regula tory guides are provided in the discussions where appropriate.Regulatory Guide 1.1Net Positive Suction Head for Emergency Core Cooling and Containment Heat Removal System PumpsDiscussionCPNPP complies with Safety Guide 1 (11/2/70) as discussed in Section 6.3.2.2.10
.Also refer to Appendix 1A(B) for further discussion.Regulatory Guide 1.2Thermal Shock to Reactor Pressure Vessels
 
DiscussionCPNPP follows all the recommendations of Safety Guide 2 (11/20/70). Regulatory Position C.1 is followed by Westinghouse's own analytical and experimental programs as well as by participation in the Heavy Section Steel Technology (HSST) program at the Oak Ridge National Laboratory.Analytical techniques have been developed by Westinghouse to perform fracture evaluations of reactor vessels under thermal shock loadings.Under the HSST program a number of 6 inch thick 39 inch outside diameter steel pressure vessels containing carefully prepared and sharpened surface cracks are being tested. Test conditions include both hydraulic internal pressure loadings and thermal shock loadings. The objective of this program is the validate analytical fracture mechanics techniques and demonstrate quantitatively the margin of safety inherent in reactor pressure vessels.A number of vessels have been tested under hydraulic pressure loadings, and results have confirmed the validity of fracture analysis techniques. The results and implications of the hydraulic pressure tests are summarized in Oak Ridge National Laboratory report ORNL-TM-5090.Three thermal shock experiments have been completed and are now being evaluated.
Preliminary information indicates that the analy tical techniques do agree favorably with experimental results.
CPNPP/FSAR1A(N)-2Amendment No. 104Westinghouse is continuing to obtain fracture toughness data for reactor pressure vessel steels through internally funded programs as well as HSST sponsored work.Fracture toughness testing of irradiated comp act tension fracture toughness specimens has been completed. The complete post-irradiation data on 0.394, 2, and 4 inch thick specimens are now available from the HSST program. Both static and dynamic post-irradiation fracture toughness data have been obtained. Evaluation of the data obtained to date on material irradiated to fluences between 2.2 and 4.5 10 19 n/cm2 indicates that the reference toughness curve as contained in the American Society of Mechanical Engineers (ASME) Code, Section III, remains a conservative lower bound for toughness values for pressure vessel steels. Another fracture toughness program is now underway. This program involves the irradiation and testing of weld metal used in fabrication of operating pressure vessels of pre-1972 construction. These welds characteristically have high copper contents and low initial Charpy V-notch "shelf" energies. Results of this program are expected in 1977.Details of progress and results obtained in the HSST program are available in the HSST program semiannual (quarterly beginning in 1974) progress reports, issued by Oak Ridge National Laboratory.
Regulatory Position C.2 is fo llowed inasmuch as no significant changes have been made in approved core or reactor designs.
Regulatory Position C.3 is followed since 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 at any point in its service life. This solution is already feasible, in principle, and could be performed with the vessel in place.Regulatory Guide 1.3Assumptions Used for Evaluating the Potential Radiological Consequences of a Loss of Coolant Accident for Boiling Water Reactors DiscussionThis regulatory guide is not applicable to the Comanche Peak Nuclear Power Plant (CPNPP).
Regulatory Guide 1.4Assumptions Used for Evaluating the Potential Radiological Consequences of a Loss of Coolant Accident for Pressurized Water Reactors Discussion Refer to Appendix 1A(B)
.
CPNPP/FSAR1A(N)-3Amendment No. 104Regulatory Guide 1.5Assumptions Used for Evaluating Potential Radiological Consequences of a Steam Line Break Accident for Boiling Water Reactors DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.6Independence Between Redundant Standby (Ons ite) Power Sources and Between Their Distribution Systems Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.7 Control of Combustible Gas Concentrations in Containment Following a Loss of Coolant AccidentDiscussionBased on a revision to 10CFR50.44, Regulatory Guide 1.7 no longer applies to CPNPP. See Section 6.2.5
.Regulatory Guide 1.8Personnel Selection and Training Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.9Selection of Diesel Generator Set Capacity for Standby Power Supplies
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.10Mechanical (Cadweld) Splices in Reinforcing Bars of Category I Concrete Structures CPNPP/FSAR1A(N)-4Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.11Instrument Lines Penetrating Primary Reactor Containment DiscussionCPNPP meets the recommendations of Safety Guide 11 (3/10/71) in accordance with the comments of Section 7.3.1.1.2
.Also refer to Appendix 1A(B) for further discussion.Regulatory Guide 1.12Instrumentation for Earthquakes Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.13Spent Fuel Storage Facility Design Basis Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.14 Reactor Coolant Pump Flywheel Integrity DiscussionThe CPNPP design follows the recommendations of Revision 1 (8/75) of Regulatory Guide 1.14 except for the following:1.Post-spin inspectionWestinghouse has shown in Reference [4] that the flywheel would not fail at 290 percent of normal speed for a flywheel flaw of 1.15 inches or less in length. Results for a double
 
ended guillotine break at the pump discharge with full separation of pipe ends assumed, show the maximum overspeed was to be less than 100 percent of normal speed. The maximum overspeed was calculated in Reference [4] to be about 280 percent of normal speed for the same postulated break, and an assumed instantaneous loss of power to the reactor coolant pump. In comparison with the overspeed presented above, the flywheel is tested at 125 percent of normal speed. Thus, the flywheel could withstand a speed up CPNPP/FSAR1A(N)-5Amendment No. 104to 2.3 times greater than the flywheel spin test speed 125 percent provided that no flaws greater than 1.15 inches are present. If the maximum speed were 125 percent of normal speed or less, the critical flaw size for failure would exceed 6 inches in length.Nondestructive tests and critical dimension examinations are all performed before the spin tests. The inspection methods employed (described in Reference [4] provide assurance that flaws significantly smaller than the critical flaw size of 1.15 inches for 290percent of normal speed would be detected. Flaws in the flywheel will be recorded in the pre-spin inspection program (see Reference [4]). Flaw growth attributable to the spin test (i.e., from a single reversal of stress, up to speed and back), under the most adverse conditions, is about three orders of magnitude smaller than what nondestructive inspection techniques are capable of detecting. For these reasons, Westinghouse performs no post- spin inspections and believes that pre-spin test inspections are adequate.2.Interference fit stresses and excessive deformationMuch of Revision 1 to Regulatory Guide 1.14 deals with stresses in the flywheel resulting from the interference fit between the flywheel and the shaft. Because Westinghouse's design specifies a light interference fit between the flywheel and the shaft; at zero speed, the hoop stresses and radial stresses at the flywheel bore are negligible. Centering of the flywheel relative to the shaft is accomplished by means of keys and/or centering devices attached to the shaft, and at normal speed, the flywheel is not in contact with the shaft in
 
the sense intended by Revision 1. Hence, the definition of "Excessive Deformation," as defined in Revision 1 of Regulatory Guide 1.14, is not applicable to the Westinghouse design since the enlargement of the bore and subsequent partial separation of the flywheel from the shaft does not cause unbalance of the flywheel. Extensive Westinghouse experience with reactor coolant pump flywheels installed in this fashion has verified the adequacy of the design.Westinghouse's position is that combined primary stress levels, as defined in Revision 0 of Safety Guide 14 (C.2.a and C.2.c), are both conservative and proven and that no changes to these stress levels are necessary. Westinghouse designs to these stress limits and thus does not have permanent distortion of the flywheel bore at normal or spin test conditions.3.Discussion B, cross rolling ratio of 1 to 3Westinghouse's position is that specification of a cross rolling ratio is necessary since past evaluations have shown that ASME SA-533 Grade B Class 1 materials produced without this requirement have suitable toughness for typical flywheel applications. Proper material selection and specification of minimum material properties in the transverse direction adequately ensure flywheel integrity. An attempt to gain isotropy in the flywheel material by means of cross rolling is unnecessary since adequate margins of safety are provided by both flywheel material selection (ASME SA-533 Grade B Class 1) and by specifying minimum yield and tensile levels and toughness test values taken in the direction perpendicular to the maximum working direction of the material.
CPNPP/FSAR1A(N)-6Amendment No. 1044.Regulatory Position C.1.a, relative to vacuum-melting and degassing process of the electroslag processThe requirements for vacuum melting and degassing process or the electroslag process are not essential in meeting the balance of the Regulatory Position nor do they, in themselves, ensure compliance with the over all Regulatory Position. The initial Safety Guide 14 (10/27/71) stated that the "flywheel material should be produced by process that minimized flaws in the material and improves its fracture toughness properties."  This is accomplished by using SA-533 ma terial including vacuum treatment.5.Regulatory Position C.2.b Westinghouse suggests that this paragraph be reworded as follows in order to remove the ambiguity of reference to an undefined overspeed transient."Design speed should be 125 percent of normal speed or the speed to which the pump motor might be electrically driven by station turbine generator during anticipated transients, whichever is greater. Normal speed is defined as the synchronous speed of the alternating current drive motor at 60 hertz."6.InspectionThe reactor coolant pump flywheel inspection is in accordance with Technical Specification 5.5.7.Regulatory Guide 1.15Testing of Reinforcing Bars for Category I Concrete Structures Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.16Reporting of Operating Information - Appendix A Technical Specifications
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.17Protection of Nuclear Power Plants Against Industrial Sabotage Discussion Refer to Appendix 1A(B)
.
CPNPP/FSAR1A(N)-7Amendment No. 104Regulatory Guide 1.18Structural Acceptance Test for Concrete Primary Reactor Containments Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.19Nondestructive Examination of Primary Containment Liner Welds
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.20Comprehensive Vibration Assessment Program for Reactor Internals During Preoperational and Initial Startup Testing DiscussionThe CPNPP position on Revision 2 (5/76) of Regulatory Guide 1.20 is discussed in Section3.9N.2.4
.Regulatory Guide 1.21Measuring, Evaluating, and Reporting Radioactivity in Solid Wastes and Releases of Radioactive Materials in Liquid and Gaseous Effluents from Light-Water-Cooled Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.22Periodic Testing of Protection System Actuation Functions DiscussionCPNPP meets the recommendations of Safety Guide 22 (2/17/72) in accordance with the comments of Section 7.1.2.5
.Regulatory Guide 1.23Onsite Meteorological Program CPNPP/FSAR1A(N)-8Amendment No. 104 Discussion Refer to Appendix 1A(B)
. Regulatory Guide 1.24Assumptions Used for Evaluating the Potential Radiological Consequences of a Pressurized Water Reactor Radioactive Gas Storage Tank Failure Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.25Assumptions 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 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.26Quality Group Classifications and Standards for Water, Steam and Radioactive-Waste-Containing Components of Nuclear Power Plants DiscussionQuality group classification of fluid system equipment of the Westinghouse scope of supply for the CPNPP is as described in Section 3.2
.Nuclear Steam Supply System fluid system components important to safety are classified in accordance with the August 1970 Draft of American National Standard (ANSI) N18.2, "Nuclear Safety Criteria for the Design of Stationary Pressurized Water Reactor Plant," except for the deviation described in Section 3.2.2. In addition, components of the accumulator subsystem and the refueling water subsystem are placed in a higher classification. The effect of this higher classification is to produce the same quality levels for all components as is achieved by the application of the 1973 version of N18.2, as finally accepted by ANSI.Classification by this means is an alternate acceptable method of meeting the intent of Revision 3 (2/76) of Regulatory Guide 1.26. The method of classifying is in accordance with NRC stated policy on regulatory guides that "methods and solutions different from those set out in the guides will be acceptable if they provide a basis for the findings requisite to the issuance or continuance of a permit or license by the Commission."
Also refer to Appendix 1A(B) for further discussion.
CPNPP/FSAR1A(N)-9Amendment No. 104Regulatory Guide 1.27Ultimate Heat Sink for Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.28Quality Assurance Program Requirements (Design and Construction)
 
DiscussionThe Westinghouse quality assurance program, including the Westinghouse position on Regulatory Guide 1.28, is presented in WCAP-8370 [5].
Also refer to Appendix 1A(B) for further discussion.Regulatory Guide 1.29 Seismic Design Classification
 
DiscussionSeismic classification of fluid system equipment of Westinghouse scope of supply for the CPNPP is as described in Section 3.2
.The classification of components by safety class provides the means of establishing applicable aseismic design requirements of both components and system. At the time the CPNPP was designed, duplication by special seismic clas sification was unnecessary since ANSI N18.2, "Nuclear Safety Criteria for the Design of Stationary Pressurized Water Reactor Plants" was considered to establish seismic design requirements of systems having components classified as Safety Class 1, Safety Class 2, or Safety Class 3. Safety class fluid system components are designed to remain functional in the event of occurrence of the Design Basis Earthquake, defined in Section 2.1.5.4 of ANSI N18.2-1973 but now identified as the Safe Shutdown Earthquake by the NRC. The Reactor Protection System includes similar aseismic design features.Classification by this means is an alternate acceptable method of meeting the intent of Revision 2 (2/76) of Regulatory Guide 1.29. The method of classifying is in accordance with NRC stated policy on regulatory guides that "methods and solutions different from those set out in the guides will be acceptable if they provide a basis for the findings requisite to the issuance or continuance of a permit or license by the Commission."
Also refer to Appendix 1A(B)
.Regulatory Guide 1.30Quality Assurance Requirements for the Installation, Inspection, and Testing of Instrumentation and Electric Equipment CPNPP/FSAR1A(N)-10Amendment No. 104 DiscussionThe design criteria Westinghouse applies to safety-related instrumentation and controls are consistent with ANSI N45.2.4-1972 (IEEE Standard 336-1971), "Installation, Inspection, and Testing Requirements of Instrumentation and Electr ical Equipment During the Construction of Nuclear Power Generating Stations."  The major actions is complying with this standard fall within the scope of plant construction. Westinghouse functions in design and procurement of instrumentation and electrical equipment are supportive to the later fulfillment of the standard at the time of construction.For those activities performed after September 1, 1972, Westinghouse follows the guidance of Safety Guide 30 (8/11/72). For those activities performed prior to September 1, 1972, the quality assurance procedures employed in the design of the CPNPP may vary in detail from the position of the regulatory guide, but meet its essential requirements.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.31Control of Stainless Steel Welding
 
DiscussionThe Westinghouse position concerning the control of delta ferrite in stainless steel welding is discussed in Section 5.2.3. The Westinghouse production weld verification program, as described in Reference [6], was approved as a satisfactory substitute for conformance with the NRC Interim Position on Revision 3 (4/78) of Regulatory Guide 1.31. The results of the verification program have been summarized and documented in Reference [7].The welding of austenitic stainless steel is controlled to mitigate the occurrence of microfissuring or hot cracking in the weld. Although published data and experience have not confirmed that fissuring is detrimental to the quality of the weld, it is recognized that such fissuring is undesirable in a general sense. Also, it has been well documented in the technical literature that the presence of delta ferrite is one of the mechanisms for reducing the susceptibility of stainless steel welds to hot cracking. However, there are insufficient data to specify a minimum delta ferrite level below which the material will be prone to hot cra cking. It is assumed that such a minimum lies somewhere between 0 and 3 percent delta ferrite.The scope of these controls discussed herein encompasses welding processes used to join stainless steel parts in components designed, fabricated or stamped in accordance with ASME B&PV Code, Section III Class 1, 2, 3 and CS components. Delta ferrite control is appropriate for the above welding requirements except in the following cases where no filler metal is used (for example, in electron beam welding and in autogenous gas shielded tungsten arc welding), where stainless steel filler metal is used for weld metal cladding, explosive welding, and welding using fully austenitic welding materials.The fabrication and installation specifications require welding procedure and welder qualification in accordance with Section III, and include the delta ferrite determinations for the austenitic stainless steel welding materials that are used for welding qualification testing and for production processing. Specifically, the undiluted weld deposits of the "starting" welding materials are CPNPP/FSAR1A(N)-11Amendment No. 104required to contain a minimum of 5 percent delta ferrite a as determined by chemical analysis and calculation using the appropriate weld metal constitution diagrams in Section III. When new welding procedure qualification tests are evaluated for these applications, including repair welding of raw materials, they are performed in accordance with Section III and Section IX. The results of all the destructive and non-destructive tests are reported in the procedure qualification record in addition to the information required by Section III.The "starting" welding materials used for fabrication and installation welds of austenitic stainless steel materials and components meet the requirements of Section III. The austenitic stainless steel welding material conforms to ASME weld metal analysis A-7 (designated A-8 in the 1974 Edition of the ASME code), type 308 or 308L for all applications. Bare weld filler metal, including consumable inserts, used in inert gas welding processes conform to ASME SFA-5.9, and are procured to contain not less than 5 percent delta ferrite in the deposit according to Section III.
Weld filler metal materials used in flux shielded welding processes conform to ASME SFA-5.4 or SFA-5.9 and are procured in a wire-flux combination to be capable of providing not less than 5percent delta ferrite in the deposit according to Section III. Welding materials are tested using the welding energy inputs to be employed in production welding. Combinations of approved heats and lots of "starting" welding materials are used for all welding processes. The welding quality assurance program includes identification and control of welding material by lots and heats as appropriate. All of the weld processing is monitored according to approved inspection programs which include review of "starting" materials, qualification records and welding parameters. Welding systems are also subject to quality assurance audit including calibration of gages and instruments, identification of "starting" and completed materials, welder and procedure qualifications, availability and use of approved welding and heat treating procedures, and documentary evidence of compliance with materials, welding parameters, and inspection requirements. Fabrication and installation welds are inspected using non-destructive examination methods according to Section III rules.To assure the reliability of these controls, Westinghouse has performed a delta ferrite verification program, described in Reference [6]. The verification program has been approved as a valid approach to verify the Westinghouse hypothesis and is considered an acceptable alternative for conformance with the Interim Position on Regulatory Guide 1.31. The Regulatory Staff's acceptance letter and topical report evaluation were received on December 30, 1974. The program results, which support the hypothesis presented in Reference [6], are summarized in Reference [7].Welds made in accordance with the criteria discussed herein have continually resulted in sound production welds, which are free from detrimental fissuring and consistently conform to SectionIII non-destructive acceptance standards.
Also refer to Appendix 1A(B)
.a.The equivalent Ferrite Number may be substituted for percent delta ferrite.
CPNPP/FSAR1A(N)-12Amendment No. 104Regulatory Guide 1.32Criteria for Safety-Related Electric Power Systems from Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.33Quality Assurance Program Requirements (Operation)
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.34Control of Electroslag Weld Properties
 
DiscussionWhere electroslag welding is used in fabricating nuclear plant components the Westinghouse procurement procedure requires vendors to meet the guidelines of Regulatory Guide 1.34 (12/28/72).Regulatory Guide 1.35Inservice Inspection of Ungrouted Tendons in Prestressed Concrete Containment Structures DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.36Nonmetallic Thermal Insulation for Austenitic Stainless Steel DiscussionThe Westinghouse practice meets the recommendations of Regulatory Guide 1.36 (2/23/73) but is more stringent in several respects as discussed below.The nonmetallic thermal insulation used on the reactor coolant pressure boundary is specified to be made of compounded materials which yield low leachable chloride and/or fluoride concentrations. The compounded materials in the form of blocks, boards, cloths, tapes, adhesives, cements, etc., are silicated to provide protection of austenitic stainless steels against stress corrosion which may result from accidental wetting of the insulation by spillage, minor leakage or other contamination from the environmental atmosphere. Each lot of insulation materials provides a compatible combination for the reactor coolant pressure boundary.
CPNPP/FSAR1A(N)-13Amendment No. 104The tests for qualification specified by this regulatory guide (ASTM- C-692-71 or RDT M12-IT) allow use of the tested insulation materials if no more than one of the metallic test samples crack. Westinghouse rejects the tested insulation material if any of the test samples crack.The Westinghouse procedure is more specific than the procedures suggested by this regulatory guide, in that the Westinghouse specification requires determination of leachable chloride and fluoride ions from a sample of the insulating material. The procedures in this regulatory guide (ASTM-D-512 and ASTM-D-1179) do not differentiate between leachable and unleachable halogen ions.In addition, Westinghouse experience indicates that only one of the three methods allowed under ASTM-D-512 and ASTM-D-1179 for chloride and fluoride analysis is sufficiently accurate for reactor applications. This is the "referee" method, which is used by Westinghouse. These requirements are defined in Westinghouse Process Specification PS-83336KA.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.37Quality Assurance Requirements for Cleaning of Fluid Systems and Associated Components of Water-Cooled Nuclear Power Plants DiscussionThis guide (dated March 16, 1973) endorses ANSI N45.2.1-1973, which applies to cleaning procedures at the construction site and is therefore not in the Westinghouse scope.
Westinghouse procurement orders apply cleaning requirements during fabrication and packaging of safety-related components so that NSSS equipment is delivered to the site in a properly cleaned condition. A Westinghouse process specification provides detailed cleaning requirements for equipment manufacturers, and is included as a procurement requirement, where appropriate.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.38Quality Assurance Requirements for Packaging, Shipping, Receiving, Storage, and Handling of Items for Water-Cooled Nuclear Power Plants DiscussionFor the CPNPP whose application was docketed prior to April 1, 1973, the quality assurance procedures employed in the design and construction phases may vary in detail from the current position of Revision 1 (10/76) of the regulatory guide but meet its essential requirements in that they follow good business practices as defined in the applicable Westinghouse process specifications.For activities initiated after January 1, 1975, for the CPNPP, Reference [5] is applicable. This plan follows the guidance of ANSI N45.2.2-1978 (Unit 1) ANSI N45.2.2-1972 (Unit 2) (which is recognized by Regulatory Guide 1.38) in the des ign, procurement, fabrication and shipment of CPNPP/FSAR1A(N)-14Amendment No. 104safety-related NSSS equipment. Measures are applied, as appropriate, to apply packaging requirements to procurement orders, to review supplier packaging procedures, to apply proper cleaning requirements, to apply proper marking and identification, to provide protection to equipment from physical or weather damage, to apply special handling precautions and to define storage requirements. A Westinghouse process specification incorporates detailed packaging and handling requirements for equipment manufacturers, and is included as a procurement requirement where appropriate.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.39Housekeeping Requirements for Water-Cooled Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.40Qualification Tests of Continuous-Duty Motors Installed Inside the Containment of Water-Cooled Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.41Preoperational Testing of Redundant On-Site Electric Power Systems to Verify Proper Load Group Assignments Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.42Interim Licensing Policy on As Low As Practicable for Gaseous Radioiodine Releases from Light-Water-Cooled Nuclear Power Reactors DiscussionThis regulatory guide was withdrawn March 22, 1976.Regulatory Guide 1.43Control of Stainless Steel Weld Cladding of Low-Alloy Steel Components CPNPP/FSAR1A(N)-15Amendment No. 104 DiscussionThe reactor vessel bottom head (Unit 1) and heads (Unit 2), shell courses, and torus sections were constructed of SA-533, GradeB, Class 1, plate material made to a fine grain practice. This material was clad by the shielded metal arc, one-wire submerged arc, and the 4-inch strip submerged arc processes; the shielded metal arc and one-wire submerged arc processes are considered to be low heat input methods of cladding.Although the plate material is SA-533, Grade B, Class 1, made to fine grain practice and not subject to qualification restrictions by Regulatory Guide 1.43 (5/73), the 4-inch strip clad process was qualified. 1.Unit 1The shielded metal arc and the one-wire submer ged arc processes (both considered low heat input) were used to clad the vessel flanges and the closure head, which was forged of SA-508, Class 3. These processes were also used to clad the primary nozzles which were constructed of SA-508, Class 2, forging material.2.Unit 2The shielded metal arc and the one-wire submerged arc processes (both considered low heat input) were used to clad the closure head and vessel flanges and the primary nozzles which were constructed of SA-508, Class 2, forging material.
The reactor vessel fabricator monitors and records the weld parameters to verify conformance with the parameters established by the procedure qualification as recommended by Regulatory Position C.3.Consequently, the reactor vessel is in full compliance with Regulatory Guide 1.43.The Unit 1 steam generator parts which are clad are constructed of SA-508, Grade 3a steel. The Unit 2 steam generator and pressurizer parts which are clad are constructed of SA-533, Grade A, Class 2, and SA-508, Class 2, steels. These materials are made to fine grain practices and all welding is done with low heat input techniques.Regulatory Guide 1.44Control of the Use of Sensitized Stainless Steel
 
DiscussionThe Westinghouse position on Regulatory Guide 1.44 (5/73) is discussed in part in Section5.2.3.4
.Westinghouse compliance with the separate positions of the guide are as follows:The use of processing, packaging and shipping controls, and preoperational cleaning to preclude adverse effects of exposure to contaminants on all stainless steel materials are in accordance with Regulatory Position C.1.
CPNPP/FSAR1A(N)-16Amendment No. 104Austenitic stainless steel starting materials are utilized in the final heat treated conditions required by the respective ASME Code, Section II, material specification for the particular type or grade of alloy in accordance with Regulatory Position C.2.The Westinghouse position concerning material inspection programs and Regulatory PositionC.3 is discussed in Section 5.2.3.4
.Westinghouse meets the intent of Regulatory Position C.4 in the manner discussed in detail in Section 5.2.3.4. However, the guide's exception (a) to Regulatory Position C.4 established 200°F as the upper limit for dissolved oxygen concentration above 0.1 parts per million (ppm).
This temperature limit should be increased to 250°F which provides for much quicker reduction of the oxygen concentration by reaction with hydrazine. Startup operations provide for adding hydrazine after the temperature is at about 225°F. Oxygen scavenging at this temperature is rapid and complete; below 200°F, considerable time can be encountered in the oxygen removal operations.The Westinghouse position is that the significant chemistry control associated with the above limits on oxygen is the control of chloride and fluoride ion concentrations at less than 0.15 ppm each at all times. The guide's exception (b) to Regulatory Position C.4 is covered in the discussion of delta ferrite in Section 5.2.3.4
.Westinghouse complies with Regulatory Position C.5 in the manner discussed in Section 5.2.3.4
. The guide's exception (a) to Regulatory Position C.5 is covered in Section 5.2.3.4 on delta ferrite.Westinghouse complies with Regulatory Position C.6 in the manner discussed in Section 5.2.3.4
.Also refer to Appendix 1A(B)
.Regulatory Guide 1.45 Reactor Coolant Pressure Boundary Leakage Detection Systems Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.46Protection Against Pipe Whip Inside Containment
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.47Bypassed and Inoperable Status Indication for Nuclear Power Plant Safety Systems CPNPP/FSAR1A(N)-17Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.48Design Limits and Loading Combinations for Seismic Category I Fluid System Components DiscussionWestinghouse supplied components are designed using the stress limits and loading combinations presented in Sections 3.9N.1 and 5.2 for Code Class 1 components and in Section3.9N.3 for Code Class 2 and 3 components. The conservatism in these limits and the associated ASME design requirements precludes any component structural failure.The operability of active Code Class 1, 2 and 3 valves and active Code Class 2 and 3 pumps (there are no active Class 1 pumps) will be verified by methods detailed in Sections 3.9N.1 and 5.2 for Code Class 1 components and in Section 3.9N.3 for Code Class 2 and 3 components.The use of the above stated methods provides an acceptable alternate method to meeting the guidance of this regulatory guide dated May 1973.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.49Power Levels of Nuclear Power Plants
 
DiscussionThe CPNPP meets the recommendations of Revision 1 (12/73) of Regulatory Guide 1.49 since the projected initial power level is less than 3800 megawatts thermal (MWt) and analyses and evaluation are made at assumed core power levels less than the levels in this regulatory guide.Regulatory Guide 1.50Control of Preheat Temperature for Welding of Low-Alloy Steel DiscussionWestinghouse considers that this regulatory guide (dated May 1973) applies to ASME Code, Section III, Class 1 components.The Westinghouse practice for Class 1 components is in agreement with the recommendations of Regulatory Guide 1.50 except for Regulatory Positions C.1.b and C.1.c. For Class 2 and 3 components, Westinghouse does not apply any of Regulatory Guide 1.50 recommendations.In the case of Regulatory Position C.1.b, the welding procedures are qualified within the preheat temperature ranges required by Section IX of the ASME Code. Westinghouse experience has shown excellent quality of welds using the ASME qualification procedures.
CPNPP/FSAR1A(N)-18Amendment No. 104In the case of Regulatory Position C.2, the Westinghouse position is that this guide recommendation is both unnecessary and impractical. Code acceptance low-alloy steel welds have been and are being made under present Westinghouse specified procedures. It is not necessary to maintain the preheat temperature until a post-weld treatment has been performed as recommended by this regulatory guide, in the case of large components. In the case of reactor vessel main structural welds, the practice of maintaining preheat until the intermediate or final post-weld heat treatment has been followed by Westinghouse. In either case, the welds have shown high integrity. Westinghouse practices are documented in Reference [8], which has been accepted by the NRC.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.51Inservice Inspection of ASME Code Class 2 and 3 Nuclear Power Plant Components DiscussionThis regulatory guide was withdrawn March 22, 1976.
Regulatory Guide 1.52Design, Testing, and Maintenance Criteria for Engineered-Safety- Feature Atmosphere Cleanup System Air Filtration and Adsorption Units of Light-Water-Cooled Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.53 Application of the Single-Failure Criterion to Nuclear Power Plant Protection Systems DiscussionWestinghouse furnished systems meet the recomm endations of this regulatory guide (dated June 1973) in accordance with the comments of Section 7.1.2.7
.Also refer to Appendix 1A(B)
.Regulatory Guide 1.54Quality Assurance Requirements for Protective Coatings Applied to Water-Cooled Nuclear Power Plants DiscussionFor the CPNPP, Westinghouse employs process specifications and the Westinghouse Quality Assurance Program, including quality assurance surveillance and auditing, to provide adequate confidence that coating work within Westinghouse scope will perform satisfactorily in service.
CPNPP/FSAR1A(N)-19Amendment No. 104This regulatory guide (dated June 1973) recognizes ANSI N101.4-1972. Westinghouse uses alternate methods which have employed process specifications for protective coatings for several years. The Westinghouse process specifications cover the application of paint systems to structures and components in the reactor Containment which may come in contact with the fission product removal and/or Containment cooling spray. Regulatory Guide 1.54 provides that equipment covered with fabricated metal insulation does not require protective coatings, and thus, may not require the use of this Westinghouse process specification, e.g., steam generators.
Applicable coating requirements are included in procurement orders.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.55Concrete Placement in Category I Structures
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.56Maintenance of Water Purity in Boiling Water Reactors
 
DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.57Design Limits and Loading Combinations for Metal Primary Reactor Containment System Components Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.58Qualification of Nuclear Power Plant Inspection, Examination, and Testing Personnel DiscussionFor work within Westinghouse scope performed for the CPNPP, before January 1, 1975, the qualification of inspection, examination, and testing personnel was controlled by standard industry practice with the exception of nondestructive examination personnel, who were qualified in accordance with the requirements of SNT-TC-1A. The qualification of inspection, examination, and testing personnel was accomplished locally by Westinghouse suppliers through on-the-job
 
training.
CPNPP/FSAR1A(N)-20Amendment No. 104For activities initiated on the CPNPP after January 1, 1975, Westinghouse follows the guidance of this regulatory guide (dated August 1973) as defined in Reference [5] and as described below.This guide recognizes ANSI N45.2.6-1973. Westinghouse policies and procedures for qualification of personnel engaged in inspection, examination and testing activities follow the guidance of this standard. Westinghouse uses demonstrated capability of performing the assigned tasks to predetermine standards or levels of proficiency as the primary basis for evaluating and certifying the personnel as an acceptable alternative to the specific years of education/experience.Westinghouse applies the guidance of this standard to personnel who perform inspection, examination and testing activities including surveillance of these activities for safety-related equipment, materials and services in the Nuclear Energy Systems Division and at outside suppliers.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.59Design Basis Floods for Nuclear Power Plants
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.60Design Response Spectra for Seismic Design of Nuclear Power Plants DiscussionThe design response spectra of Revision 1 (12/73) of Regulatory Guide 1.60 are acceptable to Westinghouse as long as the damping values discussed below under Regulatory Guide 1.61 are acceptable.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.61Damping Values for Seismic Design of Nuclear Power Plants DiscussionThe damping values listed in Regulatory Guide 1.61 (dated October 1973) are acceptable to Westinghouse with the single exception of the large piping systems faulted condition value of 3percent critical. Higher damping values when justified by documented test data have been provided for in Regulatory Position C.2. A conserva tive value of 4 percent critical has therefore been justified by testing for the Westinghouse reactor coolant loop configuration in Reference [9] and has been approved by the NRC Staff.
CPNPP/FSAR1A(N)-21Amendment No. 104For piping systems analyzed by the response spectrum method, ASME Code Case N-411 damping values may be used in lieu of the damping values in this Regulatory Guide.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.62 Manual Initiation of Protective Actions
 
DiscussionWestinghouse furnished systems meet the recomm endations of this regulatory guide (dated October 1973) in accordance with the comments of Section 7.3.2.2.7
.Regulatory Guide 1.63Electric Penetration Assemblies in Containment Structures for Light- Water-Cooled Nuclear Power Plants DiscussionThe Reg. guide as well as IEEE Std. 317 are not applicable to the NSSS Scope of Supply.
Regulatory Guide 1.64Quality Assurance Requirements for the Design of Nuclear Power Plants DiscussionThe Westinghouse commitment, as described in Chapter 17 of the CPNPP Preliminary Safety Analysis Report, was designed to meet the requirements of 10CFR50, Appendix B, which is an acceptable method for following the guidance of ANSI N45.2. For activity initiated by Westinghouse after January 1, 1975 for the CPNPP, the control measures described in Reference [5] are applicable. Reference [5] commits Westinghouse to meet the requirements of 10CFR50, Appendix B and follow the guidance of the NRC. Specifically, Westinghouse follows the guidance of ANSI/ASME NQA-1 for Unit 1 and ANSI N45.2.11-1974 for Unit 2, which is recognized by this standard in the design work for safety-related NSSS equipment. Westinghouse utilizes different but equivalent fo rms than those shown as samples in the standard. In regard to design verification, it is performed by individuals or groups other than those who performed the original design. However, in exceptional cases, when the designer's supervisor maintains a detailed expertise on the design, the supervisor will perform the design
 
verification function, and document the reason for this action.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.65Materials and Inspections for Reactor Vessel Closure Studs CPNPP/FSAR1A(N)-22Amendment No. 104 DiscussionWestinghouse is in agreement with Regulatory Guide 1.65 (dated 10/73) except for material and tensile strength guidelines.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, SectionIII, Summer
 
1973 Addenda and 10CFR50, Appendix G (July 17, 1973, Paragraph IV.A.4). These toughness requirements assure 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 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 requirements of 10CFR50, Appendix G (July 17, 1973, ParagraphI.C), although higher strength level bolting materials are permitted by the code. 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 environments stressed to 75 percent of the yield strength (given in Reference 2 of the 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.The ASME Code requirement for toughness for reactor vessel bolting has precluded the guide's additional recommendation for tensile strength limitation, since to obtain the required toughness levels, the tensile strength levels are reduced. Prior to 1972, the ASME Code required a 35 ft-lb toughness level which provided maximum tensile strength levels ranging from approximately 155 to 178 kpsi (Westinghouse review of limited data - 25 heats). After publication of the Summer 1973 Addenda to the ASME Code and 10CFR50, Appendix G, wherein the toughness requirements were modified to 45 ft-lb with 25 mils lateral expansion, all bolt material data reviewed on Westinghouse plants showed tensile strengths of less than 170 kpsi.Additional protection against the possibility of incurring corrosion effects is assured by:a.Decrease in level of tensile strength comparable with the requirement of fracture toughness as described above.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 program.c.Design of the reactor vessel studs, nuts, and washers, providing protection against corrosion by allowing them to be com pletely 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 flange are sealed CPNPP/FSAR1A(N)-23Amendment No. 104with special plugs before removing the reactor closure. Thus, the bolting materials and stud holes are never exposed to the borated refueling cavity water.Regulatory Guide 1.66Nondestructive Examination of Tubular Products DiscussionThe guide (dated October 1973) states that "Nondestructive examination applied to tubular products used for components of the reactor coolant pressure boundary and other safety-related systems...should be capable of detecting unacceptable defects regardless of defect shape, orientation, or location in the product."  To accomplish this, the regulatory guide suggests the
 
addition of angle beam scanning in two axial directions.Westinghouse considers the regulatory position regarding angle beam scanning in the axial direction as technically unnecessary since any flaws which might be developed by the processes employed in tubular product manufacture are invariably oriented in the axial direction, and the probability of developing metallurgical flaws of other than axial orientation is virtually nil. Flaws of transverse or circumferential orientatio n which might be developed would normally be mechanically induced surface defects which should be detected by surface nondestructive examination procedures.The primary pressure boundary and safety-related tubular products within the Westinghouse scope of supply and the nondestructive examinations applied are tabulated in Table 1A(N)-1
. In all cases the volumetric nondestructive examination is designed to detect the flaws inherent to
 
the manufacturing process or processes employed
. In those few cases where compliance with the guide is not indicated, Westinghouse believ es that the nondestructive examinations performed in the normal procurement of the tubular products covered by the guide achieve the same purpose as the guide.
The hardwater items identified in Table 1A(N)-1 as not being in compliance with Regulatory Guide 1.66 are constructed in accordance with the applicable ASME Code, Section III rules as a minimum.However, the ASME Code, Section III rules do not require the suggested provisions of the regulatory guide for tubular products which do not fall within the size range of 2.5 to 6 inches, outside diameter.Tubular products for core support structures function only as structural beams. For the CPNPP these tubular products were procured prior to the effectivity of Section NG of the ASME Code but were purchased using the guidelines of draft Section NG-2000.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.67Installation of Overpressure Protection Devices CPNPP/FSAR1A(N)-24Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.68Initial Test Programs for Water-Cooled Reactor Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.68.1Preoperational and Initial Startup Testing of Feedwater and Condensate Systems for Boiling Water Reactor Power Plants DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.68.2Initial Startup Test Program to Demonstrate Remote Shutdown Capability for Water-Cooled Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.69Concrete Radiation Shields for Nuclear Power Plants
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.70Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.71Welder Qualification for Areas of Limited Accessibility CPNPP/FSAR1A(N)-25Amendment No. 104 DiscussionWestinghouse practice does not require qualification or requalification of welders for areas of limited accessibility as described by the guide (dated December 1973) and has provided welds of high quality.Westinghouse believes that limited accessibility qualification or requalification, which are additional to ASME Code, Section III and IX requirements, is an unduly restrictive requirement for shop fabrication, where the welders' 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 application, the type of qualification should be considered on a case-by-case basis due to the great variety of circumstances encountered.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.72Spray Pond Plastic Piping
 
DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.73Qualification Tests of Electric Valve Operators Installed Inside the Containment of Nuclear Power PlantsDiscussionFor safety-related motor operated valves inside Containment, Westinghouse complies with the guidance of Regulatory Guide 1.73 (dated January 1974 with the exception that stem mounted limit switches are tested separately to the requirements of IEEE Standard 382-1972.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.74Quality Assurance Terms and Definitions DiscussionThis regulatory guide (dated February 1974) recognizes ANSI N45.2.10- 1973. For the CPNPP, Westinghouse follows the guidance of this standard, utilizing consistent terms and definitions in the description of the Westinghouse Quality Assurance Program.
Also refer to Appendix 1A(B)
.
CPNPP/FSAR1A(N)-26Amendment No. 104Regulatory Guide 1.75Physical Independence of Electric Systems DiscussionWestinghouse furnished systems meet the recommendations of Revision 1 (1/75) of this regulatory guide in accordance with the comments of Section 7.1.2.2.1 and Reference [10].
Also refer to Appendix 1A(B)
.Regulatory Guide 1.76Design Basis Tornado for Nuclear Power Plants
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.77Assumptions Used for Evaluating a Control Rod Ejection Accident for Pressurized Water ReactorsDiscussion Refer to Appendix 1A(B)
.Regulatory Guide 1.78Assumptions for Evaluating the Habitability of a Nuclear Power Plant Control Room During a Postulated Hazardous Chemical Release Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.79Preoperational Testing of Emergency Core Cooling Systems for Pressurized Water Reactors Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.80Preoperational Testing of Instrument Air Systems CPNPP/FSAR1A(N)-27Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.81Shared Emergency and Shutdown Electric Systems for Multi-Unit Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.82Sumps for Emergency Core Cooling and Containment Spray Systems Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.83Inservice Inspection of Pressurized Water Reactor Steam Generator Tubes DiscussionWestinghouse steam generators are designed to permit access to tubes for inspection and/or plugging. The inservice inspection program and comp liance with Revision 1 (7/75) of this guide is discussed in Section 5.4.2.2
.Also refer to Appendix 1A(B)
.Regulatory Guide 1.84Code Case Acceptability - ASME Section III Design and Fabrication DiscussionRefer to the discussion of Regulatory Guide 1.85 and Appendix 1A(B)
.Regulatory Guide 1.85Code Case Acceptability - ASME Section III Materials DiscussionThe CPNPP had its second-round Preliminary Safety Analysis Report questions issued after the July 1, 1974 date on which the or iginal versions of Regulatory G uides 1.84 and 1.85 were made effective. The major NSSS components that are Code Class 1, 2 or 3 were ordered before Westinghouse instituted procedures to control the use of code cases. The only examples of code CPNPP/FSAR1A(N)-28Amendment No. 104 cases known to have been used that are not authorized by way of Regulatory Guides 1.84 and 1.85 are Code Case 1528 and Code Case 1637. Westinghouse is conducting a testing program to determine fracture toughness properties of the materials allowed by Code Case 1528 and is in the process of obtaining authorization. Authorization has been obtained from the Commission for use of Code Case 1637 in the purchase of tubing for Class 2 and 3 components.
Refer to Appendix 1A(B) for a further discussion of the CPNPP position.Regulatory Guide 1.86Termination of Operating Licenses for Nuclear Reactors
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.87Guidance for Construction of Class 1 Components in Elevated- Temperature Reactors (Supplement to ASME Section III Code Cases 1592, 1593, 1594, 1595, and 1596)
DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.88Collection, Storage, and Maintenance of Nuclear Power Plant Quality Assurance Records DiscussionThis regulatory guide recognizes N45.2.9-1974. For the CPNPP, the Westinghouse Quality Assurance Records Program follows the guidance of this standard. Records are identified, indexed, stored, and protected in a manner consistent with Revision 2 (10/76) of Regulatory Guide 1.88.For active files, Westinghouse maintains duplicate records in separate geographical locations as an alternative to the protective construction provisions of the standard.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.89Qualification of Class 1E Equipment for Nuclear Power Plants DiscussionThe Westinghouse approach to satisfying the guidelines of Regulatory Guide 1.89 (dated November 1974) and IEEE Standard 323-1974 is documented in WCAP 8587, Revision 6-A which has been reviewed and approved by the NRC. However, as supported by the statements CPNPP/FSAR1A(N)-29Amendment No. 104of consideration for 10CFR50.49 (Federal Register, 48FR2731, January 21, 1983), the recommendations of this regulatory guide need not be applied for Class 1E equipment located in a mild environment area.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.90 Inservice Inspection of Prestressed Concrete Containment Structures with Grouted Tendons DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.91Evaluation of Explosions Postulated to Occur on Transportation Routes Near Nuclear Power Plant Sites Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.92Combining Modal Responses and Spatial Components in Seismic Response Analysis DiscussionWestinghouse takes exception to several major positions in this regulatory guide (dated December 1974) as discussed below.1.Combination of closely spaced modesIn Section B.1 it is stated that, "Because of the likelihood that the response of closely spaced modes add directly, the values of the response of these modes should be combined by taking the absolute sum of the maximum values of the response of individual closely spaced modes, as explained in Regulatory Position C.2 of this guide."The regulatory guide cited as its only reference in the closely spaced modes discussion one which did not propose to take the absolute sum of maximum values of the response of individual closely spaced modes. Instead, it has recommended that closely spaced modes be added using a coefficient E which is less than or equal to 1.0 and is a function of the frequency ratio, duration of the earthquake, and damping values. Similar formulas have been proposed by the ASME Dynamic Analysis Task Force which utilize the same Ecoefficient. The formula proposed in Regulatory Guide 1.92 has not been thoroughly discussed in the literature and does not realistically represent the dependence of the response of closely spaced modes on the proximity of frequencies and the modal damping values.
CPNPP/FSAR1A(N)-30Amendment No. 104Westinghouse has presented an alternative approach in Section 3.7(N) which has factored in the E coefficient. This formula is more conservative than the referenced formula, since E is considered to be positive for all closely spaced modes, but is equal to or less conservative than the formula proposed in the regulatory guide.2.Time-history dynamic analysisRegulatory Position C.3 recommends that time-history dynamic analysis be conducted independently for each of the three directions and summed by the square root of the sum of the squares approach.The three orthogonal earthquake components are statistically independent, and more importantly, they occur simultaneously. Furthermore, time-history analysis is most often
 
conducted in order to properly account for eithe r geometrical or material nonlinearities. All systems do not behave linearly in responding to the loading. Consequently, all three components of the input may need to be applied simultaneously, and therefore, simultaneous use of these components should be allowed by the regulatory guide in the time-history analysis.For some systems, independent application of each time-history is justified and the methods given in the regulatory guide are applicable. Simultaneous application, however, must be included as an option.For response spectra analyses, the option should be provided in the regulatory guide for the simultaneous application of the three load components of the earthquake rather than that method specified in the regulatory guide. Currently, the guide recommends independent application of the three components of the earthquake with subsequent combination by the square root of the sum of the squares. Westinghouse is currently preparing computer programs for the analyses of the Reactor Coolant System which will apply the three seismic load components simultaneously. In the seismic analysis, this method gives generally equivalent conservatisms in comparisons to the independent application of the loads and should be permitted by the regulatory guide.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.93Availability of Electric Power Sources Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.94Quality Assurance Requirements for Installation, Inspection, and Testing of Structural Concrete and Structural Steel During the Construction Phase of Nuclear Power Plants CPNPP/FSAR1A(N)-31Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.95Protection of Nuclear Power Plant Control Room Operators Against an Accidental Chlorine ReleaseDiscussion Refer to Appendix 1A(B)
.Regulatory Guide 1.96Design of Main Steam Isolation Valve Leakage Control Systems for Boiling Water Reactor Nuclear Power Plants DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.97Instrumentation for Light-Water-Cooled Nuclear Power Plants to Assess Plant Conditions During and Following an Accident Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.98Assumptions Used for Evaluating the Potential Radiological Consequences of a Radioactive Offgas System Failure in a Boiling Water Reactor DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.99Radiation Embrittlement of Reactor Vessel Materials DiscussionCPNPP complies with Revision 2 (5/88) of this Regulatory Guide as discussed in Section 5.3.2.1
.
CPNPP/FSAR1A(N)-32Amendment No. 104Regulatory Guide 1.100Seismic Qualification of Electric Equipment for Nuclear Power Plants Discussion As discussed in Section 3.10N, the CPNPP NSSS program for seismic qualification of safety-related electrical equipment to the recommendations of Regulatory Guide 1.100 is delineated in References 16 and 17. In summary
, seismic qualification will be demonstrated by the following methods:1.For equipment not subject to high ener gy line break conditions, which has been previously qualified by the single axis sine beat method (after demonstration of no resonant frequency below 33 hertz) as permitted by IEEE Standard 344-1971 "IEEE Guide for Seismic Qualification of Class 1 Electric Equipment for Nuclear Power Generating Stations" and included in the NRC seismic audit and, where required by the staff, the Supplemental Qualification Program, no additional qualification testing is required to demonstrate acceptability to IEEE 344-1975 provided that:a.It can be shown, by separate component testing and/or analysis, that there are no aging mechanisms that could prejudice the previously completed seismic qualification.b.Any design modifications made to the equipment do not significantly affect the seismic characterist ics of the equipment.c.The adequacy of the original seismic test levels can be demonstrated as conservative by plant specific verification.2.For new equipment, or equipment that cannot meet the provisions of item 1 above, seismic qualification will be performed in accordance with IEEE Standard 344-1975, "IEEE Recommended Practices for Seismic Qualification of Class 1E Equipment for Nuclear Power Generating Stations."  The method to be employed (i.e., test and/or analysis) is indicated, for the safety-related equipment in the Westinghouse scope of supply, in Reference 17. Where multifrequency biaxial inputs are employed for testing, the methodology described in Reference 18 will be employed. When flexible equipment size and weight precludes biaxial testing (e.g
., enclosures), single axis testing with justification will be utilized to meet IEEE Standard 344-1975. For rigid equipment (i.e., no resonant frequency below 33 hertz), qualification will be by analysis in accordance with IEEE Standard 344-1975. All Class 1E equipment located in a mild environment area will be seismically qualified as described above and in FSAR Sections 3.10N and 3.10B, except that the additional requirements imposed by IEEE Standard 323- 1974 do not apply. The procurement documents will specify that the effects of aging on seismic qualification be assessed and if there are aging effects, require pre-aging or analysis of aging effects as part of the seismic qualification.Refer to FSAR Section 3.10N for further discussion of Regulatory Guide 1.100.
Also refer to Appendix 1A(B)
.
CPNPP/FSAR1A(N)-33Amendment No. 104Regulatory Guide 1.101Emergency Planning for Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.102Flood Protection for Nuclear Power Plants
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.103Post-Tensioned Prestressing Systems for Concrete Reactor Vessels and Containments DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.104Overhead Crane Handling Systems for Nuclear Power Plants
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.105Instrument Setpoints DiscussionCPNPP complies with the intent of Revision 2 (2/86) of this guide as discussed below.
Westinghouse Standard Technical Specifications provide the margin from the nominal trip setpoint to the allowable value to account for rack drift and calibration when measured during periodic testing. The allowances between the nominal trip setpoint technical specification limit and the safety analysis limit include a statistical combination of the following items:1.the inaccuracies of the instrumentation,2.non-instrument related effects, i.e., process measurement accuracy,3.uncertainties in the calibration of both the transmitter and racks, and CPNPP/FSAR1A(N)-34Amendment No. 1044.Adverse environmental effects on transmitter a ccuracy caused by postulated or limiting postulated events (only for those systems required to mitigate consequences of an accident).Potential transient overshoot is accounted for in the modeling of the event in the safety analyses.Westinghouse chooses setpoints such that the accuracy of the instrumentation is sufficient to meet the assumptions of the safety analyses.The range of the instrumentation is chosen based on the span necessary for the function. Narrow range instrumentation will be used where necessary. Instrumentation will be selected based on expected environmental and accident conditions. The need for qualification testing is evaluated and justified on a case-by-case basis.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 are not supplied.
Also refer to Appendix 1A(B) for further discussion. Regulatory Guide 1.106Thermal Overload Protection for Electric Motors on Motor-Operated Valves Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.107Qualifications for Cement Grouting for Prestressing Tendons in Containment Structures DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.108Periodic Testing of Diesel Generators Used as Onsite Electric Power Systems at Nuclear Power PlantsDiscussion Refer to Appendix 1A(B)
.Regulatory Guide 1.109Calculation of Annual Doses to Man from Routine Releases of Reactor Effluents for the Purpose of Evaluating Compliance with 10CFR Part 50, Appendix I CPNPP/FSAR1A(N)-35Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.110Cost-Benefit Analysis for Radwaste Systems for Light-Water-Cooled Nuclear Power Reactors Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.111Methods for Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Routine Releases from Light-Water-Cooled Reactors Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.112Calculation of Releases of Radioactive Materials in Gaseous and Liquid Effluents from Light-Water-Cooled Power Reactors Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.113Estimating Aquatic Dispersion of Effluents from Accidental and Routine Reactor Releases for the Purpose of Implementing Appendix I Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.114Guidance on Being Operator at the Controls of a Nuclear Power Plant
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.115Protection Against Low-Trajectory Turbine Missiles CPNPP/FSAR1A(N)-36Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.116Quality Assurance Requirements for Installation, Inspection, and Testing of Mechanical Equipment and Systems Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.117Tornado Design Classification Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.118Periodic Testing of Electric Power and Protection Systems
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.119 Surveillance Program for New Fuel Assembly Designs DiscussionThis regulatory guide was withdrawn June 23, 1977.
Regulatory Guide 1.120Fire Protection Guidelines for Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.121Bases for Plugging Degraded PWR Steam Generator Tubes CPNPP/FSAR1A(N)-37Amendment No. 104 Discussion The plugging criteria for the steam generator U-tubes, as specified in the plant Technical Specifications, is based on the more conservative limit required by paragraph IWB-3521.1, Section XI of the ASME Boiler and Pressure Vessel Code, than the plugging criteria derived from the Regulatory Guide 1.121 (dated August, 1976) analysis. Alternate repair criteria which may exceed the plugging limit specified by IWB-3521.1 are defined in the plant Technical Specifications.Regulatory Guide 1.122Development of Floor Design Response Spectra for Seismic Design of Floor-Supported Equipment or Components Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.123Quality Assurance Requirements for Control of Procurement of Items and Services for Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.124Design Limits and Loading Combinations for Class 1 Linear-Type Component Supports DiscussionThe CPNPP NSSS position on Revision 1 (1/78) of this guide is as follows: 1.Paragraph B.1 In the regulatory guide, an increase in bolt allowable stress under emergency and faulted conditions is not permitted. Westinghouse believes that the present ASME Code rules are adequate for bolted connections.It is recognized after extensive experimental work by several researchers that the interaction curve between the shear and tension stress in bolts is more closely represented by an ellipse and not a line. This has been clearly recognized by the ASME.
Code Case 1644-6 specifies stress limits for bolts and represents this tension/shear relationship as a non-linear interaction equation (incorporated into ASME III AppendixXVII via the Winter 77 Addenda) and has a built-in safety factor that ranges between 2 and 3 (depending on whether the bolt load is predominantly tension or shear) based on the actual strength of the bolt as determined by test.  [19]
CPNPP/FSAR1A(N)-38Amendment No. 104Study of three interaction curves of allowable tension and shear stress based on the ASME Code (emergency condition allowables per XVII-2110 and faulted condition allowables per F-1370) and the ultimate tensile and shear strength of bolts indicates that there is adequate safety margin between the emergency and faulted condition allowables and failure of the bolts.  [20]
From this study it is observed that:
a.For the emergency condition, the safety factor (ratio of ultimate strength to allowable stress) varies between a minimum of 1.63 and a maximum of 2.73 depending upon the actual tensile stress/shear (T/S) ratio on the bolt.b.For the faulted condition, the safety factor varies between a minimum of 1.36 to a maximum of 2.29, again depending upon actual T/S ratio on the bolt.The stress limits used for Class 1 component bolting material are those given in ASME III Appendix F-1323.1(b), Pm2.4 Sm or 0.7 S u (whichever is less) using the material properties of Table I-1.3 taken at the appropriate temperature.It is thus reasonable to allow an increase in these limits for the emergency and faulted conditions.Based on the above discussion, for the emergency and faulted conditions, Westinghouse will use allowable bolt stresses specified in Code Case 1644-6, as increased according to the provisions of XVII-2100(a) and F-1370(a), respectively. The increased design limit for the stress range identified in NF-3231.1(a) shall be limited to the smaller of 2 S y or Su unless otherwise justified by shakedown analysis. 2.Paragraphs B.5 and C.8The reduction of allowable stresses to no greater than level B limits (which in reality are design limits since design, level A and level B limits are the same for linear supports) for support structures in those systems with safety related functions occurring during emergency or faulted plant conditions is overly conservative. The primary concern is that the system remains capable of performing its safety function. For active components, this is accomplished through the operability program as discussed in Section 3.9N. In the case of Class 1 piping, maintaining the pipe stresses within level D limits assures that piping geometry is maintained and that required f low is not impeded. The selection of more restrictive stress limits for component supports is not necessary to assure the functional capability of the system.3.Paragraph C.4In the design of component support, member compressive axial loads shall be limited to 0.67 times the critical buckling strength. If, as a result of more detailed evaluation of the supports the member compressive axial loads can be shown to safely exceed 0.67 times the critical buckling strength for the faulted condition, verification of the support functional adequacy will be documented and submitted to the NRC for review. The member CPNPP/FSAR1A(N)-39Amendment No. 104 compressive axial loads will not exceed 0.67 ti mes the critical buckling strength without NRC acceptance. In no case shall the compressive load exceed 0.9 times the critical buckling strength.This regulatory guide states that increases in Level A or B service limits does not apply to limits for bolted connections. The Westinghouse design of component supports restricts the use of bolting material to the following applications:a.Westinghouse design uses bolting predominantly in tension. Oversized holes are generally provided and a mechanism other than the bolts is provided to take any shear loads. Shear or shear & tension interaction occur only in isolated locations;b.Westinghouse bolts are limited to the following material A490, SA-354, SA-325, SA-540.c.The diameters used range between 1/2" and 3".
These limitations on bolt usage are standard in the Westinghouse supports. We will limit tensile loads in the bolts to 0.7 S u, but not to exceed in any case 0.9 S
: y. The allowables are taken at temperature. In those few cases where bolts are used in shear or tension and shear, ASME Code Appendix XVII - 2460 Requirements will apply with an increase factor that is defined in Regulatory Guide 1.124 or in Appendix F-1370. This provides an adequate margin of safety for the Westinghouse design. If future revisions to the bolting criteria in ASME Section III modify the Westinghouse criteria listed above, we will review the criteria at the time.4.Paragraph C.6(a)Westinghouse will interpret this paragraph as follows:  "The stress limits of XVII-2000 of Section III and Regulatory Position 3 increased according to the provisions of XVII-2110(a) of Section III and Regulatory Position 4, should not be exceeded for component supports designed by the linear elastic analysis method." 5.Paragraph C.7(b)Westinghouse will use the provisions of F-1370(d) to determine service level D allowable loads for supports designed by the lead rating method. If future revisions to Appendix F modify this criteria, it will be reviewed further. If the load rating method is used, further details of its implementation will be provided at that time.
Also refer to Appendix 1A(B)
.Regulatory Guide 1.125Physical Models for Design and Operation of Hydraulic Structures and Systems for Nuclear Power Plants CPNPP/FSAR1A(N)-40Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.126An Acceptable Model and Related Statistical Methods for the Analysis of Fuel Densification DiscussionFuel for CPNPP is provided by Westinghouse. The methodology for the analysis of fuel densification used by Westinghouse is described in Reference 12.Regulatory Guide 1.127Inspection of Water-Control Structures Associated with Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.128Installation Design and Installation of Large Lead Storage Batteries for Nuclear Power Plants
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.129Maintenance, Testing, and Replacement of Large Lead Storage Batteries for Nuclear Power PlantsDiscussion Refer to Appendix 1A(B)
.Regulatory Guide 1.130 Service Limits and Loading Combinations for Class 1 Plate- and Shell-Type Component Supports (Revision 1, October, 1978)
CPNPP/FSAR1A(N)-41Amendment No. 104 DiscussionThe Applicant takes the following except ions to this Regulatory Guide:1.Regulatory Guide states in Paragraph B.1:"Allowable design limits for bolted connections are derived on a different basis that varies with the size of the bolt. For this reason, the increases permitted by NF-3224 and F-1323.1(a) of Section III are not directly applicable to bolts and bolted connections."It is the Applicant's position that it is reasonable to allow an increase in the limits for bolted connections for emergency and faulted conditions. Further justification of this position can be found in the discussion of Regulatory Guide 1.124 on Class 1 linear type supports.2.Paragraphs C.2, C.4(a), and C.6(a) of the Regulatory Guide state that the allowable buckling strength should be calculated using a design margin of 2 for flat plates and 3 for shells for normal, upset and emergency conditions.In the design of plate-type supports, member compressive axial loads shall be limited per the requirements of Paragraph C.3 for normal, upset and emergency conditions.3.In Paragraph C.7 of the Regulatory Guide, inclusion of the upset plant condition is unappropriate in the load combination under discussion. The Applicant will not include the upset plant condition in this combination.4.In Paragraphs C.7(a) and B.1 of the Regulatory Guide, the stress limits of F-1370(c) are discussed. The criterion stated in F-1370(c), "...loads should be exceed 0.67 times the critical buckling strength of the support...". In the design of plate-type component supports, member compressive axial loads shall be limited to 0.67 times the critical buckling strength. If, as a result of a more detailed evaluation of the supports the member comp ressive axial loads can be shown to safely exceed 0.67 times the critical buckling for the faulted condition, verification of the support function adequacy will be documented and submitted to the NRC for review. The member compressive axial loads will not exceed 0.67 times the critical buckling strength without NRC acceptance.5.In Paragraph C.7(b) of the Regulatory Guide, the limit based on the test load given in the Regulatory Guide, T.L. x 0.7 S' u/Su, is overly conservative and is inconsistent with ASME Code requirements presented in Appendix F.The Applicant will use the provisions of F-1370(c) to determine service level D allowable loads for supports designed by the load rating method.Regulatory Guide 1.131Qualification Tests of Electric Cables, Field Splices, and Connections for Light-Water-Cooled Nuclear Power Plants CPNPP/FSAR1A(N)-42Amendment No. 104 Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.132Site Investigations for Foundations of Nuclear Power Plants Discussion Refer to Appendix 1A(B)
. Regulatory Guide 1.133 Loose-Part Detection Program for the Primary System of Light-Water- Cooled Reactors Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.134 Medical Evaluation of Nuclear Power Plant Personnel Requiring Operator Licenses Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.135Normal Water Level and Discharge at Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.136Material for Concrete Containments
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.137Fuel-Oil Systems for Standby Diesel Generators CPNPP/FSAR1A(N)-43Amendment No. 104 Discussion Refer to Appendix 1A(B)
. Regulatory Guide 1.138Laboratory Investigations of Soils for Engineering Analysis and Design of Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.139Guidance for Residual Heat Removal DiscussionIn lieu of Regulatory Guide 1.139, CPNPP addressed Branch Technical Position RSB 5-1 as provided in FSAR Chapter 5
.Regulatory Guide 1.140Design, Testing, and Maintenance Criteria for Normal Ventilation Exhaust System Air Filtration and Adsorption Units of Light-Water- Cooled Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.141Containment Isolation Provisions for Fluid Systems
 
Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.142Safety-Related Concrete Structures for Nuclear Power Plants (Other Than Reactor Vessels and Containments)
Discussion Refer to Appendix 1A(B)
.
CPNPP/FSAR1A(N)-44Amendment No. 104Regulatory Guide 1.143Design Guidance for Radioactive Waste Management Systems, Structures, and Components Installed in Light-Water-Cooled Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.144Auditing of Quality Assurance Programs for Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.145 Atmospheric Dispersion Models for Potential Accident Consequence Assessments at Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.146Qualification of Quality Assurance Program Audit Personnel for Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.148Functional Specification for Active Valve Assemblies in Systems Important to Safety in Nuclear Power Plants Discussion Refer to Appendix 1A(B)
.Regulatory Guide 1.150 Ultrasonic Testing of Reactor Vessel Welds During Preservice and Inservice Examinations CPNPP/FSAR1A(N)-45Amendment No. 104 Discussion The CPNPP position on Revision 1 (2/83) of this guide is as follows:Preservice InspectionA partial R.G. 1.150 inspection was performed on Units 1 and 2 reactor vessels in accordance with Reference [21].Inservice Inspection
 
CPNPP complies with revision 1 of this regulatory guide.Regulatory Guide 1.155Station Blackout Discussion Refer to Appendix 1A(B)REFERENCES 1.Fletcher, W. D., Bell, M. J. and Picone, L. F., "Post LOCA Hydrogen Generation in PWR Containment", Nucl. Technol. 10, 420-427, 1971.2.Zittel, H. E. and Row, T. H., "Radiation and Thermal Stability of Spray Solutions", Nucl. Technol. 10, 436-443, 1971.3.Allen, A. O., "The Radiation Chemistry of Water and Aqueous Solutions", Princeton, N. J., Van Nostrand, 1961.4."Reactor Coolant Pump Integrity in LOCA", WCAP-8163, September 1973.5."Westinghouse Nuclear Energy Systems Division Quality Assurance Plan," WCAP-8370, Revision 8A and subsequent revisions.6.Enrietto, J. F., "Control of Delta Ferrite in Austenitic Stainless Steel Weldments," WCAP-8324-A, June 1975.7.Enrietto, J. F., "Delta Ferrite in Production Austenitic Stainless Steel Weldments," WCAP-8693, January 1976.8.Caplan, J. S., "The Application of Preheat Temperatures after Welding Pressure Vessel Steels," WCAP-8577, February 1976.9."Damping Values of Nuclear Power Plant Components," WCAP-7921- AR, May 1974.
10.Letter NS-CE-604, dated March 31, 1975, C. Eicheldinger (Westinghouse) to the Secretary of the Nuclear Regulatory Commission.
CPNPP/FSAR1A(N)-46Amendment No. 10411."Environmental Qualification of Westinghouse Class 1E Equipment," WCAP-8587, October 1975.12.Hellman, J. M. (Ed.), "Fuel Densification Experimental Results and Model for Reactor Operation," WCAP-8218-P-A (Proprietary) and WCAP-8219-A (Non-Proprietary), March 1975.13.DELETED14.Letter NS-CE-784, dated September 22, 1975, C. Eicheldinger (Westinghouse) to the Secretary of the Nuclear Regulatory Commission.15.Letter NS-CE-1157 dated August 13, 1976, C. Eicheldinger (Westinghouse) to the Secretary of the Nuclear Regulatory Commission.16.Butterworth, G. and Miller, R. B., "Methodology for Qualifying Westinghouse WRD Supplied NSSS Safety-Related Electrical Equipment," WCAP-8587, Revision 2, February1979.17."Equipment Qualification Data Packages," WCAP-8587, Supplement 1, November, 1978.18.Jarecki, S. J., "General Method of Developing Multifrequency Biaxial Test Inputs for Bistables," WCAP-8624 (Proprietary), September 1975 and WCAP-8695 (Non-Proprietary), August 1975. 19.Fisher and Struik, Guide to the Design Criteria of Bolted & Riveted Joints, John Wiley &
Sons, 1974, p. 54. 20.Chesson, E. Jr. Faustino, N. L., Munse, W. H., High Strength Bolts Subjected to Tension and Shear, Journal of the Structural Division, Proceedings of the American Society of Civil Engineer, October 1965, pp. 155-180.21.Letter TXX-3632, dated March 1, 1983, H. C. Schmidt to B. J. Youngblood, NRC Licensing Branch No. 1.
CPNPP/FSARAmendment No. 104TABLE 1A(N)-1TUBULAR PRODUCTS WITHIN WESTINGHOUSE SCOPE RELATED TO REGULATORY GUIDE 1.66Westinghouse ApplicationTubular Product FormUT(a)a)UT - Ultrasonic ET - Eddy current
 
RT - RadiographicPR - Dye penetrant ET(a)RT(a)PT(a)Complies with Regulatory Guide 1.66Circumf. AxialSteam generator tubingSeamless tubeX(b),(c)b)X indicates that the tests are performed.c)Two directions.XYes(d)d)Unit 2 only.Pressurizer heater tubeSeamless tubeX(c)XO.D.YesHeat exchanger tubingWelded tubePart.XO.D.YesVent pipe monitor tubeSeamless tubeX(c)XO.D.YesInstrument tubingSeamless tubeX(c)O. D. endsNo (e)e)These items are outside the range of O.D. sizes covered by those sections of the ASME Code, Section III, which incorporate th e ultrasonic testing provisions of the guide.Instrument nozzlesBarX(c)XO.D.YesCRDM housingsBarX(c)XO.D., I.D.YesAdaptor flangeBarX(c)XO.D., I.D.YesReactor coolant pipe wroughtExtrusionsX(c)WeldsO.D., I.D.No (e)Surge line pipe wroughtExtrusionsX(c)WeldsO.D., I.D.No (e)
CPNPP/FSAR1A(B)-1Amendment No. 107APPENDIX 1A(B) - DISCUSSION OF REGULATORY GUIDES This appendix discusses the Comanche Peak Nuclear Power Plant (CPNPP) positions on, and compliance with, Division 1 regulatory guides as they apply to the balance of plant design and construction as well as start-up and operations.
Appendix 1A(N) is provided separately for the NSSS related information.Identification of specific issues of regulatory guides are provided in the discussions where appropriate.Regulatory Guide 1.1Net Positive Suction Head for Emergency Core Cooling and Containment Heat Removal System PumpsDiscussionThe CPNPP Containment Spray System design complies with the requirements of Safety Guide1 (11/2/70) except as follows:In the calculation of the net positive suction head (NPSH) for containment spray pumps it is assumed that the containment pressure is equal to the vapor pressure of the sump water.
The above assumption is conservative and consistent with the intent of the regulatory guide.
Also refer to Appendix 1A(N) and Section 6.2.2.3.4 for further discussion.Regulatory Guide 1.2Thermal Shock to Reactor Pressure Vessels Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.3Assumptions Used for Evaluating the Potential Radiological Consequences of a Loss of Coolant Accident for Boiling Water Reactors DiscussionThis regulatory guide is not applicable to the CPNPP which has pressurized water reactor steam supply systems.Regulatory Guide 1.4Assumptions Used for Evaluating the Potential Radiological Consequences of a Loss of Coolant Accident for Pressurized Water Reactors.
CPNPP/FSAR1A(B)-2Amendment No. 107 DiscussionThe analysis of the radiological consequences of the loss-of-coolant accident presented in Section 15.6.5 follows the guidance provided in Regulatory Guide 1.195 instead of Regulatory Guide 1.4.Regulatory Guide 1.5Assumptions Used for Evaluating Potential Radiological Consequences of a Steam Line Break Accident for Boiling Water Reactors.
DiscussionThis regulatory guide is not applicable to the CPNPP which has pressurized water reactor steam supply systems.Regulatory Guide 1.6Independence Between Redundant Standby (Ons ite) Power Sources and Between Their Distribution Systems DiscussionThe CPNPP design complies with the requirements of Safety Guide 6 (3/10/71). For details see Section 8.3
.Regulatory Guide 1.7 Control of Combustible Gas Concentrations in Containment Following a Loss of Coolant AccidentDiscussionBased on a revision to 10CFR50.44, Regulatory Guide 1.7 no longer applies to CPNPP. See Section 6.2.5
.Regulatory Guide 1.8Personnel Selection and Training
 
DiscussionMinimum qualifications of unit staffs, with the exce ption of licensed Senior Reactor Operators and Reactor Operators, will be in accordance with Regulatory Guide 1.8, Revision 2. Minimum qualifications for licensed Senior Reactor Operators and Reactor Operators will be in accordance with Regulatory Guide 1.8, Revision 3.The training requirements of Regulatory Guide 1.8, Revision 2 have been superseded by the provisions of 10CFR parts 50 and 55.
CPNPP/FSAR1A(B)-3Amendment No. 107Regulatory Guide 1.9Selection of diesel Generator Set Capacity for Standby Power Supplies DiscussionThe CPNPP Diesel generator sets comply with the requirements of Safety Guide 9 (3/10/71) with the following comment:The voltage may dip below 75 percent of nominal voltage when the diesel generator breaker closes and energizes the two 2000/2666 kVA, 6.9 kV/480 V unit substation transformers supplied from each diesel generator. The dip is due to transformer magnetizing inrush current which exists for two to three cycles. The diesel generator sets are designed to recover to 80 percent of nominal voltage within 10 cycles for this transient. The effect on the first load groups (see Tables8.3-1 and 8.3-2) therefore would be a maximum possible delay in motor starting of 12-13cycles after closure of the diesel generator circuit breaker. However, the objective of the first load group and subsequent load groups is not affected. For details see Section 8.3
.Regulatory Guide 1.10Mechanical (Cadweld) Splices in Reinforcing Bars of Category I Concrete Structures
 
DiscussionTesting and sampling of Mechanical (Cadweld) Splices in Reinforcing Bars of the CPNPP Concrete Containment Structure complies with the requirements of Revision 1 (1/2/73) of this regulatory guide. For other seismic Category I concrete structures, the testing and sampling of Mechanical (Cadweld) splices complies with the requirements of this guide except that the location of all splices are not recorded and shown in as-built drawings.
Also refer to Section 3.8
.Regulatory Guide 1.11Instrument Lines Penetrating Primary Reactor Containment DiscussionThe CPNPP instrument lines penetrating primary reactor containment comply with the requirements of Safety Guide 11 (3/10/71), as described by Section 7.3.1.1.2 and 6.2.4.1.4
.Also refer to Appendix 1A(N)
.Regulatory Guide 1.12Instrumentation for Earthquakes CPNPP/FSAR1A(B)-4Amendment No. 107 DiscussionThe installation of instrumentation for earthquakes in the CPNPP plant meets the intent of Revision 1 (4/74) of this regulatory guide with respect to the ability to determine exceedance of the OBE in a timely manner. Seismic instrumentation includes only the free-field triaxial accelerometer installed in the Yard. Determination of OBE exceedance will be based on the methods of ANSI/ANS-2.10-2003, "Criteria for the Handling and Initial Evaluation of Records
 
from Nuclear Power Plant Seismic Instrumentation."
Also refer to Section 3.7B.4
.Regulatory Guide 1.13Spent Fuel Storage Facility Design Basis
 
DiscussionThe design of the CPNPP spent fuel storage facility complies with Revision 1 (12/75) of this regulatory guide except that the air filtration system is not actuated by a high radiation level
 
alarm. Instead the normal plant exhaust filtrat ion system operates continuously. Refer to Sections 3.5
, 3.8.4, 9.1.2, 9.1.3, 9.1.4 and 9.4.2 for details.Regulatory Guide 1.14 Reactor Coolant Pump Flywheel Integrity Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.15Testing of Reinforcing Bars for Category I Concrete Structures
 
Discussion The testing of reinforcing bars for CPNPP Catego ry I concrete structures complies with the requirements of Revision 1 (12/28/72) of this regulatory guide.
Also refer to Section 3.8
.Regulatory Guide 1.16Reporting of Operating Information - Appendix A Technical Specifications DiscussionThis regulatory guide was withdrawn on August 11, 2009.
CPNPP/FSAR1A(B)-5Amendment No. 107Regulatory Guide 1.17Protection of Nuclear Power Plants Against Industrial Sabotage DiscussionRegulatory Guide 1.17 endorses the requirements and recommendations of ANSI N18.17-1973. This criteria does not reflect current regulations or industry standards and has been superseded by more recent guidelines. CPNPP takes ex ception to Regulatory Guide 1.17 and ANSI N18.17-1973 and instead implements a security program in accordance with the current applicable regulations and guidelines identified in FSAR section 13.6
. Regulatory Guide 1.18Structural Acceptance Test for Concrete Primary Reactor Containments (Revision 1, December28, 1972)
DiscussionThe structural acceptance test for the CPNPP Concrete Containments are in accordance with paragraph CC-6000 of the ASME B&PV Code, Section III, Division 2, 1980 Edition with Summer 1980 Addenda (as applicable to non-prototype containments). As such, this test is in conformance with Revision 1 of this regulatory guide except as follows:Radial deflections of the containment walls are measured along four azimuths only.Vertical deflections along one azimuth are measured at two equally spaced intermediate points between the dome apex and the springline and along four azimuths at the dome springline. Vertical deflection is also measured at the dome apex.Only radial deflections at 12 points around th e largest opening (the equipment hatch) are measured. In addition, the increase in diameter of the opening is measured in two mutually
 
perpendicular directions.
See Subsection 3.8.1.7.1 for description of the test.Regulatory Guide 1.19Nondestructive Examination of Primary Containment Liner Welds
 
DiscussionThe requirements for nondestructive examination of the CPNPP containment liner welds are in conformance with the intent of Revision 1 (08/11/72) of this regulatory guide by use of ASME-ACI359 Code applicable to this type of structure and the alternate requirements as discussed in Sections 3.8.1 and 3.8.2. Acceptance criteria are those provided in Subsection3.8.1.6.5
.
CPNPP/FSAR1A(B)-6Amendment No. 107Regulatory Guide 1.20Comprehensive Vibration Assessment Program for Reactor Internals During Preoperational and Initial Startup Testing Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.21Measuring, Evaluating, and Reporting Radioactivity in Solid Wastes and Releases of Radioactive Materials in Liquid and Gaseous Effluents from Light-Water-Cooled Nuclear Power Plants DiscussionMeasuring, evaluating and reporting of radioactive materials released from CPNPP will meet the recommendations of Revision 1 (6/74) of this regulatory guide.
Also refer to Section 11.5
.Regulatory Guide 1.22Periodic Testing of Protection System Actuation Functions
 
Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.23Onsite Meteorological Programs Discussion The meteorological monitoring program at CPNPP complies with the requirements and those applicable recommendations of the Second Proposed Revision 1 to Regulatory Guide 1.23 (April, 1986) as discussed in Section 2.3. Refer to the CPNPP Offsite Dose Calculation Manual (ODCM), Section I, 4.3.3.6 and Bases 3/4.3.3.6 for an exception. Refer to Section 2.3 for a description of the design and siting of the primary meteorological tower. The quality assurance program for meteorological monitoring is identified in FSAR Table 17A-1 and Section 17.2
.Regulatory Guide 1.24Assumptions Used for Evaluating the Potential Radiological Consequences of a Pressurized Water Reactor Radioactive Gas Storage Tank Failure CPNPP/FSAR1A(B)-7Amendment No. 107 DiscussionThe analysis of the radiological consequences of the radioactive gas storage tank failure accident presented in Section 15.7.1 complies with the requirements of Safety Guide 24 (3/23/72) except that only gamma radiation contribution is taken into account in the determination of whole body exposures and the dose calculation methodology is consistent with Regulatory Guide 1.195.Regulatory Guide 1.25Assumptions 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 DiscussionThe analysis of the radiological consequences of the fuel handling accident presented in Section 15.7.4 follows the guidance provided in Regulatory Guide 1.195 instead of that in Regulatory Guide 1.25.
Regulatory Guide 1.26Quality Group Classifications and Standards for Water-, Steam-, and Radioactive-Waste-Containing Components of Nuclear Power Plants Discussion The CPNPP quality group classification described in Section 3.2.2 is generally in accordance with ANSI N18.2, Nuclear Safety Criteria for the Design of Stationary Pressurized Water Reactor Plants, 1973, which is an alternate acceptable method of meeting the intent of Revision 3 (2/76) of this regulatory guide. Deviations are described in Section 3.2.2
.Also refer to Appendix 1A(N)
.Regulatory Guide 1.27Ultimate Heat Sink for Nuclear Power Plants DiscussionThe CPNPP ultimate heat sink meets the requirements of Revision 2 (January 1976) of the Regulatory Guide 1.27 as described in Sections 2.3.1.2.10
, 2.4.11.5, 2.4.11.6 and 9.2.5. Regulatory Guide 1.28Quality Assurance Program Requirements (Design and Construction)
CPNPP/FSAR1A(B)-8Amendment No. 107 Discussion The quality assurance program (design and co nstruction) for CPNPP complies with the requirements of Safety Guide 28 (6/7/72) except as stated in Appendix 1A(N). Revisions 1 (3/78) and 2 (2/79) of this guide are not addressed.
Also refer to Sections 17.1 and 17.2Regulatory Guide 1.29 Seismic Design Classification
 
DiscussionThe seismic Category I classifications of CPNPP structures, systems and components conforms to Revision 2 (2/76) of this regulatory guide.
Also refer to Appendix 1A(N) and Sections 3.1
, 3.2 and 13.5.Regulatory Guide 1.30Quality Assurance Requirements for the Installation, Inspection, and Testing of Instrumentation and Electric Equipment DiscussionSafety Guide 30 (8/11/72) is applicable to the installation, inspection, and testing of instrumentation and electric equipment at CPNPP. The quality assurance methods for operations phase activities will comply with the applicable guidance contained in this regulatory guide. The application of the requirements of ANSI N45.2.4 - 1972, as endorsed by this regulatory guide, will be in accordance with the guidance provided in ANSI N18.7 - 1976.Also refer to ANSI/NCSL Z540-1-1994 "American National Standard for Calibration Laboratories and Measuring and Test Equipment General Requirements" for M&TE and reference standards traceability.
Also refer to Appendix 1A(N) and to Sections 17.1 and 17.2.Regulatory Guide 1.31Control of Ferrite Content in Stainless Steel Weld Metal DiscussionThe CPNPP design complies with the recommendations of Revision 3 (4/78) of this regulatory guide except as follows:1.The acceptable alternative methods of FSAR Subsection 6.1B.1.1.3 are used.
CPNPP/FSAR1A(B)-9Amendment No. 1072.The recommendations of Revision 1 (6/73) or Revision 2 (5/77) of this regulatory guide are used.3.The exception described in Subsection 6.1B.1.1.4
.Also refer to Appendix 1A(N)
.Regulatory Guide 1.32Criteria for Safety-Related Electric Power Systems for Nuclear Power Plants DiscussionThe CPNPP design complies with the requirements of Revision 2 (2/77) of this regulatory guide. For details see Section 8.3
.Regulatory Guide 1.33Quality Assurance Program (Operation)
 
DiscussionThe quality assurance requirements for the operations phase of CPNPP are in compliance with Revision 2 (2/78) of this regulatory guide as implemented by ANSI N18.7-1976, "Administrative Controls and Quality Assurance for Operational Phase of Nuclear Power Plants", with the following exceptions:1.Biennial Reviews of Plant Procedures The quality assurance program has specified alterna tives to the program area audit frequencies stated in Regulatory Position C.4. The quality assurance program schedules the audits provided for in Regulatory Position C.4 at 24 month frequencies. The audit schedule is performance-based and additional audits may be scheduled based upon program or functional area performance or other factors that indicate the need for increased assessment.
The intent of the biennial review is accomplished by CPNPP programmatic controls already in place. The following controls assure that procedures are appropriately reviewed and revised to incorporate information based on plant operations, design changes, regulatory requirements, industry experience and other conditions that may impact plant procedures.*Site Modification Process
*Corrective Action Program*Off-Normal Occurrence*User Feedback and Procedure Compliance
*Operating Experience Review CPNPP/FSAR1A(B)-10Amendment No. 107*Vendor Technical Information*Licensed Document Change/50.59 Evaluation*Commitment Tracking System (CTS)*Trending Activities
*Infrequently Performed Evolutions Control*Requalification Training*Quality Assurance Activities In addition, biennial reviews are performed of non-routine procedures (Emergency Response guidelines (ERGs), Functional Restoration Guidelines (FRGs) and Abnormal Plant Operating
 
Procedures (ABNs)).Note:  10CFR50.59 has been revised and the terminology in Section 4.3.4 of ANSI N18.7-1976 is no longer current.
Section 17.2 has been updated to reflect the revision to 10CFR50.59.2.Identification of QA Program Requirements in Procurement DocumentsQuality Assurance program requirements consistent with 10CFR50 Appendix B or ANSI N45.2 are not imposed in procurement documents for commercial grade calibration services from a National Voluntary Laboratory Accreditation Progr am (NVLAP) or American Association for Laboratory Accreditation (A2LA) accredited calibration laboratory evaluated in accordance with Section 17.2.7.Regulatory Guide 1.34Control of Electroslag Weld Properties Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.35Inservice Inspection of Ungrouted Tendons in prestressed Concrete Containment Structures DiscussionThis regulatory guide is not applicable to the CPNPP which has a steel-lined, reinforced concrete containment structure.Regulatory Guide 1.36Nonmetallic Thermal Insulation for Austenitic Stainless Steel CPNPP/FSAR1A(B)-11Amendment No. 107 DiscussionThis regulatory guide is not applicable for components located inside CPNPP Containment Buildings, since only stainless steel metal reflective thermal insulation is used for austenitic stainless steel components located there. Nonmetallic thermal insulation used for austenitic stainless steel piping and components located outside the Containment Buildings meets the requirements of this regulatory guide dated February 23, 1973, with the exception of packaging and shipping requirements of paragraph C.1 of this guide. In lieu of controlled packaging and shipping, a receipt inspection is required, which consists of visual inspection for physical or water damage to shipping containers, to determine if insulation materials have been contaminated by external sources.
Also refer to Appendix 1A(N) and Section 6.1B, 6.2 and 5.2.3
.Regulatory Guide 1.37Quality Assurance Requirements for Cleaning of Fluid Systems and Associated Components of Water-Cooled Nuclear Power Plants DiscussionThis regulatory guide is not applicable to the design and construction of CPNPP. The quality assurance methods for operating phase activities will comply with the applicable provisions of this regulatory guide, dated March 16, 1973, for those activities in this area which are similar to construction activities. The application of the requirements of ANSI N45.2.1 - 1973, as endorsed by this guide, will be in accordance with th e guidance provided in ANSI 18.7 - 1976.
Also refer to Appendix 1A(N) and Section 17.2
.Regulatory Guide 1.38Quality Assurance Requirements for Packaging, Shipping, Receiving, Storage, and Handling of Items for Water-Cooled Nuclear Power Plants DiscussionThis regulatory guide is not applicable to the design and construction of CPNPP. The quality assurance methods and administrative controls utilized in the area of packaging, shipping,
 
receiving, storage and handling of items during the operations phase, as described in Section17.2, will comply with the applicable guidance contained in Revision 1 (10/76) of this regulatory guide. The application of the provisions of ANSI N45.2.2 - 1972, as endorsed by this regulatory guide, will reflect the guidance provided in ANSI N18.7 - 1976.Although ANSI N45.2.2 - 1972 is entitled, "Packaging, Shipping, Receiving, Storage, and Handling of Items for Nuclear Power Plants During the Construction Phase," CPNPP meets the requirements of this standard during the operation phase with the clarification noted below:
Maintenance of items in-storage during operat ions will be in accordance with the preventive maintenance requirements of ANSI N18.7-1976 as supplemented by the EPRI guidelines for determining in-storage maintenance of items for nuclear facilities (NCIG-18).
CPNPP/FSAR1A(B)-12Amendment No. 107For handling of items during operation phase, the following codes and standards shall apply. ANSI B30.9 - 1971 ANSI B30.2 - 1976 (1967 for Design and Fabrication) ANSI B30.5 - 1968 Regulatory Guide 1.38, Revision 2 (5/77) is not addressed.
Also refer to Appendix 1A(N) and Section 17.2
.Regulatory Guide 1.39Housekeeping Requirements for Water-Cooled Nuclear Power Plants DiscussionThe administrative methods utilized to control station housekeeping prac tices will comply with ANSI N45.2.3 - 1973, as endorsed by Revision 2 (9/77) of this regulatory guide and as applied to the operations phase by the provisions of ANSI N18.7 - 1976.
Also refer to Section 17.2Regulatory Guide 1.40Qualification Tests of Continuous-Duty Motors Installed Inside the Containment of Water-Cooled Nuclear Power Plants DiscussionThis regulatory guide is not applicable to CPNPP since there are no continuous-duty Class 1E motors inside the Containment. For details see Section 3.11B
.Regulatory Guide 1.41Preoperational Testing of Redundant On Site Electric Power Systems to Verify Proper Load Group Assignments DiscussionThe CPNPP onsite electric power system design complies with the preoperational testing requirements of this guide dated March 1973. For details see Section 8.3. The Initial Test Program, as described in Section 14.2
, will comply with the provisions of this regulatory guide.Regulatory Guide 1.42Interim Licensing Policy on As Low As Practicable for Gaseous Radioiodine Release from Light-Water-Cooled Nuclear Power Reactors CPNPP/FSAR1A(B)-13Amendment No. 107 DiscussionThis regulatory guide was withdrawn March 22, 1976.Regulatory Guide 1.43Control of Stainless Steel Weld Cladding of Low Alloy Steel Components Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.44Control of the Use of Sensitized Stainless Steel DiscussionThe CPNPP design will comply with this regulatory guide, dated May 1973, except for Regulatory Position C6. The intergranular corrosion tests are eliminated because the weld arc heat input is controlled as described in Section 6.1B.1.1.2, Item 1e. Exception to this regulatory position is also taken for some equipment as described in Section 6.1B.11.2, Item 2.
Also refer to Appendix 1A(N) for further discussion.Regulatory Guide 1.45 Reactor Coolant Pressure Boundary Leakage Detection Systems DiscussionThe reactor coolant pressure boundary leakage detection system meets the requirements of this guide, dated May 1973 with the exception of the radioactive gaseous monitor leak detection sensitivity (one gpm within one hour), as discussed in Section 5.2.5.3
.Regulatory Guide 1.46Protection Against Pipe Whip Inside Containment DiscussionIn accordance with Standard Review Plan 3.6.2, protection against pipe whip inside the CPNPP Containment Buildings meets the requirements of Regulatory Guide 1.46, dated May 1973, or Branch Technical Position MEB 3-1 except as discussed in Section 3.6B
.Regulatory Guide 1.47Bypassed and Inoperable Status Indication for Nuclear Power Plant Safety Systems CPNPP/FSAR1A(B)-14Amendment No. 107 DiscussionThe CPNPP bypassed and inoperable status indication system presented in Section 7.1 complies with the requirements of this regulatory guide dated May 1973.Regulatory Guide 1.48Design Limits and Loading Combinations for Seismic Category I Fluid System Components
 
DiscussionBalance of Plant components are designed using the stress limits and loading combinations presented in Section 3.9B.3. The conservatism in these limits and the associated ASME design requirements precludes any component structural failure.The operability of active Code Class 2 and 3 valves and pumps will be verified by methods detailed in Section 3.9B.3
.Alternate provisions to meeting the guidance of this regulatory guide dated May 1973, have been utilized for valves and piping as provided in Section 3.9B.3
.Also refer to Appendix 1A(N)
.Regulatory Guide 1.49Power Levels of Nuclear Power Plants Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.50Control of Preheat Temperature for Welding of Low-Alloy Steel Discussion This guide, dated May 1973, is consider ed applicable to ASME Section III Code Class 1 components only.The CPNPP design of Code Class 1 components is in agreement with the requirements of this regulatory guide except for Regulatory Positions 1(a) and 1(b). The recommendations of this regulatory guide are not applied to Code Class 2 and 3 components.In the case of Regulatory Position 2, the low alloy steel welds have been made to ASME code requirements, and therefore the regulatory guide requirements are considered unnecessary.
Also refer to Appendix 1A(N) and 6.1B for further discussion.
CPNPP/FSAR1A(B)-15Amendment No. 107Regulatory Guide 1.51Inservice Inspection of ASME Code Class 2 and 3 Nuclear Power Plant Components DiscussionThis regulatory guide was withdrawn July 21, 1975.Regulatory Guide 1.52Design, 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 DiscussionThe CPNPP design meets the requirements of Revis ion 1(07/76) of Regul atory Guide 1.52, as indicated in Table 6.5-1, except part C.2.g instrumentation (see Section 6.5.1.5); part C.3.h, water drains; Part C.3.n, ductwork design; Part C.4.c, ease of maintenance; part C.4.d, test probes; Part C.5.b, Air flow distribution; Parts C.5.c, and C.5.d, in-place testing, and part C.6, laboratory testing criteria for activated carbon.1.Part C.2.g, instrumentation:The flow rates and pressure drops for the ESF filtration units are not recorded or monitored from the control room. Operability of the ESF filtration units is maintained in accordance with the Technical Specifications. For those units provided for postulated DBA conditions, alarm annunciators in the Control Room are utilized to monitor design limits (e.g., flow, pressure drops, temperature, etc.) as well as system malfunction (e.g.,
damper, fan). This design conforms to the intent of NRC Regulatory Guide 1.52, Revision1 (07/76).2.Part C.3.e:In lieu of ORNL-NSIC-65, ANSI N509 was used for design.3.Part C.3.f:In lieu of ORNL-NSIC-65 or ERDA 76-21, filter banks are arranged in accordance with ANSI/ASME N509-1980.4.Part C.3.g:In lieu of ORNL-NSIC-65, ANSI N509 was used for design.5.Part C.3.h, Water drains:Check valves have been used on some drains in lieu of seals or traps. The drains for the demister compartments of the four Primary Plant Ventilation System ESF filtration units have not been provided with seals, traps, or check valves. Any minimal airflow through CPNPP/FSAR1A(B)-16Amendment No. 107the demister drain will be filtered prior to discharge at the stack. This design conforms to the intent of NRC Regulatory Guide 1.52, Revision 1 (07/76).6.Part C.3.n, Ductwork Design: In lieu of ORNL-NSIC-65 OR ANSI/ASME N509-1976, ANSI/ASME N509-1980 is used as noted below.The following exception is taken to the ANSI/ASME N509-1980 standard (NRC R.G. 1.52, Rev. 2, refers to ANSI/ASME N509-1976):Quantitative leak testing of ductwork is limited to:a.All Primary Plant Ventilation System ductwork located above el. 873'-6" designated as Safety Class 3. b.All ductwork from the fresh air intake up to the Emergency Pressurization Units of the Control Room Air Conditioning System (CRACS). c.All ductwork related to the make-up air system from the fresh air intakes up to the isolation dampers (CPX-VADPOU-17, 18, 20, & 21) of the CRACS. d.All ductwork penetrating the Control Room envelope. 7.Part C.4.c, Ease of Maintenance: The spacing provided between the components of the filtration units is, in some cases, less than the minimum required by this regulatory position. However, it has been determined by operation and maintenance personnel that the spacing provided is sufficient to perform all required maintenance operations. This design conforms to the intent of Reg Guide 1.52, Revision 1 (07/76). 8.Part C.4.d, Test Probes: Test ports will be provided in lieu of permanently installed test probes. Permanently installed probes are a convenience in the periodic testing of filters and absorbers. Replacing them with test ports is of no safety significance. This design meets the intent of NRC Regulatory Guide 1.52, Revision 1 (07/76).9.Part C.5.b, Air flow distribution: The air flow distribution to the HEPA filters and iodine absorbers will be tested in place for uniformity initially and after maintenance affecting the flow distribution for all units except the control room pressurization units. 10.Parts C.5.c and C.5.d, In-Place Testing Criteria:
ANSI/ASME N509-1980 and ANSI/ASME N510-19 80 will be issued for field testing activities in place of the older versions of these codes referenced in this Regulatory Guide.
CPNPP/FSAR1A(B)-17Amendment No. 107In-place testing of the HEPA filter banks and adsorber will be required following any significant painting, fire or chemical release described in position C.5.c and C.5.d of this guide. This design conforms to the intent of NRC Regulatory Guide 1.52, Revision 2 (03/78).HEPA filter and charcoal adsorber efficiency for the Primary Plant Filtration Units is 95% which corresponds to an acceptance criteria of less than 1% for in-place penetration and bypass leakage at rated flow.11.Part C.6, Laboratory Testing Criteria for Activated Carbon: Laboratory testing of activated carbon will be in accordance with ANSI/ASME N509-1980, ANSI/ASME N510-1980 and ASTM-D3803-1989. The parameters applicable to new and used charcoal at CPNPP shall be applied in the lab test as follows:
The allowable methyl iodide penetration for 99% efficiency units (control room ventilation filtration and pressurization units) shall be 0.5% instead of 0.175% as shown in Table 2 of the Regulatory Guide.The allowable methyl iodide penetration for 95% efficiency units (primary plant ventilation filtration ESF units) shall be 2.5% instead of 1.0% as shown in Table 2 of the Regulatory Guide. When all or most of the charcoal canisters in the filtration units have been used, a representative sample of the charcoal from the bed will be obtained by grain thief sampling in accordance with ANSI N509-1980, Appendix A. The representative samples obtained with the grain thief will be used for laboratory testing and/or refilling the charcoal canisters.The carbon adsorber beds will be replaced when (1) testing in accordance with the frequency specified in Footnote c of Table 2 results in a representative sample failing to pass the applicable test in Table 2 or (2) no representative sample is available for testing, at a time when testing is required.
New Charcoal Used Charcoal 4" Beds(a)a)When the carbon sample is less than 4" (e.g., as a result of settling during shipment) the correction as detailed in ASTM D3803-1989 Section 9.2 may be applied.
4" Beds(a)40 ft/min 40 ft/min30°C & 95% RH 30°C & 70% RH Pre-equilibrated Pre-equilibrated CPNPP/FSAR1A(B)-18Amendment No. 107This design conforms to the intent of NRC Regulatory Guide 1.52, revision 2 (03/78). Regulatory Guide 1.53 Application of the Single-Failure Criterion to Nuclear Power Plant Protection Systems DiscussionBOP systems meet the recommendations of this regulatory guide (dated June 1973) in accordance with the comments of Section 7.1.2.7
.Also refer to Appendix 1A(N)
.Regulatory Guide 1.54Quality Assurance Requirements for Protective Coatings Applied to Water-Cooled Nuclear Power Plants DiscussionProtective Coatings inside containment were declassified from Nuclear Safety Related to Non-safety Related during construction, prior to the receipt of the Operating License. The protective coatings program is subject to a specifically structured quality assurance program as described
 
in Appendix 17A
. A detailed "suitability of application review" of the protective coatings inside containment for Units 1 and 2 has been performed based on the guidance in EPRI Report 1003102 "Guideline on Nuclear Safety-Related Coatings", Revision 1 (formerly TR-109937) and ASTM D 5144-00, Standard Guide for Use of Protective Coating Standards in Nuclear Power Plants.  [ER-ME-124, Evaluation of CPNPP Protective Coatings]  All of the protective coatings have been evaluated and classified as either "Acceptable" or "unqualified" coatings. This evaluation concluded that all of the applied protective coatings within both containment buildings are acceptable coatings with the exception of those coatings on the Coatings Exempt Log for each unit.As of December 31, 2007, protective coatings inside containment are classified as Service Level I, coatings. The protective coatings program for ongoing Service Level I inspections, maintenance, repair and modifications is in accordance with the following guidance:EPRI Report 1003102 "Guideline on Nuclear Safety-R elated Coatings", Revision1 (formerly TR-109937).ASTM D 5144-00, Standard Guide for Use of Protective Coating Standards in Nuclear Power Plants.For the above reasons, Regulatory Guide 1.54, "Quality Assurance Requirements for Protective Coatings Applied to Water-Cooled Nuclear Power Plants", does not apply to Comanche Peak.
Also refer to Appendix 1A(N) and Section 6.1B.2 for further discussion.
CPNPP/FSAR1A(B)-19Amendment No. 107Regulatory Guide 1.55Concrete Placement in Category I Structures DiscussionThe CPNPP design and construction requirements and procedures for concrete placements in Category I structures are in conformance with the requirements of this regulatory guide dated June 1973.
Also refer to Section 3.8
.Regulatory Guide 1.56Maintenance of Water Purity in Boiling Water Reactors DiscussionThis regulatory guide is not applicable to the CPNPP which has pressurized water reactor steam supply systems.Regulatory Guide 1.57Design Limits and Loading Combinations for Metal Primary Reactor Containment System Components DiscussionThe following is applicable to structural systems, i.e. air locks, equipment hatch, etc.The design limits and loading combinations utilized for the CPNPP metal containment system components conform to the requirements of this regulatory guide dated June 1973.
Also refer to Section 3.8
.Regulatory Guide 1.58Qualification of Nuclear Power Plant Inspection, Examination, and Testing Personnel DiscussionWith reference to the subject Regulatory Guide as it applies to activities during the Construction phase:1.For inspection activities within the scope of the ASME Code, inspectors are qualified in compliance with the requirements of Regulatory Guide 1.58, Revision 1.2.For inspection activities outside the scope of the ASME Code, inspection personnel are qualified in general compliance with the requirements of Regulatory Guide 1.58, Revision1 except as follows:
CPNPP/FSAR1A(B)-20Amendment No. 107a.Some inspection personnel qualifications are documented on a TUGCO form and not on the Constructor's form.b.Some of the qualification forms are signed by a TUGCO representative and not by a Constructor representative.3.Qualification records are collected, st ored and controlled in compliance with ANSIN45.2.9 Draft 11, Revision 0 dated January 17, 1973 as included in the "Gray Book".For Operational Phase activities, CPNPP Luminant Power Operations will comply with the provisions of Regulatory Guide 1.58, Revision 1, for the qualification of quality control inspection personnel.
Also refer to Appendix 1A(N) and Section 17.2
.Regulatory Guide 1.59Design Basis Floods for Nuclear Power Plants
 
DiscussionThe CPNPP probable maximum flood (PMF) analysis was done prior to the issuance of R.G.1.59. However, a detailed examination has shown that it complies with revision 2 (8/77) of this regulatory guide except as noted below:Revision 2 of this guide differs, in part, from revision 1 in that it refers to ANSI StandardN170-1976. The CPNPP PMF analysis differs slightly from the recommended methods in ANSI N170-1976 in three areas.The probable maximum precipitation (PMP) used in the CPNPP analysis is based on Hydrometeorological Report (HMR) No. 33. ANSI N170 - 1976 refers to HMR 33 and also to a draft version of the later HMR 51. The use of HMR 33 PMP data instead of HMR 51 has only a small effect on the calculated high water levels.The CPNPP PMF analysis used a rainfall time distribution slightly different from the time sequence recommended by ANSI N170 - 1976. This results in no significant difference in calculated maximum water height in either the reservoir or Safe Shutdown Impoundment.
ANSI N170 - 1976 recommends using an antecedent rainfall preceding or following the PMF. The CPNPP analysis assumed the reservoir is full to the top of the conservation storage. The assumption of antecedent rainfall results in slig htly higher calculated maximum water levels.The combined effect of the three computational differences above results in calculated maximum water elevations that are within design limits. Specifically, the resulting minimum freeboard values are in excess of the required freeboard heights for protection against wave action at the peak of the flood.
CPNPP/FSAR1A(B)-21Amendment No. 107Regulatory Guide 1.60Design Response Spectra for Seismic Design of Nuclear Power Plants Discussion The design response spectra for the seismic desig n of the CPNPP plant is in conformance with Revision 1 (12/73) of this regulatory guide except in the high frequency region greater than 33 Hz of vertical response spectra where the vertical response spectra are reduced to a maximum vertical ground acceleration of 0.08g at 50 Hz. This exception is in accordance with NRC Standard Review Plan, Section 3.7.1 and is also consistent with the recommendation of Newmark, Blume and Kapur (Reference 14 of Section 3.7B) from which the vertical design response spectra of this regulatory guide was developed. Similarly, vertical response spectrum frequency of 4.0 Hz was recommended by Newmark, Blume and Kapur and used here instead of 3.5 Hz adopted in Regulatory Guide 1.60. The effect of these deviations is insignificant.
Also refer to Appendix 1A(N)
.Regulatory Guide 1.61Damping Values for Seismic Design of Nuclear Power Plants
 
DiscussionThe damping values utilized for the seismic design of the CPNPP are in conformance with this regulatory guide dated October 1973. For pip ing systems analyzed by the response spectrum method, ASME Code Case N-411 damping values may be used in lieu of the damping values in this Regulatory Guide.
Also refer to Appendix 1A(N) and Section 3.7B
.Regulatory Guide 1.62 Manual Initiation of Protective Actions Discussion Manual initiation controls for BOP systems meet the recommendations of this Regulatory Guide in accordance with the comments of Section 7.3.2.2.7
. System level manual actuation of BOP components (such as the auxiliary feedwater pumps, containment spray pumps, component cooling water pumps, etc.) is accomplished through the system level actuation devices described
 
in Section 7.3.2.2.7, for manual initiation of safety injection, spray actuation, or steam line isolation, as appropriate to the component.
Also refer to Appendix 1A(N)
.Regulatory Guide 1.63Electric Penetration Assemblies in Containment Structures for Light-Water-Cooled Nuclear Power Plants CPNPP/FSAR1A(B)-22Amendment No. 107 DiscussionThe CPNPP Electric Penetration Assemblies comply with the intent of Revision 2 (7/78) of this regulatory guide. For details see Section 8.3
.Regulatory Guide 1.64Quality Assurance Requirements for the Design of Nuclear Power Plants
 
DiscussionThe quality assurance program for design and construction at CPNPP incorporates the intended objectives of ANSI N45.2.11 (Draft 2, Revision 2 - 5/73). The quality assurance methods for operation phase activities will comply with applicable guidance contained in Revision 2 (6/76) of this regulatory guide. The application of the requirements of ANSI N45.2.11 - 1974, as endorsed by this regulatory guide, will be in accordance with the guidance provided by ANSI N18.7 - 1976.
Also refer to Appendix 1A(N) and Section 17.2
.Regulatory Guide 1.65Materials and Inspections for Reactor Vessel Closure Studs
 
Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.66Nondestructive Testing of Tubular Products
 
DiscussionThis regulatory guide was withdrawn September 28, 1977.Regulatory Guide 1.67Installation of Overpressure Protection Devices DiscussionThis regulatory guide was withdrawn by the NRC on April 15, 1983 because the Winter 1978 Addenda to the 1977 edition of the ASME Boiler and Pressure Vessel Code, Appendix O, Section III, Division 1, included requirements equivalent to the recommendations in this Reg.
Guide. The NRC accepted these changes in the code by reference in 50.55a of 10CFR50 (46FR20153) on April 3, 1981.Regulatory Guide 1.68Preoperational and Initial Startup Test Programs for Water-Cooled Power Reactors CPNPP/FSAR1A(B)-23Amendment No. 107 DiscussionThe testing activities conducted as part of the Initial Test Program, as described in Section 14.2
, and startup program comply with the intent of this Regulatory Guide, Revision 2, dated August1978, with the following exceptions and justification.1.Appendix A subparagraph 1.c As identified in Table 14.2-2, Sheet 42A of 60 of the FSAR, the response time acceptance criteria of the various logic channels will be consistent with Technical Specifications requirements. The Reactor Trip System Response Time is defined in the technical specifications as the time interval from when the monitored parameter exceeds its trip setpoint at the channel sensor until loss of stationary gripper coil voltage. The accident analysis accounts for conservative values for delay times, setpoint drift, etc. Therefore, it is not necessary to account these delay times in the test methods or acceptance criteria.2.Appendix A subparagraph 1.d.1, 1.e.6, 1.e.g, 1.f.1, 1.j.2 & 1.j.17There are no safety related functions of the turbine control and bypass valves as discussed in FSAR Section 10.2.2.7.7. The circulating water system also has no safety related function as described in FSAR Section 10.4.5. Therefore these systems are not included in the preoperational program. However, as identified by Section 14.2.1 these systems are intended to be acceptance tested in accordance with applicable startup administrative procedures. The feedwater control system is not required for safety but does have an interface with the protective system. These interfaces are exclusively part of the feedwater isolation valves ability to close upon the actuation of the proper logic and is covered within preoperational test summary FSAR Table 14.2-2, Sheet 50.3.Appendix A subparagraph 1.d.3The accident analysis concerning the inadvertent depressurization of the reactor coolant system is discussed in FSAR Section 3.9N.1.1, Upset Condition number 5. Subsection5.b lists the condition of the inadvertent opening of one pressurizer power operated relief valve (PORV). The analysis states that the limiting case is the actuation of the pressurizer safety valve. This is classified as an Upset Condition with no operational impairment. The design parameters listed in Table 5.4-16 of the FSAR indicate that the relieving capacity for the pressurizer power operated relief valve is one-half the capacity of the pressurizer safety valve, 210,000 lb/hr vs 420,000 lb/hr. Therefore there is no intention of performing capacity tests of the pressurizer power operated relief valves during the startup phase.Testing of these valves is listed in Table 14.2-2, Sheet 53, of the FSAR as a preoperational test.
The accident analysis covering the opening of a steam generator power operated relief valve is similar. The analysis is described in FSAR Section 15.1.4
. This accident CPNPP/FSAR1A(B)-24Amendment No. 107analysis uses a value of 968,400 lbm/hr @ 1200 psia. In addition, for plant cooldown requirements, a minimum capacity of 62,150 lbm/hr @ 100 psia is also required. Table10.3-3 in the FSAR describes these requirements. Because of extensive validation program conducted by the valve vendor, the uncertainties associated with a field test and the routine calibration of the valve stem travel stop positions, there is no need to test the capacities of the steam generator power-operated atmospheric relief valves during the startup program.The testing of the steam generator power operated relief valves is presented in FSAR Table 14.2-2, Sheet 49.4.Appendix A subparagraph 1.k.2,3The equipment identified in the above paragraphs of Regulatory Guide 1.68 is calibrated and functionally tested as part of the instrument calibration program for the TUGCO Chemistry and Health Physics section. The calibration and functional testing is performed and documented in accordance with approved station calibration procedures. Therefore, TUGCO Startup will not perform additional testing, in the form of a preoperational test, on this equipment.5.Appendix A subparagraph 1.n.11Refer to the discussion of Regulatory Guide 1.68.3.6.Appendix A subparagraph 1.o.1 The vendor has performed applicable load testing on the head lifting and internals lifting devices for 125% static loads.7.Appendix A subparagraph 4.tNatural circulation tests have been successfully completed at McGuire Unit 1, Salem 2, Sequoyah 1 and other Westinghouse plants similar to CPNPP. It is unnecessary for CPNPP to compare flow (without pumps) and temperature data to that of these plants since no design differences exist which would significantly effect natural circulation capabilities. Typical natural circulation characteristics for 4 loop Westinghouse plants are given in WCAP-8460, "Natural Circulation Test Report for Zion Station Unit 1."  However, in order to verify natural circulation cooldown and boron mixing capability per requirements of Branch Technical Position RSB 5-1, CPNPP referenced test results from Diablo Canyon Unit 1 which were found to be acceptable. See Appendix 5A for further discussion.8.Appendix A subparagraph 5.k.k The most influential contributor for this transient is the value of moderator temperature coefficient of reactivity, which has a relatively low value at beginning of core life. Since this parameter is determined in other startup tests, thus validating the safety analysis, the performance of this test provides no new information needed to veri fy the plant design. The transient does introduce the potential for thermal stress damage to the steam CPNPP/FSAR1A(B)-25Amendment No. 107generator feedwater inlet nozzles and it expends one of the analyzed thermal cycles. Therefore, we do not intend to perform a test to comply with this subparagraph.9.Appendix A, Subparagraphs 4c, 5e, 5f and 5iThe pseudo ejected rod tests and pseudo dropped rod tests referenced by these sections of the Regulatory Guide have been successfully performed at plants of similar design to Comanche Peak. Previous tests on similar facilities indicate little new information is generated by the performance of these tests. Additionally, vendor predictions indicate that a violation of the F-delta-H Technical Specification may occur if the 50% power pseudo dropped rod test is performed at Comanche Peak. Recent industry experience indicates there is an increased potential for causing severe xenon transients by performing these tests. Based on these reasons, we do not intend on performing tests to comply with Appendix A, Subparagraphs 4c, 5e, 5f and 5i. A normal function of the Digital Rod Position Indication system is to detect misaligned control rods which satisfies subparagraph 5i. The Digital Rod Positi on Indication system is a diverse and independent method of detecting control rod positions.10.Appendix A, subparagraph 5.d.CPNPP plant design does not include part-length control rods. The ability to control core xenon transients is a design feature of the Westinghouse Nuclear Steam Supply System and has been demonstrated in numerous operating pressurized water reactors. In addition, compliance with Technical Specification 3/4.2.1, "Axial Flux Difference", ensures proper power and flux distributions. On these bases, CPNPP does not intend to perform an Initial Startup Test to comply with subparagraph 5.d.11.Appendix A, subparagraph 5.i.i.The performance of this test provides no new information needed to verify the plant performance during design transients. Trip of the reactor coolant pumps result in a reactor trip with flow coastdown, as verified in the Reactor Coolant System Flow Coastdown Test, providing sufficient heat re moval to ensure DNBR does not decrease below the limit value. Performing this test expends one of the analyzed transients and results in unnecessary cost and down time for the utility.12.Appendix A, subparagraph 5.u.Operability and response times of the main steam isolation valves will be verified in hot standby (mode 3) rather than at the recommended 25% power level. Testing at hot, zero power will result in more conservative results and will eliminate the unnecessary pressure and steam flow transients which would otherwise be induced.13.Appendix A, subparagraph 5.m.m.The performance of this test provides no new information needed to verify the plant performance during design transients. Closure of all Main Steam Isolation Valves from 100% power causes a turbine trip and a reactor trip. A turbine trip and reactor trip from 100% power will be performed during initial startup testing. Closure of the MSIV's may cause the operation of the pressurizer and steam generator power operated relief valves CPNPP/FSAR1A(B)-26Amendment No. 107and/or safety valves which may then require repair and unnecessary down time for the utility. This test would expend one of the analyzed pressure transients for the reactor coolant system and steam generators and therefore will not be performed at CPNPP.14.Appendix A, subparagraph 2.bHot no flow, cold no flow and cold full flow rod drops do not provide any additional useful data. By Technical Specifications, critical operations are only permitted when plant is hot and RCP operating and thus scram testing is not required for hot no flow, cold no flow and cold full flow conditions. We do not intend to take credit for cold no flow, cold full flow and hot no flow rod drops, although one or more of these tests may be optionally performed for diagnostic or demonstration purposes.15.Appendix A, subparagraph 5.hRod drop times are measured during pre-critical testing at hot full-flow conditions. There is no provision in the design of CPNPP to allow for determination of rod scram times following normal plant trips. These tests meet the intent of subparagraph 5.h.16.Appendix A, subparagraph 5.jThe CPNPP design does not include partial scram or rod runback features. Therefore, an Initial Startup Test will not be performed to comply with subparagraph 5.j.17.Appendix A, subparagraph 5.lThe CPNPP residual heat removal (RHR) system does not include a "steam condensing mode" of operation. Also, the "reactor core isolation cooling (RCIC) system" pertains to Boiling Water Reactors. Since these features do not exist at CPNPP, they cannot be tested during the Initial Startup Test program. The remainder of paragraph 5.l will be complied with.18.Appendix A, subparagraph 5.aThe power coefficient measurement test method recommended by Westinghouse cannot be used because it requires installed instrumentation (narrow range hot leg temperature) which is not part of CPNPP design. Power coefficient measurement results, obtained during the startup of several Westinghouse plants, have verified consistency between design calculations and measurement data in plants having fuel similar to the Comanche Peak design. CPNPP's Initial Startup program includes measurement of the critical RCS boron concentration under the conditions of all rods out, hot full power, equilibrium xenon. From this, the core reactivity balance is verified. This test is considered sufficiently accurate to detect any significant differences between the designed and as-built core. This test is in addition to the minimum specifications of the Regulatory Guide.19.Appendix C, subparagraph 4.h.The power ascension program for CPNPP requires flux maps to be taken at each power plateau. The values for F Q(Z) (heat flux hot channel factor) and F N H (nuclear enthalpy CPNPP/FSAR1A(B)-27Amendment No. 107rise hot channel factor) obtained from these flux maps will be compared to and evaluated against Technical Specification limits. This evaluation will be used in place of extrapolating DNBR and linear heat rate values. This action is consistent with the Reference Startup Document supplied by the fuel vendor. Station Administrative procedures will require management review and approval of test results prior to ascending to the next power plateau. 20.Section C.8, Appendix A (Various) Testing will not be performed at the Regulatory Guide suggested 25% (30%) power. Testing originally specified at 30% RTP will be conducted at 50% RTP. Where testing had been previously performed for both 30% and 50% RTP, only the 50% RTP test will be performed. The tests that were previously prescribed to be conducted at the 30% rated thermal power (RTP) plat eau include the following: Core Performance Evaluation Unit Load Transients (10% Step Load Change) Automatic Reactor Control System Test The core performance data that could be obtained at 30% RTP is utilized for gross calibration adjustments of the Nuclear Instrumentation System (NIS) prior to power escalation to 50% RTP. This activity will be performed at 25-30% RTP as a hold prior to escalation to 50% RTP. The flux distribution measurement at 30% RTP will not be performed unless the peaking factors measured at low power do not support escalation to 70% RTP, the NIS trip setpoint for the 50% RTP testing plateau. This is per the direction of RG-1.68 Appendix C, paragraph 4.h. For Unit 2, one low power flux map will be taken prior to exceeding 30% RTP as a fulfillment of Regulatory Guide 1.68, Appendix A, subparagraph 4.e. At power, flux maps will be taken at 50%, 75% and 100% RTP to satisfy Regulatory Guide 1.68, Appendix A, subparagraph 5.b. Additional flux maps will be taken if required by Regulatory Guide1.68, Appendix C, subparagraph 4.h.For Unit 1, the unit load transient at approximately 30% RTP will be performed following completion of 50% RTP plateau testing to assure proper control system response. For Unit 2, the 30% RTP unit load transient will not be performed.
The Automatic Reactor Control System test is performed at 50% RTP and intended as a precursor to the first Unit Load Transient test. It is designed to ensure that the automatic rod control system can restore the Reactor Coolant System (RCS) temperature to within a +1.5 Deg-F deadband of the reference temperature. Prior to 50% RTP, proper operation of this function would be demonstrated by observation during the normal power escalation, where the control rods will be in automatic and already controlling the RCS temperature to within the deadband. 21.Appendix A, subparagraph 5.z CPNPP/FSAR1A(B)-28Amendment No. 107For Unit 2, each radiation monitor and detector will be calibrated in lieu of only verifying response to a radiation check source as part of the preoperational test program (Table14.2-2
, Sheet 24A). The calibration of the monitors and detectors meet the intent of RG 1.68, Revision 2, Appendix A, Sections 4.g and 5.z (see FSAR 11.5.2.11) and provides a more accurate method for demonstration of their proper operation.22.Appendix A, subparagraph 1.j.(13).The incore neutron instrumentation portion of this subparagraph cannot be fully tested as a preoperational test program item because the system is not fully installed until after initial fuel load. The fuel assemblies provide the structural support for the incore flux mapping system thimbles, the thimbles are not self-supporting and cannot be installed until after the fuel is all in place. For this reason, the only valid demonstration of proper system function over its full operational range must be performed after initial fuel load.
Portions of this testing are also customarily performed at normal operating temperatures prior to initial reactor criticality to ensure that thimble thermal expansion does not create any system operation interferences.23.Appendix A, subparagraph 1.j.(18).The neutron response checks of the auxiliary startup instrumentation are not included as part of the preoperational test program. This testing is performed prior to the start of initial fuel loading, but is addressed as an initial startup test. The auxiliary startup instrumentation is typically received only a short time prior to the start of initial fuel load and is tested prior to the actual fuel movements. The neutron response check portion of this testing is required to be pe rformed within 8 hours of the actual start of initial fuel loading. This time constraint makes it impractical to retain this testing in the preoperational testing program as it allows too little time to close out the preoperational testing program prior to fuel load.24.Appendix A, subparagraph 5.q.The failed fuel detection system consists of the failed fuel monitor with letdown chemistry samples used as both a backup and supplement. The failed fuel monitor, itself, is one of the process radiation monitors that are tested elsewhere under subparagraph 5.z.
Additional testing of this one monitor, beyond that already planned as part of the process monitor testing, would not be expected to provide additional useful test results. Normal plant operating surveillances provide sufficient assurance of failed fuel monitor operability and of the ability to detect any actual failed fuel.Regulatory Guide 1.68.1Preoperational and Initial Startup Testing of Feedwater and Condensate Systems for Boiling Water Reactor Power Plants DiscussionThis regulatory guide is not applicable to the CPNPP CPNPP/FSAR1A(B)-29Amendment No. 107Regulatory Guide 1.68.2Initial Startup Test Program to Demonstrate Remote Shutdown Capability for Water Cooled Nuclear Power Plants DiscussionThe testing activities conducted as a part of the startup test program will comply with the applicable requirements of Revision 1 (7/78) of this regulatory guide.
Also refer to Section 14.2
.Regulatory Guide 1.68.3 Preoperational Testing of Instrument Air Systems Discussion The CPNPP Instrument Air System testing meets with the intent of the requirements of NRC Regulatory Guide 1.68.3, Regulatory Positions C.1 through C.11, as described below:Position C.1:  CPNPP meets the intent of position C.1 by performing preoperational tests on those aspects of the system which are important to safety as described in Section 14.2. The balance of the Instrument Air System testing is performed under the acceptance testing program at CPNPP.Position C.7:  Air operated components which are required to operate in order to perform a safety function are provided with safety related air accumulators as described in section 9.3.1.1. These accumulators and their associated check valves are, for the purposes of single failure analysis, considered an extension of the component being supplied. In no case are safety related air accumulators shared between two redundant components. Therefore, CPNPP meets the required single failure criterion. Tests on these accumulators are described in FSAR Section14.2
.Position C.8:  Preoperational tests for loss of Instrument Air are performed as described in FSAR Section 14.2. Prerequisite tests are performed to verify air operated component failure positions. This testing meets the intent of position C.8.Position C.9:  Regulatory Position C.9 is not applicable to CPNPP since there is no provision for connecting the plant Service Air System to the Instrument Air System.Position C.10:  Regulatory Position C.10 addresses air header pressure transients caused by large air users. The CPNPP Instrument Air Systems only bulk load is the Turbine Generator Gas Purge. This function is manually initiated and is only used while the plant is not operational. To date, operation of the Turbine Generator Gas Purge has not revealed any problems associated with pressure transients. Therefore, no testing will be performed.Position C.11:  Regulatory Position C.11 addresses Instrument Air System overpressure transients. The CPNPP Instrument Air System is protected from overpressurization by relief valves which are individually tested. No additional overpressure testing is performed.
CPNPP/FSAR1A(B)-30Amendment No. 107 Also refer to Section 14.2Regulatory Guide 1.69Concrete Radiation Shields for Nuclear Power Plants
 
DiscussionThe regulatory guide states that ANSI N101.6-1972, Concrete Radiation Shields, is considered applicable to shielding structures for nuclear power plants, subject to certain conditions. These conditions are stated in Regulatory Positions Nos. 1-8 of the regulatory guide. The guidance provided in this regulatory guide, dated December 1973, is adhered to as follows:1.Regulatory Position No. 1:  The codes and standards of concrete shielding are those listed in subsection 3.8.4.2 (outside the Containment).2.Regulatory Position No. 2:  This position is complied with as described in Section 3.8
.3.Regulatory Position No. 3:  In the design of concrete radiation shields, there has been consideration of steady state and transient thermal loads and loads due to postulated
 
missiles, as described in Sections 3.3
, 3.8.3.3, and 3.8.4.3.4.Regulatory Position No. 4:  This position is complied with as described in Sections 3.8.3 and 3.8.4.5.The intent of Regulatory Position Nos. 5 and 6 is complied with.
6.Regulatory Position No. 7:  Provision is made for adequate means by transferring all forces through construction joints. All loads described in Sections 3.3
, 3.5, and 3.8 are considered in the design.7.Regulatory Position No. 8:  Vacuum box testing of pool liner welds, or an equivalent alternate method, are considered as an acceptable supplementary method of testing liner welds or leaktight integrity.
Also refer to Section 12.3.2
.Regulatory Guide 1.70Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants, LWR Edition DiscussionThe CPNPP FSAR conforms to the format of Revision 2 (9/75) of this regulatory guide with minor variations where needed for clarity. In a number of sections the NSSS information is separated from the BOP (i.e.
1A(N) and 1A(B), 3.6N and 3.6B). Appendices are used appropriately and incorporated by reference. Printing/reproduction for FSAR amendments may be performed mechanically or photographically, including "Xerox-ty pe" copier quality reproduction.
CPNPP/FSAR1A(B)-31Amendment No. 107 Following clarification is provided for Revisions Section (Page V):Amendment number and date of change is provided on each affected pages of Sections and Tables. For flow diagrams, it will be provided on the index pages in lieu of each flow diagram.Regulatory Guide 1.71Welder Qualification for Areas of Limited Accessibility
 
DiscussionThe CPNPP design complies with the requirements of this regulatory guide, dated December 1973, for piping only.
Also refer to Appendix 1A(N)
.Regulatory Guide 1.72Spray Pond Plastic Piping
 
DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.73Qualification Tests of Electric Valve Operators Installed Inside the Containment of Nuclear Power PlantsDiscussionSafety-related motor operated valves inside Containment comply with the guidance of Regulatory Guide 1.73, dated January 1974, with the exception that stem mounted limit switches are tested separately to the requirements of IEEE Standard 382-1972.For details see Section 3.11B
.Also refer to Appendix 1A(N)
.Regulatory Guide 1.74Quality Assurance Terms and Definitions DiscussionThis guide is not applicable to CPNPP design and construction. The quality assurance provisions for operating phase activities are in accordance with the guidance of
 
ANSI N45.2.10 - 1973, as endorsed by t his regulatory guide da ted February 1974.
Also refer to Section 17.2
.
CPNPP/FSAR1A(B)-32Amendment No. 107Regulatory Guide 1.75Physical Independence of Electric Systems Discussion CPNPP design complies with the intent of Revision 1 (1/75) of this regulatory guide with the following comments:Regulatory Position C.1 - Non-Class 1E power or control circuits may be isolated from their Class1E power source by two circuit breakers, two fuses or a breaker and a fuse in series, both coordinated with an upstream circuit protective device, and the circuit breakers periodically tested. Non-safety instrument circuits powered from distribution panels 1PC1, 1PC2, 1PC3, and 1PC4 will have a non-safety circuit breaker or fuse connected in series with the panel circuit breaker.The non-Class 1E AC essential lighting circuit s use interconnecting cable (i.e., from the distribution panel feeder breaker to the lighting load) routed in conduit. The routing of the circuits in conduit ensures the physical and electrical independence from Class 1E circuits beyond the isolation breaker.The non-Class 1E DC emergency lighting circuits connected to dedicated batteries are routed in conduit. The routing of the circuits in conduit ensures physical and electrical independence from Class 1E circuits.The lighting circuits routed in conduit meet the separation criteria of FSAR Section 8.3.1.4
.Electrically, Class 1E circuits are equal or superior to non-Class 1E circuits. Physically, Class 1E circuits are subject to more stringent analysis than non-Class 1E circuits. Therefore, devices qualified for non-Class 1E-to-Class 1E isolation applications provide more than adequate train-to-train isolation.Separation between Radiax and Heliax radio antenna cables and Class 1E cables is not required. The analysis is provided in Section 8.3.1.4(4)
.Separation between Thermistor and Class 1E cables is not required. The analysis is provided in Section 8.3.1.4(4)
.Fiber optic cables used in non-Class 1E monitoring circuits carry no electrical energy by themselves and therefore are not required to maintain physical separation from Class 1E circuits.Lesser internal wiring separation is being used between redundant safety systems and safety and non safety systems in BOP Analog Process Instrumentation Panels. This analysis is provided in Section 7.1.2.2
.The non-Class 1E diesel generator neutral grounding transformer is connected to the neutral of the Class 1E diesel generator. An analysis has been performed which demonstrates that a fault on the non-Class 1E portion of the circuit will not cause an unacceptable influence on the Class1E system. In addition, the interconnecting cable is routed within the diesel generator room. The cable is routed in dedicated raceway and is inspected to Class 1E requirements.
CPNPP/FSAR1A(B)-33Amendment No. 107Isolation between Non-Class 1E cables originating from Non-Class 1E, 6.9kV switchgear reactor coolant pump and potential transformer Class 1E fuse, is not required based on the analysis provided in Section 8.3
.Isolation between the Class 1E pressure indicating switch contact and Non-Class 1E time delay relay contact in Emergency Diesel Generator control panels CP1-ECCPEC-01 and 02 is not required based on the analysis provided in Section 8.3
.Isolation between Non-class 1E cables originating from the annuniciator in Spent Fuel Pool Panel CPX-EIPRLV-06 and Class 1E electronic boxes X-LY-4849A and B is not required based
 
on the analysis provided in Section 8.3.Isolation between the Non-Class 1E coaxial cable and the epoxy mica capacitor (EMC) which forms part of the Class 1E Partial Discharge Monitor Bus Coupler connected to each of the Unit 1 and Unit 2 Station Service Water Pump and Component Cooling Water motor feeders and Emergency Diesel Generators, is not required based on the analysis provided in Section 8.3
.Regulatory Position C.2 - For the purpose of electrical cable separation, acceptable barriers include rigid metal conduit, electrical metallic tubing (EMT), flexible metallic conduit, cable tray covers (both solid and ventilated types), cable bus enclosures, equipment and device enclosures, enclosed metal wireways inside equipment, a wrap of woven silicon dioxide and one hour fire rated materials (i.e. the rmolag and one hour fire rated cable).A wrap of woven silicon dioxide, thermolag and one hour fire rated cable are considered equivalent to a metal enclosed raceway with respect to protection from electrical failures. Thermolag and one hour fire rated cable shall only be used as a Regulatory Guide 1.75 electrical separation barrier when installed to satisfy the requirements described in FSAR Section 9.5.1.2
.Metal Clad (MC) cables include copper sheathed (CS) cable, aluminum sheathed (ALS) cable and Galvanized Steel Sheathed Cable (GS). MC cables are considered the same as cable inside conduit for separation purposes. See Section 8.3 for the analysis and discussion on MC cables.CS cable is constructed of continuous corrugated 16 mil thick copper tube with no outer jacket and 600V XHHW, 90°C insulation. CS cable will be used only inside the containment and only in the lighting system.ALS cable is constructed of continuous corrugated 25 mil. thick seamless aluminum tube with an outer thermosetting chlorosulphonated polyethylene jacket and 600V XHHW, 90° C insulation. ALS cable will only be used outside of the containment building in the lighting, fire protection, heat tracing and communication systems. The one hour fire rated cable provides a one hour fire rated barrier per ASTM standardE119-1971. The cable is Class 1E qualified per IEEE 323-1974 and IEEE 383-1974 for flame retardancy (unaged cables only). See FSAR Section 1A(B), Regulatory Guide 1.131. The cable is constructed of a continuously welded corrugated 12 mil thick stainless steel sheath with high temperature nickel-clad copper conductors, glass braid cable jacket and silicone rubber insulation. This cable will be used to satisfy the fire safe shutdown requirements, as described in FSAR Section 9.5.1.2, in power and control circuits outside containment where the total radiation CPNPP/FSAR1A(B)-34Amendment No. 107dose is less than or equal to 50 MRADS gamma. Cable sizes will be and smaller. The cable is considered equivalent to cable in conduit for electrical separation purposes.Regulatory Position C.4 - The multiconductor cable between the Safety System Inoperable Indication (SSII) logic panel located in the control room and the termination cabinet in the cable spreading room meet the requirements of this position except for Class 1E environmental qualification. The cable materials meet IEEE Standard 383-1974 for the attributes of flame and radiation resistance. The cable is installed in a mild environment. Based on analysis, a fault at the SSII logic panel will not impact the availability of adjacent Class 1E cables with which these associated cables are routed. This analysis is provided in Section 8.3
.Regulatory Position C.6 - Lesser separation, based on RG 1.75 Rev. 3, is being used for interaction involving instrumentation cables only. This analysis is provided in Section 8.3
.Lesser separations are being used in several locations between Class1E wiring and non-Class 1E Area Radiation Monitoring detec tor wiring and Public Address System speaker wiring based on analysis. This analysis is provided in Section 8.3
.Separation between Class 1E circuits and non-Class 1E Emergency Diesel Generator stator RTD circuits is not required based on analysis. This analysis is provided in Section 8.3
.Separation between Class 1E Cables and Non-Class 1E cables at the Electronics Boxes (X-LY-4849A-1, X-LY-4849A-2, X-LY-4849B-1 and X-LY-4849B-2) furnished by FCI is not required based on analysis. This analysis is provided in Section 8.3
.Separation between associated circuits and non-Class 1E circuits in fire panels CPX-EIPRLV-29, CPX-EIPRLV-29A, and CPX-EIPRLV-30 is not required based on analysis. This analysis is provided in Section 8.3
. Separation between associated cables and non-Class 1E cables at the Safety System Inoperable Indication panels is not required based on analysis. This analysis is provided in Section 8.3
.Separation between the output circuits of the spare inverters is not required based on the analysis provided in Section 8.3
.Separation between non-Class 1E cables originating from 6.9kV switchgear (Reactor Coolant Pump) and Class 1E PT fuses inside the Class 1E PT cabinet is not required based on the
 
analysis. This analysis is provided in Section 8.3
.Separation between associated cables and non-Class 1E Regulating transformers TXEC1, TXEC2, TXEC3 and TXEC4 is not required based on analysis. This analysis is given in Section8.3Separation between associated cables and non-class 1E cable CP2-EIPRLV-48 is not required based on analysis. This analysis is given in section 8.3
.Minimum physical separation between class 1E cables and nonclass 1E differential relay (87/ST1 and 87/ST2) protection cables are not required inside the 6.9 kV class 1E switch gear based on analysis. This analysis is provided in Section 8.3
.
CPNPP/FSAR1A(B)-35Amendment No. 107Separation between non-Class 1E Train C cables connected to the line and load terminals of breaker CP1-BSDSEB-01, CP2-BSDSEB-01 and Class 1E Train B cables connected to the shunt trip coil are adequate to ensure that the non-Class 1E cabling will not degrade the Class1E system based on analysis provided in Section 8.3.1.2.1.7.l
.When a cable, conduit or tray is protected by One-Hour Fire rated Thermo-lag installed to satisfy the requirements as described in FSAR section 9.5.1.2; there is no separation requirement from the Thermo-lag protected cable, conduit or tray, to the redundant cable, conduit or tray outside the Thermo-lag enclosure based on analysis. This analysis is provided in section 8.3
.Associated cables used to selectively connect the non-Class 1E alternate power diesel generators to the Class 1E 6.9kV switchgear are installed in outdoor raceway sections that are not seismically supported. These cables do not have Class 1E protection for over current and faults. This is based on the analysis provided in Section 8.3
.Separation/Isolation between associated control cables and non-Class 1E control cables at Instrument Air Compressor Termination Cabinet CP1-CICACO-01A is not required based on analysis. This analysis is provided in section 8.3
.Physical separation between non-Class 1E and Class 1E circuits or non-Class 1E and associated Class 1E circuits inside the Diesel Generator Engine Control Panels CP1/2-MEDGEE-01A/02A is not required based on the analysis provided in Section 8.3.1.4.5
.Regulatory Position C.9 - Splice type connections have been used to terminate field routed cables in raceways. Such splices are utilized in CPNPP design at: 1.Electric penetration assemblies (EPAs), Core Exit Thermocouple (CET) Integral Reference Junction (IRJ), Control Rod Drive Mechanism (CRDM) disconnect panel connectors and Electric Conductor Seal Assemblies (ECSAs) pigtail cables2.Solenoid valves, limit switches, level switches, etc. (local mounted devices - LMDs)3.Connection of LMDs to Electric Conductor Seal Assembly (ECSA) pigtails.An analysis to justify cable splices in raceways is provided in Appendix 8A
.Regulatory Position C.10 - Cable jackets requiring field color coding are color coded at intervals not to exceed every 5 feet for exposed cable runs (cable not in raceway, i.e., cable not in cable tray, conduit or pull box) and at each end.Regulatory Position C.12 - Power circuits for th e following equipment located inside the Control Room complex, are routed in exclusive conduits within the Control Room complex:Regulating transformers TXEC3 and TXEC4, and air conditioners CP1- VAACTC-01, CPX-VAACTC-01 and CP2-VAACTC-01.The ratings of the above equipment do not categorize them as high energy equipment.
Regulating transformers TXEC3 and TXEC4 and the air conditioners listed above are located in the Control Building Mezzanine Area, which is separated from the Control Room by a Seismic Category II partial height gypsum wall and concrete floor.
CPNPP/FSAR1A(B)-36Amendment No. 107For details see Section 8.3
.Also refer to Appendix 1A(N)
.Regulatory Guide 1.76Design Basis Tornado for Nuclear Power Plants DiscussionThe CPNPP is designed to conform to the requirements of this regulatory guide, dated April 1974, except that it is designed to withstand the effects of a Design Basis Tornado having a maximum wind speed of 360 mph which is made up of a rotational speed of 300 mph and a translational speed of 60 mph. A simultaneous pressure drop of 3.0 psi at the rate of 1.0 psi per second is considered.The Design Basis Tornado for CPNPP was determined prior to the issuance of this Regulatory Guide and was approved for use by the Atomic Energy Commission's Safety Evaluation Report Dated September 3, 1974.
Also refer to Section 3.3
.Regulatory Guide 1.77Assumptions Used for Evaluating a Control Rod Ejection Accident for Pressurized Water ReactorsDiscussionThe analysis of the radiological consequences of a control rod ejection accident presented in Section 15.4.8 follows the guidance provided in Regulatory Guide 1.195 instead of that in Regulatory Guide 1.77.Regulatory Guide 1.78Assumptions for Evaluating the Habitability of a Nuclear Power Plant Control Room During a Postulated Hazardous Chemical Release DiscussionThe CPNPP design meets the intent of this regulatory guide, dated June 1974, as discussed in Sections 2.2 and 6.4.Regulatory Guide 1.79Preoperational Testing of Emergency Core Cooling Systems for Pressurized Water Reactors CPNPP/FSAR1A(B)-37Amendment No. 107 DiscussionThe Initial Test Program, as described in Section 14.2, is in compliance with the provisions of Revision 1 (9/75) of this regulatory guide with the following exception.1.Regulatory Position C.1.b(2)Recirculation Test - Cold ConditionsA satisfactory in-plant test of the containment sump to demonstrate vortex control and acceptable pressure drops across screening and suction lines and valves was not practical for reasons which include physical limitations, difficulty of cleanliness control and the possibility of equipment damage.However, a full scale model of the Containment Recirc sumps, screens and surrounding area was used to demonstrate that unacceptable vortex formation in the sump area is precluded while simulating operation under various flow and pump combinations. In addition, the inlet loss coefficient across the sump screens and sump intake piping configuration was evaluated for comparison to analytically determined values and to verify the adequacy of new positive suction head at the pumps.The capability to realign valves and injection pumps to recirculate coolant from the containment floor was demonstrated. The full flow test was performed with the RHR pumps taking suction from the Refueling Water Storage Tank (RWST) and delivering to the RCS. The RHR pumps were not running when demonstrating the realignment capability. The net positive suction head was determined from the level in the RWST and in the containment sump and shown to be greater than the required net positive suction head for the pump.The lines from the containment sump to the RHR pumps were flushed and inspected to ensure that they are free from obstruction.For details refer to Table 14.2-2, Sheet 15.Regulatory Guide 1.80Preoperational Testing of Instrument Air Systems
 
Discussion Regulatory Guide 1.80 was superseded by Regulatory Guide 1.68.3. Refer to the discussion of Regulatory Guide 1.68.3. Regulatory Guide 1.81Shared Emergency and Shutdown Electric Systems for Multi-Unit Nuclear Power Plants CPNPP/FSAR1A(B)-38Amendment No. 107 DiscussionThe CPNPP design complies with the provisions of Revision 1 (1/75) of this regulatory guide with an exception to Regulatory Position C1. For details see Section 8.3.1.2.1 Item 8.Regulatory Guide 1.82Sumps for Emergency Core Cooling and Containment Spray Systems
 
Discussion The containment recirculation sump design in the CPNPP complies with the intent of the Regulatory Positions of this regulatory guide dated June 1974 with clarifications as noted below.
The description and design evaluation of the containment recirculation sumps is provided in Section 6.2.2
.C.3 and C.8 - The screen design with (1) an outer trash rack and (2) a fine inner screen mounted on a structure with a solid top cover has been replaced by a strainer which incorporates the function of both the screen and the trash rack. The strainer is located on the lowest floor elevation in the containment exclusive of the reactor vessel cavity. The strainer is fully submerged prior to switchover of containment spray from injection to recirculation for LOCAs and secondary pipe breaks. This design meets the intent of the Reg. Guide.C.4 and C.6 - The floor level in the vicinity of the sumps does not slope away from the sumps. However, the design meets the intent of the Reg. Guide by the provision of a one foot tall solid debris interceptor surrounding the sump strainers.Regulatory Guide 1.83Inservice Inspection of Pressurized Water Reactor Steam Generator Tube
 
DiscussionThe inservice inspection of steam generator tubes complies with the intent of Revision 1 (7/75) of this regulatory guide.Regulatory Guide 1.84Design and Fabrication Code Case Acceptability ASME Section III Division 1
 
Discussion Code cases listed in this regulatory guide will be used where appropriate.By reference to ASME Section III requirements in the procurement specifications, the use of code cases by mechanical equipment suppliers requires mutual consent of the Owner or his agent and the manufacturer. The ASME Code Cases which are used for design and erection at CPNPP are identified in the appropriate mechanical design and erection specifications or the Brown & Root QA Manual; conditionally-approved Code Cases will show justification for their CPNPP/FSAR1A(B)-39Amendment No. 107use, as required by NRC, in these documents. The application of ASME Code Cases is documented on the ASME Data Report Forms.ASME Code Case N-31-1 regarding the use of elastomer diaphragm valves in ASME Class 2 and 3 applications has been applied to CPNPP. This Code Case is listed as having contingent approval in Regulatory Guide 1.84. Based on the technical justification referenced in the applicable design specification, the Code Case with the following conditions in lieu of the conditions imposed by the Regulatory Guide should apply:1.The service life of the elastomer diaphragms should be lower of that determined based on (a) 1/2 of the average number of cycles from a minimum of three tests per the Code Case and (b) total anticipated radiation ex posure during applicable operating modes determined based on valve operability requirements; and2.the shelf life of the elastomer diaphragm should be determined in accordance with CPNPP procedures for shelf life determination.
Also refer to Appendix 1A(N)
.Regulatory Guide 1.85Materials Code Case Acceptability ASME III Division 1
 
Discussion Code cases listed in this regulatory guide will be used where appropriate.By reference to ASME Section III requirements in the procurement specifications, the use of code cases by mechanical equipment suppliers requires mutual consent of the Owner or his agent and the manufacturer. The ASME Code Cases which are used for design and erection at CPNPP are identified in the appropriate mechanical design and erection specifications or the Brown & Root QA Manual; conditionally-approved Code Cases will show justification for their use, as required by NRC, in these documents. The application of ASME Code Cases is documented on the ASME Data Report Forms.
Also refer to Appendix 1A(N)
.Regulatory Guide 1.86Termination of Operating Licenses for Nuclear Reactors DiscussionThe termination of the operating license and subsequent decommission ing of the Comanche Peak Nuclear Power Plant will address the regulations in effect at that time.Regulatory Guide 1.87Guidance for Construction of Class 1 Components in Elevated-Temperature Reactors (Supplement to ASME Section III Code Cases 1592, 1593, 1594, 1595 and 1596)
CPNPP/FSAR1A(B)-40Amendment No. 107 DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.88Collection, Storage, and Maintenance of Nuclear Power Plant Quality Assurance Records DiscussionThe quality assurance program for design and construction at CPNPP incorporates the intended objectives of ANSI N45.2.9 (Draft 11, Revision 0, 1/73). During the operations phase, the quality assurance methods and administrative controls utilized for controlling and storing QA records, as
 
described in Section 17.2, will comply with the applicable guidance provided in ANSI N45.2.9 - 1974, as endorsed by Revision 2 (10/76) of this regulatory guide; except for paragraph 3 of section 5.6. For this exception, CPNPP will comply with paragraph 3 of section 5.6.1 of ANSIN45.2.9-1979, which requires a minimum two hour rating for the structure, doors, frames and hardware of the storage facility. Application of the requirements of Revision 2 (10/76) of this regulatory guide will be in accordance with the guidance provided in ANSI N18.7 -1976.To ensure adequate protection and timely processing of quality related documentation prior to transmittal of this documentation to the permanent records storage facility for retention, the following control measures shall be implemented in accordance with approved procedures:1.Within 60 days from the time that the work activity was completed, quality related documentation shall be processed through any required post work or closure reviews and transmitted to the permanent records storage facility for retention;2.Once the work activity has been completed, the associated quality related documentation shall be provided adequate protection from damage, deterioration, loss and unauthorized alteration.Regulatory Guide 1.89Qualification of Class IE Equipment for Nuclear Power Plants DiscussionThe CPNPP Class 1E equipment design complies with the qualification program guidelines as delineated in this regulatory guide dated November 1974. However, as supported by the statements of consideration for 10CFR50.49 (Federal Register, 48FR2731, January 21, 1983),
the recommendations of this regulatory gui de need not be applied for Class 1E equipment located in a mild environment area.
Also refer to Appendix 1A(N)
.Regulatory Guide 1.90 Inservice Inspection of Prestressed Concrete Containment Structures with Grouted Tendons CPNPP/FSAR1A(B)-41Amendment No. 107 DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.91Evaluation of Explosions Postulated to Occur on Transportation Routes Near Nuclear Power Plant Sites DiscussionNo transportation routes in the vicinity of CPNPP are within the distances established by this regulatory guide dated January 1975.Revision 1 (2/78) of this guide is addressed in Section 2.2.3
.Regulatory Guide 1.92Combining Modal Responses and Spatial Components in Seismic Response Analysis
 
DiscussionModal responses and spatial components are comb ined in the seismic response analysis of the CPNPP in conformance with Revision 1 (2/76) of this regulatory guide.
Also refer to Appendix 1A(N) and 3.7B.Regulatory Guide 1.93Availability of Electric Power Sources
 
DiscussionThe CPNPP design complies with the requirements of this regulatory guide dated December1974.
Also refer to Section 8.3
.Regulatory Guide 1.94Quality Assurance Requirements for Installation, Inspection, and Testing of Structural Concrete and Structural Steel During the Construction Phase of Nuclear Power Plants DiscussionThis regulatory guide is not applicable to CPNPP design and construction activities. The quality assurance methods for operations phase activities will comply with applicable guidance contained in Revision 1 (4/76) of this regulatory guide. The application of the requirements of ANSI N45.2.5 -1974, as endorsed by this regulatory guide, will be in accordance with the guidance provided in ANSI N18.7 - 1976.
CPNPP/FSAR1A(B)-42Amendment No. 107 Also refer to Section 17.2
. Regulatory Guide 1.95Protection of Nuclear Power Plant Control Room Operators Against an Accidental Chlorine ReleaseDiscussionThe CPNPP design complies with the intent of Revision 1 (1/77) of this regulatory guide as described in Section 2.2
. Regulatory Guide 1.96Design of Main Steam Isolation Valve Leakage Control Systems for Boiling Water Reactor Nuclear Power Plants DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.97Instrumentation for Light-Water-Cooled Nuclear Power Plants to Assess Plant Conditions During and Following an Accident DiscussionA plant specific analysis of the information system requirements for CPNPP was conducted. This analysis was based on the design basis accident event scenarios and required operator actions, using the guidance provided in U.S. NRC Regulatory Guide 1.97, Revision 2. As a result, specific variables were selected and specific design and qualification criteria developed to assure the safety of CPNPP. These variables and criteria are described in detail in Section 7.5
.Regulatory Guide 1.98Assumptions Used for Evaluating the Potential Radiological Consequences of a Radioactive Offgas System Failure in a Boiling Water Reactor DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.99Effects of Residual Elements on Predicted Radiation Damage to Reactor Vessel Materials Discussion Refer to Appendix 1A(N)
.
CPNPP/FSAR1A(B)-43Amendment No. 107Regulatory Guide 1.100Seismic Qualification of Electric Equipment for Nuclear Power Plants DiscussionThe CPNPP design for Class 1E Electrical Equipment complies with the requirements and recommendations of Revision 1 (8/77) of this regulatory guide with the following clarification:The intent of Section C.1 is met by performing an analysis to verify the approach and/or by following the Equivalent Static Load Method.
Also refer to Section 3.10B and Appendix 1A(N)
.Regulatory Guide 1.101Emergency Planning for Nuclear Power Plants
 
Discussion Section 13.3 Appendix A, "Emergency Planning," is intended to comply with the contents of Revision 3 (8/92) of this regulatory guide with the following exception:Luminant Power takes exception to the part of Section C which states licensees may use either NUREG 0654/FEMA-REP-1 or NUMARC/NESP-007 in developing their EAL scheme but may not use portions of both methodologies. CPNPP EALs reflect criteria from both documents and have been specifically reviewed and approved by NRC letter of October 6, 1994.Regulatory Guide 1.102Flood Protection for Nuclear Power Plants Discussion Plant grade for the CPNPP is located above the PMF level, and Category I structures, with the exception of the Service Water Intake Structure and the Electrical and Control Building, are not subject to flooding.The operating deck and safety-related equipment in the Service Water Intake Structure are located above the PMF level. Flooding of the El ectrical and Control Building is prevented by the use of incorporated barriers (i.e., isolation valves and/or stop-gates in the Circulating Water
 
System). Emergency operating procedures are discussed in Section 3.4 and 13.5. Therefore the CPNPP is in conformance with Revision 1 (9/76) of this regulatory guide.
Also refer to Sections 2.4 and 3.4.Regulatory Guide 1.103Post-Tensioned Prestressing Systems for Concrete Reactor Vessels and Containments CPNPP/FSAR1A(B)-44Amendment No. 107 DiscussionThis regulatory guide is not applicable to the CPNPP.Regulatory Guide 1.104Overhead Crane Handling Systems for Nuclear Power Plants DiscussionThis regulatory guide was withdrawn August 16, 1979.
CPNPP cranes and hoists which are required to be single failure proof are described in "CPNPP Final Response to NUREG-0612", dated June 1983. Also refer to sections 3.2.1.1.3
, 9.1.4.2 and 9.1.4.3.Regulatory Guide 1.105Instrument Setpoints
 
Discussion The CPNPP design complies with the provisions of Revision 2 (2/86) of this regulatory guide. Setpoint securing devices do not have separate physical locks (requiring an administratively controlled key). The adjustment of setpoints and release/securing of securing devices is controlled by administrative procedures.
Also refer to Appendix 1A(N) and Section 7.1
.Regulatory Guide 1.106Thermal Overload Protection for Electric Motors on Motor-Operated Valves DiscussionThe CPNPP design complies with the provisions of Revision 1 (3/77) of this regulatory guide as described in Section 8.3.1.1.11 Item 2.Regulatory Guide 1.107Qualifications for Cement Grouting for Prestressing Tendons in Containment Structures DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.108Periodic Testing of Diesel Generators Used As Onsite Electric Power Systems at Nuclear Power Plants CPNPP/FSAR1A(B)-45Amendment No. 107 DiscussionThe CPNPP design complies with the intent of Revision 1 (8/77) of this regulatory guide. 1.The requirements of position C. 1b.4 are satisfied as described below:a.Diesel generator (D-G) "Ready Stand by" status indication in the Control Room can be acknowledged by the combination of a green light for output breaker and the absence of a "D-G disable" and a "D-G trouble" annunciator indication.b."D-G Lockout" status is indicated by means of a "D-G disable" annunciation in the Control Room. This status is also indicated by "DG PWR" indication on the safety system bypass and inoperable status indicating light box in the Control Room due to any of the following:1.DC power unavailable 2.Remote-Local-Maintenance switch not in remote on the generator control panel.c."D-G undertest" status light is not provided in the CPNPP design.d.A means of communication is provided between the diesel generator room and the Control Room.2.The requirements of Regulatory Positions are clarified as described below:Regulatory Position C.2.a.(4)The largest single load is taken to be the largest single end load and not combined distribution system loads (e.g., distribution system transformers or load centers). This load is 783 kW equal to the nameplate rating of the Component Cooling Water pump.Regulatory Position C.2.dIf the number of failures in the last 100 valid tests is seven or more for an individual diesel generator unit, the reliability of that diesel gene rator requires special ev aluation (i.e., the reliability of both diesel generators is not impacted).3.The CPNPP periodic testing program meets the intent of the regulatory guide with the following exceptions:a.Regulatory Position C.2.a.3 During preoperational testing, testing will be conducted at the full-load-carrying capability for an interval of not less than 24 hours, of which 22 hours will be at the continuous rating capability of the diesel generator and 2 hours at a load equivalent to the two hour rating of the diesel generator. At a frequency specified in accordance with Technical Specification 5.5.21, "Surveillance Frequency Control Program", testing will be conducted to demonstrate full-load-carrying CPNPP/FSAR1A(B)-46Amendment No. 107capability for an interval of not less than 24 hours, of which 22 hours will be at a load which exceeds the maximum expected diesel generator load requirements and 2 hours at a load which is approximately 110% of this maximum expected load.b.Regulatory Position C.2.a.5Demonstrate functional capability at full load temperature conditions by rerunning the test phase outlined in Regulatory Po sition C.2.a.1 and by demonstrating proper operation for shutdown-loading-sequence to shutdown-load requirements immediately following the performance of C.2.a.3, except during preoperational testing when the proper operation for the design-accident-loading-sequence to design-load requirements will be demonstrated.c.Regulatory Position C.2.a.9Demonstrate the reliability of the Emergency Diesel Generator by performing at least a total of 69 (but no less than 35 per Emergency Diesel Generator) consecutive valid start and load tests on the Emergency Diesel Generators from cold ambient conditions to at least 50 percent continuous rating for at least 1 hour with no failures. These tests need not be performed as part of the pre-operational test program, but may be performed at any time prior to the required operability of the Emergency Diesel Generator.d.Regulatory Position C.2.c.2Periodic testing of the diesel generator units during normal plant operation to demonstrate full-load-carrying capability will be conducted at a load which exceeds the maximum expected diesel generator load requirements. During this
 
test, loading to the diesel generator is accomplished in accordance with vendor recommendations.e.Regulatory Position C.2.dDiesel generators testing frequency is in accordance with the requirements of the technical specifications.4.The requirements of Regulatory Position c.3.b is satisfied as described below:Other existing reporting requirements adequately ensure that the NRC learns of significant problems with diesel generator performance. Reporting requirements for EDG failures provided in this section will not be submitted.Regulatory Guide 1.109Calculation of Annual Doses to Man from Routine Releases of Reactor Effluents for the Purpose of Evaluating Compliance with 10 CFR Part 50, Appendix I CPNPP/FSAR1A(B)-47Amendment No. 107 DiscussionCompliance with Appendix I was evaluated in accordance with Revision 1 (10/77) of this regulatory guide.
Also refer to Appendix 11A
.Regulatory Guide 1.110Cost-Benefit Analysis for Radwaste Systems for Light-Water-Cooled Nuclear Power Reactors DiscussionThis regulatory guide is not applicable to the CPNPP.
Regulatory Guide 1.111Methods for Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Routine Releases from Light-Water-Cooled Reactors DiscussionThe methods of Revision 1 (7/77) of this regulatory guide were used in the evaluation of gaseous effluents as described in Appendix 11A
.Regulatory Guide 1.112Calculation of Releases of Radioactive Materials in Gaseous and Liquid Effluents from Light-Water-Cooled Power Reactors DiscussionThe radioactive source terms calculation presented in Section 11.1 complies with the requirements of Revision O-R (4/76 - reissued 5/77) of this regulatory guide.Regulatory Guide 1.113Estimating Aquatic Dispersion of Effluents from Accidental and Routine Reactor Releases for the Purpose of Implementing Appendix I DiscussionThe methods of Revision 1 (4/77) of this regulatory guide were used in the evaluation of effluents as described in Appendix 11A
.Regulatory Guide 1.114Guidance on Being Operator at the Controls of a Nuclear Power Plant CPNPP/FSAR1A(B)-48Amendment No. 107 DiscussionThe CPNPP administrative operating procedures will incorporate the applicable guidance of Revision 1 (11/76) of this regulatory guide.
Also refer to Section 13.5
.Regulatory Guide 1.115Protection Against Low Trajectory Turbine Missiles DiscussionThe turbines of the CPNPP are so oriented that low trajectory turbine missiles cannot strike any of the essential systems as discussed in Section 3.5. The CPNPP design is in compliance with Revision 1 (7/77) of this regulatory guide.Regulatory Guide 1.116Quality Assurance Requirements for Installation, Inspection, and Testing of Mechanical Equipment and Systems DiscussionThis regulatory guide is not applicable to CPNPP design and construction. The quality assurance methods for operations phase activities will comply with the applicable guidance contained in Revision 0-R (5/77) of this regulatory guide. Application of the requirements of ANSIN45.2.8 - 1975, as endorsed by this regulatory guide, will be in accordance with guidance contained in ANSI N18.7 - 1976.
Also refer to Section 17.2
.Regulatory Guide 1.117Tornado Design Classification DiscussionThe CPNPP structures, systems, and components are designed to withstand the effects of a design basis tornado, including tornado missiles, in conformance with Revision 1 (4/78) of this regulatory guide.
Also refer to Section 3.5
.Regulatory Guide 1.118Periodic Testing of Electric Power and Protection Systems CPNPP/FSAR1A(B)-49Amendment No. 107 DiscussionAlthough the implementation of this regulatory guide, dated June 1976, does not include CPNPP, the CPNPP electrical power systems are testable to the extent described in FSAR Section8.2.1.2.2
, 8.3.1.1.11 item 3 and 8.3.2.1 item 6.Regulatory Guide 1.119 Surveillance Program for New Fuel Assembly Designs DiscussionThis regulatory guide was withdrawn June 23, 1977.Regulatory Guide 1.120Fire Protection Guidelines for Nuclear Power Plants
 
DiscussionThe fire protection system design for CPNPP is in accordance with the criteria outlines in Appendix A to Branch Technical Position APCSB 9.5-1, "Guidelines for Fire Protection for Nuclear Power Plants Docketed Prior to 7/1/76."  The fire protection system design complies with the requirements for plants under construction except as stated in Section 9.5.1 of the FSAR. Where the guidelines of Revision 1 (11/77) of Regulatory Guide 1.120 are comparable with those of BTP APCSB 9.5-1, the former criteria are employed to the extent practical for the CPNPP design.The CPNPP Fire Protection Program is described in Section 9.5.1.6.1 and Appendix 13.3B
.Regulatory Guide 1.121Bases for Plugging Degraded PWR Steam Generator Tubes
 
Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.122Development of Floor Design Response Spectra for Seismic Design of Floor Supported Equipment or Components DiscussionFloor Design Response Spectra are developed in accordance with the methods described in Revision 1 (2/78) of this regulatory guide with the following conservative clarification to C.2:In constructing instructure response spectra, uncertainties inherent to the analysis, such as the material properties of the foundation material and the structures, damping values, soil structure CPNPP/FSAR1A(B)-50Amendment No. 107 interaction, approximations in modeling techniques and computation of structural natural frequencies, are accounted for by parametric variations incorporated into the analysis and by broadening the peaks of the resulting envelope response spectra.The procedure of parametric variations consists of evaluating and using in the dynamic analysis lower bound, best estimate, and upper bound values for the foundation spring constants in the case of all seismic Category I structures with the exception of the Fuel Building and the Service Water Intake Structure, where only lower bound and upper bound values are used. In addition, the analysis of the Containment Building is performed for each set of foundation spring constants by considering a cracked and an uncracked containment wall. Then, before smoothing of the
 
envelope spectra, which envelopes the spectra developed for each parametric variation, a minimum frequency shift to the peaks of + 10 percent is also incorporated to account for other variations in the structural properties which are not considered in the described parametric variation approach. This approach is more conservative than applying a peak shifting to spectral curves generated from a single dynamic model, without considering parametric variation.The Fuel Building was re-analyzed to determine the effects of added mass due to the addition of high density spent fuel storage racks. Best estimate soil properties were used in the re-rack analysis in lieu of parametric variations invol ving upper and lower bound soil properties. The resulting spectrum peak responses were widened by at least +/- 15% in accordance with RG1.122. The results from this approach remain conservative since results of previous studies show that variations in soil properties and building structure stiffness have minimal effect on the dynamic response of the Fuel Building.
Also see Section 3.7B.2.5
.Regulatory Guide 1.123Quality Assurance Requirements for Control of Procurement of Items and Services for Nuclear Power Plants DiscussionThe quality assurance program for design and construction at CPNPP incorporates the intended objectives of ANSI N45.2.13 (Draft dated 5/73). The quality assurance methods and administrative controls utilized in the procurement of quality-related items and services, during the operations phase, as described in Section 17.2
, will be consistent with the applicable guidance contained in Revision 1 (7/77) of this regulatory guide. The application of the provisions of ANSI N45.2.13 - 1976, as endorsed by this regulatory guide, will be in accordance with the guidance provided in ANSI N18.7 - 1976 except for imposing quality assurance program requirements consistent with 10CFR50 Appendix B or ANSI N45.2 in procurement documents for commercial grade calibration services from a NVLA P or A2LA accredited calibration laboratory evaluated in accordance with Section 17.2.7.Regulatory Guide 1.124Design Limits and Loading Combinations for Class 1 Linear-Type Component Supports CPNPP/FSAR1A(B)-51Amendment No. 107 DiscussionAll non-NSSS supplied Class I linear-type supports comply with Revision 1 (1/78) of this regulatory guide, with the following exceptions: 1.Paragraph C.4 (which is also referenced in Paragraphs C.5 and C.7) Service limits for bolts shall be increased for Service Level D (faulted) plant conditions. The increased allowable permitted for tensile stress in bolts shall not exceed the lesser of 0.7 Su or Sy at temperature. The increased allowable permitted for shear stress in bolts shall not exceed the lesser of 0.42 Su or 0.6 Sy. This exception is implemented by the use of ASME III Subsection NF paragraphs NF-3225 and NF-3324.6 of the 1983 Edition -
Summer 1983 Addenda for the design of bolting. The current industry position on the design of bolting is that the maximum safe increased allowables are achieved by limiting bolting tensile stress to the lesser of 0.7 Su or Sy at temperature and bolting shear stress to 0.42 Su or 0.6 Sy at temperature. The 0.7 Su limit is well recognized in Section III of the Code. The average shear strength of bolting material is about 0.62 Su according to test data, with a standard deviation of 0.033.
Results indicate that the ratio of sear strength to tensile strength is independent of the bolt grade. Curves showing this appear on page 50 of "Guide to Design for Bolted and Riveted Joints," by J. W. Fisher. Test data are given in a paper by J. J. Wallaert and J.W.Fisher, "Shear strength of High-Strength Bolts," Journal of the Structural Division, ASCE, Volume 91, ST3, June 1965. 2.Paragraph C.8 (which is also referenced in Paragraphs C.6 and C.7) As stated in Appendix 1A(N) of Section 1.0, system functional capability is provided for in Class 1 piping systems by maintaining the pipe stresses within Level D (faulted) limits.
This assures that piping geometry is maintained and that required flow is not impaired. The selection of more restrictive stress limits for component supports is not necessary to assure the functional capability of the system. However, to provide additional conservatism, ASME Class 1 component supports associated with the Safety Injection System and the Containment Spray system are designed to the limits described in Regulatory Position C-6 for Level C (emergency) conditions when subjected to the loadings associated with the Level D (faulted) plant condition.
Also refer to Appendix 1A(N) for a discussion of NSSS-supplied Class 1 supports. Regulatory Guide 1.125Physical Models for Design and Operation of Hydraulic Structures and Systems for Nuclear Power Plants DiscussionThis regulatory guide is not applicable to CPNPP.
CPNPP/FSAR1A(B)-52Amendment No. 107Regulatory Guide 1.126An Acceptable Model and Related Statistical Methods for the Analysis of Fuel Densification Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.127Inspection of Water-Control Structures Associated with Nuclear Power Plants
 
DiscussionCPNPP commits to comply with the requirements of Revision 1 (3/78) of this regulatory guide for the Safe Shutdown Impoundment in the manner described in Chapters 2.4 and 2.5 of the FSAR. Additionally, inspections addressed in the guide relative to Embankment Slope Stability, Unlined Saddle Spillways, the Reservoir proper and the Intake Structure and Discharge Channel will be accomplished.This guide is not applicable to Squaw Creek Dam which is not safety related.Regulatory Guide 1.128Installation Design and Installation of Large Lead Storage Batteries for Nuclear Power Plants DiscussionThis regulatory guide is not applicable to CPNPP.Regulatory Guide 1.129Maintenance, Testing, and Replacement of Large Lead Storage Batteries for Nuclear Power PlantsDiscussionThe CPNPP design complies with the provisions of Revision 1 (2/78) of this regulatory guide, with the clarification that IEEE 450-1995 applies instead of IEEE 450-1975 as endorsed by the regulatory guide. Refer to Section 8.3 for further discussion.Regulatory Guide 1.130Service Limits and Loading Combinations for Class 1 Plate-and-Shell-Type Component Supports Discussion Refer to Appendix 1A(N)
.
CPNPP/FSAR1A(B)-53Amendment No. 107Regulatory Guide 1.131Qualification Tests of Electric Cables, Field Splices, and Connections for Light-Water-Cooled Nuclear Power Plants DiscussionAlthough the implementation of this regulatory guide, dated August 1977, does not include CPNPP, all Class 1E cables and field splices of the CPNPP meet most of the requirements of this regulatory guide with the few exceptions noted below:1.All prefabricated cables of the CPNPP do not meet the following requirements:a.Vertical tray flame test on the aged cables to determine their relative self-extinguishing tendencies.  (
Regulatory Guide position C.6),b.Flame testing with the gas burner face in the front (Regulatory Guide positionC.10). However, work is in progress by vendor on these items.2.All 8kv cables, 600V power and lighting cables of the CPNPP do not meet the following requirements:a."Radiation Exposure Total" - per Regulatory Guide 1.89 Position C.5.
b.Vertical tray flame test on the aged cables to determine their relative self-extinguishing tendencies. 
(Regulatory Guide position C.6).c.Flame testing with the gas burner face in the front (Regulatory Guide positionC.10).d.Gas and air flow requirements (Regulatory Guide position C.11).3.All Raychem type WCSF-N field splices of the CPNPP have not been tested according to the following regulatory guide positions:a.Vertical tray flame test on aged cable splices to determine their relative self-extinguishing tendencies.  (Regulatory Guide Position C.6).b.Flame testing with only natural grade propane and a release of approximately 70,000 BTU per hour at an air-gas ra tio of 5 to 1.  (Regulatory Guide PositionC.9).c.Flame testing with the gas burner face in the front.  (Regulatory Guide PositionC.10).d.Gas and air flow requirements.  (Regulatory Guide Position C.11).e.Flame temperature requirements.  (Regulatory Guide Position C.13).
CPNPP/FSAR1A(B)-54Amendment No. 1074.The Partial Discharge Monitor Bus Coupler jumpers (15 kV rated) installed in the motor and emergency diesel generator termination boxes are not flame retardant and are not qualified to the requirement s of Regulatory Guide 1.131.Regulatory Guide 1.132Site Investigations for Foundations of Nuclear Plants DiscussionThis regulatory guide is not applicable to CPNPP.
Regulatory Guide 1.133 Loose-Part Detection Program for the Primary System of Light-Water-Cooled Reactors DiscussionThe CPNPP O.L. Application was docketed prior to June 1, 1978, as provided by this guide dated September 1977.A discussion of the CPNPP loose parts monitoring system is provided in Section 4.4.6.4
.Regulatory Guide 1.134 Medical Evaluation of Nuclear Power Plant Personnel Requiring Operator Licenses DiscussionThe medical certification and monitoring requirements of licensed personnel comply with the requirements of Revision 2 (4/87) of this regulatory guide.Regulatory Guide 1.135Normal Water Level and Discharge at Nuclear Power Plants DiscussionThis regulatory guide is not applicable to CPNPP.
Regulatory Guide 1.136Material for Concrete Containments DiscussionThis regulatory guide is not applicable to CPNPP; however, the application of ACI-359 is discussed in Section 3.8.1.2.1
.
CPNPP/FSAR1A(B)-55Amendment No. 107Regulatory Guide 1.137Fuel-Oil Systems for Standby Diesel Generators DiscussionThe CPNPP design complies with the requirements of this regulatory guide, dated January 1978, with the following exception to portions of Parts C.1, C.1.b, C.1.d, C.1.g, C.2.b, C.2.c; and C.2.d:1.Part C.1.b (Paragraph 7.1 of ANSI N195-1976 [49]):Venting components for the storage and day tanks are not safety class 3. However, piping and components are seismically supported and missile protection requirements are satisfied for the vent path.2.Part C.1.d (Paragraph 6.1 of ANSI N195-1876):The suction from the day tank is provided from the bottom of the tank.3.Part C.1.g (Paragraph 7.5 of ANSI N195-1976):Fill lines to the storage and day tanks do not have strainers.4.Part C.2.b:Prior to addition of new fuel into the storage tanks, the fuel is tested in accordance with tests specified in ASTM D975-1981 for:
a.aAPI or Specific Gravity when tested in accordance with ASTM D1298-1980b.Kinematic viscosityc.Flash pointd.Water and Sediment (Either a Clear and Bright Test, ASTM D4176-1982 or a water and sediment content of less than or equal to 0.05% volume when tested in accordance with ASTM D1796-1968)The remainder of the tests specified in Table-1 of ASTM D975-1981 will be completed within 31 days of the fuel addition and fuel oil will meet the requirements when tested in accordance with ASTM D975-1981 except that the analysis for sulphur may be performed
 
in accordance with ASTM D1552-1979 [46], ASTM D2622-1982 [47], or ASTM D4294-2003.a.If new fuel oil does not meet the diesel generator manufacturer's requirements for absolute specific gravity at 60/60 oF of > 0.8299 or for API gravity at 60 oF of < 39o, it is acceptable to add new fuel oil to the storage tank(s) only if, after being added, the entire storage tank(s) will meet the manufacturer's recommendations.
CPNPP/FSAR1A(B)-56Amendment No. 1075.Part C.2.c:New fuel sampling procedures for the fuel oil will be in accordance with ASTMD4057-1981, "Standard Practice for Manual Sampling of Petroleum and Petroleum Products".6.Part C.1 (Paragraph 6.3 of ANSI N195-1976):The strainers provided in the diesel fuel oil transfer system are not duplex strainers.7.Part C.2.d:Accumulated condensate is checked for, and removed from storage tanks at least every 31 days.8.C.1 (Section 4 of ANSI N195-1976):Section 4 of the standard includes requirements for security for the diesel-generator fuel-oil system. The requirements of this section are not considered applicable to the CPNPP Security Plan since this subject is addressed separately in more detail in other NRC documents. See Section 13.6 for a description of security requirements.9.C.2.aIf new fuel oil does not meet the diesel generator manufacturer's requirements for absolute specific gravity at 60/60 oF of > 0.8299 or for API gravity at 60 oF of < 39o, it is acceptable to add new fuel oil to the storage tank(s) only if, after being added, the entire storage tank(s) will meet the manufacturer's recommendations.
Also refer to Section 9.5.4
.Regulatory Guide 1.138Laboratory Investigations for Soils for Engineering Analysis and Design Of Nuclear Power Plants
 
DiscussionThis regulatory guide is not applicable to CPNPP; however, soils investigations are discussed in Section 2.5
.Regulatory Guide 1.139Guidance for Residual Heat Removal Discussion Refer to Appendix 1A(N)
.
CPNPP/FSAR1A(B)-57Amendment No. 107Regulatory Guide 1.140Design, Testing and Maintenance Criteria for Normal Ventilation Exhaust System Air Filtration and Absorption Units of Light-Water-Cooled Nuclear Power Plants DiscussionThe CPNPP design, maintenance and testing of the normal HVAC systems is in compliance with the requirements of Regulatory Guide 1.140 (03/78) except part C.3.h, water drains; part C.4.b, ease of maintenance; part C.4.c, test probes;, part C.5.b, air flow distribution; parts C.5.c and C.5.d, in-place testing; and part C.6, laboratory testing criteria for activated carbon. 1.Part C.3.h, Water drains:Check valves have been used on some drains in lieu of seals or traps. The drains for the demister compartments of the Hydrogen Purge Filtration units have not been provided with seals, traps, or check valves. Any minimal airflow through the demister drain will be filtered prior to discharge at the stack. This design conforms to the intent of NRC Regulatory Guide 1.140 (03/78).2.Part C.4.b, Ease of Maintenance: The spacing provided between the components of the filtration units is, in some cases, less than the minimum required by this regulatory position. However, it has been determined by operation and maintenance personnel that the spacing provided is sufficient to perform all the required maintenance operations. This design conforms to the intent of Regulatory Guide 1.140 (03/78). 3.Part C.4.c, Test Probes: Test ports will be provided in lieu of permanently installed test probes. Permanently installed probes are a convenience in the periodic testing of filters and adsorbers.
Replacing them with test ports is of no safety significance. This design meets the intent of NRC Regulatory Guide 1.140 (03/78). 4.Part C.5.b, Air Flow Distribution: The air flow distribution to the HEPA filters and iodine adsorbers will be tested in place for uniformity initially and after maintenance affecting the flow distribution for all units except the hydrogen purge units.5.Parts C.5.c and C.5.d, In-Place Testing Criteria ANSI/ASME N509-1980 and ANSI/ASME N510-1980 shall be used for field testing activities in place of the older versions of these codes referenced in this regulatory guide. Atmospheric cleanup trains installed at CPNPP have two HEPA filter banks in series with a charcoal adsorber between them. In-place testing of the upstream HEPA bank only will be performed.
CPNPP/FSAR1A(B)-58Amendment No. 107In-place testing of the HEPA filter ba nks and adsorber will not be required following painting, fire and chemical release described in position C.5.c and C.5.d of this guide. Only laboratory testing will be performed for carbon efficiencies. This design conforms to the intent of NRC Regulatory Guide 1.140 (03/78). HEPA filter and charcoal adsorber efficiency for non-Engineered Safety Feature Filtration Units is 90% which corresponds to an acceptance criteria of less than 1% for in-place penetration and bypass leakage at rated flow.The in-place testing of the HEPA filter and charcoal adsorber for the containment preaccess filtration units is performed in accordance with ANSI N510-1980, Table 1, NOTES 2 & 5. As discussed in FSAR section 9.4A, the preaccess filtration system is a recirculating system inside containment that reduces airborne contamination inside containment prior to personnel entry. Leakage through the HEPA or charcoal adsorber would not contribute to any increased radiological release to the environment. This design conforms to the intent of Reg. Guide 1.140 (3/78).6.Part C.6, Laboratory Testing Criteria for Activated Carbon:
Laboratory testing of activated carbon will be in accordance with ANSI N509 and N510-1980 (which refers to ASTM D3803-79), except for the determination of the efficiency of charcoal to remove radioiodine. The parameters applicable to new and used charcoal at CPNPP shall be applied in the lab test as follows:
New and Used Charcoal 4" Beds 40 ft/min 30&deg;C & 95% RH Pre-equilibrated The allowable methyl iodide penetration for these units shall be 10% as shown in Table 2 of the Regulatory Guide. When all or most of the charcoal canisters in the filtration units have been used, a representative sample of the charcoal from the bed will be obtained by grain thief sampling in accordance with ANSI N509-1980, Appendix A. The representative samples obtained with the grain thief will be used for laboratory testing and/or refilling the charcoal canisters.The carbon adsorber beds will be replaced w hen (1) testing in accordance with the frequency specified in Footnote c of Table 2 results in a representative sample failing to pass the applicable test in Table 2 or (2) no representative sample is available for testing, at a time when testing is required.This design conforms to the intent of NRC Regulatory Guide 1.140 (03/78). Regulatory Guide 1.141Containment Isolation Provisions for Fluid Systems CPNPP/FSAR1A(B)-59Amendment No. 107 DiscussionThis regulatory guide is not applicable to CPNPP; however, the containment isolation is discussed in Section 6.2
.Regulatory Guide 1.142Safety-Related Concrete Structures for Nuclear Power Plants (Other Than Reactor Vessels and Containments)
DiscussionThis regulatory guide is not applicable to CPNPP; however the design of safety-related concrete structures is discussed in Section 3.8
.Regulatory Guide 1.143Design Guidance for Radioactive Waste Management Systems, Structures, and Components Installed in Light-Water-Cooled Nuclear Power Plants DiscussionThis regulatory guide is not applicable to CPNPP, however, the code, code class, safety class, and seismic classification of Liquid Waste Processing and Gaseous Waste Processing System components comply with Table 1 of Regulatory Guide 1.143, Rev. 1. Reference Section 11.2
, 11.3 and 11.4 for related information.Regulatory Guide 1.144Auditing of Quality Assurance Programs for Nuclear Power Plants
 
DiscussionThe program for auditing of Quality Assurance Programs for CPNPP complies with the requirements of Regulatory Guide 1.144 Revision 1 (9/80). The following suppliers are not audited by Luminant Power and are exempt from the requirements of this regulatory guide: National or state calibration sources
 
Authorized Nuclear Inspection Agency NVLAP and A2LA accredited commercial grade calibration suppliers evaluated in accordance with Section 17.2.7.Regulatory Guide 1.145 Atmospheric Dispersion Models for Potential Accident Consequence Assessments at Nuclear Power Plants CPNPP/FSAR1A(B)-60Amendment No. 107 DiscussionThis regulatory guide is not applicable to CPNPP.Regulatory Guide 1.146Qualification of Quality Assurance Program Audit Personnel for Nuclear Power Plant DiscussionEffective June 1, 1983, CPNPP Quality Assurance Audit Personnel are in compliance with regulatory guide 1.146, August 1980.Regulatory Guide 1.148Functional Specification for Active Valve Assemblies in Systems Important to Safety in Nuclear Power Plants DiscussionCPNPP is not committed to this Regulatory Guide. The operability program for active valves is covered in Section 3.9N and 3.9B.Regulatory Guide 1.150Ultrasonic Testing of Reactor Vessel Welds During Preservice and Inservice Examinations.
Discussion Refer to Appendix 1A(N)
.Regulatory Guide 1.155 Station Blackout DiscussionCPNPP complies with the guidance of Regulatory Guide 1.155 (August 1988) as described in Appendix 8B
.Regulatory Guide 1.163Performance-Based Containment Leak-Test Program DiscussionEffective by August 12, 1996, CPNPP complies with Regulatory Guide 1.163, September 1995.
CPNPP/FSAR1A(B)-61Amendment No. 107Regulatory Guide 1.195Methods and Assumptions for Evaluating Radiological Consequences of Design Basis Accidents at Light-Water Nuclear Power Reactors, May 2003.
DiscussionThe radiological consequences analysis for the design basis accidents follow the guidance provided in Regulatory Guide 1.195 and CPNPP adopts the dose limits defined by Regulatory Guide 1.195. The CPNPP design for skin dose calculations DCFs uses DOE/EH-0070 instead of Figure 12 recommended in Regulatory Guide 1.195.Regulatory Guide 1.196Control Room Habitability at Light-Water Nuclear Power Reactors, May 2003.
DiscussionThe Control Room Envelope Habitability Program in Technical Specification 5.5.20 is consistent with the guidance of TSTF-448, Revision 3, which incorporate the specific aspects of Regulatory
 
Guides 1.196 and 1.197. CPNPP currently uses RG 1.52, Revision 1 for the control room design. CPNPP used Revision 2 for testing only. CPNPP uses RG 1.140 as information only for non-safety related air filtration systems.Regulatory Guide 1.197Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors, May 2003.
DiscussionThe Control Room Envelope Habitability Program in Technical Specification 5.5.20 is consistent with the guidance of TSTF-448, Revision 3, which incorporates the specific aspects of Regulatory Guide 1.197 with the following exceptions:1.C. - Section 4.3.2 "Periodic CRH Assessment" from NEI 99-03 Revision 1 will be used as input to a site specificSelf assessment procedure.2.C.1.2 - No peer reviews are required to be performed.
CPNPP/FSAR2-iAmendment No. 1042.0  SITE CHARACTERISTICSTABLE OF CONTENTS SectionTitlePage2.1GEOGRAPHY AND DEMOGRAPHY.........................................................................2.1-1 2.1.1SITE LOCATION AND DESCRIPTION.................................................................2.1-12.1.1.1Specification of Location.................................................................................2.1-12.1.1.2Site Area..........................................................................................................2.1-12.1.1.3Boundaries For Establishing Effluent Release Limits......................................2.1-1 2.1.2EXCLUSION AREA AUTHORITY AND CONTROL..............................................2.1-22.1.2.1Authority..........................................................................................................2.1-22.1.2.1.1Surface Rights.................................................................................................2.1-2 2.1.2.1.2Mineral Rights.................................................................................................2.1-22.1.2.1.3Easements......................................................................................................2.1-32.1.2.1.4Status of Ownership........................................................................................2.1-3 2.1.2.1.5Minimum Exclusion Area Distance..................................................................2.1-4 2.1.2.2Control of Activities Unrelated to Plant Operation...........................................2.1-42.1.2.3Arrangements for Traffic Control.....................................................................2.1-42.1.2.4Abandonment or Relocation of Roads............................................................2.1-4 2.1.3POPULATION DISTRIBUTION.............................................................................2.1-42.1.3.1Population Within 10 Miles..............................................................................2.1-62.1.3.1.1Current Population Within 10 Miles.................................................................2.1-6 2.1.3.1.2Projected Population Within 10 Miles..............................................................2.1-92.1.3.1.3Age Distribution of Population Within 10 Miles................................................2.1-92.1.3.2Population Within 10 to 50 Miles.....................................................................2.1-9 2.1.3.2.1Current Population Within 10 to 50 Miles........................................................2.1-92.1.3.2.2Projected Population Within 10 to 50 Miles...................................................2.1-102.1.3.2.3Age Distribution of Population Within 10 to 50 Miles.....................................2.1-10 2.1.3.3Transient Population.....................................................................................2.1-102.1.3.3.1Seasonal Variation........................................................................................2.1-112.1.3.3.2Daily Variation...............................................................................................2.1-11 2.1.3.3.3Summary Effect of Transient Population Movements in 10-Mile Area..........2.1-122.1.3.4Low Population Zone.....................................................................................2.1-122.1.3.5Population Center..........................................................................................2.1-13 2.1.3.6Population Density........................................................................................2.1-132.2NEARBY INDUSTRIAL, TRANSPORTATION AND MILITARY FACILITIES.................................................................................................................2.2-12.2.1LOCATIONS AND ROUTES.................................................................................2.2-12.2.2DESCRIPTIONS...................................................................................................2.2-12.2.2.1Description of Facilities...................................................................................2.2-12.2.2.2Description of Products and Materials.............................................................2.2-1 2.2.2.3Pipelines And Wells.........................................................................................2.2-22.2.2.4Waterways.......................................................................................................2.2-22.2.2.5Aircraft.............................................................................................................2.2
-2 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage2-iiAmendment No. 1042.2.2.5.1Airports............................................................................................................2.
2-22.2.2.5.2Air Routes........................................................................................................2.2-22.2.2.6Projections of Industrial Growth......................................................................2.2-32.2.3EVALUATION OF POTENTIAL ACCIDENTS.......................................................2.2-32.2.3.1Determination of Design Basis Events............................................................2.2-32.2.3.1.1Explosions.......................................................................................................2.2-32.2.3.1.2Flammable Vapor Clouds................................................................................2.2-4 2.2.3.1.3Toxic Chemicals..............................................................................................2.2-42.2.3.1.4Fires................................................................................................................2.2-42.2.3.1.5Collision with Intake Structure.........................................................................2.2-4 2.2.3.1.6Liquid Spills.....................................................................................................2.2-42.2.3.2Effects of Design Basis Events.......................................................................2.2-42.2.3.2.1Gas Pipeline and Gas Well Accidents.............................................................2.2-5 2.2.3.2.2Accidental Release of Toxic Chemicals..........................................................2.2-82.2.3.2.3Oil Pipeline Accidents......................................................................................2.2-9REFERENCES....................................................................................................2.2-122.3METEOROLOGY........................................................................................................2.3-12.3.1REGIONAL METEOROLOGY...............................................................................2.3-12.3.1.1General Climate..............................................................................................2.3-12.3.1.2Regional Meteorological Conditions for Design and Operating Bases............2.3-22.3.1.2.1General............................................................................................................2.3
-22.3.1.2.2Hurricanes.......................................................................................................2.3-22.3.1.2.3Tornadoes.......................................................................................................2.3-32.3.1.2.4Thunderstorms................................................................................................2.3-5 2.3.1.2.5Lightning..........................................................................................................2.3
-52.3.1.2.6Hail..................................................................................................................2.3-52.3.1.2.7Air Pollution Potential......................................................................................2.3-6 2.3.1.2.8Precipitation.....................................................................................................2.3-62.3.1.2.9Dust Storms.....................................................................................................2.3-82.3.1.2.10Ultimate Heat Sink...........................................................................................2.3-8 2.3.1.2.11Extreme Winds................................................................................................2.3-92.3.2LOCAL METEOROLOGY.....................................................................................2.3-92.3.2.1Normal and Extreme Values of Meteorological Parameters............................2.3-9 2.3.2.1.1General............................................................................................................2.3
-92.3.2.1.2Surface Winds.................................................................................................2.3-92.3.2.1.3Temperatures................................................................................................2.3-10 2.3.2.1.4Water Vapor..................................................................................................2.3-112.3.2.1.5Precipitation...................................................................................................2.3-112.3.2.1.6Fog................................................................................................................2.3
-112.3.2.1.7Atmospheric Stability.....................................................................................2.3-122.3.2.1.8Mixing Heights...............................................................................................2.3-122.3.2.1.9Representativeness of the Onsite Data.........................................................2.3-12 2.3.2.2Potential Influence of the Plant and Its Facilities on Local Meteorology.......2.3-13 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage2-iiiAmendment No. 1042.3.2.2.1General..........................................................................................................2.3-1 32.3.2.2.2Impact of Squaw Creek Reservoir.................................................................2.3-132.3.2.2.3Topographical Description.............................................................................2.3-162.3.2.3Local Meteorological Conditions for Design and Operating Bases...............2.3-17 2.3.3ONSITE METEOROLOGICAL MEASUREMENTS PROGRAM.........................2.3-172.3.3.1Pre-Operational Program..............................................................................2.3-172.3.3.1.1Instrumentation and Recording Systems......................................................2.3-18 2.3.3.1.2Maintenance and Calibration.........................................................................2.3-192.3.3.1.3Data Processing............................................................................................2.3-192.3.3.2Operational Program.....................................................................................2.3-22 2.3.3.3Wind Roses By Pasquill Stability Classes.....................................................2.3-242.3.4SHORT-TERM (ACCIDENT) DIFFUSION ESTIMATES.....................................2.3-252.3.4.1Objective.......................................................................................................2.3-25 2.3.4.2Calculations...................................................................................................2.3-252.3.4.2.1The Diffusion Model for Two Hours or Less..................................................2.3-252.3.4.2.2Estimated Values of One-Hour Dilution Factors............................................2.3-27 2.3.4.2.3Diffusion Estimates for Periods Greater Than Two Hours.............................2.3-27 2.3.4.2.4Representativeness and Topographic Effects...............................................2.3-272.3.5LONG-TERM (ROUTINE) DIFFUSION ESTIMATES.........................................2.3-282.3.5.1Objective.......................................................................................................2.3-28 2.3.5.2Calculations...................................................................................................2.3-28REFERENCES....................................................................................................2.3-292.4HYDROLOGIC ENGINEERING..................................................................................2.4-12.4.1HYDROLOGIC DESCRIPTION.............................................................................2.4-12.4.1.1Site and Facilities............................................................................................2.4-12.4.1.2Hydrosphere....................................................................................................2.4-22.4.1.2.1Regional Description.......................................................................................2.4-2 2.4.1.2.2Squaw Creek...................................................................................................2.4-32.4.1.2.3Paluxy River....................................................................................................2.4-32.4.1.2.4River Control Structures..................................................................................2.4-3 2.4.1.2.5Surface Water Users.......................................................................................2.4-42.4.1.2.6Groundwater Environment..............................................................................2.4-42.4.2FLOODS................................................................................................................2.4-42.4.2.1Flood History...................................................................................................2.4-42.4.2.1.1Brazos River....................................................................................................2.4-42.4.2.1.2Squaw Creek...................................................................................................2.4-5 2.4.2.1.3Paluxy River....................................................................................................2.4-52.4.2.1.4Flood Causes..................................................................................................2.4-52.4.2.2Flood Design Considerations..........................................................................2.4-5 2.4.3PROBABLE MAXIMUM FLOOD (PMF) ON STREAMS AND RIVERS................2.4-62.4.3.1Probable Maximum Precipitation (PMP).........................................................2.4-62.4.3.2Precipitation Losses........................................................................................2.4-7 2.4.3.3Runoff Model...................................................................................................2.4-8 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage2-ivAmendment No. 1042.4.3.3.1Description of Squaw Creek Reservoir Catchment.........................................2.4-82.4.3.3.2Synthetic Hydrographs....................................................................................2.4-82.4.3.3.3Hydrograph Development...............................................................................2.4-82.4.3.3.4Non-Linearity...................................................................................................2.4-9 2.4.3.3.5Translation of Inflows......................................................................................2.4-92.4.3.4Probable Maximum Flood Flow.....................................................................2.4-102.4.3.5Water Level Determinations..........................................................................2.4-10 2.4.3.6Coincident Wind Wave Activity......................................................................2.4-102.4.3.7Flood Evaluations for Safe Shutdown Impoundment....................................2.4-112.4.4POTENTIAL DAM FAILURES (SEISMICALLY INDUCED)................................2.4-12 2.4.4.1Reservoir Description....................................................................................2.4-122.4.4.2Dam Failure Permutations.............................................................................2.4-122.4.4.3Unsteady Flow Analysis of Potential Dam Failures.......................................2.4-12 2.4.4.3.1Morris Sheppard Dam Break.........................................................................2.4-132.4.4.3.2Routing From Morris Sheppard Dam to DeCordova Bend Dam...................2.4-142.4.4.3.3DeCordova Bend Dam Break........................................................................2.4-15 2.4.4.3.4Routing from Decordova Bend......................................................................2.4-16 2.4.4.3.5Consideration of Antecedent Flow................................................................2.4-172.4.4.4Water Level at CPNPP..................................................................................2.4-172.4.5PROBABLE MAXIMUM SURGE AND SEICHE FLOODING..............................2.4-17 2.4.5.1Probable Maximum Winds and Associated Meteorological Parameters.......2.4-172.4.5.2Surge and Seiche History..............................................................................2.4-172.4.5.3Surge and Seiche..........................................................................................2.4-18 2.4.5.4Wave Action..................................................................................................2.4-182.4.5.5Resonance....................................................................................................2.4-182.4.5.6Runup............................................................................................................2.4-18 2.4.6PROBABLE MAXIMUM TSUNAMI FLOODING..................................................2.4-182.4.7ICE FLOODING...................................................................................................2.4-182.4.8COOLING WATER CANALS AND RESERVOIRS.............................................2.4-192.4.8.1Canals...........................................................................................................2.4-192.4.8.2Reservoirs.....................................................................................................2.4-192.4.8.2.1Squaw Creek Reservoir (SCR).....................................................................2.4-19 2.4.8.2.2Safe Shutdown Impoundment (SSI)..............................................................2.4-222.4.9CHANNEL DIVERSIONS....................................................................................2.4-232.4.10FLOODING PROTECTION REQUIREMENTS...................................................2.4-24 2.4.11LOW WATER CONSIDERATIONS.....................................................................2.4-242.4.11.1Low Flow In Rivers And Streams..................................................................2.4-242.4.11.2Low Water Resulting From Surges, Seiches or Tsunamis............................2.4-26 2.4.11.3Historical Low Water.....................................................................................2.4-272.4.11.4Future Control...............................................................................................2.4-272.4.11.5Plant Requirements.......................................................................................2.4-27 2.4.11.6Heat Sink Dependability Requirements.........................................................2.4-282.4.12DISPERSION, DILUTION, AND TRAVEL TIME OF ACCIDENTAL RELEASES OF LIQUID EFFLUENTS IN SURFACE WATERS.........................2.4-302.4.12.1Introduction....................................................................................................2.4-30 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage2-vAmendment No. 1042.4.13GROUNDWATER...............................................................................................2.4-302.4.13.1Description and On-Site Use.........................................................................2.4-312.4.13.1.1General Groundwater Features.....................................................................2.4-312.4.13.1.2Twin Mountains Formation............................................................................2.4-32 2.4.13.1.3Glen Rose Formation....................................................................................2.4-332.4.13.1.4Paluxy Formation..........................................................................................2.4-342.4.13.1.5Onsite Water Table.......................................................................................2.4-34 2.4.13.1.6Water Quality.................................................................................................2.4-342.4.13.1.7Onsite Water Uses........................................................................................2.4-352.4.13.2Sources.........................................................................................................2.4-35 2.4.13.2.1Regional Use.................................................................................................2.4-352.4.13.2.2Local Use......................................................................................................2.4-362.4.13.3Accident Effects.............................................................................................2.4-38 2.4.13.3.1Introduction....................................................................................................2.4-3 82.4.13.3.2Description of the Model................................................................................2.4-382.4.13.3.3Selection of Parameters................................................................................2.4-39 2.4.13.3.4Computation Results.....................................................................................2.4-41 2.4.13.4Monitoring or Safequard Requirements........................................................2.4-412.4.13.5Design Bases for Subsurface Hydrostatic Loading.......................................2.4-412.4.14TECHNICAL SPECIFICATION AND EMERGENCY OPERATION REQUIREMENTS...............................................................................................2.4-42REFERENCES....................................................................................................2.4-422.5GEOLOGY AND SEISMOLOGY.................................................................................2.5-12.5.1BASIC GEOLOGICAL AND SEISMIC INFORMATION........................................2.5-12.5.1.1Regional Geology............................................................................................2.5-32.5.1.1.1Physiography and Geologic Setting................................................................2.5-32.5.1.1.2Geologic History..............................................................................................2.5-4 2.5.1.1.3Stratigraphy.....................................................................................................2.5-62.5.1.1.4Structure..........................................................................................................2.5
-82.5.1.1.5Stability of Subsurface Materials...................................................................2.5-13 2.5.1.1.6Groundwater..................................................................................................2.5-132.5.1.2Site Geology..................................................................................................2.5-132.5.1.2.1Physiography.................................................................................................2.5-13 2.5.1.2.2Geologic History............................................................................................2.5-142.5.1.2.3Stratigraphy...................................................................................................2.5-152.5.1.2.4Structure........................................................................................................2.5-1 92.5.1.2.5Groundwater..................................................................................................2.5-202.5.1.2.6Engineering Geological Evaluation...............................................................2.5-202.5.2VIBRATORY GROUND MOTION.......................................................................2.5-31 2.5.2.1Seismicity......................................................................................................2.5-312.5.2.1.11882, October 22 - Bonham (Paris), Texas Earthquake...............................2.5-332.5.2.1.21891, January 8 - Rusk, Texas Earthquake..................................................2.5-34 2.5.2.1.31930, October 19 - Donaldsonville, Louisiana Earthquake...........................2.5-35 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage2-viAmendment No. 1042.5.2.1.41931, August 16 - Valentine, Texas Earthquake...........................................2.5-362.5.2.1.51932, April 9 - Wortham-Mexia, Texas Earthquake......................................2.5-372.5.2.1.61952, April 9 - El Reno, Oklahoma Earthquake............................................2.5-402.5.2.1.71959, June 17 - Lawton, Oklahoma Earthquake...........................................2.5-40 2.5.2.2Geologic Structure and Tectonic Activity.......................................................2.5-402.5.2.2.1Regional Tectonic Provinces.........................................................................2.5-412.5.2.2.2Geologic Structures and Faults.....................................................................2.5-45 2.5.2.3Correlation of Epicenters with Geologic Structures or Tectonic Provinces...2.5-522.5.2.3.1West Central Texas Tectonic Province.........................................................2.5-522.5.2.3.2Wichita Tectonic Province.............................................................................2.5-52 2.5.2.3.3Seminole Arch-Nemaha Uplift Province........................................................2.5-532.5.2.3.4Ouachita Tectonic Province..........................................................................2.5-532.5.2.3.5Mesozoic Shelf Tectonic Province................................................................2.5-53 2.5.2.3.6Balcones-Mexia-Talco Tectonic Province.....................................................2.5-542.5.2.3.7Gulf Coast Tectonic Province........................................................................2.5-542.5.2.3.8Far West Texas.............................................................................................2.5-54 2.5.2.4Maximum Earthquake Potential....................................................................2.5-54 2.5.2.5Seismic Wave Transmission Properties of the Site.......................................2.5-552.5.2.6Safe Shutdown Earthquake (SSE)................................................................2.5-562.5.2.7Operating Basis Earthquake (OBE)..............................................................2.5-56 2.5.3SURFACE FAULTING........................................................................................2.5-572.5.4STABILITY OF SUBSURFACE MATERIALS & FOUNDATIONS.......................2.5-572.5.4.1Geologic Features.........................................................................................2.5-57 2.5.4.2Properties of Subsurface Materials...............................................................2.5-572.5.4.2.1Static Engineering Properties........................................................................2.5-582.5.4.2.2Dynamic Properties of Subsurface Materials................................................2.5-59 2.5.4.2.3Rock Core Compositional Analyses..............................................................2.5-602.5.4.3Exploration....................................................................................................2.5-722.5.4.4Geophysical Surveys.....................................................................................2.5-72 2.5.4.4.1Seismic Refraction Survey............................................................................2.5-732.5.4.4.2Uphole Velocity Survey.................................................................................2.5-742.5.4.4.3Surface Wave Survey....................................................................................2.5-74 2.5.4.4.4Crosshole Shear Wave Surveys...................................................................2.5-742.5.4.4.5Ambient Vibration Measurement...................................................................2.5-762.5.4.4.6Borehole Geophysical Logs..........................................................................2.5-77 2.5.4.4.7Interpretation of Geophysical Data................................................................2.5-772.5.4.5Excavations and Backfill................................................................................2.5-782.5.4.6Groundwater Conditions................................................................................2.5-80 2.5.4.7Response of Soil to Dynamic Loading..........................................................2.5-802.5.4.8Liquefaction Potential....................................................................................2.5-832.5.4.9Earthquake Design Basis..............................................................................2.5-84 2.5.4.10Static Stability................................................................................................2.5-842.5.4.10.1Bearing Capacity...........................................................................................2.5-842.5.4.10.2Settlement of Foundations............................................................................2.5-85 2.5.4.10.3Lateral Forces...............................................................................................2.5-86 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage2-viiAmendment No. 1042.5.4.11Design Criteria...............................................................................................2.5-872.5.4.12Techniques to Improve Subsurface Conditions.............................................2.5-872.5.4.13Subsurface Instrumentation..........................................................................2.5-882.5.4.13.1Extensometers..............................................................................................2.5-88 2.5.4.13.2Post-construction Groundwater Monitoring...................................................2.5-882.5.4.14Construction Notes........................................................................................2.5-882.5.5STABILITY OF SLOPES.....................................................................................2.5-89 2.5.5.1Slope Characteristics....................................................................................2.5-892.5.5.2Design Criteria and Analyses........................................................................2.5-902.5.5.3Log of Borings...............................................................................................2.5-90 2.5.5.4Compacted Fill..............................................................................................2.5-902.5.6EMBANKMENTS AND DAMS.............................................................................2.5-902.5.6.1General..........................................................................................................2.5-90 2.5.6.1.1Squaw Creek Dam........................................................................................2.5-902.5.6.1.2Safe Shutdown Impoundment Dam..............................................................2.5-912.5.6.2Exploration....................................................................................................2.5-92 2.5.6.2.1Squaw Creek Dam........................................................................................2.5-93 2.5.6.2.2Safe Shutdown Impoundment Dam (SSI Dam).............................................2.5-932.5.6.2.3Borrow Material.............................................................................................2.5-932.5.6.3Foundation and Abutment Treatment............................................................2.5-94 2.5.6.3.1Squaw Creek Dam........................................................................................2.5-942.5.6.3.2Safe Shutdown Impoundment Dam..............................................................2.5-952.5.6.4Embankment.................................................................................................2.5-96 2.5.6.4.1Squaw Creek Dam........................................................................................2.5-962.5.6.4.2Safe Shutdown Impoundment Dam..............................................................2.5-962.5.6.4.3Material Properties Used for Design.............................................................2.5-97 2.5.6.4.4Rock Field Tests..........................................................................................2.5-1002.5.6.5Slope Stability..............................................................................................2.5-1042.5.6.5.1Squaw Creek Dam......................................................................................2.5-104 2.5.6.5.2Safe Shutdown Impoundment Dam (SSI Dam)...........................................2.5-1052.5.6.6Seepage Control.........................................................................................2.5-1112.5.6.6.1Squaw Creek Dam......................................................................................2.5-111 2.5.6.6.2Safe Shutdown Impoundment Dam............................................................2.5-1122.5.6.7Diversion and Closure.................................................................................2.5-1132.5.6.7.1Squaw Creek Dam......................................................................................2.5-113 2.5.6.7.2Safe Shutdown Impoundment Dam............................................................2.5-1152.5.6.8Instrumentation............................................................................................2.5-1152.5.6.8.1SSI Instrumentation.....................................................................................2.5-115 2.5.6.8.2Squaw Creek Dam Instrumentation............................................................2.5-1172.5.6.9Construction Notes......................................................................................2.5-1212.5.6.9.1Squaw Creek Dam......................................................................................2.5-121 2.5.6.9.2Safe Shutdown Impoundment Dam............................................................2.5-1232.5.6.10Operational Notes.......................................................................................2.5-125REFERENCES..................................................................................................2.5-125 CPNPP/FSARTABLE OF CONTENTS (Continued)
SectionTitlePage2-viiiAmendment No. 104APP. 2.5ACONSTRUCTION RECORDS AND DESIGN VERIFICATION OF SSI DAM .................................................................................................2.5A-12.5A.1DESIGN VERIFICATION AT FIFTY PERCENT (50%) CONSTRUCTION COMPLETION.....................................................................................................2.5A-12.5A.2DESIGN VERIFICATION AT ONE HUNDRED PERCENT (100%) CONSTRUCTION COMPLETE...........................................................................2.5A-12.5A.3FIELD DENSITY TEST DISTRIBUTION.............................................................2.5A-22.5A.4DYNAMIC STABILITY RE-EVALUATION...........................................................2.5A-2APP. 2.5BCONSTRUCTION RECORDS AND DESIGN VERIFICATION OF SQUAWCREEKDAM ...........................................................................2.5B-12.5B.1DESIGN VERIFICATION AT 50% CONSTRUCTION COMPLETION................2.5B-12.5B.2FIELD DENSITY TEST DISTRIBUTION.............................................................2.5B-1 CPNPP/FSAR2-ixAmendment No. 1042.0  SITE CHARACTERISTICSLIST OF TABLES NumberTitle2.1-1HISTORICAL AND PROJECTED POPULATIONS FOR COUNTIES WITHIN 50MILES OF CPNPP2.1-2CENTERS OF POPULATION WITHIN 50MILES OF CPNPP 2.1-3POPULATION DISTRIBUTION BY SECTOR-AREA WITHIN 10MILES OF CPNPP2.1-4POPULATION DISTRIBUTION BY AGE GROUPS WITHIN 10MILE RADIUS OF CPNPP FOR YEAR20002.1-5POPULATION DISTRIBUTION BY SECTOR-AREA WITHIN 10MILES OF CPNPP2.1-6POPULATION DISTRIBUTION BY AGE GROUPS BETWEEN 10AND 50MILE RADIUS OF CPNPP FOR YEAR20002.1-7TYPE AND TYPICAL LENGTH OF STAY OF TRANSIENTS WITHIN 10MILE RADIUS OF CPNPP2.1-8TRANSIENT POPULATION PROJECTIONS2.1-9MAXIMUM PERMANENT AND TRANSIENT POPULATION DISTRIBUTION BY SECTOR-AREA2.2-1NATURAL GAS PIPELINE INFORMATION 2.2-2WEST TEXAS GULF CRUDE OIL LINE2.3-1TORNADO POINT PROBABILITY WITHIN A GIVEN YEAR AT SELECTED LOCATIONS (1955-1967)2.3-2AVERAGE NUMBER OF THUNDERSTORM DAYS AND LARGE-HAIL DAYS2.3-2ASEASONAL AND ANNUAL ESTIMATES OF LIGHTNING STRIKES TO SAFETY-RELATED STRUCTURES2.3-3MEAN SEASONAL AND ANNUAL MIXING DEPTHS AND WIND SPEEDS AT TEXAS STATIONS NEAREST THE REGION (1960-1964)2.3-4ESTIMATED RAINFALL (INCHES) FOR THE SITE AREA 2.3-5MAXIMUM RECORDED POINT RAINFALL FOR SELECTED STATIONS IN THE REGION CPNPP/FSARLIST OF TABLES (Continued)
NumberTitle2-xAmendment No. 1042.3-6EXTREME SNOWFALLS AT SELECTED STATIONS IN THE REGION2.3-7DELETED2.3-7AONSITE METEOROLOGICAL DATA2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION2.3-8DELETED 2.3-9DELETED2.3-10DELETED2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)2.3-12MONTHLY VARIATION OF EXTREME "FASTEST MILE" WINDS FOR FORT WORTH AND DALLAS2.3-13WIND DIRECTION PERSISTENCE AT FORT WORTH (1969-1973)2.3-14WIND DIRECTION PERSISTENCE AT CPNPP2.3-15VALUES OF MEAN, AVERAGE AND EXTREME DAILY MAXIMUM, AND AVERAGE AND EXTREME DAILY MINIMUM SURFACE TEMPERATURES (&deg;F) AT FORT WORTH (1931-1960)2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS2.3-17MONTHLY AVERAGE RELATIVE HUMIDITY (PERCENT) AT FORTWORTH (1964-1973)2.3-18MONTHLY AND ANNUAL MEAN, AND EXTREME MAXIMUM AND MINIMUM DEWPOINT TEMPERATURES (&deg;F) AT FORT WORTH (1970-1975)2.3-19MONTHLY AND ANNUAL AVERAGE VALUES IN THE SITE AREA2.3-20MONTHLY PRECIPITATION EXTREMES (Inches) AT SELECTED STATIONS CPNPP/FSARLIST OF TABLES (Continued)
NumberTitle2-xiAmendment No. 1042.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS2.3-22MONTHLY AND ANNUAL STABILITY CLASS PERCENT FREQUENCY DISTRIBUTIONS AT FORT WORTH (1957-1971)2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)2.3-24MEAN MONTHLY MIXING DEPTHS FORT WORTH (May1972-April1976)2.3-25COMPARISON OF 4- AND 15-YEAR WIND AND STABILITY CONDITIONS AT FORTWORTH2.3-26METEOROLOGICAL INSTRUMENTATION COMANCHE PEAK PREOPERATIONAL METEOROLOGICAL PROGRAM2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP2.3-28MINIMUM DISTANCE FROM THE REACTOR CONTAINMENT STRUCTURE TO THE EXCLUSION-AREA BOUNDARY2.3-29DELETED2.3-30DELETED2.3-31DELETED 2.3-32DELETED2.3-33AVERAGE ANNUAL RELATIVE CONCENTRATION AT CPNPP (SEC./CUBIC METER) PERIOD OF RECORD:  5-15-72 TO 5-14-762.3-34METEOROLOGICAL INSTRUMENTATION COMANCHE PEAK OPERATIONAL METEOROLOGICAL PROGRAM2.3-34AMETEOROLOGICAL INSTRUMENTATION COMANCHE PEAK OPERATIONAL METEOROLOGICAL PROGRAM OVERALL SYSTEM ACCURACIES2.3-34BMETEOROLOGICAL INSTRUMENTATION COMANCHE PEAK OPERATIONAL METEOROLOGICAL PROGRAM DELTA TEMPERATURE SYSTEM ACCURACY2.3-35COMPARISON OF ANALOG AND DIGITAL DATA2.3-36DELETED CPNPP/FSARLIST OF TABLES (Continued)
NumberTitle2-xiiAmendment No. 1042.3-375-PERCENTILE VALUES OF THE ACCIDENT PERIOD DIFFUSION ESTIMATES AT THE LPZ2.3-3850-PERCENTILE VALUES OF THE ACCIDENT PERIOD DIFFUSION ESTIMATES AT THE LPZ2.4-1PRINCIPAL DAMS AND RESERVOIRS UPSTREAM OF COX BEND 2.4-2PRINCIPAL DAMS AND RESERVOIRS DOWNSTREAM OF COX BEND2.4-3POSSIBLE FUTURE RESERVOIRS ON BRAZOS RIVER BETWEEN POSSUM KINGDOM RESERVOIR AND LAKE WHITNEY2.4-4SURFACE WATER CLAIMS FILED (IRRIGATIONAL) - SQUAW CREEK2.4-5MUNICIPAL, INDUSTRIAL, MINING AND HYDROELECTRIC WATER USERS ON THE BRAZOS RIVER2.4-6IRRIGATIONAL WATER USAGE FROM BRAZOS RIVER BY COUNTY2.4-7ANNUAL FLOODS AT BRAZOS RIVER GAGING STATION 8-0910 (NEARGLENROSE)2.4-8ANNUAL FLOODS AT GAGING STATION 8-0917 ON PANTER BRANCH OF SQUAW CREEK2.4-9ANNUAL FLOODS AT GAGING STATION08091750 ON SQUAW CREEK NEAR GLEN ROSE2.4-10ANNUAL FLOODS AT GAGING STATION8-0915 ON PALUXY RIVER NEAR GLEN ROSE2.4-11SQUAW CREEK RESERVOIR PROBABLE MAXIMUM FLOOD2.4-12COMPARISON OF PROBABLE MAXIMUM PRECIPITATION MAXIMUM RECORDED RAINFALL AND MAXIMUM RAINFALL LIKELY TO OCCUR AT SELECTED GAGING STATIONS NEAR CPNPP2.4-13UNIT HYDROGRAPH CHARACTERISTICS2.4-14COINCIDENT WIND WAVE ACTIVITIES 2.4-15SAFE SHUTDOWN IMPOUNDMENT PROBABLE MAXIMUM FLOOD CPNPP/FSARLIST OF TABLES (Continued)
NumberTitle2-xiiiAmendment No. 1042.4-16UNIT HYDROGRAPH CHARACTERISTICS FOR THE PANTHER BRANCH WATERSHED ABOVE THE SAFE SHUTDOWN IMPOUNDMENT2.4-17SQUAW CREEK RESERVOIR AREA AND CAPACITY CHARACTERISTICS 2.4-18SAFE SHUTDOWN IMPOUNDMENT AREA AND CAPACITY CHARACTERISTICS2.4-19PREDICTED AREA AND CAPACITY CHARACTERISTICS OF THE SAFE SHUTDOWN IMPOUNDMENT AFTER FORTY YEARS OF SEDIMENTATION2.4-20CONCENTRATIONS OF RADIONUCLIDES IN POSTULATED ACCIDENTAL RELEASE2.4-20ACONCENTRATIONS OF RADIONUCLIDES IN POSTULATED ACCIDENTAL RELEASE2.4-21MAXIMUM CONCENTRATIONS IN SURFACE WATER DUE TO POSTULATED RELEASES FROM THE LIQUID RADIOACTIVE WASTE STORAGE TANK2.4-22GROUNDWATER CHEMICAL ANALYSES2.4-23ESTIMATED WATER USAGE AT CPNPP 2.4-24PUBLIC SUPPLY, INDUSTRIAL AND IRRIGATION WELLS, 0-20 MILES2.4-25LOCAL WATER WELLS2.4-26SUMMARY OF PUMPAGE DURING CONSTRUCTION IN 1975 2.4-27HISTORICAL GROUNDWATER LEVELS AROUND THE PLANT SITE2.4-28MAXIMUM DEPTH OF SIGNIFICANT CONCENTRATIONS OF RADIONUCLIDES IN THE GLEN ROSE LIMESTONE DUE TO POSTULATED ACCIDENTAL RELEASES2.4-29CONCENTRATIONS (Ci/ft
: 3) OF Cs-137 IN THE GLEN ROSE LIMESTONE DUE TO POSTULATED ACCIDENTAL RELEASES2.5.1-1TABULATION OF PRINCIPAL FAULTS-TEXAS2.5.1-2TABULATION OF PRINCIPAL FAULTS-TEXAS2.5.1-3TABULATION OF PRINCIPAL FAULTS-OKLAHOMA, ARKANSAS, LOUISIANA CPNPP/FSARLIST OF TABLES (Continued)
NumberTitle2-xivAmendment No. 1042.5.1-4TABULATION OF PRINCIPAL FAULTS-OKLAHOMA, ARKANSAS, LOUISIANA2.5.1-5WELL DATA ON ALL WELLS WITHIN FIVE-MILE RADIUS OF COMANCHE PEAK S.E.S AS OF DECEMBER 31,19802.5.1-6RESERVOIR DATA SUMMARY2.5.1-7STATISTICAL SUMMARY OF RESERVOIR PROPERTIES2.5.1-8ABSOLUTE OPEN FLOW POTENTIAL CALCULATIONS 2.5.1-9RESERVOIR DATA ON SELECTED WELLS WITHIN FIVE-MILE RADIUS OF CPNPP2.5.1-10GAS IN-PLACE ASSOCIATED WITH HYPOTHETICAL WELL2.5.1-11SURVEY OF REPORTED BOTTOM-HOLE PRESSURE IN HOOD AND SOMERVELLCOUNTIES,TEXAS2.5.2-1MODIFIED MERCALLI INTENSITY SCALE OF 1931 (Abridged) 2.5.2-2REGIONAL EARTHQUAKES2.5.2-3EARTHQUAKE ATTENUATION2.5.4-1SUMMARY OF UNCONFINED COMPRESSION TESTS 2.5.4-2SUMMARY OF DOUBLE RING SHEAR TESTS2.5.4-3SUMMARY OF BRAZIL TENSILE TESTS2.5.4-4STATIC ROCK PROPERTIES 2.5.4-5INITIALLY SELECTED VALUES OF PREEXCAVATION-DYNAMIC FOUNDATION DESIGN PARAMETERS2.5.4-5ADETAILS OF PREEXCAVATION CROSSHOLE SURVEYS2.5.4-5BREPRESENTATIVE GEOPHYSICAL DATA FROM PREEXCAVATION SURVEYS AT STTION LOCATION2.5.4-5CREPRESENTATIVE GEOPHYSICAL DATA FROM SAFE SHUTDOWN IMPOUNDMENT DAM LOCATION2.5.4-5DAMBIENT GROUND MOTION MEASUREMENTS CPNPP/FSARLIST OF TABLES (Continued)
NumberTitle2-xvAmendment No. 1042.5.4-5ELITHO-STRATIGRAPHY OF SUBSURFACE MATERIALS TO A DEPTH OF 500FT2.5.4-5FSUMMARY OF THE RESULTS OF THE POSTCONSTRUCTION CROSSHOLE SURVEY2.5.4-5GDYNAMIC ROCK PROPERTIES DETERMINED BY LABORATORY TESTING OF CORE SAMPLES2.5.4-5HDYNAMIC FOUNDATION DESIGN PARAMETERS BASED ON PREEXCAVATION AND POSTCONSTRUCTION GEOPHYSICAL SURVEYS2.5.4-6SUMMARY OF STATIC BEARING CAPACITY ANALYSIS OF CATEGORYI STRUCTURES2.5.4-6ASUMMARY OF DYNAMIC BEARING CAPACITY ANALYSIS OF CATEGORYI STRUCTURES2.5.4-7SUMMARY OF SETTLEMENT ANALYSIS FOR CATEGORYI STRUCTURES2.5.4-8SOLUBILITY ANALYSES RESULTS2.5.4-9RESULTS OF X-RAY DIFFRACTOMETER ANALYSIS 2.5.4-10RESULTS OF CHEMICAL ANALYSES2.5.4-11CYCLIC SHEAR STRENGTH CRITERIA2.5.4-12CYCLIC TRIAXIAL TEST PROGRAM SUMMARY OF DENSITIES 2.5.4-13SUMMARY OF CYCLIC STRENGTH VALUES2.5.4-13ASUMMARY OF ADDITIONAL CYCLIC SHEAR STRENGTH TESTS2.5.6-1PACKER TEST DATA 2.5.6-2TABULATION OF SELECTED ROCK-FILL DAMS STATE OF CALIFORNIA2.5.6-3TEST EMBANKMENT SECTION LARGE SCALE FIELD DENSITY TESTS2.5.6-4SPECTRAL VELOCITIES AS A FUNCTION OF FREQUENCY 2.5.6-5AVERAGE LOCAL SAFETY FACTORS2.5.6-6SAFETY FACTORS FOR WEDGE ANALYSIS CPNPP/FSARLIST OF TABLES (Continued)
NumberTitle2-xviAmendment No. 1042.5.6-7SQUAW CREEK DAM2.5.6-8TEST EMBANKMENT SECTION LARGE SCALE FIELD DENSITY TESTS2.5A-1SSI DAM SUMMARY OF CLASSIFICATION TESTS BORING SSI-12.5A-2SSI DAM SUMMARY OF CLASSIFICATION TESTS BORING SSI-2 2.5A-3SSI DAM SUMMARY OF UNCONFINED COMPRESSIVE STRENGTH TESTS2.5A-4SSI DAM SUMMARY OF CLASSIFICATION TESTS BORING IC-32.5B-1SQUAW CREEK DAM BORING SCD-1 SUMMARY OF CLASSIFICATION AND VANE SHEAR TESTS2.5B-2SQUAW CREEK DAM BORING SCD-2 SUMMARY OF CLASSIFICATION AND VANE SHEAR TESTS2.5B-3SQUAW CREEK DAM BORING SCD-3 SUMMARY OF CLASSIFICATION AND VANE SHEAR TESTS2.5B-4SQUAW CREEK DAM BORING SCD-4 SUMMARY OF CLASSIFICATION AND VANE SHEAR TESTS2.5B-5SQUAW CREEK DAM SUMMARY OF UNCONFINED COMPRESSIVE STRENGTH TESTS CPNPP/FSAR2-xviiAmendment No. 104 2.0  SITE CHARACTERISTICSLIST OF FIGURES NumberTitle2.1-1Site Location2.1-2Site Area2.1-2AOwnership of Surface Rights in the Exclusion Area2.1-2BEasements Within the Exclusion Area 2.1-2CExclusion Area Mineral Rights2.1-3Population Distribution by Sector-Area 0-10 Miles2.1-4Population Distribution by Sector-Area 10-50 Miles2.1-5Low Population Zone, 0-4 Miles2.1-61980 Cumulative Population 2.1-72020 Cumulative Population2.2-1Air Traffic, 0 to 20 Miles2.3-1Climatological Stations and Region 2.3-2Air Pollution Potential Number of Days in 5 Years2.3-3Local Meteorological Stations2.3-4Topography of the Comanche Peak Nuclear Power Plant Area 2.3-5Topographic Cross-Sections (Corresponding to Radials Shown in Figure2.3-4
)2.3-6Topographic Cross-Sections (Corresponding to Radials Shown in Figure2.3-4
)2.3-7Topographic Cross-Sections (Corresponding to Radials Shown in Figure2.3-4
)2.3-8Topographic Cross-Sections (Corresponding to Radials Shown in Figure2.3-4
)2.3-9General Topographic Features to 50 Miles CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xviiiAmendment No. 1042.3-10Wind Direction Frequency Distributions at CPNPP2.3-11Wind Direction Frequency Distributions2.3-12Facility Plan Including Location of Meteorological Tower2.3-13Deleted 2.3-14Deleted thru2.3-17 2.3-18Dilution Factors, Long Term (x10
-7 Seconds/Meter 3), 0 to 5 Miles2.3-19Dilution Factors, Long Term (x10
-8 Seconds/Meter 3), 0 to 50 Miles2.4-1Squaw Creek Reservoir Catchment2.4-2Roof Drains of Safeguard, Auxiliary and Fuel Building2.4-3Switchgear Building Roof Drains 2.4-4Topographic Map of Site2.4-5Texas Portion of Brazos River Basin2.4-6Regional Topographic Map 2.4-7Surface Water User Map of Brazos River2.4-8Mean Annual, 50 Year and Historical Peak Floods on Brazos River2.4-9Squaw Creek Reservoir Flood Routing 2.4-10Squaw Creek Watershed Unit Hydrographs2.4-11Safe Shutdown Impoundment Spillway Discharge Characteristics2.4-12Safe Shutdown Impoundment Unit Hydrograph 2.4-13Probability of Exceeding of Annual Peak Flow on the Brazos River at Station 8-0910 Near Glen Rose CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xixAmendment No. 1042.4-14Fetch Diagram Plant Site and Squaw Creek Dam2.4-15Fetch Diagram Safe Shutdown Impoundment Dam2.4-16Layout of Squaw Creek Reservoir Dam2.4-17Squaw Creek Reservoir Dam Embankment Section and Details 2.4-18Spillway Plan and Profile2.4-19Spillway Discharge Channel Grading2.4-20Spillway Underdrain System 2.4-21Safe Shutdown Impoundment Dam Cross-Section2.4-22Area and Capacity Characteristics of the Safe Shutdown Impoundment Initially and After 40 Years of Service2.4-23Layout of SSI Dam and Related Facilities 2.4-24Flow Probability Curve for the Brazos River at Station 8-0910 Near GlenRose2.4-25Flow Probability Curve for the Paluxy River at Station 8-0915 Near GlenRose2.4-26Plant Water System General: Two Units2.4-27Plant Water System: Unit #1 - Normal Operation, Unit #2 - Normal Operation2.4-28Plant Water System: Unit #1 - Normal Operation, Unit #2 - Shutdown at 4Hours2.4-29Plant Water System: Unit #1 - Shutdown at 4 Hours, Unit #2 - LOCA at Recirculation2.4-30Outcrop of Paluxy Formation2.4-31Outcrop of Glen Rose Formation 2.4-32Elevation of Top of Twin Mountains Formation2.4-33Public Supply, Industrial and Irrigation Wells, 0 to 20 Miles CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxAmendment No. 1042.4-34Piezometric Surface, Twin Mountains Formation, Site Region2.4-35Water Wells, Site Vicinity2.4-36Piezometric Surface, Twin Mountains Aquifer, Site Vicinity2.4-37Location of Production and Observation Wells 2.4-38Distance-Drawdown Curves Trinity Sand (Twin Mt.)2.4-39Hydrograph of Observation Wells2.4-40Plot Plan, Drainage Ditches Layout 2.4-41Plot Plan, Drainage Ditches Layout2.4-42Roof Drains, Detail of Relief and Drainage Opening2.5.1-1Physiography2.5.1-2Regional Stratigraphic Column2.5.1-3Regional Tectonic Structure 2.5.1-4Regional Geology2.5.1-4AEllenburger Structure2.5.1-5Regional East-West Geologic Cross Section 2.5.1-6Regional North-South Geologic Cross Section2.5.1-7Rock Density Variation with Depth2.5.1-8Regional Bouguer Gravity Map 2.5.1-9Regional Natural Gamma Aeroradioactivity2.5.1-10Vicinity Geologic Map2.5.1-11Local Geologic Column 2.5.1-12Site Geologic Map2.5.1-13Lithologic Section at Plant Site CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxiAmendment No. 1042.5.1-14Stratigraphic Section Site Vicinity2.5.1-15Vicinity Bedrock Contour Map2.5.1-16Plant Site Bedrock Contour Map2.5.1-17Natural Gas & Oil Pipelines and Wells within Five Miles of CPNPP 2.5.1-18Relationship of Stream Channel Alignments to Structural Trends in Lower Paluxy Basin2.5.1-19Pre-Cretaceous Paleotopography2.5.1-20Distribution of Expansive Soils2.5.1-21Consolidation Test Data2.5.1-22Subsidence Calculation2.5.1-23Ellenburger - Structure Map 2.5.1-23AEllenburger - Structure Map2.5.1-24Marble Falls - Structure Map2.5.1-24AMarble Falls Structure - Geo Map 2.5.1-25Marble Falls - Net Hydrocarbon Isopachous Map2.5.1-26Big Saline - Structure Map2.5.1-27Big Saline - Net Hydrocarbon Isopachous Map 2.5.1-28Strawn - Structure Map2.5.1-29Strawn - Net Hydrocarbon Isopachous Map2.5.1-30Northwest to Southeast, Structural Cross Section A-A' 2.5.1-31Southwest to Northeast, Structural Cross Section B-B'2.5.1-32Structural Map Overlay Upper Glen Rose Marker Bed Zone I/Zone II2.5.1-33Structural Cross-Section Locations CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxiiAmendment No. 1042.5.1-34Cretaceous Structure West to East Cross-Section C-C'2.5.1-35Cretaceous Structure Northwest to Southeast Cross-Section D-D'2.5.2-1Seismic Risk Map - Algermissen and Perkins2.5.2-2Tectonic Provinces and Earthquake Epicenter Map 2.5.2-31882 Bonham (Paris), Texas, Earthquake Isoseismal Map2.5.2-41930 Donaldsonville, La., Earthquake Isoseismal Map2.5.2-51931 West Texas Earthquake Isoseismal Map 2.5.2-61932 Wortham-Mexia Earthquake2.5.2-7Mexia Earthquake Observations2.5.2-81952 El Reno, Oklahoma, Earthquake Intensity Map2.5.2-91959 Southern Oklahoma Earthquake Isoseismal Map2.5.2-10Distribution of Gypsiferous Formations, Anhydrite Uplifts and Louann Salt 2.5.2-11Balcones Fault Zone Cross-Section2.5.2-12Mexia Fault Zone Cross-Section2.5.2-13Faults and Basement Configuration 2.5.2-14Earthquake Attenuation2.5.4-1Stress-Strain Plot (25 Sheets)2.5.4-2Typical Stress-Strain Curve, Claystone 2.5.4-3Mohr Diagram, Claystone Samples2.5.4-4Stress Vs. Vertical Strain Using SR-4 Strain Gages2.5.4-5Stress Vs. Lateral Strain Using SR-4 Strain Gages 2.5.4-6Stress Vs. Vertical Strain Using SR-4 Strain Gages2.5.4-7Stress Vs. Lateral Strain Using SR-4 Strain Gages CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxiiiAmendment No. 1042.5.4-8Stress Vs. Vertical Strain Using SR-4 Strain Gages2.5.4-9Stress Vs. Lateral Strain Using SR-4 Strain Gages2.5.4-10Stress Vs. Vertical Strain Using SR-4 Strain Gages2.5.4-11Stress Vs. Lateral Strain Using SR-4 Strain Gages 2.5.4-12Stress Vs. Vertical Strain Using SR-4 Strain Gages2.5.4-13Stress Vs. Lateral Strain Using SR-4 Strain Gages2.5.4-14Plot Plan, Geophysical Surveys 2.5.4-14A Plan and Location of Post-Construction Crosshole Survey Borings2.5.4-15Seismic Profile 12.5.4-16Seismic Profile 22.5.4-17Seismic Profile 32.5.4-18Seismic Profile 4 2.5.4-19Uphole Compressional Wave Velocity Boring P-12.5.4-20Uphole Compressional Wave Velocity Boring M-52.5.4-21Uphole Shear Wave Survey (Primacord Method) Boring M-5 2.5.4-22Electrical and Gamma Ray Logs Boring P-102.5.4-23Electrical and Gamma Ray Logs Boring DI-22.5.4-24Electrical and Gamma Ray Logs Boring DI-8A 2.5.4-25Electrical and Gamma Ray Logs Boring DI-92.5.4-26Electrical and Gamma Ray Logs Boring M-12.5.4-27Plan View Plant Excavation 2.5.4-28Cut and Fill Plantsite2.5.4-28AService Water Intake Channel Cut & Fill CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxivAmendment No. 1042.5.4-29Class I Backfill Material Quarries2.5.4-30Plant Site Geologic Section2.5.4-30AGeneralized Subsurface Profile and Seismic Wave Velocities (2 Sheets)2.5.4-31Service Water Intake Category I Backfill 2.5.4-32Typical Cross Sections Category I Backfilled Excavations2.5.4-33AFracture Map Unit 1 Foundation2.5.4-33BFracture Map Unit 1 Foundation 2.5.4-34Fracture Map Unit 1 Reactor Wall2.5.4-35Fracture Map Unit 1 Containment Wall2.5.4-36Photo Grid Unit 1 Containment and Reactor Walls2.5.4-37Excavation Photographs (21 Sheets)2.5.4-37APlan Profile of SWI 2.5.4.38Gradation Limits, Class I Backfill Material, Class I Bedding Material2.5.4-38ACyclic Triaxial Test Program, Sample #1 Gradation, Filter "A"2.5.4-38BCyclic Triaxial Test Program, Sample #2 Gradation, C-33 Fine Aggregate 2.5.4-38CCyclic Triaxial Test Program, Sample #3 Gradation, Glen Rose Crushed Stone2.5.4-38DCyclic Triaxial Test Program, Sample #4 Gradation, Crowder Quarry Crushed Stone2.5.4-39Typical Cyclic Triaxial Test Results (4 Sheets)2.5.4-40Cross-Section 'A-A'2.5.4-41Cross-Section 'B-B' 2.5.4-42Foundation Pressure Distribution Under Containment During SSE2.5.4-43Effect of Claystone on Foundation CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxvAmendment No. 1042.5.4-44Relative Density Test Summary fo r Backfill Around Category I Electrical Manholes and Duct Bank2.5.4-45Percent Compaction Test Summary for Backfill Around Category I Conduit2.5.4-46Relative Density Summary for Bedding Around Category I Pipelines2.5.4-47Percent Compaction Test Summary for Backfill Around Category I Pipelines2.5.4-48Percent Compaction Test Summary for Backfill Around the Service Water Intake Structure2.5.4-49Service Water Pipe Trench Backfill, Histogram of Gradation Limits for Bedding Sand2.5.4-50Duct Bank Backfill, Histogram of Gradation Limits for Bedding Sand2.5.4-51Service Water Intake Structure Backfill, Histogram of Gradation Limits for Crushed Rock2.5.4-52Duct Bank Trench and Manhole Backfill, Histogram of Gradation Limits for Crushed Rock2.5.4-53Surface Water Pipe Trench Backfill, Histogram of Gradation Limits for Crushed Rock2.5.4-54Static and Dynamic Lateral Earth Pressures2.5.4-55Location of Plant Piezometers2.5.4-56Piezometer Detail 2.5.4-57Cyclic Triaxial Testing, Bridgeport Limestone2.5.5-1Slope Profile & Stability, Sec. 1-12.5.5-2Slope Profile & Stability, Sec. 2-2 2.5.5-3Slope Profile & Stability, Sec. 3-32.5.5-4Slope Profile & Stability, Sec. 4-42.5.5-5Location of Borings, Plant Site CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxviAmendment No. 1042.5.5-6Location of Borings, Squaw Creek Dam2.5.5-7Log of Boring P-12.5.5-8Log of Boring P-22.5.5-9Log of Boring P-3 2.5.5-10Log of Boring P-42.5.5-11Log of Boring P-52.5.5-12Log of Boring P-6 2.5.5-13Log of Boring P-72.5.5-14Log of Boring P-82.5.5-15Log of Boring P-92.5.5-16Log of Boring P-9A (2 Sheets)2.5.5-17Log of Boring P-10 2.5.5-18Log of Boring P-10A (2 Sheets)2.5.5-19Log of Boring P-112.5.5-20Log of Boring P-12 2.5.5-21Log of Boring P-132.5.5-22Log of Boring P-142.5.5-23Log of Boring P-15 2.5.5-24Log of Boring P-162.5.5-25Log of Boring P-172.5.5-26Log of Boring P-18 2.5.5-27Log of Borings P-19 & P-202.5.5-28Log of Boring P-21 CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxviiAmendment No. 1042.5.5-29Log of Boring P-222.5.5-30Log of Boring P-232.5.5-31Log of Boring P-242.5.5-32Log of Boring P-25 2.5.5-33Log of Boring P-262.5.5-34Log of Boring P-272.5.5-35Log of Boring P-28 2.5.5-36Log of Boring P-292.5.5-37Log of Boring P-302.5.5-38Log of Borings P-31 & P-332.5.5-39Log of Borings P-32 & P-34R2.5.5-40Log of Borings P-35R, P-36R, P-37R, P-38R 2.5.5-41Log of Borings P-39R, P-40R, P-41R, P-42R2.5.5-42Log of Borings P-43R, P-44R, P-45R2.5.5-43Log of Borings M-1 & M-2 2.5.5-44Log of Boring M-32.5.5-45Log of Boring M-42.5.5-46Log of Borings M-5 & M-6 2.5.5-47Log of Borings M-8 & M-92.5.5-48Log of Boring M-102.5.5-49Log of Borings MS-7 & MS-8 2.5.5-50Not Used2.5.5-51Log of Boring DI-1 CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxviiiAmendment No. 1042.5.5-52Log of Boring DI-22.5.5-53Log of Boring DI-32.5.5-54Log of Borings DI-4 & DI-52.5.5-55Log of Boring DI-6 2.5.5-56Log of Borings DI-7 & DI-82.5.5-57Log of Boring DI-8A2.5.5-58Log of Boring DI-9 2.5.5-59Log of Boring DI-102.5.5-59ALog of Boring SS-172.5.5-59BLog of Boring SS-182.5.5-59CLog of Borings TP-2, TP-3, TP-62.5.5-60Log of Borings BA-1 & BA-2 2.5.5-61Log of Borings DII-1 & DII-22.5.5-62Log of Borings DII-3 thru DII-62.5.5-63Log of Borings DII-7 thru DII-10 2.5.5-64Log of Borings DII-11 thru DII-132.5.5-65Log of Borings DII-14 thru DII-172.5.5-66Log of Borings SS-1 & SS-2 2.5.5-67Log of Borings SS-3 & SS-42.5.5-68Log of Borings SS-5 thru SS-72.5.5-69Log of Borings SS-8 thru SS-11 2.5.5-70Log of Borings SS-12 thru SS-152.5.5-71Log of Borings SS-16 thru SS-18 & SSA-1 CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxixAmendment No. 1042.5.5-72Log of Borings SSA-2 thru SSA-42.5.5-73Log of Borings SO-1 thru SO-42.5.5-74Log of Borings SO-5 thru SO-10 & ES-12.5.5-75Log of Borings ES-2 thru ES-9 2.5.5-76Log of Borings SY-1 thru SY-4 (3 Sheets)2.5.5-77Piezometer Observation2.5.5-78Log of Boring 9 (2 Sheets) 2.5.5-79Log of Boring 10 (2 Sheets)2.5.5-80Log of Boring 11 (2 Sheets)2.5.5-81Log of Boring 12 (2 Sheets)2.5.5-82Log of Boring 13 (2 Sheets)2.5.5-83Log of Boring 14 (2 Sheets) 2.5.5-84Log of Boring 15 (2 Sheets)2.5.5-85Log of Boring 16 (2 Sheets)2.5.5-86Log of Boring 17 (2 Sheets) 2.5.5-87Log of Boring 18 (2 Sheets)2.5.5-88Log of Boring 19 (2 Sheets)2.5.5-89Log of Boring 20 (2 Sheets) 2.5.5-90Log of Boring 21 (2 Sheets)2.5.5-91Log of Boring 22 (2 Sheets)2.5.5-92Log of Boring 23 2.5.5-93Log of Boring 242.5.5-94Log of Boring 25 CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxxAmendment No. 1042.5.6-1Vicinity and Reservoir Map2.5.6-2Profile SCD Completed Excavation2.5-6-3Profile SSI Dam Completed Excavation2.5.6-4ASSI Dam Construction Photographs 2.5.6-4BSSI Dam Construction Photographs2.5.6-4CSSI Dam Construction Photographs2.5.6-4DSSI Dam Construction Photographs 2.5.6-4ESSI Dam Construction Photographs2.5.6-4FSSI Dam Construction Photographs2.5.6-4GSSI Dam Construction Photographs2.5.6-5ASquaw Creek Dam Construction Photographs2.5.6-5BSquaw Creek Dam Construction Photographs 2.5.6-5CSquaw Creek Dam Construction Photographs2.5.6-5DSquaw Creek Dam Construction Photographs2.5.6-5ESquaw Creek Dam Construction Photographs 2.5.6-5FSquaw Creek Dam Construction Photographs2.5.6-5GSquaw Creek Dam Construction Photographs2.5.6-5HSquaw Creek Dam Construction Photographs 2.5.6-5ISquaw Creek Dam Construction Photographs2.5.6-5JSquaw Creek Dam Construction Photographs2.5.6-6Not Used 2.5.6-7Geologic Profile, Centerline, Squaw Creek Dam2.5.6-8Geologic Profile, Service Outlet Works CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxxiAmendment No. 1042.5.6-9Geologic Profile, Service Spillway2.5.6-10Geologic Profile, Centerline of SSI Dam2.5.6.11Geologic Profile, Equalization Flow Channel2.5.6-12SSI Dam, Grain Size Distribution of Core, Filters and Rockfill 2.5.6-13SSI Dam, Shell Model Gradation2.5.6-14Shell Model Material, SSI Dam2.5.6-15SSI Dam, Clay Core 2.5.6-16SSI Dam, Clay Core2.5.6-17SSI Dam, Clay Core2.5.6-18Test Embankment Section, Deformation Vs. No. of Passes2.5.6-19Test Embankment Section, Percent Deformation Vs. No. of Passes2.5.6-20Test Embankment Section, Layer Thickness Vs. Required No. of Passes 2.5.6-21Field Shear Test Stress Vs. Shearing Movement2.5.6-22Field Shear Test Stress Vs. Shearing Movement2.5.6-23Field Shear Test Shearing Stress Vs. Normal Stress 2.5.6-24Mechanical Analysis2.5.6-25Field Shear Test2.5.6-26Slope Stability Analysis, Squaw Creek Dam 2.5.6-27SSI Dam, Static Analysis2.5.6-28Finite Element Analysis2.5.6-29Finite Element Analysis 2.5.6-30Finite Element Analysis2.5.6-31Finite Element Analysis CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxxiiAmendment No. 1042.5.6-32Finite Element Analysis2.5.6-33Finite Element Analysis2.5.6-34Finite Element Analysis2.5.6-35Finite Element Analysis 2.5.6-36Finite Element Analysis2.5.6-37Finite Element Analysis2.5.6-38Finite Element Analysis 2.5.6-39Finite Element Analysis2.5.6-40Finite Element Analysis2.5.6-41Finite Element Analysis2.5.6-42Finite Element Analysis2.5.6-43Finite Element Analysis 2.5.6-44Finite Element Analysis2.5.6-45Finite Element Analysis2.5.6-46Finite Element Analysis 2.5.6-47Cyclic Shear Strength Criteria For Rock Fill2.5.6-48Assumed Cyclic Shear Strength Criteria Used For Filter Materials2.5.6-49Derivation of a41 2.5.6-50Derivation of Wedge F2.5.6-51SSI Dam Liquification Study2.5.6-52Rock Acceleration Analysis 2.5.6-53Section and Profile of Instrumentation on SSI Dam2.5.6-54Plan, SSI Dam, Instrumentation CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxxiiiAmendment No. 1042.5.6-55Instrumentation, Squaw Creek Dam2.5.6-56Instrumentation, Squaw Creek Dam, Plan View2.5A-1Log of Borings, SSI-12.5A-2Log of Borings, SSI-2 2.5A-3SSI Dam, Representative Gradation of Impervious Core2.5A-4SSI Dam, Typical Stress-Strain Curve, Unconfined Compression Test2.5A-5SSI Dam, Triaxial Test Results, Borings SSI-1 and SSI-2 2.5A-6Log of Borings, IC32.5A-7SSI Dam, Results of Triaxial Test Boring IC32.5A-8SSI Dam, Boring IC3, Consolidation Test Results2.5A-9SSI Dam, Boring IC3, Consolidation Test Results2.5A-10SSI Dam, Boring IC3, Consolidation Test Results 2.5A-11SSI Dam, Density Test Distribution (15 Sheets)2.5A-12SSI Dam, Histogram of Percent Compaction, Impervious Core2.5A-13SSI Dam, Histogram of Moisture Variation, Impervious Core 2.5A-14SSI Dam, Histogram of Relative Density, Filter A & B2.5A-15SSI Dam, Histogram of Rockfill Density2.5A-16SSI Dam, Cyclic Strength of Filter "A" 2.5A-17SSI Dam, Cyclic Shear Stress Criteria, Filter "A" Material2.5A-18SSI Dam, Dynamic Stability Analysis, Ratio2.5A-19SSI Dam, Histogram of Gradation Limits, Rockfill 2.5A-20SSI Dam, Histogram of Gradation Limits, Filter A2.5A-21SSI Dam, Histogram of Gradation Limits, Filter B CPNPP/FSARLIST OF FIGURES (Continued)
NumberTitle2-xxxivAmendment No. 1042.5B-1Squaw Creek Dam, Log of Boring SCD-12.5B-2Squaw Creek Dam, Log of Boring SCD-22.5B-3Squaw Creek Dam, Log of Boring SCD-32.5B-4Squaw Creek Dam, Log of Boring SCD-4 2.5B-5Squaw Creek Dam, Stress-Strain Plot2.5B-6Squaw Creek Dam, Triaxial Test Results2.5B-7Squaw Creek Dam, Density Test Distribution (33 Sheets) 2.5B-8Squaw Creek Dam, Histogram of Percent Compaction, Impervious Core & Random Fill2.5B-9Squaw Creek Dam, Histogram of Moisture Variation, Impervious Core & Random Fill2.5B-10Squaw Creek Dam, Histogram of Relative Density, Filter Material CPNPP/FSAR2.1-1Amendment No. 1042.1GEOGRAPHY AND DEMOGRAPHY2.1.1SITE LOCATION AND DESCRIPTION2.1.1.1Specification of LocationThe CPNPP site is located in Somervell County in North Central Texas. Squaw Creek Reservoir (SCR), established for station cooling, extends northward into Hood County. The site is owned by the Applicants. The site is situated along Squaw Creek, a tributary of the Paluxy River, which is a tributary of the Brazos River. The station site is over 30 miles southwest of the nearest portion of Fort Worth and approximately 4.5 miles north- northwest of Glen Rose, the nearest community (see Figure 2.1-1
). Site coordinates are: 2.1.1.2Site AreaThe site area map (
Figure 2.1-2) shows the concurrent plant property and site boundary line, the Exclusion Area, and Squaw Creek Reservoir (SCR). The site area is approximately 7,700 acres.
Site area access is by a plant railroad, which connects to the Atchison, Topeka and Santa Fe Railroad Company main line at Tolar, Texas, by a plant access road which connects to FM 56 (previously Highway 201) and by County road 213 (also known as Coates Rd) which connects to State Highway 144. The plant railroad and access road are owned and controlled by the Applicants. There are no other highways, railways or navigable waterways which traverse or are immediately adjacent to the site. Luminant Power maintains Squaw Creek Park and controls access to the park and reservoir. Principal plant structures are also shown on Figure 2.1-2
.2.1.1.3Boundaries For Establishing Effluent Release LimitsThe Exclusion Area consists of approximately 4,170 acres.
Figure 2.1-2 depicts the Exclusion Area boundary. This boundary is used for establishing effluent release limits and enables the owners to fulfill their obligations with respect to the requirements of 10 CFR Parts 20 and 100
 
(see Section 2.1.2.1.5
).Figure 2.1-2 shows that the points of release for each of the two units are located closer to the southwest property line than any other segment of the property line. This southwesterly distance Unit No. 1Unit No. 2Texas Grid (Feet)Y = 229,723.96X = 1,911,921.11 Y = 230,010.86X = 1,911,951.27U.T.M. Grid (Zone 14)
(Meters)N = 3,573,903 E = 614,393 N = 3,537,991E = 614,401Latitude32&#xba; 17' 52.02"32&#xba; 17' 54.85"Longitude97&#xba; 47' 06.15"97&#xba; 47' 05.79" CPNPP/FSAR2.1-2Amendment No. 104coincides with the minimum Exclusion Area boundary distance, which is 5,067 feet (1544 meters) from the midpoint of the centerline between the Containment buildings.2.1.2EXCLUSION AREA AUTHORITY AND CONTROL 2.1.2.1Authority2.1.2.1.1Surface RightsLuminant Power has acquired and will maintain surface ownership of all the land within the Exclusion Area (see Figure 2.1-2A). Accordingly, Luminant Power has the authority to determine all activities within the Exclusion Area, except for certain improbable and de minimus mineral exploration activities as discussed in greater detail below. That portion of Squaw Creek Reservoir which is within the Exclusion Area is subject to the waterway exclusion provided in 10 CFR Part 100.3(a). Consistent with that regulation, appropriate and effective arrangements will be made to control traffic on the reservoir to protect the public health and safety in case of emergency. The Exclusion Area is not traversed by any public highway or railroad. See Figure 2.1-2. The nearest primary public road, FM 56 (previously State Highway 201 as denoted on Figure 2.1-2), lies outside the Exclusion Area approximately 8900 feet southwest of the center line between the Containment buildings.
Luminant Power owns and operates the plant railroad from the plant to its junction with the Atchison, Topeka and Santa Fe Railroad at Tolar, Texas, approximately 11 miles from the site. 2.1.2.1.2Mineral Rights Luminant Power has acquired mineral rights beneath all seismic Category I structures (see Figure 2.1-2C). Portions of the remainder of the Exclusion Area are subject to certain outstanding mineral rights. As noted above, Luminant Power owns the surface rights for the entire Exclusion Area. As to the mineral rights within the Exclusion Area not owned by Luminant Power, Luminant Power will assure that the exercise of such mineral rights will pose no health and safety threat during normal reactor operation or in the event of an accident. The only outstanding mineral rights in the Exclusion Area for CPNPP, and surrounding areas, relate to the exploration for and production of oil, gas, and other subsurface minerals. There are no outstanding rights which permit the production of surface minerals. As discussed in Section 2.5.1
, the potential for commercial production of minerals at CPNPP and in the surrounding area is low. Thus, it is anticipated that the exercise of such outstanding mineral rights would involve only sporadic, exploratory activity, and little or no production.Nevertheless, Luminant Power will maintain sufficient authority and control over, and knowledge of, attempted ingress into the Exclusion Area to ensure that no unauthorized entry is allowed by use of a mobile patrol at random intervals. Ingress for the purpose of exercising mineral rights in any area within 2250 feet of a seismic Category I building (See Section 2.2.3.2.1) or within 2800 feet of either Containment Building (See Section 2.1.2.1.5) is prohibited by virtue of Luminant Power ownership of the mineral rights or by deed restrictions on any reserved mineral rights.
This area has been designated in Figure 2.1-2C as the "External Hazard Free Zone."  The distances of 2250 and 2800 feet are based upon the analysis of a postulated gas well in Section 2.2.3. The distance of 2250 feet from any seismic Category I building assures that any CPNPP/FSAR2.1-3Amendment No. 104 conceivable detonation (of the maximum quantity of explosives that could be used within the exclusion area) would have no effect on the safety-related structures and components (see Regulatory Guide1.91). The forbidden zone of 2800 feet in radius corresponds to the equivalent distance for the 2 hour dose limit of 10 CFR 100 and the maximum design basis accidents for CPNPP (See Section 15.6). Ingress to the remaining outer areas of the Exclusion Area will only be permitted pursuant to written agreements between Luminant Power and the necessary parties which would provide that Luminant Power has absolute authority to determine all activities within
 
the Exclusion Area, including removal of personnel and equipment.A mineral owner or lessee has no legal right to use physical force or to create a public disturbance to obtain access to the outer areas of the Exclusion Area for purposes of mineral exploration or extraction. If such access is sought as to areas outside the "External Hazard Free Zone", Luminant Power likewise will refuse to allow access unless the written agreement discussed above has been executed by the mineral owner or lessee. In such case, legal remedy of a mineral owner or lessee to obtain access to the surface of the Exclusion Area after being so excluded would be to file a lawsuit in the State District Court for the county where the land is located (either Somervell or Hood County). Should such a suit be filed, Luminant Power would then file an immediate cross-action to condemn the mineral rights of the party seeking ingress and thereby prevent the ingress. Luminant Power has statutory authority to do so. Article 3269, V.A.T.S.In this manner, Luminant Power will have absolute authority to determine all activities within the Exclusion Area, including the authority to exclude or remove persons. Thus, the exercise of mineral rights in the Exclusion Area will pose no health and safety threat during normal reactor operation or in the event of an accident. In view of the unusual nature and limited scope of activities associated with the mineral rights and the plan and commitments by Luminant Power to control all activities within the Exclusion Area, the present status of ownership is deemed to be of de minimis safety consequence. As stated above, Luminant Power has acquired the mineral rights beneath all seismic Category I structures as well as beneath the Squaw Creek Dam (See Figure 2.1-2C). No measurable subsidence due to mineral extraction is anticipated. See Section 2.5.1.2.6 for a discussion of the effects of mineral extraction in the area of the site.2.1.2.1.3Easements A 6-inch natural gas pipeline and a 26-inch crude oil pipeline traverse the Exclusion Area about 4,900 feet southwest of the midpoint of the centerline between the Containment buildings as
 
shown on Figure 2.1-2B. These pipelines are also described in Section 2.2.3
. Luminant Power has granted the pipeline owners easements which retain for Luminant Power absolute control to determine all such activities within the Exclusion Area including ingress and egress for the purpose of maintaining the pipelines and their right-of-way. 2.1.2.1.4Status of Ownership
 
Luminant Power has acquired all of the land which will constitute the site property. One small tract of land within the site area has been excluded from purchase: the Hopewell cemetary east of the plant (see Figure 2.1-2). This tract is outside the Exclusion Area and is fenced off from the site property.
CPNPP/FSAR2.1-4Amendment No. 1042.1.2.1.5Minimum Exclusion Area DistanceThe minimum distance to the Exclusion Area boundary from the midpoint of the centerline between the Containment buildings is 5,067 feet (1,544 meters) to the west-southwest. The minimum Exclusion Area boundary distance is substantially larger, and therefore more conservative, than the distance which literal compliance with 10 CFR 100 would dictate (See Section 15.6
). 2.1.2.2Control of Activities Unrelated to Plant Operation Activities unrelated to plant operation which may be permitted within the Exclusion Area include the exercising of mineral rights and the maintenance of pipelines as described in Sections 2.1.2.1.2 and 2.1.2.1.3 above, and cattle grazing. Luminant Power will have the necessary control to determine these activities and will require that all persons involved in them report to the Plant Manager (See Section 13.1.1.2.1) or a designated representative prior to engaging in the activities.Arrangements have been made (in coordination with the appropriate agencies) to control access to, activities on, and the removal of persons and property from the CPNPP owner controlled area in case of emergency. Arrangements for recreational use and emergency procedures governing such use have been completed. Luminant Power has the authority to exclude or remove any person from this area at any time.Luminant Power conducts practices that provide knowledge of the approximate number and location of persons within the Exclusion Area engaged in such activities. Normal evacuation of persons within the Exclusion Area will take no more than two hours.2.1.2.3Arrangements for Traffic ControlIn the event of an emergency, traffic on the plant access road will be controlled by Luminant Power.If Squaw Creek Reservoir is opened to the public, arrangements will be made to control traffic in the event of an emergency (see Section 2.1.2.2
, above).2.1.2.4Abandonment or Relocation of RoadsAn unpaved county road which traversed the northeast corner of the Exclusion Area was abandoned in April 1975 because of the construction of Squaw Creek Dam and Reservoir. Arrangements for the closing of this section of road were made with the Somervell County Commissioner's Court in December 1974. No other public roads traverse the Exclusion Area.2.1.3POPULATION DISTRIBUTIONThe purpose of this section is to provide detailed estimates of the present and projected size and distribution of population within a 50-miles radius of CPNPP. The population estimates provided in the PSAR have been reviewed, revised, and updated for purposes of the FSAR. Estimates of population distribution are provided for 1970 (most recent census year), 1976 (current year), and for census decades 1980 through 2020.
CPNPP/FSAR2.1-5Amendment No. 104In reviewing and updating the population estimates in the PSAR, it was recognized that the actual centerline locations of the containment structures for Units 1 and 2 differ slightly (approximately 88 feet) from the locations as originally shown. In these revised population estimates, the actual centerline of the Unit 1 containment structure has been taken as the point of origin for the sector lines and concentric distance circles which form the sector-areas used in portraying population distribution within the 50-mile radius of CPNPP. While the 1970 county-by-county population base in the CPNPP area remains the same as shown in the PSAR, the slight difference in Unit 1 location causes some change in location of sector lines and distance circles. Thus, very small changes ar e found in this updated population study in the 1970 distribution of population by sector- areas.The territory included within the 50-mile radius of CPNPP includes all or a part of 19 counties, all in Texas. The general location of CPNPP in Somervell County and the locations of the rest of the counties located within 50 miles of the plant site are shown in Figures 2.1-3 and 2.1-4. The population of these 19 counties is given in Table 2.1-1 for the census decades 1930 through 1970; in addition, the table provides an estimate of the 1976 p opulation for each county and the projected future population for each census decade 1980 through 2020. Footnotes to the table provide brief comment regarding the sources of the historical data and the projections. Within the 50-mile radius of CPNPP, there is wide diversi ty in land use, urbanization, and population density. The plant site is located in Hood and Somervell counties, which are essentially rural, sparsely-populated areas. The entire population of Somervell County was 2,793 residents in 1970. Hood County, which is much larger in area than Somervell County (as may be seen in Figure 2.1-3), had a population of 6,368 inhabitants in 1970. In 1970, there were three small communities with a total of 4,339 people within the 10-mile area around the CPNPP site. The total population within the 10-mile area at that time was 5,353, or an overall population density of approximately 17 persons per square mile.The sparsely-settled rural character extends well beyond the 10-mile radius, as indicated in Table2.1-2, which lists all incorporated communities and all unincorporated settlements with over 1,000 inhabitants within the entire 50-mile radius of the site. The area extending from 10 to 20 miles out from the CPNPP site is even more sparsely populated than the 0 to 10-mile area. As the table shows, in 1970 there were two communities totaling 1,028 people within the entire 10 to 20-mile area around the CPNPP site, and the total population in this area was 7,532 (this is a 1970 population density of only 8 persons per square mile). Beyond the 20-mile radius there are more communities, and the 30 to 50-mile area to the northeast is dominated by the Fort Worth metropolitan complex.In reviewing the county-by-county population projections which were given in the PSAR, it was found that most of the county population projections should be revised somewhat in accordance with current population estimates and the most recent projections prepared by the councils-of-government and the state agencies. Accordingly, in providing updated county population data (Table 2.1-1), current estimates for 1976 are given along with the revised projections for the years 1980 through 2020. It should be noted that the current estimates and the projections of expected population growth in Hood and Somervell counties are based upon an enumeration of housing units in the two counties in mid-1976 and an updated evaluation of recent and probable future trends in recreational development in the local area. Moreover, the estimates for Hood and Somervell counties include detailed consideration of the current and possible future impact of CPNPP construction and operation on population growth. As a general procedure in determining population distribution, the 1970 population of each county (wholly or partially within the 50-mile radius of the plan) was allocated to sector-areas within the county on CPNPP/FSAR2.1-6Amendment No. 104 the basis of (1) the population of each communit y and enumeration district located wholly within a particular sector-area, and (2) a percentage share of the population of each enumeration district and community partially within a particular sector-area (the percentage share of population of an enumeration district to be allocated to a particular sector-area was generally assumed to be equal to the percentage portion of the area of the enumeration district within the particular sector-area).In the case of Hood and Somervell counties, the county and enumeration district populations were allocated to sector-areas on the basis of (1) an actual count of housing units within each sector-area, and (2) the estimated number of residents per housing unit, considering available census data for the particular local area. The housing count for Hood and Somervell counties for the PSAR was made in 1973 utilizing a combination of available mapping, aerial photography, and field survey resources. The housing unit count made in mid-1976 for the FSAR was based on a comprehensive field survey and housing enumeration for all of Hood and Somervell counties. The estimates of population within individual sector-areas have been reconciled to the population totals for each county (or a portion of a county).The percentage ratio of the total population of a county which was estimated to be within each individual sector-area in the county in 1970 (1976 in the case of Hood and Somervell counties) was assumed to remain the same in 1980 and beyond. This assumption was made after
 
concluding that there is little possibility of a significant and radical change in the basic pattern of current population distribution within individual counties in the 50-mile area.2.1.3.1Population Within 10 MilesThe area within the 10-mile radius of CPNPP is predominantly a rural agricultural area. In 1970, there were three small communities having more than 100 residents. The total population of Hood and Somervell counties changed little over the period from 1930 to 1970 (see Table 2.1-1
).2.1.3.1.1Current Population Within 10 MilesSince 1970, Hood and Somervell counties have experienced increases in population, as indicated by the following:The estimates for 1976 are based upon the July/August 1976 enumeration of housing units in the two counties (including the communities). The growth of Granbury may be understated in PopulationCounty (and Community)1970 (census)1976 (estimate)
Hood County6,36815,601Granbury (county seat)  2,4733,526Tolar312435Somervell County2,7935,216Glen Rose (county seat)1,5542,790 CPNPP/FSAR2.1-7Amendment No. 104comparing the data above because much of the urban growth of the community has taken place beyond the city limits.The increase in population of Hood County since 1970 is largely related to the attractions of Lake Granbury for residential developments. These developments are attracting large numbers of permanent residents as well as vacation and recreational visitors. In 1970, there were 2,628 housing units in use as permanent residences in Hood County. By 1976, there were 5,566 housing units accounting for an estimated population of 15,601 full-time residents in Hood County and there were an additional 1,648 housing units in use primarily during weekends and vacations. A significant portion of the increase in housing units has been in mobile homes used both as vacation homes and permanent residences. The increase in permanent residents in Hood County is partially accounted for by attractive living conditions; many people that have moved into Hood County are commuting to jobs elsewhere. Significant numbers of retired people have established their permanent residence in Hood County. With the above, and the general stimulus of vacation and recreational activity, there has been an increase in local economic activity and job opportunity within the county.The number of permanent housing units in Somerv ell County increased from 1,203 in 1970 (but only 1,035 households at that time) to an estimated 1,856 housing units in 1976. An additional 26 vacation homes were located in the housing enumeration, but as the data indicates, virtually
 
the entire housing inventory of Somervell Coun ty (fixed structures, mobile homes, and apartments or courts) was permanently occupied in mid-1976. Somervell County has participated only peripherally in the Lake Granbury stimulus to housing development and recreational activity.In addition to the foregoing, it should be noted that the influx of construction workers employed on CPNPP accounts for a significant portion of the population increase from 1970 to 1976, particularly in the case of Somervell County. For example, at the end of July 1976, there were 2,285 workers regularly employed at the CPNPP construction site. Of that number, 216 had moved into Somervell County specifically to work at CPNPP. In addition to the 2,285 man active work force as of the end of July 1976, there was a total of 1,968 workers who had been terminated since the start of construction on CPNPP in October 1974. Of these terminated
 
employees, 177 had moved into Somervell County for the purpose of employment at CPNPP. Data on the CPNPP work force indicates that, on the average, each worker had 1.8 dependents.
Thus, considering both active and terminated workers, a total of 1,100 workers and dependents had moved into Somervell County as of July 1976.The tabulation below provides a summary showing the total number of CPNPP workers who have moved into Hood and Somervell counties through July 1976:Total No. of Workers as of July 1976ActiveTerminatedTotal (on-site work force)2,2851,968 Residing in Somervell County:Local Hire160138 CPNPP/FSAR2.1-8Amendment No. 104The total number of workers (both active and terminated) and dependents relocating to Hood and Somervell counties through July 1976 is estimated as follows:While 45 to 47 percent of these totals are represented by now terminated CPNPP employees and dependents, there are strong indications that a large portion of the terminated employees who originally moved with their dependents into the local area to work on CPNPP actually stayed in the area after termination of employment at CPNPP. The overall growth of population in both counties is creating increasing opportunities fo r employment in local service industries. Moreover, as indicated earlier, substantial numbers of new residents in Hood and Somervell counties are commuting to jobs outside the local area.Table 2.1-3 shows estimated population distribution by sector and mileage zones within 10 miles of CPNPP for the years 1970 and 1976 and for the census decades 1980 through 2020. Figure2.1-3 indicates the location of the plant in Somervell County and the sector areas out to a 10-mile radius. As may be seen from the data in the table, a substantial part of the increase in population in the two counties from 1970 to 1976 has occurred in or near the established communities. The population of the remainder of Somervell County has increased by an estimated 95 percent over the same period (1970-1976) and examination of the data in the table indicated that this growth was widely distributed in the county.In some contrast to Somervell County, the population growth in Hood County has been more highly concentrated (in the areas near Lake Granbury). The population of the county seat of Granbury (within the city limits) increased by an estimated 42 percent from 1970 to 1976. The population of the balance of Hood County increased by well over 300 percent. Much of this increase has occurred in the north, north-north-east, and northwest sectors in the 5 to 10-mile area and the 10 to 20-mile area. These increased concentrations of population within particular sector-areas in Hood County are clearly evident in a comparison of the 1970 and 1976 data in Table 2.1-3
.Relocated216 177Residing in Hood County:Local Hire278 240Relocated201173TotalWorkersDependents TotalHood County  374 673 1,047Somervell County393707 1,100 Total No. of Workers as of July 1976ActiveTerminated CPNPP/FSAR2.1-9Amendment No. 1042.1.3.1.2Projected Population Within 10 Miles The size and distribution of population within 10 miles of the CPNPP plant site as projected for the census decades 1980 through 2020 are shown in Table 2.1-3 (along with estimates for 1970 and 1976). These projections of future population distribution within the 10-mile radius of the site are fully reconciled to the overall population projections for Hood and Somervell counties (as described earlier). These projections take into account the size and residential distribution of the CPNPP construction work force and the expected phase-out of construction activity over the period 1980-1982.It is expected that the continued growth of population and employment opportunities associated with lake-oriented residential community development and recreational activities in Hood County will tend to offset the sharp drop in construction employment on CPNPP. It is also expected that the completion of CPNPP will cause an actual decline in population in Somervell County after 1980 (for a period of two to three years), but by 1990 the loss will be regained due to the underlying slow rate of growth expected for the county.2.1.3.1.3Age Distribution of Population Within 10 MilesTo provide an estimate of the population by age groups, it was necessary first to compare the 1970 population distribution by age g roup for Somervell County and the U.S. as a whole. Because the percentage distribution by age groups 0 to 11, 12 to 18, and 19 and over for Somervell County and for the U.S. for 1970 differed by less than 10 percent, the distributions for the year 2000 for the project area were assumed to be the same as the Bureau of Census age-group distribution projections for the U.S. for the year 2000. If the difference had been greater than 10 percent, the U.S. percentages would have required adjustment based on projections for the North Central Texas region.
The U.S. projection for the year 2000 came from Table No. 3 of the "U.S. Statistical Abstract, 1975."  The data had to be modified slightly, however, to compensate for somewhat different age groupings. The population projection for the 10-mile area of CPNPP came from Table 2.1-3. The resulting population distribution by age group fo r the 10-mile area around CPNPP for the year 2000 (the mid-point of expected plant life) is given in Table 2.1-4
.2.1.3.2Population Within 10 to 50 Miles
 
The population within the 10 to 50-mile radius of CPNPP includes the population of a large number of communities and cities including Fort Worth, as listed in Table 2.1-2. The location of all population centers is shown on Figure 2.1-4, which also shows sector lines and distance circles out to the 50-mile radius from CPNPP.2.1.3.2.1Current Population Within 10 to 50 MilesThe distribution of the 1970 population and the estimated 1976 population within the 10 to 50-mile radius of CPNPP is shown by sector-area in Table 2.1-5
. The estimates of population distribution by sector-area for 1976 are correlated with the county-by-county projections, as described earlier. There was a 13.4 percent increase in population within the entire 10 to 50 mile area from 1970 to 1976 (compared with the 127 percent increase within the 10-mile area). Within the 10 to 50-mile area there are significant differences among co unties with respect to population increase (or loss) from 1970 to 1976 as may be seen in reviewing Table 2.1-1. For CPNPP/FSAR2.1-10Amendment No. 104example, the population of Johnson County (to the east of the site) increased by 20 percent while Stephens County (to the west of the site) decreased by 3 percent. These differences in recent growth trends among the counties are reflected in the estimates of current population distribution by sector-area.2.1.3.2.2Projected Population Within 10 to 50 MilesThe present and projected population growth through the year 2020 is shown by county in Table2.1-1 for all counties within the 50-mile radius of CPNPP. Table 2.1-5 provides estimates of the distribution of projected population by sector-area for the census decades 1980 through 2020 (along with comparable estimates for 1970 and 1976). As may be seen in a comparison of the cumulative estimates of population for 0 to 10 miles, 0 to 20 miles, etc., for each of the census years (summarized at the end of Table 2.1-5), population growth for the entire 0 to 50-mile area is projected to increase at a much slower rate than for the 0 to 10-mile area, as shown below:2.1.3.2.3Age Distribution of Population Within 10 to 50 MilesThe age distribution of the population of Somervell County (in which the plant is located) in 1970 differed by less than 10 percent from the 1970 age distribution for the populations of the United States as a whole. Accordingly, the projected percentage age distribution for the United States for the year 2000 (mid-point of plant life) was assumed for the population within the 10 to 50-mile area around CPNPP for the year 2000. The projected populated distribution by age group for the 10 to 50-mile area is provided in Table 2.1-6
.2.1.3.3Transient PopulationAfter consideration of the overall patterns of settlement, land use, and population distribution within the entire 50-mile radius of the site, it was concluded that transient population movements and daily and seasonal variations in population distribution and concentration within the 10-mile radius of CPNPP should be examined in some detail. It was also concluded that no such examination and projections should be made of transient movements in the 10 to 50-mile area. There are large-scale movements of daily commuters (in all directions) within the Fort Worth metropolitan complex. However, but the potential significance and meaning of such movements (compared with the potential significance of movements within the 10-mile area) does not appear to justify the inordinate effort that would be re quired to characterize, analyze, and project transient population movements within the 10 to 50-mile area. Accordingly, the discussions below pertain only to transient population within the 10-mile radius of CPNPP.
Population (000)
Percent IncreaseArea (radius)19762020 0-1012.131.1156 0-2024.764.9163 0-3083.8 198.5137 0-40438.81,024.8134 0-50894.02,090.5134 CPNPP/FSAR2.1-11Amendment No. 1042.1.3.3.1Seasonal VariationThis category of transient population is specifically concerned with overnight visitors coming into the 10-mile area. As will be shown, there are many more overnight visitors in the summer season than during other times of the year, but overnight visitors are found in the area throughout the year. The seasonal or overnight category of transients includes visitors staying for several days or weeks (this category excludes consideration of daily transients, regardless of the season). This category of transient population (seasonal or overnight visitors) includes visitors that would be found in hotel/motels, camp-grounds, recreational vehicle parks, organized camps (church groups, youth groups, etc.), mobile home-parks, and vacation homes. It also includes live-in students in a children's home despite the fact that their stays are for extended periods. These children are not included as part of the permanent population.Because this category of transients is predominantly comprised of recreational and vacationing visitors, there is a distinct peaking in the summer season of total transients in the area at any one time. Moreover, normal and holiday weekend peaking is different and week- days differ from week-ends, both in summer and winter. See Table 2.1-7 for estimates of the length of stay of various types of transients.In developing the estimates of seasonal transient population given in Table 2.1-8
, consideration has been given to (1) the location and capacity of various facilities that accommodate overnight visitors, and (2) the actual patterns or levels of use which are typically experienced by the facilities at various time of the year. The table presents estimates of weekly, typical weekend and holiday week, and daily and overnite transient during summer and winter.With respect to the projection of future levels of seasonal or overnight transients, different assumptions were made for the several different types of facilities. Sector-area estimates of vacation home and hotel/motel visitors were assumed to increase from 1980 through 2020 in proportion to the projected increase in population for the county as a whole (in which the sector-areas are located). Organized camp attendance is expected to remain at 1976 levels and the children's institution will remain stable from 1980 onward. Camping at various types of facilities along Lake Granbury is expected to reach its peak by 1990 (achieving levels similar to those at other older facilities in North Central Texas) and level off thereafter. Camping elsewhere in the 10-mile area (away from Lake Granbury) was estimated to grow in general accordance with the population growth projected for Dallas and Tarrant counties (major counties in the larger metroplex).2.1.3.3.2Daily Variation This category of transient population is concerned with daily movements of population into and within the 10-mile area and peaking in the number of transients found in a particular sector-area at any given time. Estimates of daily transient movements and population concentration include consideration of movements to such facilities as public schools, private schools, urban and community shopping centers, and recreational facilities such as parks and lakes. Estimates have been made of daily visitor recreational use of Lake Granbury (in addition to use by overnight and vacationing visitors). Beginning in 1980, when it will have been filled, it is assumed that limited daily visitor recreational use will be permitted at a non-camping park facility on Squaw Creek Reservoir.
CPNPP/FSAR2.1-12Amendment No. 104It is apparent from Table 2.1-8 that there are great differences in daily transient population movements depending on the season of the year and on the time of the week (weekday, normal weekend, and holiday weekend). It should be noted that the table does not provide estimates of the total number of daily visitors (of different types) but rather it provides estimates of the maximum number of visitors that might be expected in a sector-area during the peak hours of the day. It is also important to note that t he estimates of peak daily transient population concentration in a particular sector-area are not accompanied by corresponding decreases in population in sector-area from which the transients originated. This is the situation where large numbers of school children (from numerous sector-areas) are concentrated daily in a single sector-area. This is simply a recognition that peak population concentration in different sector-areas may occur at different times of the day.The general approach in estimating daily transient movements in 1976 was to utilize empirical data wherever possible, as in the case of school enrollments and the daytime use of some recreational and park facilities. The experience of state parks and other older reservoirs and water-oriented facilities was used as a basis for estimating current and projected daytime use of Lake Granbury and Squaw Creek Reservoir. The numbers and movement patterns of permanent and vacation residents in making use of shipping facilities in Granbury and Glen Rose was estimated on the basis of the geographical distribution of households and a number of
 
working assumptions regarding the frequency and time of week for shoppers coming from various distances. It was assumed that the above communities served only the areas of their respective counties. Again, the estimates indicate the peak number of transients that would be in a sector-area at a particular time and not the total number of transients during a day.
With respect to the projections of daily transients for future years, several assumptions were made as in the case of the seasonal population estimates. Projections of daily transients associated with school enrollments and community shopping activity were related to basic population projections. Recreational use of Lake Granbury and Squaw Creek Reservoir was assumed to reach mature levels by 1990 and level off thereafter at levels found at similar, but older, water-related facilities elsewhere in North Central Texas. It is noted that Unit 2 of CPNPP will not be completed until 1982 or thereafter and that a construction work force will remain on site after completion and start of operations (at least in a test mode) of Unit 1 in late 1980.2.1.3.3.3Summary Effect of Transient Population Movements in 10-Mile Area The most conservative estimate of area population, provided in Table 2.1-9, is the sum of the permanent population and the maximum transient population estimate (summer holiday weekend daily transients). Similar estimates for other transient periods may be obtained by simply summing the permanent population estimate (Table 2.1-4) and the appropriate transient population estimate. Comparison of Table 2.1-4 and 2.1-9 shows that inclusion of the maximum transient population increases total population by nearly 60 percent.2.1.3.4Low Population ZoneIn accordance with 10 CFR Part 100 guidance, the low population zone shown in Figure 2.1-5 is defined as that area falling within a four-mile radius of the center of the station site. The present number of residents (approximately 500 persons according to the 1976 estimate) within this area is sufficiently small to ensure a reasonable probability that appropriate protective action could be taken in their behalf in the event of a serious accident as required by 10 CFR 100.3.
Section15.6 shows that this area is of sufficient size to preclude an individual located on its outer CPNPP/FSAR2.1-13Amendment No. 104boundary from receiving a total dose following a postulated accident in excess of requirements in 10 CFR Part 100.11. Resident and transient populations within the zone have been discussed in detail in Sections 2.1.3.1 through 2.1.3.3.2.1.3.5Population CenterThe nearest population center (defined in 10 CFR Part 100 as more than 25,000 people) is Fort Worth, Texas. According to the 1970 census, Fort Worth has a population of 393,476 people (approximately 613,000 in metropolitan area). T he growth rate was 10.4 percent between 1960 and 1970. The geographic center of Fort Worth, which is approximately 41 miles northeast from CPNPP, does not differ significantly from its population center. Dallas, with 844,401 inhabitants (1,555,950 in metropolitan area), is 67 miles northeast of the station. Cleburne, 23 miles east of the station site with a population of 16,015 people is the next largest community in the area.
Cleburne is expected to reach a population of 25,000 by the mid 1980's, thus becoming the nearest population center as defined by 10 CFR Part 100. 2.1.3.6Population DensityThe cumulative resident population projected for the year of initial plant operation (1980) is compared with a cumulative population resulting from a uniform population density of 500 people/square mile in all directions from the plant in Figure 2.1-6. A similar comparison is made for the end of plant life (2020), but compared with a cumulative population resulting from a uniform population density of 1,000 people/square mile in Figure 2.1-7
.
CPNPP/FSAR Amendment No. 104TABLE 2.1-1HISTORICAL AND PROJECTED POPULATIONS FOR COUNTIES WITHIN 50MILES OF CPNPP(Sheet 1 of 3)County19301940195019601970Bosque15,75015,76111,83610,80910,966 Comanche18,43019,24515,51611,86511,898 Coryell19,99920,22616,28423,96135,311 Dallas325,691398,564614,799951,5271,327,321 Eastland34,15630,34523,94219,52618,092 Ellis53,93647,73345,64543,39546,638 Erath20,80420,76018,43416,23618,141 Hamilton13,52313,30310,6608,4887,198 Hill43,03638,35531,28223,65022,596 Hood6,7796,6745,2875,4436,368 Jack9,04610,2067,7557,4186,711 Johnson33,31730,38431,39034,72045,769 McLennan98,682101,898130,194150,091147,553 Palo Pinto17,57618,45617,15420,51628,962 Parker18,75920,48221,52822,88033,888 Somervell3,0163,0712,5422,5772,793 Stephens16,56012,35610,5978,8858,414 Tarrant197,178225,521361,253538,495716,317 Wise19,17819,07416,14117,01219,687 CPNPP/FSAR Amendment No. 104 ProjectionsCounty197619801990200020102020 Bosque10,77510,71110,42310,29510,35310,610 Comanche11,85011,89912,04612,42813,01513,780 Coryell37,00037,50039,90041,90043,60045,000 Dallas1,520,0001,678,1002,126,1002,658,1003,294,9004,056,700 Eastland17,00016,72615,66914,92914,32813,857 Ellis52,10055,50063,00069,60076,00082,000 Erath19,20019,90021,90023,80025,60027,400 Hamilton6,7506,4005,6004,9004,3003,700 Hill21,90021,86121,64122,00822,81624,055 Hood15,60122,00027,50033,57740,79649,118 Jack6,6006,5006,3006,0005,7005,400 Johnson55,00062,35886,509105,627128,337154,518 McLennan152,900156,600166,600174,700181,700187,700 Palo Pinto23,65024,00025,00025,75026,25026,500 Parker36,60042,58950,10556,88163,05568,975 Somervell5,2165,6165,6006,2007,5009,000 Stephens8,2008,0777,9227,9648,1308,424 Tarrant825,000892,0001,114,3001,370,9001,673,8002,029,900 Wise21,60022,90026,60030,50034,70039,300
 
Sources:
a.Historical data for 1930-1970 are from US Bureau of Census.
b.Estimates for 1976 for Hood and Somervell Counties are based on a comprehensive enumeration of housing units by Westwood Research, Inc.TABLE 2.1-1HISTORICAL AND PROJECTED POPULATIONS FOR COUNTIES WITHIN 50MILES OF CPNPP(Sheet 2 of 3)
CPNPP/FSAR Amendment No. 104c.Estimates for 1976 for counties other than Hood and Somervell, are derived from the long-term trend lines considering historical data through the 1970 Census and long-term projections described below.d.The long-term projections of population growth in all counties are projections made by various local councils of governments and Texas state agencies. Where there are significant differences in projections made by different authorities for the same county, recent experience and current and short-term trends have been considered in selecting the long-term projections for inclusion in the table.TABLE 2.1-1HISTORICAL AND PROJECTED POPULATIONS FOR COUNTIES WITHIN 50MILES OF CPNPP(Sheet 3 of 3)
CPNPP/FSAR Amendment No. 104TABLE 2.1-2CENTERS OF POPULATION WITHIN 50MILES OF CPNPP(Sheet 1 of 4)
Community(a)1970Population(b)Distance from Site in Miles (c)Direction 0-10 MilesGlen Rose1,554 4.3-5.5SE,SSE, &S Granbury2,473 9.5-10.9N Tolar312 9.7-10.6NW10-20 MilesGranbury(see Granbury, 0-10 Miles)NGodley53318.1-18.8NE Tolar(see Tolar, 0-10 Miles)NW Walnut Springs49516.3-17.5S20-30 MilesAledo62029NNEBenbrook8,16929-35NNE & NE Blum38225ESE Cleburne16,01521-25ENE & EHico97526SW & SSWIredell31622SSW Joshua92426ENE Keene2,44028ENE Lipan33322NW Meridian1,16227SSE Morgan41522SSE Rio Vista37024E Stephenville9,27724-27WSW & W CPNPP/FSAR Amendment No. 10430-40 MilesAlvarado2,12934ENE & EBenbrook(see Benbrook, 20-30 Miles)NNE & NE Burelson7,71330-33NE & ENE Clifton2,57837SSE Crowley2,66232NE Dublin2,81036WSWFort Worth393,476 (d)33-50NNE & NEEdgecliff1,14336NE Everman4,57037NE Forest Hill8,23639-40NE Gordon45738WNW Lakeside98839-40NNE Mineral Wells18,41138-42NNW River Oaks8,19339-41NNE & NE Weatherford11,75031-33N Westover Hills37437NE Westworth Village4,57838NNE & NE White Settlement13,44935-38NNE Willow Park23031-34NNE40-50 MilesArlington90,643 (d)42-50NEAzle4,49342-44NNE Blue Mound1,293 47NEDallas844,401 (d)47-50 ENETABLE 2.1-2CENTERS OF POPULATION WITHIN 50MILES OF CPNPP(Sheet 2 of 4)
Community(a)1970Population(b)Distance from Site in Miles (c)Direction CPNPP/FSAR Amendment No. 104DalworthingtonGardens75746NEDe Leon2,170 46WSW Fort Worth(see Fort Worth, 30-40 Miles)
(d)NNE & NEGrand Prairie50,904 (d)49-50ENEGustine357 48SW40-50 MilesHaltom City28,12744-48NEHamilton2,76044-46SSW Hillsboro7,224 42-46ESEHurst27,215 (d)49-50NEKennedale3,076 40-41NE Lake Worth4,958 40-41NNE Mansfield3,658 41-42ENE Maypearl46245EMidlothian2,32248-49ENEMineral Wells(see Mineral Wells, 30-40 Miles)NNW Mingus27340-41WNWNorth Richland Hills16,514 (d)47-50NEPantego1,16846NE Reno68844-49NNE Richland Hills8,86547-50NE River Oaks(see River Oaks, 30-40 Miles)NNE & NESaginaw2,38245-47NNETABLE 2.1-2CENTERS OF POPULATION WITHIN 50MILES OF CPNPP(Sheet 3 of 4)
Community(a)1970Population(b)Distance from Site in Miles (c)Direction CPNPP/FSAR Amendment No. 104Sansom Park4,77141-42NNESpringtown1,19446-47N Strawn78645WNW Valley Mills1,02249-50SSE Venus41441ENEWatauga3,611 (d)49-50NEa)Communities include all unincorporated settlements with 1,000 or more inhabitants, and all incorporated communities.b)Source is the US Bureau of Census (Ref. 2.1-1).c)Distances are indicated to the nearest and most distant portion of the densely settled area of a community rather than to city limits, as such. Beyond 20 miles the distance is rounded to the nearest mile.d)Population of the community is located partly outside of the 50 mile radius of CPNPP.TABLE 2.1-2CENTERS OF POPULATION WITHIN 50MILES OF CPNPP(Sheet 4 of 4)
Community(a)1970Population(b)Distance from Site in Miles (c)Direction CPNPP/FSAR Amendment No. 104TABLE 2.1-3POPULATION DISTRIBUTION BY SECTOR-AREA WITHIN 10MILES OF CPNPP(Sheet 1 of 2)0 to 1 Mile Zone1 to 2 Mile ZoneSector1970197619801990200020102020Sector1970197619801990200020102020 NN0000000NNENNE0000000 NENE0000000ENEENE6000000 EE0000000ESEESE3344455 SESE0000000SSENO RESIDENT POPULATIONSSE0000000 SS0000000SSWSSW3344455 SWSW6454747536477WSWWSW6121313141721 WW1291012141621 WNWWNW3333333 NWNW3000000 NNWNNW3000000TOTALTOTAL45758183921101322 to 3 Mile Zone3 to 4 Mile ZoneSector1970197619801990200020102020Sector1970197619801990200020102020N36911131620N9233341506174NNE691317202429NNE2740577187106127 NE1542587391111132NE18202936445364 ENE9999101315ENE18293743516275E0000000E15262828313845ESE1591010111315ESE426267667487106 SE36667810SE12262828313845 SSE334445606121313141721S9141414161923S0344456SSW0000000SSW9999111315 SW3121213141721SW091010111416 WSW3344456WSW6679101215W9121923283542W24202936445364WNW66911131620WNW15233139475769 NW0000000NW0000000 NNW6678101215NNW3000000TOTAL90137174203241294354TOTAL204308382433509616742 CPNPP/FSAR Amendment No. 1044 to 5 Mile Zone5 to 10 Mile ZoneSector1970197619801990200020102020Sector1970197619801990200020102020N363753668198118N1,4343,8395,4146,7668,26310,04012,087NNE21172430374554NNE931,2071,7032,1292,5993,1583,802 NE27104144181221268324NE1474095767218801,0691,287 ENE13202936445364ENE126144201249302368443E18262828313845E69189203202223270324ESE69849090100120145ESE196549591589653790948 SE9076828291110131SE70115124123136165198 SSE1,2582,2602,4332,4262,6363,2493,900SSE3637267817808631,0431,262S88185199198219265319S3898106105117141169SSW26515555617488SSW81180194193214259311 SW18454848536577SW63879494104125150 WSW6344456WSW66116144165194235283W12142025303744W4579112140171208251WNW30314455678298WNW96196275344420610614 NW3000000NW2493484916137499101,096 NNW24202936445364NNW1313626106387799461,140TOTAL1,7392,9733,2823,3603,7694,5625,477TOTAL3,2728,64311,51918,85116,66720,23724,354CUMULATIVE POPULATIONS(Miles from Site)Year0-10-20-30-40-50-10 19703 481383422,0815,353 19760 752125203,49312,136 19800812556373,91915,438 19900 832867194,07917,930 20000 923338424,61121,278 201001104041,0205,58225,819 202001324861,2286,70531,059TABLE 2.1-3POPULATION DISTRIBUTION BY SECTOR-AREA WITHIN 10MILES OF CPNPP(Sheet 2 of 2)
CPNPP/FSAR Amendment No. 104TABLE 2.1-4POPULATION DISTRIBUTION BY AGE GROUPS WITHIN 10MILE RADIUS OF CPNPP FOR YEAR2000 (Mid point of plant life)
PopulationAge GroupsNumberPercentage (a)a)As specified in Appendix D of the Regulatory Guide 4.3, Revision 2, a "test of significance" was made comparing the 1970 population distribution by age groups of Somervell County with that of the United States as a whole. The test indicated that the two distributions differed less than 10 percent. Thus, the percentages in the table above are based on the unadjusted population distribution by age groups as projected for the United States in the year 2000. The United States projection of the population by age grou ps is found in Table No. 3 of the Statistical Abstract of the United States, 1975 (Ref. 2.1-3).0-114,80722.612-182,84313.4 19 and over13,62864.021,278(b)b)Population total of the area 0 to 10 miles for the year 2000 is from Table 2.1-3100.0 CPNPP/FSAR Amendment No. 104TABLE 2.1-5POPULATION DISTRIBUTION BY SECTOR-AREA WITHIN 10MILES OF CPNPP10 to 20 Mile Zone20 to 30 Mile ZoneSector1970197619801990200020102020Sector1970197619801990200020102020N1,7793,9355,5176,8838,39210,17312,223N1,4371,5521,8062,1242,4122,6742,925 NNE8192,2133,0723,8504,6935,6916,838NNE2,0652,2412,6013,0693,4973,8934,283NE7821,1131,3661,8222,2242,7033,255NE1,6751,9252,1232,7623,3814,1134,965ENE5296427301,0121,2351,5001,806ENE13,04215,67517,77124,65530,10436,57844,037E3123774285927228781,056E14,14816,99619,26926,72932,63639,65047,738ESE280334374502606733880ESE1,9582,0382,1312,4242,6823,0143,415SE185184187193199211228SE463452451443445455474SSE201211212207209217230SSE1,9161,8821,8711,8211,7991,8081,853S647660659641640653679S235231229223220222227SSW150175182193201221245SSW1,2041,1501,1111,016939878827 SW265292304331361392426SW918913906898894896897WSW338369388429470509549WSW7,8958,3558,6599,63110,35811,14211,923W290315339379419461504W2,9873,1603,2753,6053,9174,2144,510WNW298351402462526595671WNW465490508558605651696NW3985808131,0161,2391,5031,809NW7811,0451,3771,6782,0022,3832,815 NNW2598031,1231,4011,7062,0682,484NNW9751,0531,2301,4481,6451,8282,003TOTAL7,53212,55416,09619,91323,84228,50833,883TOTAL52,16459,15865,31882,98497,536114,339133,58830 to 40 Mile Zone40 to 50 Mile ZoneSector1970197619801990200020102020Sector1970197619801990200020102020N14,44815,61018,16521,37124,25126,89229,418N4,1084,4405,1306,0296,8487,6058,340NNE35,19440,38143,80654,57466,91181,38698,337NNE32,03736,71239,92649,63260,68773,59488,663 NE211,833243,980263,809329,597405,492495,083600,405NE313,754361,432390,785488,176600,592733,291889,299ENE14,67517,46319,60426,64132,57639,61647,765ENE13,81815,84417,15421,18125,54430,61536,474E2,7183,1783,5554,7915,7786,9568,319E2,2582,5372,7423,3233,8084,3514,947ESE3,0132,9192,9142,8852,9343,0423,208ESE8,7618,4978,4868,4098,5588,8779,361SE3,4963,4013,3923,3433,3773,4763,641SE1,9691,9481,9581,9782,0292,1012,195 SSE3,2963,2403,2203,1343,0963,1133,189SSE2,1352,1182,1212,1102,1182,1492,208S768750741711693687694S911922917930939951957SSW472442420368322283243SSW3,5333,3133,1422,7472,4052,1091,815SW615623626644664686710SW1,0651,0521,0481,0441,0581,0911,138WSW3,6823,8974,0384,4434,8305,1965,560WSW3,5063,4963,5123,5603,6753,8514,078W7367808088899661,0391,112W1,2831,2431,2371,2121,2061,2101,226WNW733647654693725753774WNW1,3431,1311,1311,1681,2011,2221,232 NW1,2601,0441,0441,0881,1201,1421,153NW1,1389439439821,0121,0321,041NNW18,74816,56617,29218,70819,90720,90821,752NNW10,7699,56210,00810,85211,57112,17212,685TOTAL315,687354,921384,088473,880573,652690,258826,280TOTAL402,388455,190490,240603,333733,251886,2211,065,659CUMULATIVE POPULATIONS(Miles from Site)Year0-100-200-300-400-5019705,35312,88565,049380,736783,124 197612,13624,69083,848438,769893,959198015,43831,53496,852480,940971,180199017,93037,843120,827594,7071,198,040 200021,27845,120142,656716,3081,449,559201025,81954,327168,726858,9841,745,205202031,05964,942198,5301,024,8102,090,469 CPNPP/FSAR Amendment No. 104a)As specified in Appendix D of the Regulatory Guide 4.3, Revision 2, a "test of significance" was made comparing the 1970 population distribution by age groups of Somervell County with that of the United States as a whole. The test indicated that the two distributions differed less than 10 percent. Thus, the percentages in the table above are based on the unadjusted population distribution by age groups as projected for the Un ited States in the year 2000. The United States projection of the population by age grou ps is found in Table No. 3 of the Statistical Abstract of the United States, 1975 (Ref. 2.1-3).b)Population total of total area between 10 miles and 50 miles for the year 2000 is from Table2.1-5
.TABLE 2.1-6POPULATION DISTRIBUTION BY AGE GROUPS BETWEEN 10AND 50MILE RADIUS OF CPNPP FOR YEAR2000 (Mid point of plant life)
PopulationAge GroupsNumberPercentage(a)0-11322,79122.612-18191,39013.419 and over914,09064.01,428,271100.0 CPNPP/FSAR Amendment No. 104TABLE 2.1-7TYPE AND TYPICAL LENGTH OF STAY OF TRANSIENTS WITHIN 10MILE RADIUS OF CPNPPType of TransientsTypical Length of StayOvernight Transients (Seasonal Visitors)Camping (Campgrounds and RV Parks)Winter visitors for weekends Summer visitors for one weekChildrens' InstitutionIndefinite(a)a)The children of the institution are listed as transients because they are not included in the estimate and projections of the permanent population. Some students are live-in and some attend day only.Hotels/MotelsTwo daysOrganizational CampsWinter campers for weekends Summer campers for 1 to 2 weeksVacation HomesWinter visitors for weekends Summer length of stay cannot be specified for lack of dataDaily TransientsChildrens' InstitutionEight hours Recreation (Parks and Lakes)Four hours SchoolsEight hours Shopping CentersThree hours CPNPP/FSAR Amendment No. 104TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 1 of 24)Daily Transient - Summer Weekday0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020N0310101010N038143143143143 NNE0727272727NNE02388888888 NE014444NE080295295295295 ENE014444ENE01452525252E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW001111NW027777 NNW014444NNW01347474747TOTAL01350505050TOTAL01706326326326322 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N000000 NNE000000NNE000000 NE0210101010NE000000 ENE025555ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW100110138171211260 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW013333NW013333 NNW01350505050NNW013333TOTAL01868686868TOTAL100112144177217266 CPNPP/FSAR Amendment No. 104Daily Transient - Summer Weekday4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020N000000N84011611535180721352505 NNE000000NNE176219380380380380 NE000000NE171213369369369369 ENE000000ENE000000E000000E000000ESE000000ESE000000SE000000SE000000 SSE285308309346419504SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL285308309346419504TOTAL118715932284255628843254CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-1019760001003851572 1980131832013136212214 19905068275089412033487 20005068275092212683824 20105068275096713864270 202050682750101615204774TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 2 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Summer Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N0623232323N085319319319319 NNE01761616161NNE052195195195195 NE029999NE0177660660660660 ENE029999ENE031115115115115E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW012222NW0416161616 NNW028888NNW028106106106106TOTAL030112112112112TOTAL037714111411141114112 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N000000 NNE000000NNE000000 NE0622222222NE000000 ENE0311111111ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW8008781102137016932076 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000NW026666NW025555 NNW030113113113113NNW016666TOTAL041152152152152TOTAL8008811113138117042087TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 3 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Summer Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N207528743778446452916222 NNE000000NNE392488845845845845 NE000000NE381475822822822822 ENE000000ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE535580585653790952SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL535580585653790952TOTAL284838375445613169587889CUMULATIVE TRANSIENT POPULATION(miles from site)YEAR0-10-20-30-40-50-10 197600080013354183 198030407448132919095746 199011215231675278833738818 200011215231675305637099840 2010112152316753379416911,127 2020112152316753762471412,603TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 4 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Summer Holiday Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N0935353535N0133495495495495 NNE02593939393NNE080302302302302 NE0414141414NE02741022102210221022 ENE0415151515ENE049179179179179E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW014444NW0624242424 NNW0313131313NNW044164164164164TOTAL046174174174174TOTAL058621862186218621862 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N000000 NNE000000NNE000000 NE0833333333NE000000 ENE0517171717ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW96910601330165820442506 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW0310101010NW029999 NNW047174174174174NNW029999TOTAL063234234234234TOTAL96910641348167620622524TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 5 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Summer Holiday Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N312743285697672579659362 NNE000000NNE6087571312131213121312 NE000000NE5907351275127512751275 ENE000000ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE122413391496176621602625SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL122413391496176621602625TOTAL43255820828493121055211949CUMULATIVE TRANSIENT POPULATION(miles from site)YEAR0-10-20-30-40-50-10 197600096921936518 198046632695175930988918 1990174236025943942543813,722 2000174236025944270603615,348 2010174236025944656681617,368 2020174236025945118774319,692TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 6 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient - Winter Weekday0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020N015555N028888 NNE015555NNE024444 NE014444NE031114114114114 ENE014444ENE0416161616E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW001111NW027777 NNW014444NNW0413131313TOTAL0523232323TOTAL0451621621621622 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N000000 NNE000000NNE000000 NE012222NE000000 ENE015555ENE000000E000000E178787878787ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW8811141721 SW000000SW000000 WSW000000WSW000000WOOOOOOW000000WNW000000WNW000000 NW013333NW013333 NNW0210101010NNW013333TOTAL0520202020TOTAL2597104107110114TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 7 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient - Winter Weekday4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020N000000N121516992160261131563769 NNE000000NNE6986151151151151 NE000000NE6885147147147147 ENE000000ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE71677476885210311238SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW221312389475579696 NNW000000NNW000000TOTAL71677476885210311238TOTAL157321922847338440334763CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-10 1976000257412314 1980550551529263118 19902318520530910773924 20002318520531211644548 20102318520531513465379 20202318520531915576320TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 8 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Winter Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N028888N0313131313 NNE029999NNE026666 NE027777NE051187187187187 ENE027777ENE0727272727E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW012222NW0312121212 NNW026666NNW0623232323TOTAL01139393939TOTAL0722682682682682 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N000000 NNE000000NNE000000 NE013333NE000000 ENE029999ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW202227344251 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW015555NW014444 NNW0516161616NNW014444TOTAL0933333333TOTAL202435425059TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 9 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Winter Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N163122851209350942315047 NNE000000NNE116145250250250250 NE000000NE113141243243243243 ENE000000ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE515556555616745897SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL515556555616745897TOTAL186025711702400247245540CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-10 1976000205352395 19801183921166723243 1990393073403759302632 2000393073403829985000 20103930734039011355859 20203930734039912966836TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 10 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Winter Holiday Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020N0416161616N0727272727 NNE0417171717NNE0412121212 NE0415151515NE0104390390390390 ENE0416161616ENE01555555555E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW014444NW0725252525 NNW0413131313NNW01347474747TOTAL02181818181TOTAL01505565565565562 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N000000 NNE000000NNE000000 NE027777NE000000 ENE0518181818ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW4752658099122 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW0310101010NW029999 NNW0934343434NNW029999TOTAL01969696969TOTAL47568398117140TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 11 of 24)
CPNPP/FSAR Amendment No. 104Daily Transient-Winter Holiday Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N258536124627556066847951 NNE000000NNE241300520520520520 NE000000NE234292505505505505 ENE000000ENE000000E000000E000000ESE000000ESE000000 SE000000SE000000 SSE6817367408249981200SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL6817367408249981200TOTAL306042045652658577098976CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-10 1976000477283788 1980211711902469825186 19908163770678915297181 20008163770680416288213 20108163770682318219530 202081637706846204611,022TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 12 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Summer Weekday0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NNNNENNENENEENEENEEEESEESESESESSENO TRANSIENT POPULATIONSSENO TRANSIENT POPULATION SSSSWSSWSWSWWSWWSWWWWNWWNWNWNWNNWNNWTOTALTOTAL2 to 3 Mile Zone 3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NN000000NNENNE000000 NENE000000ENEENE000000 EE137070707070ESEESE000000 SESE000000SSENO TRANSIENT POPULATIONSSE000000 SS000000SSWSSW8088110138170208 SWSW000000WSWWSW000000 WW000000WNWWNW000000 NWNW000000NNWNNW000000TOTALTOTAL93158180208240278TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 13 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Summer Weekday4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020N000000N520708945110713021525 NNE000000NNE7489741253143816591913 NE000000NE241320472519576641 ENE000000ENE263645556680E275275275275275275E242626283441ESE000000ESE183184184185187189 SE000000SE450450450450450450 SSE240297314341379423SSE000000S000000S000000SSW000000SSW000000 SW707070707070SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL585642659686724768TOTAL219226983375378242744839CUMULATIVE TRANSIENT POPULATION(miles from site)YEAR0-10-20-30-40-50-10 1976000936782870 19800001588003498 19900001808394214 20000002088944676 20100002409645238 202000027810465885TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 14 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Summer Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NNNNENNENENEENEENEEEESEESESESESSESSESNO TRANSIENT POPULATIONSNO TRANSIENT POPULATIONSSWSSWSWSWWSWWSWWWWNWWNWNWNWNNWNNWTOTALTOTAL2 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NN000000NNENNE000000 NENE000000ENEENE000000 EE137070707070ESEESE000000 SESE000000SSESSE000000 SS000000SSWNO TRANSIENT POPULATIONSSW161175220274337413
 
SWSW000000WSWWSW000000 WW000000WNWWNW000000 NWNW000000NNWNNW000000TOTALTOTAL174245290344407483TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 15 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Summer Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N99413461814211324702879 NNE000000NNE157418322417278832283737 NE000000NE44959089696710521150 ENE000000ENE527390109133160E275275275275275275E485251576982ESE000000ESE191192192194198203 SE000000SE450450450450450450 SSE306373409459524601SSE000000S000000S000000SSW000000SSW000000 SW707070707070SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL651718754804869946TOTAL375845355910667876008661CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-1019760001748254583 19800002459635498 199000029010446954 200000034411487826 201000040712768876 2020000483142910,090TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 16 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Summer Holiday Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NNNNENNENENEENEENEENO TRANSIENT POPULATIONENO TRANSIENT POPULATIONESEESESESESSESSESSSSWSSWSWSWWSWWSWWWWNWWNWNWNWNNWNNWTOTALTOTAL2 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NN000000NNENNE000000 NENE000000ENEENE000000ENO TRANSIENT POPULATIONE137070707070ESEESE000000 SESE000000SSESSE000000 SS000000SSWSSW161175220274337413 SWSW000000WSWWSW000000 WW000000WNWWNW000000 NWNW000000NNWNNW000000TOTALTOTAL174245290344407483TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 17 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Summer Holiday Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N145719922695313336524252 NNE000000NNE209627843670422748865647 NE000000NE6558561316141115241654 ENE000000ENE80112138168204246E400400400400400400E72777785103123ESE000000ESE200202201204209215 SE000000SE556556556556556556 SSE67667979093111051312SSE000000S000000S000000SSW000000SSW000000 SW100100100100100100SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL117611791290143116051812TOTAL51166579865397841113412693CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-10197600017413506466 198000024514248003 1990000290158010,233 2000000344177511,559 2010000407201213,146 2020000483229514,988TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 18 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Winter Weekday0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NNNNENNENENEENEENEEEESEESESESESSENO TRANSIENT POPULATIONSSENO TRANSIENT POPULATION SSSSWSSWSWSWWSWWSWWWWNWWNWNWNWNNWNNWTOTALTOTAL2 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 NN000000NNENNE000000 NENE000000ENEENE000000 EE137070707070ESEESE000000 SESE000000SSENO TRANSIENT POPULATIONSSE000000 SS000000SSWSSW000000 SWSW000000WSWWSW000000 WW000000WNWWNW000000 NWNW000000NNWNNW000000TOTALTOTAL137070707070TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 19 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Winter Weekday4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N990900N200280357431517617 NNE000000NNE206288369443530631 NE000000NE486592104119136 ENE000000ENE101417212631E000000E101111121417ESE000000ESE333445 SE000000SE000000 SSE02828313845SSE000000S000000S000000SSW000000SSW000000 SW000000SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL02828313845TOTAL477661849101512101437CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-10 19760001313490 19800007098759 19900007098947 2000000701011116 2010000701081318 2020000701151552TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 20 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Winter Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NNNNENNENENEENEENEEEESEESESESESSENO TRANSIENT POPULATIONSSENO TRANSIENT POPULATION SSSSWSSWSWSWWSWWSWWWWNWWNWNWNWNNWNNWTOTALTOTAL2 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NN000000NNENNE000000 NENE000000ENEENE000000 EE137070707070ESEESE000000 SESE000000SSESSE000000 SS000000SSWNO TRANSIENT POPULATIONSSW000000
 
SWSW000000WSWWSW000000 WW000000WNWWNW000000 NWNW000000NNWNNW000000TOTALTOTAL137070707070TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 21 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Winter Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N266369475569682812 NNE000000NNE363467575667776902 ENE000000ENE121721253137E100100100100100100E121313141721ESE252525252525ESE179179179180181182 SE000000SE235235235235235235 SSE240285303330366406SSE000000S000000S000000SSW000000SSW000000 SW707070707070SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL435480498525561601TOTAL115013921655187021292426CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-10 1976000134481598 1980000705501942 1990000705682223 2000000705952465 2010000706312760 2020000706713097TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 22 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Winter Holiday Weekend0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NNNNENNENENEENEENEEEESEESESENO TRANSIENT POPULATIONSENO TRANSIENT POPULATIONSSESSESSSSWSSWSWSWWSWWSWWWWNWWNWNWNWNNWNNWTOTALTOTAL2 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020
 
NN000000NNENNE000000 NENE000000ENEENE000000 EE137070707070ESEESE000000 SESE000000SSENO TRANSIENT POPULATIONSSE000000 SS000000SSWSSW161175220273337413 SWSW000000WSWWSW000000 WW000000WNWWNW000000 NWNW000000NNWNNW000000TOTALTOTAL174245290343407483TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 23 of 24)
CPNPP/FSAR Amendment No. 104Overnight Transient-Winter Holiday Weekend4 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N000000N5467811002120214401715 NNE000000NNE78810621337158318752213 NE000000NE160216304345394450 ENE000000ENE3650627592111E100100100100100100E323434384655ESE757575757575ESE188189189190192194 SE000000SE235235235235235235 SSE57165776890910781280SSE000000S000000S000000SSW000000SSW000000 SW707070707070SW000000 WSW000000WSW000000W000000W000000WNW000000WNW000000 NW000000NW000000 NNW000000NNW000000TOTAL8169021013115413231525TOTAL198525673163366842744973CUMULATIVE TRANSIENT POPULATION (miles from site)YEAR0-10-20-30-40-50-10 19760001749902975 198000024511473714 199000029013034466 200000034314975165 201000040717306004 202000048320086981TABLE 2.1-8TRANSIENT POPULATION PROJECTIONS(Sheet 24 of 24)
CPNPP/FSAR Amendment No. 104TABLE 2.1-9MAXIMUM PERMANENT AND TRANSIENT POPULATION DISTRIBUTION BY SECTOR-AREA(Sheet 1 of 2)0 to 1 Mile Zone1 to 2 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N0935353535N0133495495495495 NNE02593939393NNE080302302302302 NE0414141414NE02741022102210221022 ENE0415151515ENE049179179179179E000000E000000ESE000000ESE344455 SE000000SE000000 SSE000000SSE000000S000000S000000SSW000000SSW344455 SW000000SW454747536477 WSW000000WSW121313141721W000000W91012141621WNW000000WNW333333 NW014444NW0624242424 NNW0313131313NNW044164164164164TOTAL046174174174174TOTAL7566722692278229623182 to 3 Mile Zone3 to 4 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N6911131620N233341506174 NNE91317202429NNE40577187106127 NE4266106124144165NE202936445364 ENE91426273032ENE293743516275E000000E262828313845ESE91010111315ESE6267667487106 SE6667810SE262828313845 SSE344456SSE121313141721S141414161923S344456SSW000000SSW97810691339166920572521 SW121213141721SW91010111416 WSW344456WSW679101215W121923283542W202936445364WNW6911131620WNW233139475769 NW0310101010NW029999NNW654182184186189NNW029999TOTAL137237437475528588TOTAL127714461781218526783266 CPNPP/FSAR Amendment No. 1044 to 5 Mile Zone5 to 10 Mile ZoneSector197619801990200020102020Sector197619801990200020102020 N3753668198118N6966974212,46314,98818,00521,449 NNE172430374554NNE181524603,4413,9114,4705,114 NE104144181221268324NE99913111,9962,1552,3442,562 ENE202936445364ENE144201249302368443E262828313845E189203202223270324ESE849090100120145ESE549591589653790948 SE76828291110131SE115124123136165198 SSE348437723922445254096525SSE7267817808631,0431,252S185199198219265319S98106105117141169SSW515555617488SSW180194193214259311 SW454848536577SW879494104125150 WSW344456WSW115144165194235283W142025303744W79112140171208251WNW314455678298WNW196275344420510614 NW000000NW3484916137499101,095 NNW202936445364NNW3625106387799461,140TOTAL419746214856553567228102TOTAL12,96817,33922,13525,97930,78936,303CUMULATIVE POPULATIONS(Miles from Site)Year0-10-20-30-40-50-10 197607521214895,68618,654 19804671395023967,01724,356 19901742443288046619,51731,652 200017424522927511210,64736,626 201017424702998567612,39843,187 202017424923080634614,44850,751TABLE 2.1-9MAXIMUM PERMANENT AND TRANSIENT POPULATION DISTRIBUTION BY SECTOR-AREA(Sheet 2 of 2)
CPNPP/FSAR2.2-1Amendment No. 1042.2NEARBY INDUSTRIAL, TRANSPORTATION AND MILITARY FACILITIES2.2.1LOCATIONS AND ROUTESInvestigation has been undertaken to locate all significant manufacturing plants; chemical plants; refineries; storage facilities; mining and quarrying operations; military bases; missile sites; transportation routes (air, land, and water); transportation facilities; oil and gas pipelines, drilling operations and wells; and underground gas storage facilities. The search included military firing ranges, and nearby airplane high and low-level flights and landing patterns (commercial, general aviation and military).The CPNPP vicinity is essentially devoid of most of these features. Within the 10-mile area, there are no military bases, missile sites, military firing ranges, munitions facilities, airport approaches, chemical plants, and storage facilities, tank farms or upstream sources of corrosive or oil discharges. The nearest military base s are Carswell Air Force Base, approximately 38 miles north-northeast, and Fort Hood, approximately 65 miles south. There are no missile sites
 
within 50 miles. The nearest manufacturing facility is a textile plant in Granbury, 10 miles north.Principal transportation routes extending to within 10 miles of the Station site consist of two U. S. highways and one state highway, one railroad, eleven air routes (refueling tracks and Victor lanes), three gas transmission pipelines, and one cr ude oil transmission pipeline. Air routes out to more than 20 miles are shown on Figure 2.2-1; other transportation routes can be seen in Figure 2.1-5
.No heavily traveled highways pass close to the site. All nearby roads have one or two lanes and have relatively light traffic (Figure 2.1-5). The nearest highway is State Highway 144, 2.5 miles northeast. The closest approach to U. S. Highway 67 is approximately 4.5 miles south-southwest, and the nearest approach to U. S. Highway 377 is nine miles north-northeast. The Atchinson, Topeka and Santa Fe Railroad nearest approach is about 9.5 miles to the northwest.2.2.2DESCRIPTIONS 2.2.2.1Description of FacilitiesThe only industrial, transportation, or military fa cilities within five miles of the site are the transportation corridors shown on Figures 2.1-5 and 2.2-1. Furthermore, there are no industrial, transportation or military facilities at greater distances which are significant to CPNPP from a safety standpoint.2.2.2.2Description of Products and Materials The only hazardous materials (excluding local gas stations and materials not directly related to CPNPP) regularly manufactured, stored, used, or transported in the site vicinity are crude oil and natural gas transported through the pipelines described in Section 2.2.2.3
.2.2.2.3Pipelines And Wells
 
The four pipelines traversing the site vicinity are described in Tables 2.2-1 and 2.2-2; their locations are shown in Figure 2.5.1-17. Two of the pipelines (the West Texas Gulf crude oil line CPNPP/FSAR2.2-2Amendment No. 104and the Lone Star Gas Company line) were relocated around Squaw Creek Reservoir to avoid the immediate Station and reservoir areas. The relocated routes are shown on Figure 2.1-2b
. Figure 2.5.1-17 also shows the location of gas and oil wells within five miles of CPNPP.2.2.2.4WaterwaysSquaw Creek Reservoir (SCR) is a 3,272 acre cooling reservoir located on Squaw Creek (see Section 2.4), which is not used for navigation. A Safe Shutdown Impoundment (SSI) on the Panther branch of SCR impounds water for the Station Service Water System as described in Sections 2.4 and 9.2.5.2.2.2.5Aircraft 2.2.2.5.1AirportsThere are no airports within five miles of the Station. Furthermore, there are no airports with greater than 500 d 2 ("d" is the distance in miles from the Station) movements per year within 10miles, nor are there any airports with projected operations in excess of 1000 d 2 movements per year within 50 miles.The nearest landing field (Bar L Ranch) is a sod strip located six miles west-southwest of the site. There are several other sod strips within 20 miles of the site, but the only paved strips are Nassau Bay (private), Pecan Plantation (private), and the Granbury Municipal Airport. The Granbury Municipal Airport (11 miles north-northwest) has a lighted 2,000-foot paved runway, but there are no regularly scheduled commercial flights.2.2.2.5.2Air Routes Eleven air routes pass within 10 miles of the sit
: e. Three of these routes are military refueling tracks (flight levels:  24,000 to 31,000 feet) having 10 nautical-mile wide paths (Figure 2.2-1
). The outer limits of all three refueling tracks miss the Station site; their nearest approach to the site is the north edge of AR-102B (East), located 1.7 miles south. The north edge of AR-102B (West) is the next closest refueling track, 2.5 miles south. The closest approach of the south limit of AR-102 A (East) is 8.5 miles north of the Station.The other air routes are Victor lanes which (Figure 2.2-1
) are cleared for general, commercial and military aviation. Victor 163W and Victor 163 air lanes are the only routes which pass within 2 miles of the Station location.The probability of an aircraft crashing into the plant (PFA) is estimated in the following manner:PFA=C
* N
* X * (A/B) where:
C=inflight crash rate  (crashes per mile),
N=number of flights per year in the air sector, CPNPP/FSAR 2.2-3Amendment No. 104For CPNPP:
Therefore, P FA = 1.91 x 10
-7. This probability is sufficiently low that an aircraft crash into the plant is not considered a design basis.2.2.2.6Projections of Industrial GrowthIndustrial growth includes the Station and related pipelines, transmission lines, railroad spur, and access roads. With the exception of natural ga s exploration, no industrial growth can reasonably be expected to occur in the site vicinity.2.2.3EVALUATION OF POTENTIAL ACCIDENTSThe nearby industrial, transportation, and military facilities described above were evaluated for their potential effects on the station in order to identify potential accidents to be considered as design basis events. In addition, the onsite storage of chlorine was evaluated for its effect on control room habitability as described in Section 6.4
.2.2.3.1Determination of Design Basis EventsEvents which potentially qualify as design basis events were categorized by the physical effects which accompany the accident.
2.2.3.1.1ExplosionsThere are no offsite sources of explosive materials in the vicinity and transportation routes do not approach CPNPP within the distance prescribed by Reg. Guide 1.91 [8].
X=flight distance in passing possible collision area,A=effective area of plant, and B=possible collision areaC=1.14 x 10-9 crash/mile,N=130,104 flights/year, X=12.63 miles A=0.02 square miles, B=314.16 square miles.
CPNPP/FSAR2.2-4Amendment No. 104An explosion, therefore, is not considered a design basis event.2.2.3.1.2Flammable Vapor Clouds The three natural gas pipelines in the site vicinity could be a source of flammable vapor clouds and were evaluated for their potential effects on the plant.The gas wells in the site vicinity, described in Section 2.5.1, could also be a source of flammable vapor clouds and were evaluated for their potential effects on the plant. Since exploration in the area is still active, a hypothetical gas well was postulated using data available from the Texas Railroad Commission. A discussion of this hypothetical well is provided in Section 2.5.1
.2.2.3.1.3Toxic Chemicals Toxic chemicals which are stored and used onsite at CPNPP are evaluated in accordance with the criteria and guidance of Regulatory Guide 1.78 and NUREG 0570.2.2.3.1.4FiresThe only non-plant-related source of fire in the vicinity of CPNPP is the crude oil pipeline. The rupture of this pipeline was evaluated for its potential effect on the plant.2.2.3.1.5Collision with Intake Structure The Service Water Intake Structure is located on the Safe Shutdown Impoundment (see Figure1.2-1), which is not open to public transportation. Therefore, a significant collision with this structure is not considered a credible event.2.2.3.1.6Liquid Spills The only source of liquid spills in the vicinity of CPNPP is the crude oil pipeline which was evaluated for its potential effect on the plant.2.2.3.2Effects of Design Basis EventsThe design basis events identified above are:1.Gas Pipeline and Gas Well Accidents 2.Accidental Release of Toxic Chemicals3.Crude Oil Pipeline RuptureEach of these is evaluated below.
2.2.3.2.1Gas Pipeline and Gas Well Accidents Potential accidents involving the release of natural gas from exis ting pipelines and postulated wells described in Section 2.2.2 do not pose a hazard to the plant. As shown below, in the event of an accident the concentration of gas at all plant air intakes is well below the lower flammability CPNPP/FSAR 2.2-5Amendment No. 104limit. Also detonation of an unconfined natural gas-air mixture is not considered to be a credible event [1,2,3,4].Each of the existing pipelines and a potential gas well were analyzed to determine the most limiting potential accident condition; the results of this analysis indicated that the most limiting release of natural gas would involve a break in the 36-inch Lo-Vaca natural gas pipeline. The analysis of this accident was performed using the following conservative assumptions:
: 1. 2.Gas is released by a constant enthalpy process yielding a gas temperature for dispersion calculations of 40&#xba;F (for a 60&#xba;F initial gas temperature) due to the Joule-Thompson effect.3.The flowrates out of the break is the maximum steady flow for single-ended break (572m3/sec) and a double-ended break (1144 m 3/sec).4.Atmospheric dispersion factors were based on the 5-percentile meteorological conditions from onsite data analyses with a virtual source distance correction to account for initial finite source size.5.A conservatively low wind speed of 1.0 m/sec was used.6.Plume rise is in accordance with Briggs equation for stable (classes F and G) atmospheric conditions [5] and an air temperature of 100&#xba;F.A perfect gas prior to its escape from the broken pipe will expand and accelerate toward the break. As the gas expands, it will tend to cool down from its original equilibrium temperature. In doing so, a temperature gradient between the pipe and the flowing gas will be established. In addition, friction between the pipe wall and the flowing gas will tend to heat the gas slightly above the temperature it would possess in a frictionless expansion. In the first instance, small amounts of heat will flow from the pipe wall into the expanding gas and in the other, energy already possessed by the gas is simply transformed into heat and causes the gas temperature to rise slightly more. Thus, the gas gains a small amount of energy from the pipe wall during this process.In the second part of the blowdown process, the gas expands through the break at sonic velocity and, if still above atmospheric pressure, continues to expand until it reaches atmospheric pressure. During this phase, the process is essentially adiabatic. No work is performed either during the expansion or the slowing down period. Consequently, the net energy possessed by the gas just prior to reaching the break, and after it slows down in the atmosphere, remains unchanged.Since (1) no work has been performed by the escaping natural gas, (2) small quantities of heat have been transferred from the pipe to the gas, and (3) a transformation of energy has occurred by virtue of the fact that the gas is at a substantially lower pressure at the end of the blowdown, the energy gain from (2) above and the energy tran sformation indicated in (1) above must be present in the form of heat. Therefore, the slowed down natural gas in the atmosphere would be at a slightly higher temperature than the original temperature. The blowdown is therefore, in CPNPP/FSAR 2.2-6Amendment No. 104essence, a throttling or isenthalpic process. Since natural gas is a real gas, not a perfect gas, the Joule-Thompson effect will cause the natural gas to be about 20&#xba;F below that expected for a perfect gas after blowdown.The above description of the process indicates that there is a tendency for a perfect gas after the blowdown and mixing phase to be at a slightly higher temperature than the original temperature. However, with real gases, this temperature increase is lessened or, perhaps, reversed slightly. Therefore, extra conservatism is introduced into the plume rise analysis by assuming that the natural gas does not mix thermally with air and is cooled isenthalpically 20&#xba;F below the temperature it possessed prior to the break.
The flowrate was found using the American Gas Association gas pipeline formula [6] using an initial upstream pressure of 1050 psig, a final (downstream or break) pressure of 14.7 psia, and pipe length of 70 miles. This length is the distance from the break to both the upstream and downstream compressors.Dispersion of potentially explosive gas vapors resulting from a gas pipeline rupture is governed by meteorological conditions existing in the locality at the time. This analysis used design basis accident meteorological assumptions determined fo r a radioactive release in the analysis of a flammable and/or explosive structure. The design basis accident assumption doses were calculated using conditions which conservatively calculate radioactive cloud concentrations, i.e., those conditions which minimize diffusion of the c loud. The conditions assume five percentile dispersion factors as an analysis basis conservatism. The Dispersion calculations also conservatively assumed that there was no momentum flux in the plume rise calculation. In reality, because the pipe is below grade, the gas would be expected to have a significant vertical velocity component. This would tend to carry the plume higher than calculated. Atmospheric dispersion factors and the model used for virtual source correction are discussed as part of the description of the gas well blowout hazard analysis at the end of this section (2.2.3.2.1
).
CPNPP/FSAR 2.2-7Amendment No. 104 Though a sustained gas fire may occur at or near the gas well head, a gas well fire at the closest point where mineral exploration may be permitted has negligible heat effects on the nearest safety-related structure, and no effect on safety-related structures due to the release and delayed ignition of non-buoyant natural gas components such as ethane and propane. Conservatively estimating all the heat from a gas well blow out to be radiated isotropically, the resultant sustained incident energy on the surface of a sphere 2250 feet away gives a heat flux loading of about ten percent of the maximum solar insolation at the site. The heated air would rise clear of the plant at low wind speeds, while a strong wind is needed to keep the buoyant heated plume near the surface. These conditions imply ventilation and mixing sufficient to keep any temperature rise at the plant to a non-significant level.Each Control Room fresh air intake is equipped with a smoke detector that will annunciate in the Control Room in the advent of elevated smoke levels. Their operation is discussed in Section6.4.2.4 and 9.4.1.3. Thus, smoke effects from mineral explosion fires are responded to adequately in a manner similar to smoke from plant fires.
The atmosphere dispersion model used for the gas well blowout hazard analysis was the Gaussian plume model for centerline concentrations with ground level releases and the Pasquill-Gifford dispersion parameters for an assumed non-buoyant release. Atmosphere dispersion factors for an instantaneous release with a finite initial volume were calculated in accordance with Reg. Guide 1.78 [13]. Wind speed was selected to maximize the instantaneous concentration within the Control Room. Additional credit due to building wake effects was not included in the model. Also, the difference in height of the release point and Control Room inlet is not large enough to allow credit for an elevated release. Atmospheric dispersion factors for a continuous release are based on a 5-percentile meteorological conditions (such as Pasquill F at 1.0 meters/second) at the site. To establish these conditions, the 5-percentile x/Q's for each time period were first determined from the result s of onsite dispersion modeling. See Section 2.3.4
. Because approximately 30 percent of hourly obse rvations at the plant si te are in the Pasquill F CPNPP/FSAR2.2-8Amendment No. 104and G stability classes, a Pasquill F stability was assumed, and the wind speed was defined at the 5 percentile probability level of relative co ncentration. Having def ined the 5-percentile wind speed and Pasquill Class for the three time periods of interest, x/Q values were then calculated at selected distances using these meteorological conditions. The parameters used were:*Distance from plant to well:  2250 ft.*Maximum postulated gas well blowout flow rate:  52.4 x 10 6 ft3 day-1 (17.2 m3 sec-1)*Lower well gas flammabilit y limit concentration: 4%*Virtual source correction: 278 ft.The assumption is that the concentration of the released gas at the break is limited to unity. To satisfy this requirement, the source is taken to be a virtual point located a distance away from the actual release point. From a table of the 5-percentile x/Q's for the plant, this value is found to occur at a distance of 278 ft. This then is effectively added to the plant-well separation distance as the virtual source correction term.The flammable limit was calculated on a mole-fraction-weighted bases of all the components assuming they are mixed in the turbulent stream emitted from the well. The well gas composition used was:2.2.3.2.2Accidental Release of Toxic ChemicalsA study has been performed to evaluate the potential for chlorine releases from offsite chlorine storage and transportation affecting control room habitability. This study revealed no chlorine storage locations or frequent chlorine transportation within a 5 mile radius of CPNPP in quantities that are large enough to require evaluation under the criteria of Regulatory Guide 1.78. Therefore, potential accidents involving the release of chlorine from offsite storage locations and transportation routes do not pose a significant hazard to control room habitability.Nitrogen 2.36 mole %
CO2 0.55 mole %Methane73.97 mole %
Ethane13.58 mole %
Propane 6.95 mole %
Iso-butane 0.88 mole %
N-butane 0.83 mole %
Iso-pentane 0.35 mole %
N-pentane 0.22 mole %
Hexanes plus 0.33 mole %
CPNPP/FSAR 2.2-9Amendment No. 104 The circulating cooling water and service water sy stems will be chemically treated for control of biological growth with solutions of sodium hypochlorite and sodium bromide. The diluted sodium hypochlorite and sodium bromide solutions will not present a threat to control room habitability. No liquified chlorine will be stored within the site boundary in containers exceeding 150 lbs capacity. The only liquified chlorine that will be stored within the protected area will be in small quantities of 20 lbs or less to be used for laboratory purposes.Other toxic chemicals which are stored and used onsite at CPNPP are evaluated for potential impact of their release upon control room habitability in accordance with the criteria and guidance of Regulatory Guide 1.78 and NUREG 0570. Toxic chemicals which are determined to be hazardous to control room habitability are controlled and detection instrumentation is provided, as appropriate.2.2.3.2.3Oil Pipeline Accidents Gulf indicates that from experience the lower limit on immediate detection and isolation is 400Bbl/hr.[10]  Smaller leaks could be detected over a period of time and would result in the initiation of an immediate search for the leak. CPNPP personnel will monitor for oil accumulation in the three retaining ponds located between the  pipeline and the westside of the SSI once per day ensuring that leaks smaller than 400 Bbl/hr do not go undetected for more than 32 hours. 
 
CPNPP/FSAR 2.2-10Amendment No. 104 In order to prevent the spilled oil from reaching the SSI, three retaining ponds will be built between the pipeline and the SSI. These ponds will be designed to hold the maximum quantity of oil given above or 14,770 Barrels. Rain water accumulation in these ponds will be drained through an inverted weir to ensure capacity is available for the  maximum oil spill quantity. These retaining ponds eliminate any potential hazards resulting directly or indirectly from the crude oil spilling onto the SSI surface.
With the crude oil being kept from the SSI by the retaining ponds, the only remaining potential impact on the plant would be from drifting vapor c louds. Potential toxic and flammable vapor effects have been considered as discussed below. The crude oil carried in the pipe may contain hydrogen sulfide (H 2S) which is toxic gas. The pipeline operator has indicated that the maximum H 2S concentration is 80 ppm in air measured 23/4" above a crude oil sample at 60&#xba;F [9,11]. Fu rther information from Gulf indicated the best available measurement of H 2S concentration in the crude is 250 ppm obtained by mass spectrographic techniques, while 400 ppm is obtained by other techniques.[11]
 
A conservative calculation of H 2S concentration in the CPNPP control room was made assuming: 1.All H2S was released instantaneously from a leak of 13,500 Bbl/hr of crude oil containing 400 ppm H 2S. 2.This formed a continuous source of H 2S which is blown toward the plant with worst 5percentile site atmospheric dispersion. 3.The control room air intake sees the resulting plume centerline concentration (94mg/m
: 3) for 10 minutes (note that the pipeline leak flow only occurs for 2.5 minutes.)  4.Normal control room ventilation of 3000 CFM continues for the entire 10 minutes.
Maximum Rate Case Maximum Quantity Case CPNPP/FSAR2.2-11Amendment No. 104The resulting maximum concentration in the control room is 8.5 mg/m
: 3. This is less than the time weighted average threshold limit value of 15 mg/m 3 recommended by the American Conference of Governmental Industrial Hygienists.[12]  The control room concentration and the outside air concentration are far below the R.G. 1.78[13] toxic limit of 750 mg/m
: 3. Considering the conservative calculations and the adequate odor detection threshold of H 2S the oil pipeline is not a credible potential gas hazard. Gulf Oil indicates that the crude oil in the pipeline may contain significant fractions of light hydrocarbons. The maximum light fraction concentrations are as follows:[14]  As indicated above, the maximum oil spill quantity occurs for the 400 Bbl/hr spill rate. At this rate even if all the light fractions were vaporized instantaneously the maximum concentration at the nearest plant safety related structure would be 0.24% which is 15% of the mixture lower flammable limit of 1.6%. This result is for worst 5 percentile site meteorology and a distance of 2400 feet from the nearest retaining pond to the Service Water Intake Structure. This effectively assumes the spilled oil gets all the way to the retaining pond without losing any vapor, but when it
 
does reach the pond all the volatile fraction is released immediately. This maximizes the vapor release rate and minimizes the source to plant distance.For the maximum spill rate case two situations have been analyzed. The first is for vaporization from the oil accumulated in the retaining pond (conservatively assuming water in the pond). The second situation is for vaporization from the oil spill on land between the pipe and the retaining pond.The rate of vaporization from the oil spill was determined from a heat balance equating the heat lost by evaporation to the heat gain from either the water or the soil plus heat from solar radiation.The evaporation rate was determined from the mass transfer relationships of Bird, Stewart and Lightfoot.[15]  The mass transfer coefficient was obtained from the heat/mass transfer analogy using forced convection flat plate correlations of Krieth.[16]  The vapor phase composition was determined from the crude oil composition given abov e using two phase equilibrium ratios from Reference [17].Heat transfer from water was determined assuming simple convection from the water at a maximum natural water temperature of 97&#xba;F using a overall film coefficient of 100 Btu/hr ft 2 &#xba;F. For a spill on land transient heat conduction from soil was considered utilizing a procedure which accounted for soil temperature variation with depth from a 135&#xba;F initial surface temperature and Methane      0.60%  Ethane        0.14%
Propane        0.92%
Butane        3.74%
Pentane        44.6%
CPNPP/FSAR 2.2-12Amendment No. 104an initial oil temperature of 74&#xba;F. Solar heat flux of 365 Btu/hr ft 2 was used. These temperatures are for worst case daytime summer conditions. Temperatures at other times would be much less.The results of the analysis indicate that on water the oil reaches a maximum temperature of 86&#xba;F with a maximum specific evaporation rate of 9.6 lb/hr ft
: 2. On land the oil reaches a maximum temperature of 77&#xba;F with a corresponding specific evaporation rate of 6.8 lb/hr ft
: 2. These values are based on the initial oil composition and do not reflect the reduction in evaporation rate which occurs as the more volatile fractions are evaporat ed. Also the maximum conditions on land last for only a very short time due to the continued cooling of the soil.
From the above discussion it is concluded that vapors released from oil spilled as a result of failure of the Gulf Oil pipeline do not result in a credible potential hazard to CPNPP. This conclusion and the ability of the retaining ponds to prevent crude oil liquid from reaching the SSI indicate that the Gulf Oil crude oil pipeline does not present a credible hazard to the CPNPP. REFERENCES1.Foster, J. C., Jr., et al., "Detonatability of Some Natural Gas- Air Mixtures," Air Force Armament Laboratory, AFATE-TR-74-80, November 1970.2.Kogarko, S. M., et al., "An Investigation of Spherical Detonations of Gas Mixtures."  International Chemical Engineering, Vol. 6, No. 3, July 1966.3.Loesch, F. C., "Thermal Radiation and Overpressure from Instantaneous LNG Release into the Atmosphere," TRW Report No. TRW-08072-4, April 26, 1968.4."Safety Evaluation Report, Tennessee Valley Authority, Hartsville Nuclear Plants A and B."  U. S. Nuclear Regulatory Commission, NUREG-0014.5.Briggs, G. A., "Plume Rise," TID 25075, Equations 4.19c, 4.32, and 5.7, November 1969.Pond Area (ft 2)Distance from SSWS INTAKE (ft)Concentration as fraction of LFL 1              2 3
CPNPP/FSAR2.2-13Amendment No. 1046.Natural Gas Processors Suppliers Association, Engineering Data Book, Eighth Edition, p.96, 1966.7.Nuclear Power Plant Control Room Ventilation System Design for Meeting General Criterion 19, K. G. Murphy and Dr. K. G. Murphy and Dr. K. M. Campe, 13th AEC Air Cleaning Conference, August 1974.8.NRC Regulatory Guide 1.91, "Evaluation of Explosions Postulated to Occur on Transportation Routes Near Nuclear Power Plant Sites," Revision 1, February 19789.Letter from H. E. Evans (Gulf Refining Co.) to H. C. Schmidt (Texas Utilities Services, Inc.), dated October 2, 1978.10.Telecon between R. W. Haskovec (Texas Utilities Services Inc.) and Mr. Newton Fincher (Gulf Refining Co.), August 24, 1979.11.Telecon Between A. O. Smyth (Gulf Refining Co.) and E. R. Schmidt (NUS Corporation),
February 12, 1980.12."Threshold Limit Values for Chemical Substances in Workroom Air," American Conference of Governmental Industrial Hygienists, 1978.13.NRC Regulatory Guide 1.78, "Assumptions for Evaluating the Habitability of a Nuclear Power Plant Control Room During a Postulated Hazardous Chemical Release", June1974.14.Letter from H. E. Evans (Gulf Refining Co.) to H. C. Schmidt (Texas Utilities Services, Inc.) dated August 9, 1978.15.Bird, R. B., Stewart, W. E., and Lightfoot, E. N., Transport Phenomena, John Wiley and Sons, New York (1942 pp 662-663).16.Krieth, F., Principals Of Heat Transfer, Second ed., International Textbook Company, Scranton (1965) pp 296-314.17."Technical Data Book - Petroleum Refining", American Petroleum Institute, Third Edition, 1976.18.NRC Regulatory Guide 1.95, Protection of Nuclear Power Plant Control Room Operators Against An Accident Chlorine Release, Revision 1, January 1977.19.NRC Regulatory Guide 1.111, Methods for Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Routine Releases from Light-Water-Cooled Reactors, Revision 1, July 1977.20.NRC Regulatory Guide 1.145, Atmospheric Dispersion Models for Potential Accident Consequences Assessments at Nuclear Power Plants, Revision 1, November 1982.
CPNPP/FSAR Amendment No. 104TABLE 2.2-1NATURAL GAS PIPELINE INFORMATION CPNPP/FSAR Amendment No. 104TABLE 2.2-2 CPNPP/FSAR2.3-1Amendment No. 1042.3METEOROLOGY2.3.1REGIONAL METEOROLOGY2.3.1.1General ClimateThe regional climatology of the site is described for the area bounded by 30 North, 100 West, 34North, 96 West, shown in Figure 2.3-1. The Comanche Peak site is located approximately equidistant between Cleburne and Stephenville, Texas, west of the Brazos River. The site elevation is approximately 810 feet mean sea level (MSL). Over the region depicted in Figure2.3-1, the terrain slopes gradually from 300 to 700 feet MSL in the southeast to 1,200 to 1,800 feet MSL in the northwest.The climate of the region is continental and is characterized by rapid changes in temperature, marked extremes, and large daily and annual temperature ranges. The mean annual temperature decreases from southeast to northwest because of elevation and latitude changes. The general climate of the region is modified frequently by advancing warm moist air from the Gulf of Mexico, resulting in high humidities and cloudiness. Rainfall ge nerally decreases from east to west and is heaviest in late spring and early summer.In summer, the Bermuda High exerts a strong in fluence upon the weather of the region. It furnishes the tropical maritime air from the G ulf of Mexico which almost completely dominates the weather from May to September. This air mass is responsible for almost all of the thunderstorm activity in the region regardless of time of year. Occasionally, in summer, tropical continental air may move into West Texas from the high plateaus to the west. This air mass is characterized by very hot daytime temperatures and almost cloudless skies. Typically, summer has over 100 days with temperatures of 90&deg;F or above and temperatures often exceed 100&deg;F [1,2, and 3]. Rainfall occurs during brief but sometimes intense showers and thunderstorms.During the winter and early spring, outbreaks of polar continental air are the most common frontal activity. Although these fronts frequently have little weather associated with them, they often stall in Central and South Texas. Low ceiling and poor visibility may persist for three to four days or even longer over large areas [3]. On occasion
, arctic air masses push through the region and cause some of the coldest temperatures. Cold spells, however, rarely last more than a few days. Normally, temperatures drop to 32&deg;F or below about 30 days each year [1, 2]. Winter is the driest season, but one or two occurrences of snow and one or two occurrences of sleet or freezing rain may be expected in both January and February, the coldest months [3].Pacific maritime cold fronts are more frequent in spring and fall than in winter or summer. These air masses usually bring clear skies to the region, although the weather along the leading edge of the front may be quite violent. Most of the dust storms of early spring and the violent thunderstorms during April, May, and June are associated with these frontal systems. Warm fronts are generally confined to the late fall and early spring months in this region. They are usually confined to the southern half of the region and move northward very slowly.Spring is characterized by rapid changes of temperature, i.e., alternating periods of warm and cold conditions. On the average, thunderstorms are more frequent and more violent in the spring than any other season. Spring is normally the wettest season of the year. The fall is characterized by fair weather, low wind speeds, and moderate temperatures. It is the most pleasant season of the year.
CPNPP/FSAR2.3-2Amendment No. 104Another major influence on the climate of this region is the so-called "dewpoint front," which marks the westward extent of the moist air from the Gulf of Mexico. This trough of low pressure can exist at all times of the year. In summer, it marks the westward extension of the Bermuda High, while in winter it forms behind the migratory high moving across Central Texas following a cold front. The movement of this trough eastward results in a shift to west or southwest winds and dryer weather [3].Annually, the prevailing surface winds in the region are from the south to southeast while the average wind speed is about 12 miles per hour (mph) [2]. In winter there is a secondary wind direction maximum from the north to northwest due to frequent outbreaks of polar air masses.Annual average relative humidity is approximately 65 percent in the region while the mean percentage of possible sunshine is about 70 percent [1, 2].Severe weather in the region is usually associated with heavy thunderstorms (including tornadoes) and tropical cyclones. Property damage occurs from flooding and high winds. 
 
Damaging hail also occurs in the site region.The interplay between synoptic scale phenomena and topography is small in the region of interest. The effect of terrain features on synoptic scale flow can readily be ascertained when a larger area, which takes in the high country of West Texas and Eastern New Mexico, is included; i.e., the principal effect is that the high country forms a natural barrier to the flow of air. Consequently, moist tropical air from the Gulf of Mexico and air from the arctic or polar sources,
 
which flows uninhibited through the site region, is effectively blocked from the areas to the west of the mountains. The net result is wide fluctu ations in rainfall, humidities, and annual sunshine over the larger area.2.3.1.2Regional Meteorological Conditions for Design and Operating Bases2.3.1.2.1GeneralMeteorological data are presented in this section for severe weather phenomena such as hurricanes, tornadoes, thunderstorms, lightning, hail, high air pollution, and ice storms. Also presented are the meteorological data used for evaluating the performance of the ultimate heat sink and design basis tornado parameters.2.3.1.2.2HurricanesTropical cyclones including hurricanes lose strength rapidly as they move inland, and the greatest concern is potential damage from winds or flooding due to excessive rainfall. The tropical cyclone season for Texas extends from June to October; storms are more frequent in August and September, and rarely occur after the first of October. The average frequency of tropical cyclones that affected Texas for the period 1931 to 1960 is approximately two per year; and of these about one in four were of hurricane force, i.e., winds greater than 74 mph [4].
The Probable Maximum Hurricane (PMH) is discussed in Section 2.4. For the Comanche Peak site, the PMH sustained (10-minute average) wind speed at 30 feet above ground is computed to be 81 mph [47].
CPNPP/FSAR2.3-3Amendment No. 1042.3.1.2.3TornadoesDuring the period 1955 through 1967, 58 tornadoes (4.46 mean annual frequency) occurred within a one-degree square centered near the Comanche Peak site [5]. It should be noted that statistical data on severe local storms, tornadoes particularly, are highly dependent on human observation. For example, as population density increases, the number of tornado occurrences observed and accurately re ported generally increases.The probability (P) of a tornado hitting a point in a given year is:where A is the area (in square miles) of a one-degree latitude-longitude square centered at the point, and t is the mean annual frequency [6]. The return period is the reciprocal of P.
Table2.3-1 summarizes the results for the site and nearby areas for the period 1955 through 1967. In the area north of about 31 North latitude, there is a greater frequency of large tornadoes with wide paths and long trajectories.Based on the 13-year period of record from 1955 - 1967, the mean seasonal and annual number of tornado occurrences for Texas are [5]:During the period from 1968-1977 there were approx imately 64 recorded tornado occurrences within about 40 miles of the plant site [40], but none of these occurrences were in Somervell County. Estimated characteristics of these tornados, expressed in terms of the Fujita- Pearson (FPP) tornado scale [4], are summarized below:2.3-1Winter  4.7Summer 44.8Spring  71.1Autumn 23.7Annual143.6P2.8209tx()/A=
CPNPP/FSAR2.3-4Amendment No. 104For example, a tornado having a wind speed of 200 mph, a path length of 10 miles, and a path width of 100 yds would be expressed on the FPP scale as 3, 3, 2. The above data indicate that most of the tornados in this area have a path length of less than 20 miles, a path width of less than 180 yards, and a maximum wind speed of less than 160 mph.The design basis tornado parameters used in the design and operation of CPNPP are listed below: Compliance with Regulatory Guide 1.76 [7] is discussed in Appendix 1A(B). Tornado loadings are discussed in Section 3.3.2
.Scale No.Maximum Windspeed(a)Path LengthPath Width F Scale(mph)ExpectedDamageNo. ofOccurrences P  Scale(miles)No. ofOccurrencesP Scale No. ofOccurrences0 40-72Light12<1.0 (b) 33<18 yd (b)231 73-112  Moderate 341.0-3.1918-55 yd14 2 113-157 Considerable 143.2-9.9856-175 yd11 3 158-206 Severe  410-315176-556 yd  5 4 207-260 Devastating  032-9100.3-0.9 mile0 5 261-318 Incredible  0100-31501.0-3.1 mile1Unknown9Unknown 10a)Subjective estimate based on observed damage given in the literature.b)Tornados given in the literature as short and narrow are included in these categories.Translational Speed 60 mphRotational Speed 300 mph Maximum Wind Speed (sum of the translational and rotational speed) 360 mphMaximum Pressure Drop 3.0 psi Rate of Pressure Drop 1.0 psi/sec CPNPP/FSAR2.3-5Amendment No. 1042.3.1.2.4Thunderstorms Thunderstorms, from which damaging local weather can develop (tornadoes, hail, high winds, and flooding), occur about 46 days each year based on Fort Worth data [8]. The maximum frequency of thunderstorms occurs from April to June, while months November through February have few thunderstorms. The monthly and seasonal distributions are displayed in Table 2.3-2
.2.3.1.2.5LightningA typical thunderstorm is believed to produce one to three cloud-to-ground flashes each minute. The number of lightning strikes per square mile has been determined from photographs, records of strikes to power lines, and from electrical lightning counters. The combined results of several studies indicate that the number of flashes to ground per square mile per year is equal to between 0.05 to 0.8 times the number of thunderstorm days per year [9].Applying these results to the thunderstorm data for Fort Worth in Table 2.3-2, the seasonal and annual estimates of lightning strikes are:Thus, the annual expectancy of lightning strikes for a square mile area in the site vicinity is between 2 and 36.The expected probability of lightning strikes to the safety-related structures at the site on a seasonal and annual basis are presented in Table 2.3-2A. Included in this Table is the attractive area of each building and building dimensions used in the Table's development. The number of thunderstorm days for each season and annually, presented in Table 2.3-2
, as well as the attractive area of each building, geographic latitude of the site and building dimensions were used in the development of Table 2.3-2A
[42].2.3.1.2.6HailAlmost all localities in Texas experience damage from hail. While the most commonly reported hailstones are 1/2 to 3/4 inch in diameter, hailstones 3 to 3-1/2 inches in diameter are reported in Texas several times a year.During the period 1955 through 1967, there were 42 reports of large hail (3/4 inch diameter or larger) occurrences within a one-degree square centered near the Comanche Peak site [5]. This gives a mean annual frequency of 3.2 potentially damaging hailstorms per year for the entire one-degree square. Fortunately, recurrence of damaging hail at a specific location is very infrequent. The annual frequency of hail at Fort Worth is less than 0.05 percent of the hours observed [3].The monthly and seasonal breakdown of large-hail occurrences (3/4 inch diameter or larger) for the state of Texas is given in Table 2.3-2
[5]. Damaging hailstorms are most frequent during April, May, and June, the period of severe-thunderstorm activity.Winter 0.2 - 3.2Summer 08 - 12.8Spring0.9 - 14.4Autumn 0.4 - 6.4Annual2.3 - 36.0 CPNPP/FSAR2.3-6Amendment No. 1042.3.1.2.7Air Pollution Potential Conditions in the region generally favor turbulent mixing. Two conditions which reduce mixing, increasing the air pollution potential, are surface inversions and stable air layers aloft.The surface inversion is generally a short-term effect and surface heating on most days creates a uniform mixing layer by mid-afternoon. On the other hand, if warming caused by subsiding air
 
occurs, the second condition, namely a subsidence inversion, may result. Since both conditions usually occur in conjunction with light winds, the air pollution potential is amplified.Holzworth [10] has computed mean morning and afternoon mixing depths and corresponding wind speeds for several stations in Texas. There is considerable variation in mixing depths among Texas stations; but the mixing depths all display similar seasonal variation, the depth being greatest during the warm months and shallowest during the cold months.Since no data were presented by Holzworth for stations within the site region, data for Midland and San Antonio are presented in Table 2.3-3. Isopleths of the total number of forecast-days of high air pollution potential in five years are given in Figure 2.3-2. The data indicate that stable periods with light wind conditions are gener ally of short duration in the region.
Based on a 30-year period of record (1936-1965), Korshover [11] tabulated the number of times stagnating anticyclones persisted for four or more and seven or more days. Occurrences of stagnation were determined primarily on the basis of a surface pressure-gradient analysis. In the general area of the site, there were only three stagnation cases which persisted for at least four days during the 30-year period; the total number of stagnation days was 14. There were not any stagnation cases which persisted for seven or more days. The three stagnation cases which persisted for at least four days occurred during the fall.2.3.1.2.8Precipitation Maximum rainfall, estimated by statistical analysis of regional precipitation data, is given in Table2.3-4 for return periods of one to 100 years and fo r rainfall durations of from one-half hour to one day [12].Probable maximum precipitation (PMP), sometimes called maximum possible precipitation, for a given area and duration is the depth which can be reached but not exceeded under known meteorological conditions. For the site area, the PMP for 6, 12, 24, and 48 hours is 25.5, 31.3, 34.7, and 39.1 inches, respectively [13]. These values are based on a 64 square-mile area.
The maximum recorded point rainfall for durations of 5 minutes to 24 hours at Abilene, Fort Worth, and Waco, are give in Table 2.3-5 [14].On the other hand, drought conditions (extended periods of widespread meager precipitation) are known to occur in Texas. The most severe this century in Texas occurred during 1954-1956
 
(see Section 2.4.11). Fort Worth precipitation records, which illustrate the regional conditions, indicate that the average annual precipitation for this three-year period was 21.1 inches, with only 18.55 inches occurring in 1956 [15]. Although this period represents the worst drought in Texas, there have been three occurrences of annual precipitation less than 18.55 inches during the 81-year period from 1895 - 1975 at Fort Worth [8, 16]. The extreme minimum annual precipitation recorded, 17.91 inches, occurred in 1921.
CPNPP/FSAR2.3-7Amendment No. 104Extreme snowfalls for representative stations in the area are given in Table 2.3-6 [17, 18].Ice storms, precipitation in the form of freezing rain and/or sleet, occur occasionally in the region during the period December through March. The annual frequency of freezing rain at Carswell Air Force Base Fort Worth is only 0.3 percent of the hours observed, but the percentages for December, January, February, and March are 0.3, 2.5, 0.5, and 0.1 percent, respectively [3]. Moderate to heavy ice storms can be quite damaging to utility lines and trees as well as being a serious traffic hazard.The worst ice storm on record in the Fort Worth-Dallas area occurred on January 6-9, 1937 [19]. As much as two inches of ice formed on wire and did not disappear until the 12th. Communications were disrupted and highway traffic was extremely hazardous. The estimated probability of ice thickness  2 inches occurring somewhere in North Texas, Arkansas, or Oklahoma in any one year is 0.06 [20].The 100-year return period snow and ice pack for the area in which the plant is located, in terms of snow load on the ground and water equivalent, is listed below [21]:The maximum 24-hour and seasonal snowfall recorded (1898-1970) in Fort Worth is 12 and 15.3inches, respectively [18]. If the maximum seasonal snowfall (water equivalent of 1.5 inches) occurred in one storm on the 100-year return period snow and ice pack, the total water equivalent would be only 2.8 inches. In the period from 1970 - 1978, the maximum seasonal snowfall in Fort Worth was 17.6 inches (1977
- 1978 season). Even assuming the maximum winter snowfall occurred in one storm on top of an already present 100-year return period snowpack of 13 inches, the total weight would only be approximately 16 lbs/ft
: 2. This value is far below the design load on all nuclear safety-related buildings of an eight-inch maximum uniform depth of water (weight of about 42 lbs/ft
: 2) in addition to the regular live loads (see Section2.4.1.1
).The 48-hour Probable Maximum Winter Precipitation (PMWP) for a 64 square-mile area is estimated to be 28.8 inches [13]. Because of the southern location of the site, almost all of this PMWP occurs as liquid. The roof drainage utilizes an exterior system, whereby the openings in the parapet walls are actually combined relief and drainage openings. These parapet walls relief openings insure that the eight-inch level is not exceeded during the PMP. They are specifically located at all roof low points and extend from the roof low point elevation to the top of the parapet (approximate height four feet). Their location is shown in Figure 1.2-2
, 1.2-3, 1.2-5, 1.2-39 and 2.4-2. The length of an opening is six feet.The size of these openings and their location preclude:
1.the possibility of ice and snow build-up blocking them and2.roof ponding.All design features of the relief and drainage opening are shown in Figure 2.4-42
.Snow Load= 7 lbs/ft 2Water Equivalent= 1.3 inches CPNPP/FSAR2.3-8Amendment No. 1042.3.1.2.9Dust StormsBlowing dust or sand may occur occasionally in West Texas where strong winds are more frequent and vegetation is sparse. While blowing dust or sand may reduce visibility to less than five miles over an area of thousands of square miles, dust storms that reduce visibility to one mile or less are quite localized and depend on soil type, soil condition, and vegetation in the immediate area. At Fort Worth during the six year period from 1970-1975, only 0.02 percent of
 
the observations had visibilities of one mile or less due to dust [22].2.3.1.2.10Ultimate Heat Sink
 
The performance of the ultimate heat sink is discussed in Section 9.2.5. The meteorological parameters used in the analysis are presented in Tables 2.3-7A
, 2.3-7B and 2.3-7C.Three meteorological records were examined in the analysis. These records are data from the onsite station and data from two offsite stations, Dallas-Fort Worth Regional Airport (DFW) and Waco Madison Cooper Airport. DFW is approximately 59 miles northeast of CPNPP, with a ground elevation of 551 ft. The DFW record available on magnetic tape begins with May 1953. Until the end of 1973, DFW observations were taken at Love Field. Waco is approximately 53miles southeast, with ground elevation of 501 ft. The Waco record begins with July 1948. At the time of the analysis, data through December 1991 at both stations were available. The data consists of hourly (or three-hourly for th e period 1965-1980) air and dew point temperatures, windspeed and direction, cloud cover and atmospheric pressure. In addition to these variables, surface heat exchange computations require solar radiation, which can be determined from cloud cover.The onsite data set is not as complete as the offsite data. For this reason, no direct use of the onsite meteorological data set was made in the analysis. However, the 1974 onsite data set (Table 2.3-7A), previously identified as resulting in high Safe Shutdown Impoundment (SSI) temperatures for years preceding 1978, is presented here for comparison to the data sets selected from the offsite records for SSI performance analysis (Tables 2.3-7B and 7C). The day with the highest water temperature, as computed from the onsite meteorological record as a response to atmospheric heating or cooling, is July 15, 1974.The two offsite records were used to compute SSI temperatures under normal operating conditions for comparison to SSI routinely monitored intake temperatures. These comparison showed that the DFW meteorological data more accurately represented onsite conditions than the Waco data. The DFW data were used for the SSI performance analysis.The entire DFW record (39 years) was then used to compute fully-mixed water temperatures responding to atmospheric heating or cooling and steady heat load similar to those used in the SSI analysis. From this long record of response temperatures, 1-, 5-, 10-, 20-, and 30-day average response temperature were computed. Maximum values of these average temperatures were then identified and ranked by year. From this table, 1990 was identified as the year that would produce the highest temperatures in the SSI for all durations. The meteorological data from 1990 are shown in Table 2.3-7B for the period of maximum SSI temperatures. This period includes data for both for the 24 hour transient analysis and for the peak SSI intake temperature analysis. The day with the highest water temperatures computed from this meteorological record is August 31, 1990.
CPNPP/FSAR2.3-9Amendment No. 104A similar search was conducted for the maximum 30-day evaporation. The fully-mixed computation was used to determine evaporation rates. The period of 30-day maximum evaporation was identified by examining the entire 39 year record using a moving sum procedure. The maximum natural evaporation occurred in 1980. The meteorological data for this period are shown in Table 2.3-7C. The 30-day period with the greatest potential for evaporation is June 25, 1980 to July 25, 1980. In order to be conservative, the evaporation analysis was continued for nine days beyond the 30 day minimum specified in R.G.1.27. The additional data are also shown in the Table. 2.3.1.2.11Extreme Winds Estimated extreme winds (fastest mile) for the general area based on the Frechet distribution are [24]:Fastest mile winds are sustained winds, normalized to 30 feet above ground and include all meteorological phenomena except tornadoes.Wind loadings for the site are discussed in Section 3.3.1
.2.3.2LOCAL METEOROLOGY2.3.2.1Normal and Extreme Values of Meteorological Parameters2.3.2.1.1General In this section, the normal and extreme statistics of wind, temperature, water vapor, precipitation, fog, and atmospheric stability are described. Long-term data from proximal weather stations
 
(see Figure 2.3-3) have been used to supplement the shorter-term onsite data.2.3.2.1.2Surface Winds Percentage frequencies of surface wind (wind roses) at Love Field, Dallas, for the years 1951-1960 are shown on an annual and monthly basis in Table 2.3-11 [25]. The symbol "+" indicates that the value is less than one-half of one percent but greater than zero. According to the annual table, surface wind directions at Dallas ar e from the southeast, south-southeast, and south 45 percent of the time. These directions predominate during the individual months also,
 
but to a lesser extent during November through March. The annual average wind speed (not shown in Table 2.3-11) is 11.0 miles per hour. The maximum average wind speed occurs in the spring, while the minimum occurs in the fall.
Return Period (Years)Wind Speed (Miles Per Hour)2511061 507110076 CPNPP/FSAR2.3-10Amendment No. 104 Monthly and annual onsite wind frequency distribut ions at the 10-meter level are included in Table 2.3-27
, presented in Section 2.3.3 [26]. Similar to the offsite distribution, the surface wind is from the southeast, south-southeast, and south 40 percent of the time. The annual average wind speed is lower onsite, averaging 8.5 miles per hour.
The "fastest mile" of record (long-term) at Fort Worth and Dallas for each month is presented in Table 2.3-12 [8, 27].Frequency distributions of wind direction persistence, determined from observations at three-hour intervals over a five-year period (1969- 1973) from Fort Worth, Texas [28], are presented in Table 2.3-13. Persistence values are given for both one sector and three sectors (indicated by wind sector +22.5&#xba; in Table). Persistence was maintained through calm or missing observations if it was maintained subsequent to them. Because of these criteria, persistence as given by the number of consecutive three-hour observations tends to have a bias towards long durations.Monthly and annual wind direction persistence, determined from hourly onsite observations at the 10-meter level [26] are presented in Table 2.3-14. These distributions, which are independent of stability, indicate that most cases of persistence are less than 12 hours in duration. During the four-year period of record, there were only eight cases of persistence greater than 24 hours, five of which occurred in the NNW sector. In the average wind speeds given in Table 2.3-14, 99.99 indicates that the wind speeds were invalid.2.3.2.1.3TemperaturesMonthly and annual values of daily mean temperature and average and extreme daily maximum and minimum temperatures are shown in Table 2.3-15, based on data records for Fort Worth [8]. From these data, the annual mean temperature in the site area is 66&deg;F. The monthly averages indicate that July and August are the hottest months and January the coldest month.The monthly and annual diurnal distributions of temperature at the site are shown in Table 2.3-16
[26]. Values of the mean, absolute maximum and minimum, and average daily maximum and
 
minimum temperature for each month are also pr esented. The annual mean temperature from the onsite data is 17.1&deg;C (63&deg;F), which is some 3&deg;F lower than the long-term mean as given by Fort Worth data.Table 2.3-16 indicates that there were 93.8 percent valid primary T measurements (10-60m) during the 4-year period of record (5/15/72 - 5/14/76). Table 2.3-23 shows that there were a total of 95.8 percent valid delta temperature (T) measurements during the same 4-year period of record, including secondary T measurements when primary T measurements were invalid. Therefore, only two percent secondary T measurements (10-30m) were substituted in the data record for invalid primary T measurements.In order to justify the direct substitution of secondary T measurements during periods when the primary T measurements were invalid, a simultaneous comparison of stability classes calculated from both T measurements was made. Seven random days, encompassing all seasons, were selected from the 4-year period for the comparison. The comparison showed that there was a good correlation between the two T samples with a higher frequency of both the most stable (F and G) and unstable (A and B) occurrences using the secondary T measurements. Since the relative concentrations for CPNPP were calculated for an assumed CPNPP/FSAR2.3-11Amendment No. 104ground-level release, maximum relative concentrations (other conditions being equal), would occur during Pasquill G stabilities, the next highest relative concentrations would occur during Pasquill F stabilities, and so on. During the 7-day period of comparison, there were considerably more F and G occurrences for secondary T measurements than for primary T measurements. Therefore, substitution of secondary T measurements during periods when primary T measurements were invalid (two percent of the time) is quite conservative.
See Section 2.3.2.1.7 for more information on atmospheric stability.2.3.2.1.4Water Vapor Monthly and annual average relative humidity for four different times of day are given in Table2.3-17 from 10 years of record at the Fort Worth weather station [8]. Based on these data the annual average relative humidity is estimated to be about 68 percent. Monthly and annual average dewpoint temperatures and extreme maximum and minimum dewpoint temperatures are shown in Table 2.3-18, based on 1970-1975 data from Fort Worth [22].The monthly and annual diurnal distributions of dewpoint temperature and relative humidity at the site are shown in Table 2.3-16, based on four years of onsite measurements [26]. Values of the mean, absolute maximum and minimum, and average daily maximum and minimum for both parameters are also presented. The annual average relative humidity is 63 percent, or five percent lower than the estimated long-term average at Fort Worth.2.3.2.1.5PrecipitationMonthly and annual precipitation normals and the mean number of days with precipitation equal to or greater than 0.10 and 0.50 inches, estimated for Comanche Peak by averaging data from Rainbow, Stephenville, Cleburne, Dublin, and Fort Worth are presented in Table 2.3-19 [15]. These data indicate that the highest monthly average rainfall occurs in May with an annual average of 31.3 inches in the area. The number of days with measurable precipitation (0.01inches) is also presented in Table 2.3-19 based on 1954-1973 data from Fort Worth [8]. Monthly precipitation extremes (maximum and minimum), presented in Table 2.3-20 for several stations in the area, indicate that the largest rainfalls occur during April and May [8, 15].Snow and sleet occur from December through March with an occasional snow flurry in late November or early April. Monthly and annual average totals of snow and sleet from 20 years of record at Fort Worth [8] are shown in Table 2.3-19. These data give an annual expectancy of 2.9inches of snow. Extremes of snowfall at selected stations in the area were previously presented in Table 2.3-5
.Monthly and annual precipitation wind roses are presented in Table 2.3-21. These data are based on four years of data at Fort Worth concurrent with the onsite data record [29]. These data show that of the 5.8 percent of the time that precipitation occurred, the maximum frequency of precipitation occurred with north winds.  (Onsite data were not used because most of the hourly onsite precipitation data are invalid.)2.3.2.1.6Fog Heavy fog is that which reduces visibility to one-quarter mile or less. Average monthly and annual number of heavy fog days based on 20 years of data at Fort Worth are presented in CPNPP/FSAR2.3-12Amendment No. 104Table2.3-19 [8]. These data indicate that most of the heavy fog days occur in winter with a few occurrences during the remainder of the year.2.3.2.1.7Atmospheric Stability Based on data for the period 1957-1971 at Fort Worth, the monthly and annual frequency distributions of stability classes are shown in Table 2.3-22 [30]. The stability classes are based on the Pasquill classification [31] and are defined in Table 2.3-22. These data indicate that the frequency of stable classes reaches a peak during the late summer and early fall.Monthly summaries of the diurnal distribution of stability and stability persistence are presented in Table 2.3-23 for the onsite period of record [26]. Stability is determined from the 10-60 meter delta temperature measurements onsite and the class intervals specified in NRC Regulatory Guide 1.23 [32]. The annual percentages by stability class are as follows:These frequencies are not directly comparable to the long-term frequencies at Fort Worth, since each distribution is based on a different criteria for determining Pasquill stability classes. 2.3.2.1.8Mixing Heights The frequencies of seasonal and annual mixing heights are included and discussed in Section2.3.1.2.7. Since onsite measurements of mixing depth are neither required nor made, monthly mixing depths from upper air data at Carswell AFB, Fort Worth (5/72-10/73) and Stephenville, Texas (11/73-4/76), and surface observations from the National Weather Service (NWS) station in Fort Worth, concurrent with the onsite data record, are presented in Table2.3.24 [33]. The method used for determining mixing depths is the same as described by Holzworth [10] with observations identified as P (precipitation), C (cold air advection), and M (missing) excluded from the record. Inclusion of P and C types would tend to increase the mean
 
mixing depths given in Table 2.3-24
. 2.3.2.1.9Representativeness of the Onsite Data To demonstrate that the onsite data sample is representative of a long term climatological average, concurrent data from Fort Worth (May 1972 through April 1976) were compared to a longer data record for Fort Worth (January through December, 1957-1971). The wind frequency distribution and the stability class frequency distribution and mean wind speeds are presented in Table 2.3-25
.Generally, the wind frequencies and stability distributions are in excellent agreement. The largest difference in wind frequency is only three percent and occurs in the south sector. One notable difference is the higher frequency of calms during t he four-year period. The only significant differences in the stability class distributions occur in the "D" and "F" and "G" classes. For the four-year period, there are approximately five percent less "D" occurrences and five percent more "F" and "G" occurrences. The mean wind speeds are also in good agreement, averaging about one knot less during the four-year period.ABCDEFG3.21.42.222.740.419.910.2 CPNPP/FSAR2.3-13Amendment No. 104Generally, the comparison implies that the Comanche Peak onsite data are representative of longer-term climatological conditions. The differences that do occur indicate that diffusion estimates will probably be higher than normal (conse rvative) for the four-year period of record.2.3.2.2Potential Influence of the Plant and Its Facilities on Local Meteorology2.3.2.2.1General Potential modifications of the local meteorology at the site resulting from the construction and operation of the plant are believed to be small. The Reactor Complex is located approximately 450m west-northwest of the meteorological tower. The top of the dome is 69m above the level of the base of the meteorological tower. The Reactor Complex meets the requirements of the Standard Review Plan (46). Additionally wind was recorded from the west-northwest sector approximately 2.1% of all recordings; thus, any effect that the Reactor Complex does exhibit on our overall meteorological measurements program will be minimal. See Section 2.3.3.2 for a description of the Meteorological Instrumentation Building.In addition, no other structures are in such proximity to the tower that will cause a significant alteration of the meteorological data. This is based upon the criteria that no structure equal to or greater than the height of a measuring level is closer than 10 times that measuring level to the tower, or that all sensors are at least 5 times the building height away from any building that is equal to or greater than the measuring levels.The fill dirt pile located east-northeast of the meteorological towers is actually a mound of topsoil and will be distributed as required over the finish grade of the site. The topsoil mound is approximately 3000 feet from the primary meteorological tower location. Top of the pile is E1.865'-9" approximate and the lower measure level on the tower E1. 870' approximate. Due to the linear distance away from the tower, and the relative height of the mound, the effects of the mound on meteorological measurements will be minimal. Additionally, wind was recorded from the ENE direction only 4% of all recorded winds (FSAR Table 2.3-21
); therefore, for overall purposes, even if the topsoil mound did exhibit effects on measurements, the effect on cumulative total measurements would be minimal.In sum, the Containment Building and associated facilities are expected to have some small influence on the local air flow; specifically, mechanical turbulence is expected downwind of the plant, due to building wake effects.2.3.2.2.2Impact of Squaw Creek Reservoir Filling of Squaw Creek Reservoir commenced on February 15, 1977 with completion in May1979. The potential impacts of the Squaw Creek Reservoir upon onsite meteorlogy are discussed in the Dames & Moore Report [34] which supports the conclusion that the reservoir will have a minimal effect upon local meteorology. Although no specific monitoring program is proposed to examine such effects, various meteorological measurements are sampled as
 
discussed in 2.3.3.1.1
.The effects of the reservoir on wind speed, wind direction and vertical temperature gradient should be minimal. Small increases in the wind sp eed would be expected because the surface frictional coefficient of the air-water interface would be different from that which is now existent at elevation 770' MSL (reservoir elevation). Since Squaw Creek Reservoir has a maximum fetch of CPNPP/FSAR2.3-14Amendment No. 104about 4 1/2 miles, wind speeds may increase slightly for wind directions along the maximum fetch (southeast-northwest orientation). Small changes in the wind direction would also be expected due to variations of the surface frictional coefficient.During winds from the northwest, northeast, and east-northeast, some modification of atmospheric conditions may occur:  first as the trajectory moves over the reservoir surface, and subsequently as it returns to land, passes the tower and the reactor building, and then to the site boundary and some distance beyond. At all times with these wind directions the tower is likely to record higher wind speeds than prevail through t he balance of a trajectory to the site boundary and beyond. As the trajectory returns to land, the reduction in wind speed due to the friction of land surfaces will be accompanied by increased turbulence. As a result of the offsetting process, the resultant dispersion values are not significantly altered.On clear nights during light onshore winds from the above wind directions, the thermal stability of the air column may increase while the air column moves from the tower toward the site boundary and beyond. However, unless wind speeds are below about 3 mph, the overwater trajectory is not likely to have been of sufficient duration for significant modifications in its thermal stability to occur. In cases where the wind speed exceed s 3 mph, the tower will observe the air column stability near its overland equilibrium value and its readings will be representative of the thermal stability which will prevail throughout the trajectory to the site boundary and beyond.With wind speeds of 3 mph or less in these directions, departures from overland stability values will be sensed at night by the tower, and the air column will move toward its more stable overland
 
values during the trajectory from the reservoir shore to the site boundary and beyond. Conditions when the tower observed data may be somewhat unrepresentative and more favorable than the actual dispersion conditions downwind of the reactor building include the
 
following:1.When the wind direction is from the northwest, northeast, and east-northeast, and 2.The wind speed is 3 mph or less, and3.Overland thermal stabilities have equilibrium values of Pasquill E, F, or G, and4.During nighttime hours.
The onsite meteorological tower data for the 4-year period of record shows that conditions one through three occur concurrently only about 2.5 percent of the time. If daytime conditions were eliminated, the percentage would be somewhat smaller. By comparison, the combined frequency of occurrence of winds from these three directions is about 12 percent.Thus, (1) 2.5 percent or less of the time, tower stability observations may be somewhat nonconservative when used to represent dispersion conditions at CPNPP, and (2) wind speeds may be higher than the representative overland values about 12 percent of the time, but
 
downwind modifications to overland speeds are likely to be offset by compensatory increases in mechanically induced turbulence.The effects of the reservoir on air temperatures in the area will be significant only when ventilation across the pond is at a minimum. The lack of ventilation would give air over the pond enough time to have its temperature measurably changed by the temperature of the surface CPNPP/FSAR2.3-15Amendment No. 104water for northwest or southeast winds. For low wind speeds, the maximum increase in air temperature would probably be large enough to have an effect upon thermal stability. It is estimated that the reservoir, due to heating of the air, would cause a decrease in the frequency of the more stable classifications and an increase in the frequency of the more unstable classifications. Thus, although overall changes are expected to be small, the Squaw Creek Reservoir should cause a slight improvement in diffusion meteorology due to enhanced ventilation and a reduction in the frequency of the very stable conditions.Anticipated effects of the proposed Squaw Creek Reservoir on monthly average temperature, relative humidity, frequency of fogs for various visibility classes, and frequency of icing have been
 
determined for the months of January and July (representing winter a nd summer conditions). Details of the methods used and the results ar e available in the Dames & Moore report [34] on the Squaw Creek Reservoir.1.Temperature and Humidity ChangesThe night hours of both January and July experience the greatest modification in temperature and relative humidity. Largest modifications occur over the reservoir, with smaller effects over adjacent land area. Th e night hours of January and July show the greatest anticipated change of +1.2 degrees in temperature and the July nighttime hours have a 3.2 percent increase in relative humidity with 73 percent and 90 percent of the area affected, respectively. The daylight hours of July exhibit the smallest influence from the proposed reservoir.2.Fogging - Frequency of OccurrenceConditional fog frequencies have been determined for various visibility classes for each of the following situations:  (a) natural fogs unaffected by the reservoir, i.e., the baseline state, (b) natural fogs with visibilities altered by the reservoir, and (c) reservoir generated fogs.Natural fog (baseline) occurrences were determined from 3-hourly meteorological observations taken at the Dallas National Weather Service (NWS) station during the months of January and July over a 3-year period (1965-1967); occurrences were summarized by visibility classes. Natural fogs are not recorded by the NWS unless the visibility is seven miles or less. Onsite observations of fogs were not made.Data from the Dallas NWS station were selected to represent natural (baseline) fog occurrences at CPNPP on the basis of being the most representative data available. Fog occurrence at the Dallas NWS station is quite small [34]. Although these frequencies cannot be directly correlated to onsite fog frequencies, there are no known physical reasons that would contribute to markedly different baseline fog frequencies at CPNPP. The following meteorological characteristics are presented as evidence that baseline fog frequencies are similar or even less frequent onsite than at the Dallas NWS station:a.Pure radiation fog, which can be extremely localized, seldom occurs in the site area except for shallow patches [3].
CPNPP/FSAR2.3-16Amendment No. 104b.Patchy or localized fog is more predominant, generally, in low lying area. Since CPNPP is located as much as 200 f eet above adjacent terrain, baseline fog occurrences at the site should be less than at nearby low lying areas.c.The site is not located adjacent to any major bodies of water (the Brazos River is over three miles away) that might increase local fog occurrences onsite.d.Moisture levels decrease from East to West across much of Texas. Since CPNPP is located approximately 50 miles west of the Dallas NWS station, moisture conditions should be somewhat less favorable for fog formation onsite than at the Dallas NWS station.Generally, except for July daylight hours, the presence of Squaw Creek Reservoir will decrease the visibility in naturally occurring fogs. In January, an increase of up to five percent is expected in the occurrence of fogs. July nighttime conditions show the least influence of the reservoir, with no change in the frequency of fog occurrence. During July daylight hours, a decrease of up to one percent in the occurrence of fog is expected.3.Fogging - Visibility of One Mile or LessFog with visibility of one mile or less may be frequent enough to limit activities in the area.
Daylight hours show the greatest increase of fog frequencies in this range of visibilities,
+5 percent, and the largest area modified. During January daylight hours, the study also shows that Highway 144, East of the reservoir, should experience a three percent increase in occurrence of visibility restricted to one mile. Road 201, west of Squaw Creek Reservoir, should experience a one percent increase of fog visibility less than or equal to one mile. Highway 144 is expected to have an increase of one to two percent in fog frequency with visibility less than or equal to one mile during the night hours of January.
This fog will extend for about 1.7 miles on the southeast side of the reservoir.July daylight hours, for this visibility range, are expected to have a two percent increase in the maximum frequency of fogs. A one percent increase over natural fog frequencies is expected along Highway 144 north of the reservoir and along Roads 201, 204, and 51, west of Squaw Creek Reservoir. No modification is anticipated for the July night hours in
 
this visibility class.4.Icing Potential icing conditions are specified by the occurrence of reservoir produced fog accompanied by subfreezing temperature. January night hours are anticipated to have a maximum of one percent increase in the frequency of icing. These conditions occur over or near the reservoir, and therefore have little effect on the area.2.3.2.2.3Topographical DescriptionA map of the Comanche Peak area for a distance of five miles from the site is shown in Figure2.3-4. The eight radial lines correspond to the eight individual topographic cross-sections which appear in Figure 2.3-5 through 2.3-8. These figures indicate the maximum elevation versus distance from the plant in each sector. The site elevation is approximately 810 feet MSL.
CPNPP/FSAR2.3-17Amendment No. 104The terrain varies from 600 to 1,000 feet MSL within five miles of the site, and is generally in this range out to 50 miles. General topographic features for a radius of fifty miles are shown in Figure2.3-9
.Variable terrain has a potential to influence local diffusion characteristics. Terrain variations on the order of plus or minus 200 feet are not pronounced enough to cause any significant flow blocking. Two possible influences, though, cold air drainage and channeling, have been investigated. The occurrences of cold (more dense) air drainage down Squaw Creek was assessed by a comparison of wind direction frequencies between the 10-meter (850 ft. MSL) and 60-meter (1000 ft. MSL) levels (
Figure 2.3-10) for a 131-day period. If drainage occurs, then marked increases of down-valley wind frequencies (ESE and SE) from the upper to the lower level would be expected. Marked changes in frequency do not appear in the data; therefore, it is concluded that cold air drainage along Squaw Creek is not significant. Though not significant, the occurrence of cold air drainage cannot be completely ruled out on the basis of a comparison of wind directions measured at approximately 850 and 1000 ft. MSL, since the Squaw Creek drainage basin lies below 700 ft. MSL. However, the Squaw Creek Reservoir has been filled since this comparison was made (see Section 2.3.2.2.2). This effectively modifies the topography over a large area surrounding CPNPP to a minimum elevation of 770 ft. MSL, or only about 40 feet less than site elevation. Thus, cold air drainage is unlikely.Channeling of air flow, the other potential topographical effect, was studied by comparing 10-meter wind directions with nearby wind direction data from Dallas Love Field, where surroundings are relatively flat. A significant increase in wind direction frequencies for both up and down valley sectors (WNW, NW, NNW, ESE, and SE) should occur if channeling is an important influence. Approximately eight months of concurrent wind direction data, shown in Figure 2.3-11, indicate that channeling of the air along Squaw Creek is not a prominent effect.The channeling and air-drainage study results are indicati ve of a relatively flat terrain. There is even less topographical variation after creation of the reservoir. This implies that there is less topographic effect on the local airflow and, therefore, a slight improvement in diffusion meteorology. In conclusion, the onsite data collected prior to, and after, the creation of the reservoir does not change appreciably.2.3.2.3Local Meteorological Conditions for Design and Operating BasesLocal meteorological data have not been used for design and operating basis considerations other than those conditions referred to in Sections 2.3.4 and 2.3.5. Design wind loadings, tornado loadings, and snow loadings are referred to under Regional Meteorology, Section 2.3.1
.2.3.3ONSITE METEOROLOGICAL MEASUREMENTS PROGRAM 2.3.3.1Pre-Operational ProgramThe pre-operational onsite meteorological program is designed to measure the parameters needed to evaluate the dispersive characteristics of the site for both the routine operational and the hypothetical accidental releases of radionuclides to the atmosphere.
CPNPP/FSAR2.3-18Amendment No. 1042.3.3.1.1Instrumentation and Recording Systems The majority of the measurements are made on a 200-foot steel-framed tower which is located 1,500 feet east of the reactor complex (See Figure 2.3-12). The location of the tower in relation to the entire site area is shown in Figure 2.1-2. The terrain surrounding the tower is relatively hilly and is covered by widely scattered scrub brush, small mesquite, and cedar.The following measurements are sampled on the tower:1.Wind speed at two levels (10 and 60 meters) 2.Wind direction at two levels (10 and 60 meters)3.Ambient temperature at three levels (10, 30, and 60 meters)4.Ambient dewpoint temperature at two levels (10 and 60 meters) 5.Thermal stability, for two height intervals (10 to 30 meters, and 10 to 60 meters)6.Wind direction variability (10 meters)In addition to these measurements, precipitation and solar radiation (both total and net) are sampled near the base of the tower.Descriptions of the instruments employed in these measurements are found in Tables 2.3-26
.To assure a high percentage of data recovery, duplicate recording systems are used. All variables are recorded in analog form on strip charts which record continuously, and digitally on magnetic tape which records "one scan each minute."  The latter is the most common method of complying with criteria in Reg. Guide 1.23 for digital recording systems; that is, to record instantaneous values of each meteorological parameter once each minute. If the total number of minute observations during the hour for any parameter is less than 15, then that parameter is considered to be invalid for that hour. The magnetic tape is the primary recording system.A comparison of analog and digital hourly average values was made to support the use of instantaneous values recorded once each minute to represent hourly average conditions. Comparisons of both wind speed and direction at the 10-meter level for a randomly selected 2-week period are summarized in Table 2.3-35. These data indicate overall agreement between the hourly average values from the analog and digital recording systems.The digital recording system reduces each sensor output signal to a digital voltage form, with a range of 0 to 999 millivolts (mv) (except delta T, with a range of -999 to 999 mv), and records all variables on magnetic tape once per minute.Data lost during outages or malfunctions of the digital recorder are reduced manually from the strip chart record. The hourly averages are logged for insertion into the meteorological record.
CPNPP/FSAR2.3-19Amendment No. 1042.3.3.1.2Maintenance and CalibrationTo assure data quality and accuracy, a comprehensive calibration of the meteorological station components is performed at six month intervals. The procedure includes close visual inspection of all instrument sensors for wear, electronic component calibration, ambient temperature, and dewpoint comparison using mercury-type thermometers, and calibration of recorders.Normal maintenance includes a comprehensive inspection of the station's electronic and mechanical equipment as part of an ongoing operation and maintenance program. Inspections are performed on a weekly frequency, as a minimum, but on average two operational inspections are performed per week. Station operating procedures call for, among other things, a manual check of the zero and full-scale positioning of the analog recorders, as well as a verification of the associated DC voltages displayed by the digital panel meter for the primary recording system.The calibration and maintenance program is accomplished through the effort of experienced Luminant Power technicians.Pre-operational data recovery and analysis was initiated on May 15, 1972. For the four year period ending May 14, 1976, about 96 percent recovery of primary variables (wind speed, wind direction, and delta temperature) was accomplished.2.3.3.1.3Data ProcessingWith the exception of precipitation and wind direction, hourly averages of the digital minute-by-minute observations are calculated from the following scalar equation:Whereas most of the averages are scalar inform, the average wind directions are determined by the following averaging technique:2.3-2whereBj=the average hourly value for the j th variable (engineering units)n=the total number of minute observations during the hour normally 60, but if n<15, data for that hour are considered to be missing)
Bji=the ith minute observation of the j th variable (millivolts) rj=the conversion factor to change the j th variable into engineering units Bjrjn---Bjii1=n=
CPNPP/FSAR2.3-20Amendment No. 104Each minute observation of wind vector (speed and direction) is broken into its components, uand v, according toThe ui and vi are added separately and the sums are divided by the total number of minute observations for the hour to establish the average components, u and v, i.e.:The average wind direction is found by converting the average components into a vector direction, i.e.,
2.3-3whereui=the east-west component of wind for the minute vi=the north-south component of wind for the minute Si=the scaler wind speed for the minutei=the wind direction for the minute 2.3-4where=the average east-west component of wind for the hour
=The average north-south component of wind for the hourn=the number of valid minute observations for the hour 2.3-5where=the average vector wind direction during the hour uiSii-()sinx=viSii-()cosx=u1n---uii1=n=v1n---vii1=n=uvtan1-u/v+()=
CPNPP/FSAR2.3-21Amendment No. 104The precipitation accumulated during the hour is established by subtracting the amount of precipitation measured by the rain gauge at the beginning of the hour from the amount measured at the end of the hour.Data analysis for both wind distribution and diffusion characteristics of the site require three basic atmospheric variables. These three variables together with the primary and secondary (back-up) measurements for each are as follows:The secondary measurement is needed only during periods of outage of the primary system, and is reduced to the appropriate level as follows:  wind speed at 60 meters is converted to wind speed at 10 meters using the power law [35]: Wind direction at 60 meters is directly substituted for wind direction at 10 meters. T (redundant) between 10 and 60 meters is substituted for T between 10 and 60 meters, as required, for classification of atmospheric stability in accordance with Table 2 of Regulatory Guide 1.23.The final step in the data reduction program is the listing, in sequential order, of the concurrent, hourly-averaged values of the weather elements observed at the site. The data record provides the input data for all types of meteorological analyse s needed to define the site atmospheric dispersive qualities. The hourly onsite data record used in the Section 2.3 analyses will be provided to the NRC separately from this report.Horizontal wind speed:primary, 10-meter levelsecondary, 60-meter levelHorizontal wind direction: primary, 10-meter levelsecondary, 60-meter levelDelta temperature (T)primary T, 10 to 60 meterssecondary T, 10 to 60 meters 2.3-6whereV10=wind speed at 10 meters V60=wind speed at 60 metersS=.26 for Pasquill classes A, B, C, and D or .50 for Pasquill classes E, F, and G V10V601060------S=
CPNPP/FSAR2.3-22Amendment No. 1042.3.3.2Operational ProgramPrior to fuel load of Unit One, the meteorological measurements program of the Comanche Peak Nuclear Power Plant shall consist of the following:1.A primary meteorological measurements program.2.A backup meteorological measurements system.3.A system for making near real-time predictions of the atmospheric effluent transport and diffusion.4.A capability for remote interrogation, on demand, of the atmospheric measurements and prediction systems by the licensee, emergenc y response organiz ations, and the NRC Staff.To accomplish these goals, "the pre-operat ional meteorological instrument system" has been modified. The current "operational meteorological measurements system" transmits the above mentioned meteorological parameters to a multi-channel digital recorder, METSYS Computer and the plant computer.The operational program consists of a 60m multi-level primary meteorological tower located at plant grid coordinates N9519.44 ft. by E12111.75 ft. (el. 838 ft. - 9 in.) which is east of the Unit 1 and Unit 2 reactor buildings. The primary meteorological tower directly monitors or provides information to determine the following meteorological parameters:*Wind speed at 10m and 60m;*Wind direction at 10m and 60m;
*Ambient temperature at 10m;*Delta-temperature between 10m and 60m (redundant channels at each level);*Sigma theta at 10m;
*Precipitation near ground-level.The primary tower is a 60m, guyed, open lattice type tower with an instrument elevator and instrumentation booms located at the 10m and 60m levels. These booms are oriented to the west. The aspirated temperature shields at 10m and 60m are oriented laterally to the north. The primary and backup tower instrument translators are located in an environmentally controlled building which is approximately 70 ft. West-Northwest of the primary tower.The Meteorological Instrumentation Building was constructed near the base of the tower to support both primary and backup tower field instruments. It is 12 ft. wide by 16 ft. long by 9 ft.
high with a steel floor and galvanized steel sidin g, roof and ceiling on a concrete slab. Environmental control in the summer is maintained by an air conditioning unit. In winter, environmental control is maintained by an electric heating system. The heating/AC unit is controlled by an automatic thermostat.
CPNPP/FSAR2.3-23Amendment No. 104The operational program also consists of a separate 10m backup meteorological tower located approximately 75 ft. East-Northeast from the 60m primary tower. The backup tower monitors or determines the following parameters:*Wind speed at 10m;*Wind direction at 10m;
*Temperature at 10m;*Sigma theta at 10mThe backup tower is a 10m free standing open lattice type tower with an instrumentation boom located on top of the tower at 10m. The aspirated temperature shield is orientated laterally to the north to further minimize the effects of direct sunlight on the measured temperature.To ensure that meteorological data being collected by the backup tower at its location near the primary tower was representative of coincident data being recorded at the 10 meter level of the primary tower, a real-time data analysis consisting of a 3-month time period was performed. The real-time representativeness analysis consisted of statistical correlations for coincident wind speed, wind direction, and sigma-theta parameters from the two towers for the minimum time period specified above. The results of this analysis was used to demonstrate that meteorological data from the backup tower can be reliably substituted during loss-of-data periods from the primary tower.The recording of meteorological data from both the primary and backup towers is accomplished by utilizing one digital and one auxiliary analog system. The recorder system is a digital paperless recorder on the meteorological instrument panel in the Control Room. All meteorological parameters from the primary tower, and wind speed, wind direction and sigma theta from the backup tower, are displayed on this recorder.To ensure an acceptable data recovery of the precipitation measurements for the operational program, equipment was procured and is maintained to assure at least 90% annual data recovery. The primary system for recording precipitation data is checked at least once per week to assure its continued function.Meteorological data from both towers is provided to the Met and plant computers. Signals from both meteorological towers are transmitted through shielded twisted pair cable to the digital to analog converter of the meteorological system receiver located in the Unit 1 Plant Computer Room.Digital output of the Met and plant computers are located in the Unit 1 Plant Computer and Control Room. Digital output of the plant computers are also located in the Technical Support Center (TSC) and Emergency Operation Facility (EOF), where meteorological data consistent with the requirements of NUREG-0696 (45) are displayed.The Met computer is designed to provide digital readout of meteorological data received from the primary and backup towers for all parameters. Both 15-minute and hourly-averaged data are generated. The 15-minute averaged data are derived from the meteorological parameters that are sampled every five seconds (except precipitation which is a totalized value). The hourly CPNPP/FSAR2.3-24Amendment No. 104averaged data are derived from the 15-minute averages. The 15-minute averaged data and the hourly-averaged data can be stored internally in the computer for a period of up to 10-years. The methodology for meteorological data processing as described in Section 2.3.3.1 was used on the meteorological data collected during the pre-operational monitoring program and for the data initially collected under the approved CPNPP operat ional meteorological monitoring program. The data averaging methodology has been updated with the installation of the Met computer. This updated data averaging methodology continues to meet the requirements of Regulatory Guide 1.23.The plant computer is designed to provide digital readout of 15-minute averaged data from the primary meteorological tower. The 15-minute averaged data are based on a 5-second sampling rate. Trending data for the previous week are also available from the plant computer.The following table shows the sampling time, averaging time and number of samples per averaging period for both the Met and plant computers:The operational program will be conducted in accordance with the requirements specified in Regulatory Guides 1.21 and 4.1 (36, 37), Second Proposed Revision 1 to Regulatory Guide1.23(44), and Revision 1 to NUREG-0654 (43). Descriptions of the instruments employed
 
in the Operational meteorological measurements program are found in Table 2.3-34
. Tables2.3-34A and 2.3-34B provide information about meteorological instrumentation system accuracy.2.3.3.3Wind Roses By Pasquill Stability ClassesMonthly and annual wind roses for each Pasquill stability class (and all classes combined) for the four-year period of record onsite are shown in Table 2.3-27 [26]. These tables are based on wind distributions at the 10-meter level and the 10-60 meter T measurements. During periods of outage of the primary variables, secondary wind and T measurements were used as discussed in Section 2.3.3.1.3
.A discussion of the representativeness of the onsite data is provided in Section 2.3.2.1.9
.ComputerSamplingTime (sec)Averaging Time (min)Number of SamplesPer Averaging PeriodMet515180 Met(a)a)The hourly average is derived from the 15-minute averages.
60(a)Plant computer515180 CPNPP/FSAR2.3-25Amendment No. 1042.3.4SHORT-TERM (ACCIDENT) DIFFUSION ESTIMATES2.3.4.1ObjectiveThe onsite meteorological data record at the Comanche Peak site for the period May 15, 1972, through May 14, 1976, has been used to calculate dilution factors which can be anticipated in the event of an accidental release of radionuclides into the atmosphere. The one-hour dilution factors are calculated at the site boundary (exclusion area); for longer time periods the factors are calculated at the outer boundary of the low population zone (LPZ).2.3.4.2CalculationsDiffusion calculations for accidental or short-term releases of radionuclides were initially performed in accordance with the criteria provided in Regulatory Guide 1.4 [38]. Short term diffusion estimates were subsequently recalculated to incorporate the modeling features of NRC Draft Regulatory Guide 1.XXX [48]. It was assumed that the releases emanate from a point source at ground level; i.e., no advantage is realized from effluent emissions from elevated release points. During downwind transport, the effluent plume is assumed to spread according to a Gaussian dispersion model.2.3.4.2.1The Diffusion Model for Two Hours or LessThe analytical procedure for evaluating the 0-2 hour accident period is based on a revision of the model described in NRC Regulatory Guide 1.4; the revision incorporates the modeling features of NRC Draft Reg. Guide 1.XXX [48]. The changes reflect variations in atmospheric diffusion factors that occur as a function of wind direction and varying site boundary distance. Allowances are made for meandering plumes during light winds and stable atmospheric conditions. The model is distance and direction-dependent. The hourly /Q values used to represent the 0-2hour accident period were determined in the following manner.During neutral and stable conditions when the wind speed at the lower level is less than 6 meters per second (mps) the relative concentration is computed as:provided it is less than the greater value calculated from either or2.3-72.3-82.3-9Q----1u  yz-------------------------
-=Q----1uyzcA+()--------------------------------------
=Q----1u3yz()---------------------------
-=
CPNPP/FSAR2.3-26Amendment No. 104During all other atmospheric stability and/or wind speed conditions, /Q is the greater value calculated from Equations 2.3-8 and 2.3-9.Plume meander was accounted for by modifying the lateral diffusivity, y. The meander function (M) is evaluated as follows:For Pasquill stabilities A-C at all wind speeds or all stabilities when wind speed > 6 mps; M = 1. For wind speed 2 mps;Stab D; M = 2Stab E; M = 3Stab F; M = 4 Stab G; M = 6For wind speed between 2 and 6 mps, M is evaluated by a curve fitting technique and multiplied byy.The direction dependent 5- and 50-percentile /Q's by sector were calculated by the following procedure. The 5- and 50-percentile values were determined by normalizing the frequency of wind into the sector of interest. The 5-percentile /Q value is the point in a given sector /Q where,/Q=relative concentration at ground level (s/m 3)=hourly average wind speed at 10 m level (mps)y=lateral plume spread (m) (a function of atmospheric stability, wind speed, and downwind distance from the release). For distances up to 800 meters,y = My; where M is a function of atmospheric stability and wind speed. For distances greater than 800 meters,A=minimum cross-sectional area of the reactor containment structure (3200 m
: 2) assuming that:  width of containment building = 140 feet
 
height of spring line above grade = 190.5 feetradius of dome circle = 70 feetc=building shape factor (taken as 0.5)y=lateral plume spread (m) at a given distance and stabilityz=vertical plume spread (m) at a given distance and stability.
uyM1-()y@800m()y+=
CPNPP/FSAR2.3-27Amendment No. 104 cumulative frequency distribution which is equalled or exceeded (5 x 6.25/f) percent of the time, where f is the frequency in percent of winds in the sector. Similary, the 50-percentile value is the point in a given sector /Q cumulative frequency distribution which is equalled or exceeded (50x6.25/f) percent of the time. Calm conditions were included in the calculations by setting the wind speed to the threshold value of the wind direction sensor (0.75 mph) and distributing them among the 16 direction sectors in proportion to the directional frequencies in each stability class of wind speeds of 2 mph or less. This is a slightly larger speed class interval than the 1.5 mph limit recommended by Reg. Guide 1.XXX [48], but is justified due to the relatively small number of observations in the lowest wind speed class (1 mph) at CPNPP.2.3.4.2.2Estimated Values of One-Hour Dilution FactorsThe minimum Exclusion Area Boundary (EAB) distances in each sector are presented in Table2.3-28. For each wind direction sector, the minimum EAB distance was assumed to be the minimum distance within a 45 degree direction sector, centered on the direction sector of interest. See Section 2.1.2 for a discussion of the exclusion area boundary parameters.The highest 5-percentile concentration in any sector is 1.6 x 10
-4 s/m3 and occurs northwest of the plant. This maximum /Q was calculated at a distance of 2080m although the actual minimum EAB distance in the NW sector is 2106m. This is conservative. The highest 50-percentile concentration is 4.5 x 10
-5 s/m3 and occurs north-northwest of the plant.2.3.4.2.3Diffusion Estimates for Periods Greater Than Two Hours Determination of /Q's for time periods of 0-8 hours, 8-24 hours, 1-4 days, and 4-30 days was accomplished by graphical interpolation between 2-hour /Q's in each sector and the annual average /Q's in each sector, both at the LPZ distance (4 miles). Hourly 5- and 50-percentile Q's for each sector were computed at the LPZ using the same technique as described above for the 5- and 50-percentile/Q's by sector at the EAB (hourly /Q's were used to represent the 0-2 hour /Q's). The annual average /Q's used in the graphical interpolation are those given in Table 2.3-33 at the LPZ distance of 4 miles. For each sector, the hourly 5-percentile /Q's and the annual average /Q's, both at the distance of the LPZ, were plotted on a log-log coordinate graph with ordinate values representing /Q and abscissa values being hours.These two points, (/Q1, 2 hours) and (/Q annual, 8760 hours) were connected by a straight line and values of /Q for periods of 8, 16, 72 and 624 hours were extracted. These /Q's represent the 0-8 hour, 8-24 hour, 1-4 day, and the 4-30 day accident period 5-percentile /Q's per sector at the LPZ distance. Similar graphical interpolation was used to determine 50-percentile /Q's for each accident period.The 5- and 50-percentile /Q's for each accident period at the LPZ are given in Tables 2.3-37 and 2.3-38 for each of the 16 meteorological sectors.2.3.4.2.4Representativeness and Topographic Effects As discussed in Section 2.3.2.1.9, the onsite data sample was considered to be conservatively representative of meteorological conditions at the site. The notable differences observed during the onsite period of record were a higher frequency of calm wind speeds and a higher frequency CPNPP/FSAR2.3-28Amendment No. 104of stable conditions. These conditions have undoubtedly increased the magnitude of the /Q values given in Section 2.3.4 above those to be expected over a longer climatological interval.Topographic effects at the site were discussed in Section 2.3.2.2.3. The results were indicative of a flat terrain with no appreciable effects on short-term diffusion estimates. After creation of the Squaw Creek Reservoir, a slight improvement is expected in diffusion meteorology due to both reduced topographic variation and the ameliorative effects of a heated reservoir on the frequency of very stable conditions.2.3.5LONG-TERM (ROUTINE) DIFFUSION ESTIMATES 2.3.5.1Objective The onsite meteorological record (5/15/72 to 5/14/
: 76) is used to provide realistic estimates of annual average atmospheric dilution factors to a distance of 50 miles from the plant for use in calculating the dispersion through air pathways of radionuclides released in routine plant operations. As indicated in Section 2.3.3, the hourly onsite data record will be provided to the NRC separately from this report.2.3.5.2CalculationsThe average annual dilution factors which are applicable to routine venting or other routine gaseous-effluent releases have been evaluated from the data record using the technique presented in Regulatory Guide 1.111 [39]. The equation used is a sector-spread equation, namely:2.3-10where,/Q(i,D)=dilution factor (seconds/meter
: 3) at distance D, in affected direction Sector im=number of valid hourly observations in the data recordn=number of occurrences in the data record affecting direction Sectorii=wind direction Sector indexp=Pasquill stability class index z(p,D)=hourly average vertical dispersion coefficient of the plume (meters) for a given Pasquill class, at distance Dc=building wake shape factor (taken as 0.5)/Q iD,()TmBD-------------
- 2n-------n11u i() z2pD,()cV2/+()1/2------------------------------------------------------------------------
=
CPNPP/FSAR2.3-29Amendment No. 104The wake factor (cV 2/) influence is limited such that the resultant /Q may not be reduced greater than a factor of , i.e., [/Q] wake [  no wake]. Calm conditions are included in the calculations by setting the wind speed to one-half the threshold value of the speed or direction sensor and distributing them among the 16 direction sectors in proportion to the directional frequencies of the one and two mph speed class intervals in the appropriate stability class.Equation 2.3-10 is the straight-line trajectory model defined in NRC Regulatory Guide 1.111 assuming a ground-level release mode; that is, the release occurs at an elevation less than or equal to the adjacent building height. Since the site is basically in open terrain with gently rolling
 
hills, the T factor in Equation 2.3-10 is t he open terrain correction factor given in Reg. Guide1.111[39].Annual average dilution factors to a distance of 50 miles from the plant are shown in Table2.3-33. The maximum value at the actual EAB is 3.3 x 10
-6 seconds/meter 3 and occurs north-northwest of the plant at a distance of 1.29 miles. There are no higher values beyond the site boundary since for ground level releases concentrations monontonic ally decrease from the release point to all locations downwind.Long-term dilution factor estimates for distances out to five miles are displayed in Figure 2.3-18
. Estimates out to 50 miles are illustrated in Figure 2.3-19
.The annual average dilution factors given in this section are likely to be quite conservative for the reasons given in Section 2.3.4.2.4
.REFERENCES1.Visher, Stephen S., "Climatic Atlas of the United States," Howard University Press, Cambridge, Mass., 1966.2."Climatic Atlas of the United States," U.S. Department of Commerce, ESSA, Environmental Data Service, June 1968.3.Orton, Robert B., "The Climate of Texas and Adjacent Gulf Waters," U.S. Government Printing Office, Washington, D.C., 1965.V=vertical height of the reactor containment structure (79.4 meters)B=horizontal plume spread factor (taken as /8 radians)
=hourly average wind speed (meters/second) affecting direction Sector iD=distance from reactor containment structureT=terrain correction factor; open terrain, valley flow, or other factor for /Q adjustment (distance dependent) ui()31/3/Q()
CPNPP/FSAR2.3-30Amendment No. 1044.Cry, George W., "Effects of Tropical Cyclone Rainfall on the Distribution of Precipitation over the Eastern and Southern United States," ESSA, Professional Paper 1, U.S.Department of Commerce, Washington, D. C., June 1967.5.Pautz, M.E., "Severe Local Storm Occurrences, 1955-1967," U. S. Department of Commerce, Weather Bureau, Office of Meteorological Operations, Weather Analysis and Predicting Division, Silver Springs, Md., September 1969.6.Thom, H. C. S., "Tornado Probabilities," Monthly Weather Review, October-December, 1963.7."Design Basis Tornado for Nuclear Power Plants," Regulatory Guide 1.76, U. S. Nuclear Regulatory Commission, April 1974.8.Local Climatological Data, Fort Worth, Texas - Annual Summary with Comparative Data, U. S. Department of Commerce, NOAA, Environmental Data Service 1973.9.Uman, Martin A., "Understanding Lightning," Westinghouse Research Laboratories, Bek Technical Publications, Carnegie, Pa., 1971.10.Holzworth, G. C., "Mixing Heights, Wind Sp eeds, and Potential For Urban Air Pollution Throughout the Contiguous United States," EPA, Research Triangle, N.C., January 1972. 11.Korshover, Julius, "Climatology of Stagnating Anticyclones East of the Rocky Mountains, 1936-1965," U. S. Department of Health, Education and Welfare, National Center for Air Pollution Control, Cincinnati, Ohio, 1967.12.Hershfield, David M., "Rainfall Frequency Atlas of the United States for Durations from 30Minutes to 24 Hours and Return Periods From 1 to 100 Years," U. S. Government Printing Office, Washington, D.C., May 1961.13."Seasonal Variation of the Probable Maximum Precipitation East of the 105th Meridian for Areas From 10 to 1000 Square Miles and Durations of 6, 12, 24 and 48 Hours," Hydrometeorological Report No. 33, U. S. Department of Commerce, Weather Bureau, Washington, D.C., April 1956.14."Maximum Recorded United States Point Rainf all for 5 Minutes to 24 Hours for 296 First Order Stations." Technical Paper No. 2, U. S. Weather Bureau, Washington, D.C., 1963.15.Climatography of the United States No. 86-36, Climatic Summary of the United States - Supplement for 1951 through 1960, Texas, U. S. Department of Commerce, Washington,
 
D. C., 1964.16.Climatic Summary of the U. S., Section 32 - Northeast Texas, U.S. Department of Agriculture, Weather Bureau, 1931.17.Climates of the States, Texas, U. S. Department of Commerce, NOAA, Environmental Data Source, 1969.18."Extremes of Snowfall: United States and Canada," Weatherwise, December 1970.
CPNPP/FSAR2.3-31Amendment No. 10419.Ludlum, David M., "Weather Record Book," Weatherwise, Inc., Princeton, N. J., 1971.20.Tattlemen, P. And Gringorten, I. I., "Estimated Glaze Ice And Wind Loads at the Earth's Surface for the Continuous United States," Air Force Cambridge Research Laboratories, L. G. Hanscom Field, Bedford, Mass., October 1975.21."Requirements for Minimum Design Loads in Buildings And Other Structures," American National Standards Institute, ANSI A58.1, 1972.22.Local Climatological Data, Fort Worth, Texas - Observations at 3- Hour Intervals, U.S.Department of Commerce, NOAA, Environmental Data Service, 1970-1975.23.DELETED 24.Thom, H. C. S., "New Distributions of Extreme Winds in the United States," Journal of the Structural Division, Proceedings of the ASCE, July 1968.25."Climatography of the United States No. 82-41, Summary of Hourly Observations, Dallas, Texas, 1951-1960," U. S. Government Printing Office, Washington, D. C., 1962.26."On-site Local Meteorological Data - 5/72 to 5/76, Comanche Peak Steam Electric Station, Texas Utilities Generating Company," Dames & Moore, Job #4486-025, Houston, Texas.27.Local Climatological Data, Dallas, Texas - Annual Summary With Comparative Data, U.S. Department of Commerce, NOAA, Environmental Data Service, 1973.28."Persistence of Surface Direction by Wind Speed, 1969-1973, Fort Worth, Texas," U.S.Department of Commerce, NOAA, Environmental Data Service, 1976.29."Monthly And Annual Special Wind Direction vs. Wind Speed With And Without Precipitation, Based on 8 obs/day, Fort Worth, Texas," U. S. Department of Commerce, NOAA, Environmental Data Service, National Climatic Center, Asheville, N.C., October 1976.30."Monthly And Annual Wind Distribution by Pasquill Stability Classes, 1957-1971, Based on 8 obs/day, Fort Worth, Texas," U. S. Department of Commerce, NOAA, Environmental Data Service, National Climatic Center, Asheville, N. C., June 1976.31.Turner, D. B., "A Diffusion Model for an Ur ban Area," Journal of Applied Meteorology, February 1964.32."Onsite Meteorological Programs," Regulatory Guide 1.23, U. S. Nuclear Regulatory Commission, February 1972.33."Daily Mixing Height Study, Tables I & II, Fort Worth, Texas,"U.S. Department of Commerce, NOAA, Environmental Data Service, National Climatic Center, Asheville, N.C., October 1976.
CPNPP/FSAR2.3-32Amendment No. 10434."Potential Impact of the Release of Heat And Moisture from the Squaw Creek Reservoir," for Texas Utilities Services Inc.," by Dames & Moore, Houston, December 1973.35."Recommended Guide for the Prediction of the Dispersion of Airborne Effluents," ASME, May 1968.36."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," U. S. Regulatory Guide 1.21, U. S. Nuclear Regulatory Commission, Revision 1, June 1974.37."Program for Measuring Radioactivity in the Environs of Nuclear Power Plants,"
Regulatory Guide 4.1, U. S. Nuclear Regulatory Commission, Revision 1, April 1975.38."Assumptions Used for Evaluating the Potential Radiological Consequences of a Loss of Coolant Accident for Pressurized Water Reactors," Regulatory Guide 1.4, U. S. Nuclear Regulatory Commission, Revision 1, June 1973.39."Methods for Estimating Atmospheric Transport And Dispersion of Gaseous Effluents in Routine Releases from Light-Water-Cooled Reactors," Regulatory Guide 1.111, U.S.Nuclear Regulatory Commission, March 1976.40.Storm Data - Monthly, U. S. Department of Commerce, NOAA Environmental Data Service, Asheville, N. C., Janua ry 1968 through December 1977.41.Fujita, T. T., "Tornados Around the World," Weatherwise, April 1973.
42.Marshall, J. L., "Lighting Protection," John Wiley & Sons, New York, 1973.43."Criteria for Preparation And Evaluation of Radiological Emergency Response Plans And Preparedness in Support of Nuclear Power Plants," NUREG-0654, U.S. Nuclear Regulatory Commission, (FEMA-REP-1, Federal Emergency Management Agency),
November, 1980.44."Meteorological Measurement Programs for Nuclear Power Plant." Second Proposed Revision 1 to Regulatory Guide 1.23, U.S. Nuclear Regulatory Commission, April, 1986. 45."Functional Criteria for Emergency Respo nse Facilities," Final Report, NUREG-0696, U.S. Nuclear Regulatory Commission, February, 1981.46."Onsite Meteorological Measurements Programs," Section 2.3.3, "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants," LWR Edition, NUREG-0800, Rev. 1, May, 1978.47."Meteorological Characteristics of the Probable Maximum Hurricane, Atlantic and Gulf Coasts of the United States," HUR 7-97, U.S. Department of Commerce, May 1968.48."Atmospheric Dispersion Models for Potential Accident Consequence Assessments at Nuclear Power Plants," Draft Regulatory Guide 1.XXX, September 23, 1977.
CPNPP/FSAR Amendment No. 104TABLE 2.3-1TORNADO POINT PROBABILITY WITHIN A GIVEN YEAR AT SELECTED LOCATIONS (1955-1967)
(a)a)Period of record is in parentheses on this and succeeding tables when applicable.Square LocationSignificance Annual Frequency, Probability PReturn Period (Years)Plant Site4.460.00313320 Adjacent (East)Area Comparison3.540.00248403 Adjacent (South)Area Comparison3.230.00241 415 Adjacent (West)Area Comparison2.080.00146685 Adjacent (Northwest)Maximum in Texas5.230.00371269 North of Oklahoma CityMaximum in U.S.8.000.00588170 t
CPNPP/FSAR Amendment No. 104TABLE 2.3-2AVERAGE NUMBER OF THUNDERSTORM DAYS (a) AND LARGE-HAIL(b) DAYSa)Defined as day on which thunder is heard at station.b)3/4-inch diameter and larger.
PeriodThunderstormsFort Worth (1954-1973)Large HailTexas (1955-1967)January1<1/2 February22 March47 April725 May730 June618 July54 August51 September42 October33 November21 December1<1/2Winter42Spring1862 Summer1623 Autumn96 Annual4693 CPNPP/FSAR Amendment No. 104TABLE 2.3-2ASEASONAL AND ANNUAL ESTIMATES OF LIGHTNING STRIKES TO SAFETY-RELATED STRUCTURES Name of Safety-Related StructureWinter  Spring  SummerAutumnAnnual Auxiliary Building0.0190.0840.0740.0420.214Reactor Building (Each Unit)0.0740.3320.2950.1660.848Electrical and Control Building0.0110.0510.0460.0260.131Safeguards Building (Each Unit)0.0180.0790.0710.0400.203Diesel Building (Each Unit)0.0070.0300.0270.0150.077 Fuel Building0.0180.0820.0730.0410.209Service Water Intake Structure0.0020.0100.0090.0050.024Condensate Storage Tank0.0030.0150.0140.0080.039 Reactor Makeup Water Storage Tank0.0020.0070.0070.0040.019Refueling Water Storage Tank0.0030.0150.0140.0080.039(Attractive Areas and Building Dimensions.)
Name of Safety Related Structure Height(a)(meters) a)Maximum heights of each building were generally used.Length(meters)Width(meters)Attractive Area (kilometers)Auxiliary Building32.3158.5234.750.0272Reactor Building79.2542.6742.670.1078Electrical and Control Building23.1650.6036.580.0167 Safeguards Building (b)b)Due to the shape of this building, it was partitioned into two sections. The values for length and width are adjusted values.32.9240.0140.010.0258Diesel Building20.7339.019.750.0098Fuel Building32.9243.2841.450.0266 Service Water Intake Structure8.8432.4614.630.0031Condensate Storage Tank15.2415.2415.240.0050Reactor Makeup Water Storage Tank10.979.149.140.0024Refueling Water Storage Tank15.2415.2415.240.0050 CPNPP/FSAR Amendment No. 104TABLE 2.3-3MEAN SEASONAL AND ANNUAL MIXING DEPTHS AND WIND SPEEDS AT TEXAS STATIONS NEAREST THE REGION (1960-1964)MidlandSan Antonio Mixing Depth (meters)Wind Speed (meters/sec)
Mixing Depth (meters)Wind Speed (meters/sec)I.Morning Winter2905.74595.8 Spring4297.57486.5 Summer6067.29155.7 Autumn4196.06545.5Annual4366.66945.9II.AfternoonWinter12767.811126.8 Spring24499.015527.2 Summer27446.721196.0 Autumn18876.715726.1 Annual20897.515896.5 CPNPP/FSAR Amendment No. 104TABLE 2.3-4ESTIMATED RAINFALL (INCHES) FOR THE SITE AREAAverage Return Period  (Years)Duration125102550100 30 min1.151.491.952.242.623.003.27 1 hr1.501.822.402.843.343.754.20 2 hrs1.742.182.953.454.064.605.10 3 hrs1.932.433.243.854.475.155.64 6 hrs2.352.903.884.605.456.056.85 12 hrs2.953.384.605.456.457.258.20 24 hrs3.103.905.306.307.458.459.45 CPNPP/FSAR Amendment No. 104TABLE 2.3-5MAXIMUM RECORDED POINT RAINFALL FOR SELECTED STATIONS IN THE REGIONAbilene (1906-1961)Ft. Worth (1899-1961)Waco (1941-1961)
DurationAmount(Inches)DateAmount(Inches)Date Amount (Inches)Date5 min.0.685/18/420.715/20/28(a)a)Period of record is 1903 through 1961.0.756/5/61 (b)b)Period of record is 1953 through 1961.10 min.1.255/18/421.045/20/28(a)1.156/5/61 (b)15 min.1.765/18/421.408/22/16(a)1.557/18/47 (c)c)Period of record is 1947 through 1961.30 min.2.755/18/421.988/22/16(a)2.357/18/47 (c)1 hr3.477/31/113.359/05/323.156/19/472 hrs4.425/22/085.599/05/324.206/19/47 3 hrs4.535/11/285.999/04/324.206/19/47 6 hrs6.265/11/286.939/04/324.445/12/5312 hrs6.565/11/289.049/04/324.645/12/5324 hrs6.785/22/08 (d)d)Period of record is 1886 through 1961.9.579/04/327.185/11/53 (e)e)Period of record is 1894 through 1961.
CPNPP/FSAR Amendment No. 104TABLE 2.3-6EXTREME SNOWFALLS AT SELECTED STATIONS IN THE REGIONAbilene (1886-1970)Ft. Worth (1998-1970)Waco (1899-1970)
PeriodAmount(Inches)DateAmount(Inches)Date Amount(Inches)Date24 hrs 8.01/15/191/16/19(a)a)Amount also occurred on earlier date(s) 12.11/15/641/16/6413.02/26/24 CalendarMonth9.52/9012.11/6413.012/29 (a)Season18.41918-1915.31963-6415.01929-30(1940-1968)(1954-1968)(1943-1968)MonthAmountYearAmountYearAmountYear January6.6196612.11964 7.01949 February8.419562.91966 (a)4.81966March5.71962 2.51962 1.01962 (a)AprilT1950(a)0.0--0.0--OctoberT19670.0--0.0--
 
November8.11968T1968 (a)T1968(a)December4.319462.619632.01946T, trace <01 in.
CPNPP/FSAR Amendment No. 104TABLE 2.3-7THIS TABLE HAS BEEN DELETED CPNPP/FSAR Amendment No. 104TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 1 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-17/13/74075.970.04.00373.969.10.90672.069.10.027978.171.12.531331287.168.04.761051591.964.05.659731893.961.04.72363 2187.163.04.007/14/74082.063.04.00378.162.11.60 675.063.01.616982.966.93.130531291.961.04.06307 1597.060.14.061741898.160.13.123892189.164.05.607/15/74075.970.08.70373.070.04.00671.166.92.50 980.166.94.030531288.064.94.761051593.963.06.35946 1893.063.07.823632187.164.94.007/16/74080.166.94.00375.968.02.50673.068.00.90981.071.11.614871289.164.96.357071593.064.06.349951893.063.06.31911 2184.068.011.011 CPNPP/FSAR Amendment No. 1047/17/74075.968.04.00373.068.01.60670.068.01.632978.170.05.629201287.164.95.650751591.062.18.758661888.064.911.92363 2182.066.95.607/18/74075.961.02.50373.964.01.60 670.064.91.632978.169.14.729891286.066.06.34969 1593.963.04.760171893.060.16.326542182.063.05.607/19/74075.964.07.20373.964.02.50673.068.03.127 980.166.96.329471290.064.05.660681595.057.06.36078 1897.055.95.622302189.161.06.3167/20/74081.060.19.40379.062.13.10678.163.02.516984.964.96.329471295.061.04.063661598.159.05.657071898.157.95.62256 2191.059.04.737TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 2 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1047/21/74084.057.94.00382.061.04.70678.159.01.616988.060.14.729891298.155.94.7613715100.953.16.3589318100.952.06.32458 2193.055.94.007/22/74084.961.04.053382.963.05.627 679.062.12.527989.162.15.628451299.057.04.76158 15102.955.95.6586618100.957.96.315392193.962.15.61067/23/74087.164.04.053382.964.04.753681.063.01.643 990.064.95.629991299.061.04.7605215102.957.07.25866 18102.057.97.823892193.961.04.01337/24/74088.064.94.795384.064.915.753681.064.98.743987.166.08.725801296.162.18.749791599.061.07.838491895.063.011.91794 2191.064.913.4133TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 3 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1047/25/74086.063.013.480384.064.97.853679.069.17.227978.173.06.313961293.068.012.5604115100.062.19.4602618102.057.97.21794 2193.962.113.41337/26/74088.062.111.0122384.960.15.680 682.062.19.4106987.164.923.528561295.064.07.86371 1597.064.94.030531873.971.16.3532177.071.14.707/27/74075.972.00.00375.071.13.10673.071.10.90 981.073.93.129991291.070.04.760521596.168.05.65378 1893.969.18.719912186.064.95.607/28/74082.072.03.10379.072.03.10677.072.02.50987.175.91.629201295.075.02.561851598.175.04.757071898.173.95.61858 2190.071.16.30TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 4 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1047/29/74084.071.14.70380.171.14.00675.970.03.10989.173.91.630531295.060.14.7545815100.087.15.659091899.087.15.6733 2177.066.911.007/30/74075.068.03.10370.068.06.30 670.070.02.50972.069.14.010621275.069.13.12527 1582.966.94.723251882.966.94.76372180.168.04.007/31/74077.068.00.00375.070.01.60672.069.11.60 977.069.13.113271286.064.93.157071590.064.05.65707 1890.064.07.29292182.069.17.208/1/74075.070.07.20372.070.03.10670.070.03.10978.170.06.321501289.166.97.251971581.069.14.016301872.069.17.2101 2172.070.07.20TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 5 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1048/2/74070.070.04.70371.170.03.10671.170.02.50977.069.15.618581289.173.92.542471586.070.010.362381886.064.97.21168 2180.164.94.708/3/74075.066.92.50373.970.04.70 672.069.11.60975.971.14.015291280.160.17.81746 1584.955.08.727561884.052.011.015932177.050.07.208/4/74073.046.90.00370.048.92.50668.051.10.00 975.051.14.719911281.054.05.651761586.057.95.65644 1886.057.04.08652182.061.04.008/5/74077.064.94.00373.966.91.60672.068.02.50973.969.14.713011279.064.07.812481578.164.06.37431869.166.97.8207 2168.066.02.50TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 6 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1048/6/74068.066.94.70366.966.93.10664.064.06.30966.964.92.53451272.063.04.715551575.063.04.014971875.964.97.2797 2172.069.14.008/7/74069.169.14.70366.966.91.60 666.966.90.90971.169.13.117621273.971.14.03483 1582.068.06.339711882.969.19.417412177.070.04.708/8/74072.071.16.30371.171.15.60673.070.04.70 971.171.17.25471271.171.111.09451579.072.013.41858 1882.972.014.116032179.075.011.908/9/74075.075.07.80373.975.07.80675.073.98.70978.173.912.517571286.071.115.045871591.070.013.438231891.070.014.11858 2184.973.911.90TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 7 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1048/10/74080.172.012.50377.073.97.80677.073.95.60978.175.09.413751282.973.911.021231570.069.17.82391871.169.13.1865 2168.068.06.308/11/74068.068.06.30366.064.97.20 666.064.02.50972.071.11.614011278.170.05.62458 1582.973.07.240661886.072.03.114912181.073.03.108/12/74077.072.03.10375.075.03.10677.073.96.30 975.977.04.77651284.073.96.339821589.171.16.34895 1890.066.04.718852184.068.01.608/13/74073.073.04.70371.172.02.50672.068.02.50979.078.15.627501287.175.06.353141591.070.04.746401887.173.94.7823 2182.973.94.00TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 8 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1048/14/74078.173.09.40373.973.93.10671.168.02.50980.177.05.627241289.173.07.861051591.970.04.745771893.070.07.21707 2186.071.16.308/15/74079.073.04.00373.973.93.10 671.168.04.00980.175.95.627881289.173.97.85973 1593.070.07.857761893.069.18.718482186.068.06.308/16/74079.070.05.60377.075.06.30678.173.04.00 980.175.97.228931288.073.07.262121593.069.16.35548 1895.066.015.718692186.068.011.008/17/74081.070.07.20377.075.06.3149673.975.02.5133981.075.95.630791290.072.011.059991593.970.011.053091895.066.97.82060 2186.070.04.780TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 9 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1048/18/74082.072.05.653379.073.06.3186675.075.06.3133982.077.011.931221291.072.010.362381595.069.19.458401896.166.95.62097 2187.169.13.11758/19/74082.069.14.7133379.070.05.680 675.073.99.480982.975.07.230261291.070.09.46105 1595.068.09.455741896.166.97.817462187.166.06.3168/20/74082.972.07.20379.077.07.216675.075.97.216 982.073.98.730531291.070.011.061051595.068.010.35553 1893.968.09.416992187.171.17.208/21/74080.171.14.70375.073.93.10673.066.92.50979.073.05.630261289.166.09.459781593.963.07.253351895.063.07.21673 2187.166.05.60TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 10 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 1048/22/74080.166.93.10375.970.02.50673.072.00.00982.078.10.028131290.073.00.057071582.072.02.57971882.073.95.6133 2177.070.00.008/23/74075.069.12.50372.066.92.50 673.069.14.70981.073.00.023891288.073.93.15113 1595.075.03.142261893.073.07.210622181.066.97.80TABLE 2.3-7AONSITE METEOROLOGICAL DATA(Sheet 11 of 11)AIRDEWPOINT,WINDSPEED,SOLAR RADIATION,DATEHOURTEMP, FTEMP, FMPHBTU FT 2DAY-1 CPNPP/FSAR Amendment No. 104TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 1 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg8/26/90082.966.90.00029.38181.066.90.00029.37281.066.90.00029.37 378.168.00.00029.38478.168.00.00029.38575.968.00.00029.39 675.066.90.00029.41778.166.90.0701029.42884.968.06.72446029.43 988.069.16.74224029.441091.970.00.05736029.451195.069.10.06831029.441298.168.04.96644429.431399.068.04.36232529.411499.066.00.05785529.39 15100.066.04.95248429.3816100.063.00.04122329.3717100.064.00.02462329.361898.166.03.4792329.361993.066.00.00329.35 2090.064.90.00029.362187.164.90.00029.382286.064.90.00029.38 2384.964.90.00029.388/27/90082.066.00.00229.38182.066.00.00229.38 281.066.00.00329.37381.064.90.00729.37479.066.00.00629.37 581.066.00.00629.38675.066.90.00029.40 CPNPP/FSAR Amendment No. 104779.069.10.0686029.42887.169.10.02366229.42991.964.00.04097229.421095.063.00.05719029.431199.062.10.06813029.4212100.062.10.07347129.39 13100.064.00.07370129.3714102.063.00.06703229.3615102.064.00.05676229.33 16102.064.00.04232229.311799.064.90.02561129.301899.064.03.4810029.31 1996.166.00.00029.302093.066.90.00029.312191.068.00.00029.32 2287.169.10.00029.332387.168.00.00029.338/28/90084.968.00.00029.33184.969.10.00029.33282.969.10.00029.32 382.068.00.00029.32482.068.00.00029.31578.169.10.00029.32 675.968.00.00029.33778.169.10.0671029.34884.971.10.02411029.35 989.170.00.04190029.351093.970.00.05701029.361197.066.02.56794029.351298.164.93.47374029.34TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 2 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041398.163.00.07395029.321499.064.94.96855029.3015100.066.03.45797029.28 16100.066.06.74282129.261799.062.14.32542029.261897.064.03.4778029.25 1993.964.00.00029.252089.166.00.00029.272188.066.00.00029.29 2286.066.00.00029.302384.966.90.00029.308/29/90082.968.00.00029.29182.969.12.50029.29282.061.00.00029.29381.069.10.00029.29 479.069.10.00029.30577.070.00.00029.30677.069.10.00029.31778.170.00.0657029.32884.071.10.02394029.33 988.071.10.04172029.341093.970.00.05684029.351196.168.00.06775029.351298.168.06.77305129.331399.066.90.07371029.301499.066.92.56827029.28 15100.066.90.05728129.2616100.066.04.34164229.241799.064.93.42489129.24 1898.164.93.4746029.23TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 3 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041993.066.90.00029.232089.168.00.00029.252188.068.00.00029.27 2287.168.03.40029.282384.969.10.00029.308/30/90082.068.03.40029.29182.069.13.40029.29281.068.00.00029.29382.068.00.00029.29 479.068.00.00029.29577.068.00.00029.30678.168.00.00029.30 779.069.10.0641029.31884.969.10.02376029.32991.969.10.04155029.321093.969.12.55666029.331198.166.93.46756029.331298.168.04.37284129.3113100.964.90.07155229.2914100.963.03.46755129.27 15102.061.04.95733029.2516102.060.10.04239029.2317100.961.04.32468029.22 1899.062.10.0641429.221993.062.10.00429.222090.062.13.40529.23 2189.164.04.30429.242287.164.90.00329.262384.966.94.90229.27TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 4 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1048/31/90082.966.94.90329.27184.066.04.30329.27282.066.00.00229.26 379.064.90.00229.27480.166.90.00229.27579.068.00.00229.28 678.166.00.00129.29778.168.00.0627029.31887.169.10.02358029.32 991.966.04.34136029.331095.068.03.45647029.341199.066.97.66736029.3312100.964.94.37262129.3113102.964.96.77131229.2814106.061.04.36594229.26 15105.163.03.45552229.2416102.961.04.33957329.2317104.059.04.92287329.2218100.960.13.4523629.221995.061.03.40329.24 2089.164.03.40029.252188.064.00.00029.282287.162.10.00229.30 2387.166.00.00229.309/1/90087.166.00.00329.31186.066.94.30229.30 282.966.90.00229.30380.166.06.70229.30479.066.04.30129.31 577.064.94.30129.32TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 5 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 104677.066.00.00229.33779.066.90.0576329.34884.069.14.31960529.34 986.070.00.03877329.351090.069.16.74714529.351191.068.06.76323329.361291.968.00.04966729.351393.066.04.35589629.331499.064.94.34594729.31 1598.160.110.75336329.291697.057.013.44166029.271797.055.014.12391029.28 1893.951.111.6583429.301990.054.04.90529.322084.955.90.00429.34 2186.059.09.20429.362282.066.010.10429.382378.166.00.00229.399/2/90075.966.90.00329.39173.966.90.00529.39 273.066.00.00329.39372.066.00.00329.40470.066.00.00329.41 570.066.00.00329.43670.066.00.00029.43772.066.90.0597029.44 877.068.00.02322029.45982.066.00.04100029.471084.964.94.35609029.481187.164.00.06695029.48TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 6 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041291.063.06.77217129.461391.062.13.47222129.441493.063.08.36536229.42 1593.061.07.65487229.401693.962.18.34021229.391793.962.19.22291229.39 1891.062.14.9603229.391989.163.03.40329.412086.064.00.00429.43 2186.064.99.20529.452282.966.04.30229.462380.166.94.30029.459/3/90077.066.94.30229.45175.966.90.00329.44275.968.00.00229.45 375.966.90.00229.46475.068.00.00529.47575.968.00.00629.48673.968.00.00629.49775.970.00.0548329.51 882.070.00.02289129.52984.969.10.04054129.531088.068.04.95554129.541188.068.04.95980429.531290.066.94.35546629.521393.066.96.75548629.50 1493.064.910.14553729.481595.064.90.03816729.461693.966.06.72788729.45 1793.066.94.31937529.44TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 7 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041893.064.94.9527429.451990.064.04.30329.452087.166.93.40329.48 2184.966.00.00229.492282.966.93.40029.492382.066.90.00029.509/4/90082.066.96.70029.50180.166.96.70029.51277.068.04.90029.51 375.966.90.00029.53475.968.00.00029.52575.068.00.00029.54 673.068.00.00129.56777.068.00.0568029.58882.970.00.02286029.60 988.069.10.04062029.601091.068.00.05570029.601191.966.04.96609129.601293.066.98.36794329.581393.966.03.46465429.56 1496.166.07.65957429.541596.164.96.75238329.521697.064.94.93816329.50 1796.164.97.62258129.481893.964.90.0557029.481991.064.00.00129.48 2087.164.00.00129.492186.064.90.00229.502282.064.90.00029.52 2381.066.00.00229.53TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 8 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1049/5/90081.066.00.00229.52180.166.00.00529.52280.166.00.00529.53 382.064.90.00429.52475.966.00.00329.52575.066.00.00229.53 675.064.90.00129.53777.066.00.0550129.54884.066.90.02252129.56 988.068.04.34017129.551091.968.02.55514129.551197.064.92.56631029.541298.164.90.07145129.521399.066.04.97000229.501499.064.04.36445229.47 15100.064.00.05384229.441698.164.00.03596429.421799.062.10.02219129.401897.061.00.0494329.401993.066.00.00729.39 2088.064.90.00329.402188.066.04.30829.422284.966.90.001029.42 2384.068.00.001029.419/6/90082.068.00.001029.41181.068.00.001029.40 281.066.90.001029.40379.068.00.00829.39478.166.00.00829.40 575.066.90.00829.40TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 9 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 104675.066.90.00729.40777.069.10.0413629.40882.068.00.02117329.41 988.068.00.03788329.401093.068.00.05386229.401196.166.90.06436229.391298.164.94.36980229.371399.064.94.36972229.3514100.064.96.76414229.32 15100.064.07.65349229.3016100.064.03.43741329.281799.064.06.72064329.27 1897.064.08.3414529.261993.064.04.30329.262089.164.92.50229.27 2189.164.94.90229.282287.164.93.40529.292387.163.07.60729.309/7/90086.063.07.60629.31184.063.07.60429.31 282.963.09.20629.31380.164.04.90629.32478.164.04.30829.32 578.164.94.30829.33675.966.02.50829.33777.068.00.0306829.33 881.070.06.71302829.33984.970.06.73067629.341091.070.04.94936429.341193.068.04.33846829.35TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 10 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041296.166.93.424991029.331398.164.04.924951029.311499.063.07.622931029.29 1598.161.04.93186829.261698.162.17.62681729.231797.061.010.71802529.22 1895.062.18.3437329.231990.062.10.00229.232088.063.00.001029.26 2186.063.00.001029.272286.064.00.001029.282384.963.00.001029.289/8/90081.064.00.00929.28182.964.00.00929.28282.964.98.30929.28 384.066.94.30929.29482.968.04.90829.30582.069.12.50929.30679.069.10.00929.31779.069.10.01781029.32 881.070.02.57741029.32982.970.06.71886929.321089.171.16.72598929.331191.070.06.722971029.321293.068.06.724901029.311388.064.94.924841029.31 1482.070.00.022811029.311579.071.17.618961029.301675.973.07.613631029.28 1775.973.90.07391029.28TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 11 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041877.073.94.31521029.291975.975.06.701029.292077.073.90.001029.30 2175.973.96.701029.332273.972.04.901029.332375.072.00.001029.339/9/90073.971.10.001029.33173.971.10.00929.33272.071.10.001029.34 373.071.10.001029.34473.071.10.001029.33573.072.00.001029.33 673.072.00.00929.33773.973.00.0235929.34875.073.00.01280829.35 977.073.00.01877929.371078.172.02.519131029.381180.171.14.922891029.401279.071.110.724811029.381375.970.08.324741029.37 1479.069.18.322701029.361579.069.14.32547929.341679.069.10.013481029.33 1778.168.04.97241029.321877.069.10.01421029.331975.969.16.70929.33 2073.970.04.30929.352173.070.00.00829.362272.070.00.00729.36 2372.069.10.00829.37TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 12 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1049/10/90073.971.13.401029.37173.971.10.001029.37273.071.10.00929.37 372.070.00.00929.36471.169.10.00629.34572.070.00.001029.36 670.069.10.00629.37771.170.00.0328729.38873.070.00.07601029.39 973.969.14.313801029.391072.070.04.919061029.411172.071.18.322801029.421273.971.18.324711029.401379.070.06.724631029.381481.069.14.33766829.35 1577.071.10.02529929.331680.166.96.72225829.311781.066.913.41382729.301878.166.97.6288629.311973.966.94.90529.33 2072.066.90.00329.342172.066.94.30429.362271.168.00.00529.36 2372.068.03.401029.369/11/90071.168.06.701029.35171.168.04.901029.34 270.068.08.301029.33370.068.08.301029.31470.068.04.901029.31 570.068.08.301029.32TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 13 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 104669.169.17.601029.33769.169.16.71641029.34869.169.19.27531029.34 970.069.18.313721029.351071.170.010.718971029.361172.069.110.122711029.361277.070.010.124621029.351375.069.18.324521029.341473.971.12.522441029.32 1573.970.04.318551029.311678.171.14.91784929.281779.070.04.9941929.29 1878.170.00.0165929.291975.969.10.001029.302075.071.10.001029.31 2172.070.00.001029.322272.070.00.001029.332373.071.10.001029.339/12/90071.170.00.00529.33171.170.00.00829.32 271.171.10.001029.32371.171.10.00829.31472.072.00.001029.32 572.071.10.001029.33672.071.10.001029.34773.072.00.01581029.36 873.071.10.07461029.37973.971.10.013651029.381075.971.10.02556929.391181.071.12.53775829.38TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 14 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041282.971.14.34091829.371384.969.12.54073829.351486.066.92.53725829.33 1582.970.09.218421029.311682.070.06.72177829.311784.069.13.41324729.30 1882.069.10.0187829.311980.171.10.00829.312079.071.12.501029.32 2177.072.00.00829.332275.971.10.00329.352373.970.00.00329.359/13/90073.970.00.00329.35173.070.00.00329.34271.169.10.00329.34 371.170.00.00229.33471.170.00.00629.33571.170.00.00329.34671.170.00.00429.35771.171.10.01541029.36 873.972.00.07401029.37975.072.00.013571029.381075.973.90.018811029.381180.172.00.03049929.381279.071.13.43303929.361380.173.07.63287929.35 1480.173.04.322191029.331584.072.04.33050829.301684.972.02.52152829.28 1787.171.12.51296729.28TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 15 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041884.070.02.5263429.281981.070.00.00229.282078.171.14.30529.30 2175.971.10.00229.322275.971.14.30229.332375.971.10.00129.339/14/90073.971.13.40129.33173.071.10.00129.34273.071.10.00429.34 373.973.02.501029.34473.973.00.001029.34575.073.00.001029.35 673.973.00.001029.36775.072.00.0202929.37880.172.00.01427729.38 981.072.02.52252829.401082.972.00.03647729.401187.172.04.33036929.401288.071.13.43289929.381391.068.02.54035829.36 1493.068.02.53682829.341595.068.04.33026829.321693.966.90.02126829.31 1790.070.03.4880929.301889.170.04.3126929.301984.971.10.00829.31 2082.072.00.00329.322180.172.00.00329.332278.171.16.70329.34 2378.172.00.00329.32TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 16 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1049/15/90075.971.10.00229.32175.071.10.00229.32275.071.10.00229.32 373.971.10.00229.31472.070.00.00229.31571.170.00.00229.32 672.070.00.00529.32773.071.10.0195929.35878.173.90.01210829.35 986.072.00.03212529.351089.170.02.55015329.341191.069.12.55721429.331293.066.94.35792529.311393.966.02.55759529.291496.163.02.55249529.26 1596.162.13.44606429.231696.163.04.92452729.211793.963.03.41061829.201890.064.03.4114929.201984.964.90.001029.20 2082.963.00.001029.212182.064.90.001029.222281.066.92.501029.22 2380.168.03.401029.229/16/90077.069.12.501029.22177.070.00.001029.22 275.970.00.001029.22375.070.00.00929.23475.971.10.001029.22 575.071.10.00929.23TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 17 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 104675.071.10.00829.24773.971.10.0271729.25882.973.00.01398729.26 987.173.00.02920629.271090.071.14.34062629.271193.070.02.53713829.271295.066.06.73260929.241395.064.90.03240929.221495.063.07.62950929.20 1595.066.98.317851029.181693.968.08.312441029.171791.966.08.36211029.19 1891.066.98.3761029.201988.066.00.001029.222087.169.16.701029.26 2182.968.014.101029.302279.068.04.901029.262378.166.00.001029.269/17/90075.966.90.00929.25173.966.90.001029.27 275.068.00.001029.30373.966.90.001029.30475.068.00.001029.30 573.968.00.00929.31673.968.00.00929.31775.069.12.5182929.33 878.172.03.47111029.35980.173.96.713261029.361082.073.013.42499929.371184.973.09.22998929.37TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 18 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041287.172.08.323991029.361388.070.010.123821029.341490.069.19.22931929.32 1591.969.19.23447729.301691.069.18.32050829.301788.069.14.9820929.30 1888.069.17.6681029.311975.072.07.601029.322077.075.00.001029.35 2175.975.00.00929.372275.973.00.001029.382375.073.00.00829.399/18/90075.072.00.00729.39173.973.00.00329.39273.973.00.00529.38 373.072.00.00429.38473.072.00.00529.39573.073.00.00929.39673.073.00.00829.40773.973.00.0216829.42 877.073.94.91541629.43981.073.94.92567729.441084.073.07.64023629.441187.172.07.65647429.431290.071.18.36424329.411391.969.19.26376329.39 1493.069.14.95793329.361593.969.16.74494429.341693.968.07.62903529.32 1793.068.09.21514429.31TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 19 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041891.068.09.2168229.311987.169.14.90129.332084.070.00.00429.35 2184.070.04.90329.362282.072.00.00329.382381.072.00.00129.389/19/90081.072.04.30429.37179.072.04.30229.36278.172.04.30729.35 378.172.06.70529.35477.072.04.30229.33575.973.00.00029.35 673.972.00.00129.37775.973.00.0355129.39880.173.04.91977129.40 982.972.04.93646229.401087.171.110.15091229.401187.169.110.74276729.401289.171.14.94628729.391391.969.16.76343329.36 1493.071.14.95756329.311593.970.09.24457429.281693.970.09.22332729.26 1793.069.19.21123729.261890.068.03.4126529.271986.066.90.00729.29 2084.970.00.00629.302182.970.03.40529.292279.070.00.00229.32 2381.071.17.60429.35TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 20 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1049/20/90080.171.14.30929.35175.972.00.001029.34275.972.00.00929.34 375.972.00.00629.34475.071.13.40729.34575.071.10.00929.34 673.971.10.00929.35775.071.12.51201029.35877.072.02.56891029.35 980.172.00.013021029.361082.073.07.618201029.361184.972.09.221861029.351287.173.09.223661029.341388.072.09.223451029.321488.069.19.221261029.30 1591.069.110.117261029.271673.070.07.611821029.311773.071.10.05611029.261875.072.00.0461029.271975.071.10.001029.28 2075.072.00.001029.302175.972.00.001029.312275.071.10.00829.31 2375.072.00.00829.329/21/90077.072.00.00829.30175.072.00.00629.31 275.073.00.00429.32375.973.00.00929.32475.973.90.00929.33 575.973.94.90629.33TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 21 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 104675.973.94.90929.33777.073.97.6225729.33879.075.010.11137829.34 982.073.910.12158829.341082.973.911.62450929.341184.073.910.721751029.361282.973.07.623541029.361382.973.00.023331029.341482.071.17.621121029.34 1582.071.17.617111029.331682.071.14.911671029.321781.070.07.65471029.33 1878.170.08.3401029.341975.971.14.301029.342075.071.10.001029.35 2175.071.10.001029.372273.971.14.301029.392375.973.00.001029.399/22/90073.071.10.00829.40173.972.03.401029.40 273.972.00.001029.40373.973.03.401029.40473.973.04.301029.41 573.971.18.301029.42673.971.16.701029.43773.069.14.31111029.44 873.968.06.7912929.46977.066.910.12502729.471078.164.09.23507729.481182.961.04.94738629.48TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 22 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041284.957.97.65127629.481387.157.07.64517729.461484.957.08.34085729.45 1588.055.04.92829829.441687.153.110.711511029.431784.955.015.05321029.45 1882.055.014.1341029.471980.157.00.001029.472075.955.93.401029.48 2173.057.00.001029.502271.157.00.00729.532370.057.00.00729.549/23/90068.059.00.00729.55168.059.06.70729.56270.055.06.70829.58 366.951.17.601029.59466.048.010.10529.61563.046.910.70229.63662.146.011.60129.65761.043.010.7303129.67 862.142.115.01892129.69964.937.914.13551229.711066.937.914.15086129.711169.137.910.76115129.701271.137.014.16616129.691372.037.011.66590029.67 1473.037.913.45954029.651575.037.011.64802029.621673.937.913.43222129.60 1773.037.910.71439229.59TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 23 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1041870.037.98.375329.601963.039.96.70229.592059.042.14.30329.60 2161.042.14.90429.612257.944.14.301029.622355.044.13.40929.619/24/90055.944.14.901029.60157.042.14.301029.60255.943.00.001029.60 354.043.03.40929.60454.043.00.00829.60555.043.04.30929.60 654.044.13.40829.60757.046.00.0171829.62860.146.00.01099829.62 964.944.16.72115829.621066.937.94.92973829.621170.039.94.94174729.601272.039.94.93869829.581375.039.99.25020629.55 1477.037.94.93453829.521575.041.07.62253929.501673.039.98.311201029.48 1773.037.93.45031029.471872.041.03.431929.461969.145.03.401029.45 2068.045.03.40829.452166.946.04.30829.442266.946.94.301029.44 2368.046.94.301029.44TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 24 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 1049/25/90066.948.04.90829.42164.046.96.70329.41261.048.94.90229.41 361.048.96.70129.40462.148.97.60129.40562.150.07.60729.41 661.050.07.60429.40762.151.16.7277129.40866.950.013.41861029.40 972.051.18.33596029.411075.950.08.35064029.401181.050.08.36094029.391282.951.110.16591029.371384.053.18.36515029.351484.954.08.35871029.33 1586.055.96.74714029.311686.055.97.63154029.291786.055.07.61395029.291882.954.08.353029.291977.055.94.30029.29 2077.055.98.30029.302172.055.96.70029.312271.157.08.30029.32 2369.157.07.60029.33TABLE 2.3-7BOFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION (Sheet 25 of 25)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATION BTU FT2DAY-1CLOUDCOVER,TENTHSPRESSURE, IN Hg CPNPP/FSAR Amendment No. 104TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 1 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg6/25/80087.169.19.20029.22384.073.010.10029.22679.073.04.3173029.28 991.973.99.24984029.3212100.972.013.47959029.3115108.066.010.16546029.28 18105.164.09.21773029.262193.061.09.20029.276/26/80084.064.06.70029.29382.068.07.60029.28681.066.99.2168129.29997.070.010.14976029.3212106.066.96.77956029.3215111.960.17.66548029.2818108.057.08.31776029.27 2196.161.07.60029.286/27/80090.064.98.30029.28386.066.08.30029.27682.966.06.7160229.27998.166.97.64968029.2912108.064.94.97953029.2815111.964.07.66550029.2218109.062.110.71778029.18 2197.063.08.30029.216/28/80091.066.010.70029.23386.070.010.10029.20 682.070.06.7159029.23993.071.110.74960029.2712102.969.19.27950029.26 15109.966.08.36551029.2218107.164.010.71780029.19 CPNPP/FSAR Amendment No. 1042193.964.010.10029.236/29/80089.169.111.60029.26384.069.110.70029.24 679.071.14.9138429.29991.071.16.74661329.3412100.068.07.67740229.34 15106.064.97.66510129.2918105.159.010.11781029.272191.063.06.70029.306/30/80088.064.99.20029.33382.068.04.90029.35679.069.14.9140329.36 991.070.010.74942029.4012102.066.010.77944029.3815106.062.16.76511129.33 18104.061.09.21782029.292191.964.07.60029.317/1/80087.166.97.60029.32384.072.08.30029.32681.072.06.7144029.35 993.971.110.14922029.3912104.064.911.67941029.3615109.062.17.66554029.30 18105.163.010.11783029.282195.064.97.60029.307/2/80089.166.98.30029.35386.069.18.30029.34681.069.16.7139029.37995.068.07.64924029.4012106.066.99.27937029.39TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 2 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 10415109.961.07.66554029.3218106.057.910.71783029.292195.064.010.70029.337/3/80086.063.04.90029.31375.961.00.00029.31680.164.97.6133029.36 993.066.96.74915029.3712102.064.96.77933029.3515109.059.09.26554029.29 18104.061.010.11781029.282195.069.110.10029.307/4/80088.070.04.30029.34386.071.19.20529.33682.068.08.3126129.36991.968.07.64905029.391299.066.94.97929029.3815102.964.09.26554029.3318100.064.06.71781029.312191.064.06.70029.347/5/80084.964.94.90029.37382.966.09.20029.36679.069.16.7122029.41990.071.18.34896029.441297.066.09.27925029.4315100.964.99.26554029.3618100.960.18.31778029.33 2191.068.08.30029.367/6/80087.166.94.30029.39382.969.14.90029.39 681.070.04.9117029.43TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 3 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 104991.069.18.34886029.461297.068.09.26634529.4515104.066.010.15871429.39 18100.064.09.21776029.352191.066.06.70029.377/7/80086.066.04.30029.40382.066.94.90029.40682.070.07.6110029.42991.969.113.44876029.4712100.068.04.37866129.4615102.068.09.25871429.4018100.066.010.11727229.35 2191.969.17.60129.357/8/80089.169.16.70029.40384.970.06.70029.43 681.070.04.3102229.44989.171.16.74359429.4412100.968.013.47091429.4415105.164.910.76507129.3818100.964.010.71769029.34 2191.964.04.30029.367/9/80087.166.06.70029.38380.164.94.30029.38 679.066.06.799029.42995.068.07.64855029.4412100.966.04.97703229.43 15105.161.07.66378229.3618102.061.06.71478529.332193.062.18.30229.36TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 4 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 1047/10/80086.063.04.30529.40380.163.04.30029.39680.168.06.794029.41 993.970.09.24813129.4612100.066.06.77442329.4315102.062.13.46503129.37 18102.061.04.31759029.332191.963.06.70029.367/11/80087.163.04.90029.37380.164.04.30029.36679.066.94.988029.39995.069.19.24834029.4112102.064.09.27695229.3815105.161.09.26500129.3218102.061.08.31754029.28 2195.063.06.70029.307/12/80089.164.94.90029.33384.064.99.20029.32680.164.94.374429.37993.969.18.34823029.4012100.964.96.77895029.3715106.064.010.76539029.3118102.961.08.31748029.28 2190.059.04.30029.297/13/80084.061.04.30029.32382.966.09.20029.34 679.066.04.977029.36991.964.99.24812029.4012100.063.010.17890029.39 15106.057.910.76536029.31TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 5 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 10418104.057.09.21741029.282191.057.04.90029.307/14/80082.062.14.30029.33384.964.96.70029.35680.166.09.272029.37991.966.010.14801029.4012102.961.013.47885029.3915107.159.09.26532129.3318102.962.110.11733029.31 2193.064.97.60029.337/15/80088.064.94.90029.35384.968.07.60029.37 682.069.19.265229.40991.069.19.24790029.4212100.068.09.27880029.40 15106.063.013.46528029.3418102.061.011.61725029.302191.962.16.70029.327/16/80088.063.06.70029.34384.964.910.10029.35 680.166.94.962029.36991.969.19.24778129.3812102.062.16.77874029.37 15108.053.16.76522129.3018106.048.94.31716029.252190.052.06.70029.267/17/80086.053.10.00029.31380.155.04.90029.29681.059.06.743629.31 995.057.06.72784829.34TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 6 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 10412104.055.09.24595829.3215108.054.06.74442729.2718106.053.16.71607329.22 2195.054.06.70029.257/18/80086.057.04.90029.27381.057.04.90029.26 681.057.96.752029.29995.061.09.24756029.3112104.060.13.47862029.31 15109.059.010.15834429.2718105.157.98.31685129.232195.059.06.70029.287/19/80089.160.14.30029.31386.062.16.70029.33684.064.04.347029.35 991.966.98.34744029.3812100.964.06.77856029.3615102.063.09.26463129.3118100.060.18.31685029.282191.060.14.30029.287/20/80088.063.04.30029.30382.062.14.30029.30681.064.94.343029.31 989.166.04.34732029.331298.164.08.37391329.3115102.963.04.35823429.26 18100.960.14.91631229.242190.060.13.40129.27TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 7 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 1047/21/80086.063.02.50429.29382.064.02.50429.29680.164.92.537229.31 993.066.94.93953529.3612100.963.010.76569529.321591.069.16.74423729.29 1893.064.90.05821029.282182.969.10.00929.317/22/80082.968.04.30529.33381.068.02.501029.34678.168.03.420829.37986.070.04.92749829.401297.068.09.26564529.3815102.062.111.65430529.3018100.059.07.61606229.28 2187.154.00.00029.337/23/80082.054.04.30029.35375.953.16.70029.33673.953.17.630029.34987.155.04.34696029.361297.043.010.77830029.3415102.946.013.46475029.2818100.053.19.21635029.24 2189.159.06.70029.277/24/80081.057.90.00029.29375.055.93.40029.28 673.059.04.327129.30988.061.010.14410329.341295.057.010.77772129.32 15100.053.110.76424129.28TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 8 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 1041897.051.18.31611129.262189.151.14.90029.287/25/80079.055.02.50029.30377.057.90.00029.29677.062.12.522329.31991.066.010.74550229.3512100.064.94.96545529.3315104.063.010.75785429.2818100.057.97.61564229.26 2191.957.94.90029.287/26/80087.160.14.90029.29384.964.97.60029.29 681.066.06.721129.31991.066.97.64659029.3212100.963.07.67807029.29 15105.160.19.23765829.231888.066.94.95571029.222184.066.93.40329.237/27/80082.064.02.50029.25380.164.00.00629.26 680.166.92.58929.27988.070.06.72714829.281297.070.04.36989429.27 1588.071.14.94387729.201886.071.19.21073729.222175.966.92.50029.277/28/80075.068.06.70529.30373.068.02.50229.28673.066.90.014029.30 982.970.03.44634029.33TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 9 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 1041295.071.13.47740129.3215100.961.06.76384129.281899.055.98.31466329.28 2186.059.00.00029.307/29/80082.066.97.60029.32375.066.92.50029.33 672.064.92.312029.36988.069.12.54621029.401298.157.06.77783029.39 15102.057.09.26414029.351899.057.97.61540029.322184.960.14.30029.337/30/80080.161.04.30029.36377.063.06.70029.35677.066.07.610029.37 990.068.07.64608029.3912100.961.08.37774029.3715105.157.97.66402029.3018102.055.09.21521029.282191.961.010.10029.317/31/80087.159.07.60029.36381.063.06.70029.36680.166.06.78029.39 991.963.09.24595029.4212102.950.013.47765029.4015106.048.97.66389029.35 18102.046.910.11502029.322186.050.04.90029.35TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 10 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 1048/01/80080.157.04.90029.38372.057.04.90029.37675.959.04.97029.39 990.061.04.94581029.4312100.054.09.27756029.4015102.951.16.76375029.33 18100.948.98.31473129.282186.053.14.90029.298/02/80082.057.94.90029.30378.155.94.90029.28675.959.08.35029.31990.066.013.44568029.301299.063.011.67746029.2715104.057.013.46321129.2018102.057.910.71452129.16 2193.960.18.30029.17TABLE 2.3-7COFFSITE METEOROLOGICAL DATA USED IN ULTIMATE HEAT SINK WATER SUPPLY PERFORMANCE EVALUATION(Sheet 11 of 11)DATEHOURAIRTEMP.FDEW-POINTTEMP.FWIND-SPEEDMPHSOLARRADIATIONBTU FT2DAY-1CLOUDCOVER,TENTHSPRESSUREIN Hg CPNPP/FSAR Amendment No. 104TABLE 2.3-8 DELETED CPNPP/FSAR Amendment No. 104TABLE 2.3-9 DELETED CPNPP/FSAR Amendment No. 104TABLE 2.3-10 DELETED CPNPP/FSAR Amendment No. 104TABLE 2.3-11 PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 1 of 13)AnnualWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN11221+6 NNE+121++5 NE1221++5 ENE+111++4E+12+++4ESE+121++5 SE13531+13 SSE+2562+16 S12562+16 SSW+1121+6 SW1111++4 WSW++++++1 W+1++++2 WNW+11+++2 NW11111+4 NNW+1121+5 Calm22TOTAL921322891100 CPNPP/FSAR Amendment No. 104JanuaryWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN13331+10 NNE1221+06 NE121+005 ENE+11+002E+11+002ESE+11++03 SE1242+09 SSE+2541+12 S11562+14 SSW+1121+5 SW1111++4 WSW+++++01 W111++02 WNW+111++3 NW12221+8 NNW12331+10 Calm33TOTAL1322312681100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 2 of 13)
CPNPP/FSAR Amendment No. 104FebruaryWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN12321+9 NNE1222+07 NE1321+06 ENE+11++03E111++03ESE+121+04 SE12421+10 SSE+1351+11 S12342+12 SSW+1111+4 SW1111++5 WSW++++++1 W11++++3 WNW+1111+3 NW12221+8 NNW12231+9 Calm22TOTAL10213026102100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 3 of 13)
CPNPP/FSAR Amendment No. 104 MarchWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN12321+8 NNE+222+06 NE1231+06 ENE+121++4E+121+04ESE+122++5 SE+243109 SSE+1363+13 S+1253112 SSW++121+5 SW+111++4 WSW+++1++2 W+1111+3 WNW++111+4 NW+112116 NNW+1232+8 Calm11TOTAL6172931143100TABLE 2.3-11 PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 4 of 13)
CPNPP/FSAR Amendment No. 104 AprilWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN+1221+7 NNE+2221+7 NE1221++6 ENE+111++3E+111+03ESE+111++4 SE+1451+12 SSE++385117 S+1275116 SSW++121+5 SW+111++3 WSW+++1++2 W+11+++2 WNW+++11+2 NW+1111+4 NNW+1211+5 Calm11TOTAL4132636183100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 5 of 13)
CPNPP/FSAR Amendment No. 104MayWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN1121++5 NNE+111+04 NE1221++5 ENE+121++4E+12+++4ESE+121+05 SE12551+14 SSE+2494118 S+1495119 SSW+1121+6 SW+111+03 WSW++++++1 W+11+++2 WNW++1+++1 NW+111++3 NNW+111++4 Calm11TOTAL6182932132100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 6 of 13)
CPNPP/FSAR Amendment No. 104 JuneWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN+11+++2 NNE+111++3 NE+11+++4 ENE+121+04E+121+04ESE+132+06 SE+2661+16 SSE+26104+23 S+2595122 SSW+1231+7 SW+111++4 WSW+++++01 W++++0+1 WNW++++++1 NW+++++01 NNW+++++01 Calm++TOTAL4143236131100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 7 of 13)
CPNPP/FSAR Amendment No. 104JulyWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN+11++02 NNE+111++2 NE+21++04 ENE+121++4E+221+05ESE+231+06 SE14641+16 SSE+2781+19 S+3882+21 SSW+1331+9 SW1232+06 WSW+111+02 W+++++01 WNW+++++01 NW+++++01 NNW++++++1 Calm11TOTAL52139296+100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 8 of 13)
CPNPP/FSAR Amendment No. 104 AugustWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN+11++02 NNE+111+03 NE121+++4 ENE+221+05E1221+05ESE+231++7 SE1485+017 SSE+2881+21 S+3961+19 SSW+122++6 SW+121++5 WSW++++001 W++++001 WNW+++++01 NW++++001 NNW++++++1 Calm11TOTAL622422630100TABLE 2.3-11 PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 9 of 13)
CPNPP/FSAR Amendment No. 104 SeptemberWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN1111+04 NNE1221++6 NE1431+010 ENE1221+05E134++08ESE+241++8 SE1483+016 SSE+2651+15 S12551+14 SSW+112+04 SW111+++3 WSW++++001 W+++++01 WNW+++++01 NW+1+++02 NNW+11++02 Calm22TOTAL92640223+100TABLE 2.3-11 PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 10 of 13)
CPNPP/FSAR Amendment No. 104 OctoberWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN1222++7 NNE1221++5 NE131++06 ENE+21++04E121++04ESE123++06 SE1573++17 SSE+2641+13 S12441+13 SSW+112++4 SW1111+04 WSW+++++01 W+1+++02 WNW+1++++2 NW1111++5 NNW+121++5 Calm33TOTAL1328342041100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 11 of 13)
CPNPP/FSAR Amendment No. 104 NovemberWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN12221+9 NNE1221++6 NE131++06 ENE+11+003E121++04ESE+11+003 SE1431+09 SSE+2451012 S12552+15 SSW+1121+5 SW1111++4 WSW+1+++02 W11++++2 WNW+111++3 NW12111+6 NNW12221+7 Calm44TOTAL1526272371100TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 12 of 13)
CPNPP/FSAR Amendment No. 104 DecemberWindDirectionWind Speed (Miles per Hour)0-34-78-1213-1819-2425TotalN12221+8 NNE+111++4 NE1111+04 ENE+11++02E+11++02ESE+111++3 SE1332+09 SSE+2551+14 S12451+13 SSW+1221+6 SW1211+05 WSW+1++++2 W1111++4 WNW1111++5 NW12221+9 NNW+2231+8 Calm22TOTAL1224292771100+indicates percentages less than 0.5 but greater than zero.TABLE 2.3-11PERCENT FREQUENCY DISTRIBUTION OF WIND AT LOVE FIELD (1951-1960)(Sheet 13 of 13)
CPNPP/FSAR Amendment No. 104TABLE 2.3-12MONTHLY VARIATION OF EXTREME "FASTEST MILE" WINDS FOR FORT WORTH AND DALLASFort Worth (1954-1973)Dallas (1941-1973)
MonthSpeed(MPH)DirectionYearSpeed(MPH)Direction (a)a) Direction recorded to 8 compass points only.YearJanuary46N195750W1966 February51N1962(b)b) Record also occurred in earlier year(s).61SW1948March55WNW195459W1954 April55NW197058N1961 May55SE195551S1952 June52NW195565N1954 July65N196143S1948 August73N195953SE1954 September53ESE1961 (b)47NW1954October44W195761NW1960 November50NNW195749NW1957
 
December53NW196847W1957 (b)Year73N195965N1954 CPNPP/FSAR Amendment No. 104TABLE 2.3-13WIND DIRECTION PERSISTENCE AT FORT WORTH (1969-1973)(Sheet 1 of 2)WindSectorConsecutive 3-Hourly Observations (a)2345678910111215N27413074371910641000 NNE1314814420000000 NE64215400000000 ENE4041110000000 E1213312310000000 ESE126378211100000 SE18564251042000000 SSE363136582484210000 S662332179116623820159752 SSW26389321030000000 SW68124100000000 WSW3081110000000 W56228320000000 WNW35113200000000 NW943918822110000 NNW1928937201410211110Total2704107547924612067322211862 CPNPP/FSAR Amendment No. 104WindSector+/-22.5&deg;Consecutive 3-Hourly Observations (a)234567101520253040N2761821319565441331100 NNE1187649412819610000 NE10545251495000000 ENE6429161096300000 E1728041221410100000 ESE16510264432714600000 SE235157996742321411000 SSE3482592011481179043145220 S323253200166141111774523931 SSW26318313397764932136310 SW9549251051000000 WSW613013521000000 W83372212106110000 WNW6132171055320000 NW916748312822820000 NNW19111156372318500000Total26511692114080860143321282361561a)Values in each sector are cumulative, beginning with the longest duration.TABLE 2.3-13WIND DIRECTION PERSISTENCE AT FORT WORTH (1969-1973)(Sheet 2 of 2)
CPNPP/FSARAmendment No. 104TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 1 of 26)JANUARY (1973 - 1976): 10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE12106610102000100000000000NE441110000000000000000000 ENE510000000000000000000000E201000000000000000000000ESE940000000000000000000000 SE2774320000000000000000000SSE2379213210100000000000000S31147321320200000100000000 SSW21118422010000100000000000SW9125220012001000000000000WSW1445102000000000000000000 W10120410000000000000000000WNW1532201000000000000000000NW26158513100000000000000000 NNW22127652111101210000100002N21710311510220000000000001 CPNPP/FSARAmendment No. 104JANUARY (1973 - 1976): 10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.393.354.203.6099.990.2.280.3.560.0.0.99.990.0.0.0.0.0.0.0.0.0.0.NE2.723.051.683.203.560.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.052.380.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E1.050.3.230.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.312.280.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.572.502.151.882.630.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE3.243.723.163.932.443.445.095.200.4.320.0.0.0.0.0.0.0.0.0.0.0.0.0.S3.744.934.554.014.592.846.125.240.5.620.0.0.0.0.7.550.0.0.0.0.0.0.0.SSW4.784.605.304.946.246.400.7.240.0.0.0.7.210.0.0.0.0.0.0.0.0.0.0.
SW4.784.183.996.124.340.0.6.706.430.0.5.250.0.0.0.0.0.0.0.0.0.0.0.WSW3.053.804.662.040.3.910.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W3.233.070.7.321.740.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW3.632.364.002.420.3.240.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW2.863.072.952.739.893.612.940.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NNW3.643.963.824.575.213.766.4899.993.916.040.4.894.669.240.0.0.0.6.580.0.0.0.8.56 N4.873.595.144.6599.9910.456.024.770.5.254.580.0.0.0.0.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2976TOTAL NO. OF INVALID OBSERVATIONS=  13399.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 2 of 26)
CPNPP/FSARAmendment No. 104FEBRUARY (1973 - 1976): 10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE930001000000000000000000NE134100000000000000000000ENE342000000000000000000000E810010000000000000000000 ESE1110000000000000000000000SE1542501010000000000000000SSE22137121110000000100000000 S33118973001010001010000000SSW21167592320000100000000000SW1292320020100000000000000 WSW1111222001000000000000000W911010000000000000000000WNW1443320000000000000000000 NW25186213200200001000000000NNW24164123421111100001000000N1578221011001100000000001TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 3 of 26)
CPNPP/FSARAmendment No. 104FEBRUARY (1973 - 1976): 10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE2.582.550.0.0.3.960.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NE6.482.442.742.020.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.142.122.400.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E2.341.860.0.2.030.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE3.444.250.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE3.062.862.023.560.1.600.2.720.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE3.573.573.752.317.064.555.263.450.0.0.0.0.0.0.5.570.0.0.0.0.0.0.0.S3.495.554.595.565.776.560.0.8.530.9.800.0.0.4.730.7.310.0.0.0.0.0.0.SSW4.594.255.705.587.095.517.058.760.0.0.0.4.150.0.0.0.0.0.0.0.0.0.0.
SW4.315.694.386.104.870.0.6.160.5.400.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW4.464.924.955.606.207.400.0.5.180.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W4.1911.031.120.3.000/0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW2.604.956.406.065.270.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW4.674.335.448.373.844.347.270.0.3.810.0.0.0.8.810.0.0.0.0.0.0.0.0.NNW4.514.604.326.285.174.675.176.2810.465.24.824.038.370.0.0.0.8.130.0.0.0.0.0.
N4.354.695.713.286.315.100.5.119.830.0.6.156.380.0.0.0.0.0.0.0.0.0.7.78TOTAL NO. OF OBSERVATIONS= 2715TOTAL NO. OF INVALID OBSERVATIONS=  12499.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 4 of 26)
CPNPP/FSARAmendment No. 104MARCH (1973 - 1976): 10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE1643005000000000000000000NE666100000000000000000000ENE1032010000010000000000000E1603101010000000000000000 ESE15118211200000000000000000SE27216533010010000000000100SSE2522101152110010000000000000 S321410933112003000000001000SSW17112242000100000000000000SW1461410000010000000000000 WSW1354010000000000000000000W563210000000000000000000WNW1313200001000000000000000 NW15104630100000000000000000NNW1468103311211000100000000N1276221101010002000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 5 of 26)
CPNPP/FSARAmendment No. 104MARCH (1973 - 1976): 10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.725.856.110.0.5.060.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NE2.453.424.033.760.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.352.813.750.4.240.0.0.0.0.4.580.0.0.0.0.0.0.0.0.0.0.0.0.
E3.080.3.7799.990.2.550.4.060.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.913.494.274.687.474.074.410.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE3.334.422.905.416.376.030.2.710.0.6.440.0.0.0.0.0.0.0.0.0.3.150.0.
SSE4.865.724.205.695.535.792.685.530.0.9.650.0.0.0.0.0.0.0.0.0.0.0.0.S6.216.705.856.606.417.5713.415.238.870.0.7.95.0.0.0.0.0.0.0.0.8.760.0.0.SSW6.257.909.117.068.2510.360.0.0.9.170.0.0.0.0.0.0.0.0.0.0.0.0.0.
SW4.175.515.584.9510.910.0.0.0.0.5.230.0.0.0.0.0.0.0.0.0.0.0.0.WSW5.325.305.070.8.350.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W3.565.875.615.536.260.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW5.801.485.483.380.0.0.0.6.640.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW4.694.665.546.246.400.6.640.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NNW5.633.185.609.720.6.138.696.815.456.717.507.680.0.0.6.270.0.0.0.0.0.0.0.
N4.387.596.274.098.024.376.310.6.240.5.900.0.0.7.720.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS=2976TOTAL NO. OF INVALID OBSERVATIONS=12599.99I NDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 6 of 26)
CPNPP/FSARAmendment No. 104APRIL(1973-1976):10-METERLEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE683220000 000000000000000NE1270001000000000000000000ENE1012110200100000000000000E12124112100000000000000000 ESE2896132111300001000000000SE211810653222200000000000000SSE26179715221120000010000001 S16128431330100000001000000SSW1524110000000000000000000SW1012000001000000000000000 WSW610000000000000000000000W504000000000000000000000WNW442100100000000000000000 NW1376321110110000001000000NNW17124121300120000100000001N753312010100000000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 7 of 26)
CPNPP/FSARAmendment No. 104APRIL (1973-1976):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE2.473.682.315.836.610.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NE3.233.280.0.0.2.040.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.641.393.436.033.670.4.000.0.4.800.0.0.0.0.0.0.0.0.0.0.0.0.0.
E4.804.173.182.156.734.244.890.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE3.704.525.932.664.844.936.077.668.318.640.0.0.5.970.0.0.0.0.0.0.0.0.0.SE4.344.003.693.815.906.424.045.254.505.240.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE4.224.695.465.83 11.507.438.108.867.617.938.160.0.0.0.0.7.510.0.0.0.0.0.7.63S4.466.006.057.304.807.188.527.150.6.930.0.0.0.0.00.6.720.0.0.0.0.0.SSW4.152.406.667.385.080.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SW3.402.926.720.0.0.0.0.6.550.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW5.825.270.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W2.780.8.100.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW2.053.726.263.640.0.7.200.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW3.814.005.352.834.299.763.936.040.7.183.800.0.0.0.0.0.7.150.0.0.0.0.0.NNW3.954.314.565.964.307.736.650.0.6.476.570.0.0.0.6.360.0.0.0.0.0.0.7.57 N2.643.783.293.187.814.450.6.690.99.990.0.0.0.0.0.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2880TOTAL NO. OF INVALID OBSERVATIONS=  21799.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 8 of 26)
CPNPP/FSARAmendment No. 104MAY (1972 - 1976): 10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE933300310000000000000000NE643110000000000000000000 ENE1671010000000000000000000E1053120000000000000000000ESE24134010010001000000000000 SE2595260310100000000000000SSE4117101220312001000001000000S31215864311402100000000000 SSW16510213000000000000000000SW1320110000000000000000000WSW1101100000000000000000000 W330100000010000000000000WNW1241100000000000000000000NW1464241000011000100000000 NNW1842201200000000000000000N1633111000000000000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 9 of 26)
CPNPP/FSARAmendment No. 104MAY (1972 - 1976): 10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.013.103.643.160.0.5.091.770.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NE3.103.202.936.48.340.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.132.024.170.3.890.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E3.051.923.731.132.600.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE3.082.323.340.2.150.0.2.610.0.0.8.180.0.0.0.0.0.0.0.0.0.0.0.SE2.713.713.682.793.820.3.883.020.3.210.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE3.134.263.413.763.450.5.188.614.030.0.5.390.0.0.0.0.3.280.0.0.0.0.0.S3.544.004.395.393.443.974.784.424.005.020.5.245.410.0.0.0.0.0.0.0.0.0.0.SSW4.262.764.894.534.395.180.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SW2.862.590.4.927.000.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW2.930..344.850.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W5.345.130.4.700.0.0.0.0.0.4.910.0.0.0.0.0.0.0.0.0.0.0.0.
WNW3.682.284.134.360.0.0.0.0.0.0.0.0.00.0.0.0.0.0.0.0.0.0.NW2.363.265.024.203.926.000.0.0.0.5.105.230.0.0.4.700.0.0.0.0.0.0.0.NNW3.683.254.3912.840.4.743.900.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
N3.115.923.206.303.754.340.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2955TOTAL NO. OF INVALID OBSERVATIONS=  29299.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 10 of 26)
CPNPP/FSARAmendment No. 104JUNE (1972 - 1975): 10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE622120000000000000000000NE1151000010000000000000000 ENE732100000000000000000000E1692000010000000000000000ESE2687300000000000000000000 SE49249510100000000000000000SSE512713433330010020010000000S4420111375432321210210000000 SSW22136625110001000010000000SW11132102100000000000000000WSW601000000000000000000000 W823100000000000000000000WNW301000000000000000000000NW611000000000000000000000 NNW701000000100000000000000N250000000000000000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 11 of 26)
CPNPP/FSARAmendment No. 104JUNE (1972 - 1975): 10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.773.813.733.482.860.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NE3.043.813.350.0.0.0.3.660.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.542.344.023.040.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E3.032.692.400.0.0.0.4.000.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.573.032.742.900.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.833.202.732.285.300.3.010.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE3.143.112.895.254.986.296.134.490.0.9.070.0.6.480.0.3.180.0.0.0.0.0.0.S3.784.465.374.424.063.916.205.254.815.145.718.945.705.330.7.016.860.0.0.0.0.0.0.SSW4.855.464.395.395.254.885.925.400.0.0.6.400.0.0.0.2.960.0.0.0.0.0.0.
SW2.633.693.894.810.4.054.750.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW2.150.2.910.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W2.314.541.685.360.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW1.560.4.580.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW1.561.881.840.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NNW3.150.1.650.0.0.0.0.0.5.070.0.0.0.0.0.0.0.0.0.0.0.0.0.
N2.274.050.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2883TOTAL NO. OF INVALID OBSERVATIONS=  14299.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 12 of 26)
CPNPP/FSARAmendment No. 104JULY (1972-1975):  10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE1451110000000000000000000NE843200000000000000000000ENE1531000000000000000000000E741110000000000000000000 ESE2133252010000000000000000SE45203541000010000000000000SSE5229191443330110000000000000 S422216846441100200000000000SSW242112445102000101000000000SW1824312000000000000000000 WSW1221000000000000000000000W1113000000000000000000000WNW610000000000000000000000 NW841000000000000000000000NNW420000000000000000000000N814100100000000000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 13 of 26)
CPNPP/FSARAmendment No. 104JULY (1972-1975):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE2.982.713.032.231.240.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NE2.433.222.993.690.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.174.132.610.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E2.392.723.011.961.650.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.163.573.224.863.562.840.3.730.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.963.352.613.553.243.270.0.0.0.4.440.0.0.0.0.0.0.0.0.0.0.0.0.
SSE2.923.433.733.844.573.712.713.980.4.395.390.0.0.0.0.0.0.0.0.0.0.0.0.S3.243.833.965.064.793.946.604.804.303.940.0.7.050.0.0.0.0.0.0.0.0.0.0.SSW3.764.353.973.193.913.898.630.5.770.0.0.4.980.6.300.0.0.0.0.0.0.0.0.
SW3.352.973.224.405.604.620.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW2.512.783.590.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W1.952.284.1800.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW2.692.470.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW1.572.501.910.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NNW2.422.100.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
N2.622.944.301.790.0.3.060.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2976TOTAL NO. OF INVALID OBSERVATIONS=  1299.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 14 of 26)
CPNPP/FSARAmendment No. 104AUGUST (1972-1975):  10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE810010101100000000000000NE1351110000000000000000000ENE720000000000000000000000E1521201000000000000000000 ESE29177510000000000000000000SE491914431011000000000000000SSE5027181222011000010000000000 S4834151174011000000100000000SSW36229350111221000000000000SW11133200010000000000000000 WSW1200000000000000000000000W300000000000000000000000WNW310000000000000000000000 NW431100100000000000000000NNW820000000000000000000000N440000000000000000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 15 of 26)
CPNPP/FSARAmendment No. 104AUGUST (1972-1975):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE2.463.010.0.4.240.6.300.3.714.080.0.0.0.0.0.0.0.0.0.0.0.0.0.NE2.723.981.685.612.820.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.322.360.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E2.161.973.142.650.3.350.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.442.772.952.242.700.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.672.522.361.792.582.330.2.463.630.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE2.683.173.853.104.325.300.3.695.190.0.0.0.3.640.0.0.0.0.0.0.0.0.0.S3.673.673.944.213.974.720.4.814.800.0.0.0.0.0.5.580.0.0.0.0.0.0.0.SSW3.683.874.024.583.530.5.013.985.784.105.434.710.0.0.0.0.0.0.0.0.0.0.0.
SW2.773.302.833.540.0.0.3.800.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW1.860.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W1.440.0.00.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW1.68.480.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW2.581.972.102.390.0.1.730.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NNW2.573.660.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
N3.123.320.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2976TOTAL NO. OF INVALID OBSERVATIONS=    3199.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 16 of 26)
CPNPP/FSARAmendment No. 104SEPTEMBER (1972-1975):  10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE25116231101000000010000000NE2182501000000000000000000ENE1152320100100000000000000E1361210000000000000000000 ESE2657220000000000000000000SE26206452010000000000000000SSE301513822111100010002000000 S27164565211200100000000000SSW983430011000000000000000SW430000000000000000000000 WSW401000000000000000000000W300000000000000000000000WNW641000000000000000000000 NW1096510120001000000000000NNW23103001000100000000000000N37910471101000111000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 17 of 26)
CPNPP/FSARAmendment No. 104SEPTEMBER (1972-1975):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.243.674.133.245.162.416.970.4.860.0.0.0.0.0.0.5.540.0.0.0.0.0.0.NE2.802.593.034.540.3.170.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.112.854.422.945.270.4.140.0.2.930.0.0.0.0.0.0.0.0.0.0.0.0.0.
E2.212.002.251.982.810.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.192.492.663.102.120.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.252.622.932.362.403.690.3.990.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE2.953.223.883.884.633.013.104.783.393.900.0.0.3.230.0.0.5.250.0.0.0.0.0.S3.863.974.253.985.314.395.533.607.014.310.0.3.910.0.0.0.0.0.0.0.0.0.0.SSW3.324.865.175.865.400.0.5.665.220.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SW4.224.070.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW2.230.2.000.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W1.240.0.00.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW1.951.602.750.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW2.373.072.403.181.870.2.403.090.0.0.3.600.0.0.0.0.0.0.0.0.0.0.0.NNW3.183.066.760.0.1.980.0.0.5.350.0.0.0.0.0.0.0.0.0.0.0.0.0.
N3.054.274.813.054.206.563.010.7.010.0.0.6.467.504.660.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2880TOTAL NO. OF INVALID OBSERVATIONS=  3599.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 18 of 26)
CPNPP/FSARAmendment No. 104OCTOBER (1972-1975):  10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE866110000100000000000000NE1230200000000000000000000ENE631000000000000000000000E1031000000000000000000000 ESE2272402001000000000000000SE37246342200000010000000000SSE4415151157523001000010000000 S352611782113120000000000000SSW191010230100000000000000000SW861000000000000000000000 WSW640000000000000000000000W730000010000000000000000WNW523100000000000000000000 NW2563340010000000000000000NNW12122221000200001010000000N1078123100111000000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 19 of 26)
CPNPP/FSARAmendment No. 104OCTOBER (1972-1975):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE2.603.073.296.313.100.0.0.0.7.160.0.0.0.0.0.0.0.0.0.0.0.0.0.NE2.332.410.2.290.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE1.491.741.710.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E1.642.343.650.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE1.912.822.072.220.3.190.0.3.770.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.162.582.271.932.273.322.680.0.0.0.0.0.3.100.0.0.0.0.0.0.0.0.0.
SSE2.513.243.583.394.204.424.474.014.940.0.5.200.0.0.0.4.220.0.0.0.0.0.0.S3.713.844.916.025.164.475.502.814.933.494.660.0.0.0.0.0.0.0.0.0.0.0.0.SSW4.404.064.304.243.640.1.240.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SW2.792.214.910.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW1.962.870.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W2.012.380.0.0.0.0.1.430.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW1.381.793.341.980.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW2.502.492.542.642.450.0.3.430.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NNW3.123.943.773.864.135.580.0.0.4.960.0.0.0.4.160.5.240.0.0.0.0.0.0.
N2.135.513.473.333.674.637.150.0.2.075.707.490.0.0.0.0.0.0.0.0.0.0.0.TOTAL NO. OF OBSERVATIONS= 2976TOTAL NO. OF INVALID OBSERVATIONS=  6799.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 20 of 26)
CPNPP/FSARAmendment No. 104NOVEMBER (1972-1975):  10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE10102041010000000000000000NE1051200000000000000000000ENE1212100000000000000000000E520200000000000000000000 ESE635102000000000000000000SE271212562210100000000000000SSE39916364232010000000000000 S251311522122010110000000000SSW7155411410000000000000000SW662211100001000000000000 WSW560100000000000000000000W1123001100000000000000000WNW1667101000000000000000000 NW20175373110000000100000000NNW20101922121000100010100001N1265341111100110000000000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 21 of 26)
CPNPP/FSARAmendment No. 104NOVEMBER (1972-1975):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.022.111.160.3.245.410.4.390.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NE2.372.571.262.630.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.273.311.93.620.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E1.891.770.2.060.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE1.511.762.382.490.2.310.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.672.422.993.093.494.404.034.360.5.450.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE3.654.453.333.335.443.902.394.672.930.3.360.0.0.0.0.0.0.0.0.0.0.0.0.S3.684.614.076.584.765.883.637.334.980.4.540.4.329.740.0.0.0.0.0.0.0.0.0.SSW3.914.135.743.917.066.066.857.040.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SW3.913.656.704.775.787.144.580.0.0.0.6.790.0.0.0.0.0.0.0.0.0.0.0.WSW4.293.330.1.840.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W2.061.943.360.0.2.056.050.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW2.412.404.333.130.4.810.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW3.513.816.114.502.826.354.439.210.0.0.0.0.0.0.9.140.0.0.0.0.0.0.0.NNW5.553.793.304.684.686.534.964.585.910.0.0.4.900.0.0.6.410.7.740.0.0.0.7.00 N3.973.843.433.583.964.724.445.844.983.600.0.8.526.870.0.0.0.0.0.0.990.0.0.TOTAL NO. OF OBSERVATIONS= 2880TOTAL NO. OF INVALID OBSERVATIONS=  2199.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 22 of 26)
CPNPP/FSARAmendment No. 104DECEMBER (1972-1975):  10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE951520010100000000000000NE421100000000000000000000ENE411000000000000000000000E410100000000000000000000 ESE1300100000000000000000000SE30143411100000000000000000SSE27159233100200001000000000 S26227354232000100000000000SSW1784525000000001000000000SW1384211000000000000000000 WSW1163010110000000000000000W1043100000000000000000000WNW1556101000000000000000000 NW38187574210111001000000000NNW251811712201001110010000001N1837222200000020000001000TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 23 of 26)
CPNPP/FSARAmendment No. 104DECEMBER (1972-1975):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.404.163.363.762.750.0.3.470.2.340.0.0.0.0.0.0.0.0.0.0.0.0.0.NE2.272.9099.994.720.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.101.131.110.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
E1.13.580.2.250.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.170.0.1.970.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.SE2.172.722.071.871.322.241.322.241.320.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
SSE2.963.462.795.394.804.455.110.0.3.640.0.0.0.5.900.0.0.0.0.0.0.0.0.S4.754.605.274.064.495.444.976.325.120.0.0.7.610.0.0.0.0.0.0.0.0.0.0.SSW4.894.746.236.475.395.810.0.0.0.0.0.0.0.6.820.0.0.0.0.0.0.0.0.
SW4.004.823.515.855.828.110.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.WSW3.344.063.250.6.120.4.004.430.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W2.102.853.252.230.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.
WNW2.973.302.505.420.6.050.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW2.953.795.153.264.964.593.826.090.3.254.087.010.0.6.15.0.0.0.0.0.0.0.0.0.NNW3.994.634.255.135.773.864.290.8.280.0.7.067.387.370.0.7.050.0.0.0.0.0.8.80 N4.313.114.746.555.756.627.300.0.0.0.0.0.5.670.0.0.0.0.0.5.790.0.0.TOTAL NO. OFOBSERVATIONS= 2976TOTAL NO. OF INVALID OBSERVATIONS=  7499.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 24 of 26)
CPNPP/FSARAmendment No. 104ANNUAL (5/72-5/76):  10-METER LEVELWIND DIRECTION PERSISTENCE - PASQUILL ALL1 SECTOR PERSISTENCECONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24 NNE1316832201696353001000100 00000NE108562317320100000000000 00000ENE10634166503002100000000 00000E118441811641200000000000 00000ESE23081492112103323010010000 00000SE3791918151401611834200100000 00100SSE4272121498735342419126620410430 00001S39022511284604124221613668224210 01000SSW2241447942362611743223020100 00000SW128802621962431120000000 00000WSW11030175441110000000000 00000W8534209311100100000000 00000WNW112352712232010000000000 00000NW2041145335301510604330022010 00000NNW1941044329141616659445212312 00005N162646322221212446423430000 01002TABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 25 of 26)
CPNPP/FSARAmendment No. 104ANNUAL (5/72-5/76):  10-METER LEVELAVERAGE WIND SPEED (M/SEC)CONSECUTIVE HOURSSECTOR23456789101112131415161718192021222324>24NNE3.093.303.723.643.774.715.623.213.824.530.0.99.990.0.0.5.540.0.0.0.0.0.0.NE2.753.113.043.872.242.600.3.660.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ENE2.222.443.073.084.470.4.040.0.3.864.580.0.0.0.0.0.0.0.0.0.0.0.0.
E2.672.743.202.093.073.594.894.030.0.0.0.0.0.0.0.0.0.0.0.0.0.0.0.ESE2.602.993.412.913.833.354.974.676.048.640.8.180.0.5.970.0.0.0.0.0.0.0.0.SE2.763.132.813.013.654.353.413.724.214.795.440.0.3.100.0.0.0.0.0.0.3.150.0.
SSE3.223.773.674.145.094.904.545.074.524.647.305.290.4.965.900.5.194.590.0.0.0.0.7.63S3.944.454.725.144.744.976.375.525.694.965.857.215.847.545.546.797.086.720.0.8.760.0.0.SSW4.414.555.015.175.755.376.306.695.635.795.435.555.450.6.560.2.960.0.0.0.0.0.0.
SW3.533.964.205.215.955.434.665.716.475.405.236.020.0.0.0.0.0.0.0.0.0.0.0.WSW3.363.843.953.986.725.664.004.435.180.0.0.0.0.0.0.0.0.0.0.0.0.0.0.W2.633.894.425.853.672.056.051.430.0.4.910.0.0.0.0.0.0.0.0.0.0.0.0.
WNW3.092.754.224.035.274.705.860.6.640.0.0.0.0.0.0.0.0.0.0.0.0.0.0.NW3.153.614.294.024.115.134.425.160.4.514.335.280.0.7.486.920.7.150.0.0.0.0.0.NNW3.994.004.545.584.895.055.915.706.805.725.365.916.108.314.166.316.238.137.190.0.0.0.8.14 N3.624.664.643.894.975.575.695.607.014.205.196.827.126.436.700.0.0.0.0.5.790.0.7.78TOTAL NO. OF OBSERVATIONS= 35043TOTAL NO. OF INVALID OBSERVATIONS= 126799.99 INDICATES INVALID DATA POINTTABLE 2.3-14WIND DIRECTION PERSISTENCE AT CPNPP(Sheet 26 of 26)
CPNPP/FSAR Amendment No. 104TABLE 2.3-15VALUES OF MEAN, AVERAGE AND EXTREME DAILY MAXIMUM, AND AVERAGE AND EXTREME DAILY MINIMUM SURFACE TEMPERATURES (&deg;F) AT FORT WORTH (1931-1960)Month MeanAverage Daily MaximumExtreme Maximum(a)a)Period of record is July 1963 through 1973; year of occurrence given in parenthesis.Average Daily Minimum Extreme Minimum(a)January465688(1969)354(1964)February496087(1969)3912(1971)
March566791(1971)4419(1965)
April657695(1972)5430(1973)
May738396(1967)6342(1971)
June8292105(1972)7151(1964)
 
July8596105(1964)
(b)b)Record also occurred in earlier year(s).7559(1972)
(b)August8596108(1964)7556(1967)September7889102(1963)6846(1971)
(b)October687996(1963)5637(1966)
(b)November556688(1965)
(b)4424(1970)December485884(1966)3710(1963)Annual6677108(1964)554(1964)
CPNPP/FSAR Amendment No. 104 TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 1 of 13)JANUARY (1973 - 1976)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXAS TEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C15.1-.963.93.32625.62441.6F24.9-.864.33.42635.72461.6F 34.5-.965.33.22695.52461.6F 44.2-1.066.43.22815.62551.6F 54.0-1.067.33.42835.62561.5F 63.7-1.267.53.42965.82661.6F 73.5-1.267.73.43045.72731.6F 83.6-.967.83.33085.52741.3F 95.1-.564.23.82985.5270.5E 106.9-.259.34.62825.9268-.0E 118.5-.354.84.92636.1258-.2E 1210.0-.549.95.02576.3253-.3D 1311.1-.945.25.22536.5248-.4D 1411.8-.843.75.22566.4251-.3D 1512.1-.943.15.02576.3251-.3D 1612.2-.843.14.82466.1238-.2E 1711.4-.745.44.22325.8221.2E 1810.1-.650.03.52065.7191.8F 198.9-.354.53.32005.91761.2F 208.0-.356.73.32215.81931.3F 217.3-.558.33.32335.92081.4F 226.8-.660.03.32465.72251.4F 236.2-.860.43.32565.72341.5F 246.0-.463.33.42585.62371.4FABSOLUTE MAX28.520.799.914.217.4AVG DAILY MAX12.83.176.96.79.0MEAN7.4-.757.33.92635.8244.8FCLIMATIC MEAN7.4-.658.34.15.8AVG DAILY MIN2.0-4.439.61.52.5ABSOLUTE MIN -14.3-20.812.50.00.0STANDARD DEV7.57.320.92.42.9 VALID OBS267726382520271826422449244726512651INVALID OBS299338456258334527529325325 TOTAL OBS297629762976297629762976297629762976 DATA RECOVERY90.088.684.791.388.882.382.289.189.1 CPNPP/FSAR Amendment No. 104FEBRUARY (1973 - 1976)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 18.31.461.94.02456.32241.3F 27.91.563.63.92406.12271.3F 37.41.565.33.82455.92331.2F 47.11.566.53.72515.72411.2F 56.71.467.73.62655.52501.3F 66.51.469.83.72755.82611.4F 76.11.070.53.72795.72681.3F 86.71.268.03.72815.3271.7E 98.31.564.04.52705.5263.1E 1010.21.958.45.32615.9252-.2E 1111.62.153.15.62526.2246-.3D 1212.71.548.55.92586.8263-.4D 1314.01.145.05.92576.8258-.4D 1414.61.342.06.02556.7254-.5D 1515.21.240.46.02507.0252-.4D 1615.31.140.15.92396.7245-.3D 1714.81.341.85.12246.3222-.1E 1813.61.344.84.31915.9194.3E 1912.21.449.04.01826.1180.8F 2011.21.452.34.01866.21681.0F 2110.61.454.74.12196.31821.1F 229.81.357.04.12186.31971.1F 239.31.358.24.02226.22071.1F 248.81.359.33.92476.22231.3FABSOLUTE MAX29.519.2100.016.116.4AVG DAILY MAX15.94.873.67.59.3MEAN10.41.455.64.52506.2239.6ECLIMATIC MEAN10.71.356.24.66.3AVG DAILY MIN5.4-2.138.71.83.4ABSOLUTE MIN -6.2-14.69.70.0.4 STANDARD DEV7.27.021.32.72.8VALID OBS215621242054261924892125212423622362INVALID OBS55658865893223587588350350 TOTAL OBS271227122712271227122712271227122712 DATA RECOVERY79.578.375.796.691.878.478.487.187.1TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 2 of 13)
CPNPP/FSAR Amendment No. 104MARCH (1973 - 1976)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 111.85.264.44.61796.61721.1F 211.25.067.24.51886.31811.1F 310.84.968.04.31976.21861.1F 410.44.868.74.21986.01881.1F 510.14.870.14.11955.91921.1F 69.84.871.64.01845.71821.1F 79.84.771.74.21865.81941.0F 810.55.069.24.71885.8198.4E 911.85.364.55.41866.3199.1E 1013.25.259.35.71896.6202-.1E 1114.54.955.86.01956.9211-.2E 1215.54.952.36.12006.8212-.2E 1316.84.848.26.22047.1212-.3D 1417.74.644.96.22057.0208-.3D 1518.14.643.76.41927.1200-.3D 1618.44.343.26.21887.2196-.2E 1718.24.443.86.11857.3196-.1E 1817.44.445.35.61677.0177.1E 1916.14.849.95.01566.8150.5E 2015.05.053.54.81567.0144.8F 2114.15.357.54.81637.21571.0F 2213.35.259.84.61666.81571.1F 2312.65.261.44.61816.71741.2F 2411.94.763.35.01816.81751.2FABSOLUTE MAX36.422.4100.018.317.9AVG DAILY MAX19.49.478.78.310.0MEAN13.84.957.95.11866.6186.5ECLIMATIC MEAN14.04.959.05.26.8AVG DAILY MIN8.5.439.22.03.5ABSOLUTE MIN -2.4-12.111.00.00.0 STANDARD DEV6.66.922.62.82.8VALID OBS238023802302280627692338230925692569INVALID OBS596596674170207638667407407 TOTAL OBS297629762976297629762976297629762976 DATA RECOVERY80.080.077.494.393.078.677.686.386.3TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 3 of 13)
CPNPP/FSAR Amendment No. 104APRIL (1973 - 1976)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 115.511.074.74.21516.5139.9F 215.311.175.04.11556.3145.9F 315.011.476.83.91616.0152.9F 414.611.077.63.71625.9153.9F 514.110.677.93.61685.6151.9F 613.710.277.73.71595.71431.0F 713.810.277.53.81535.6142.7E 814.810.675.24.11435.4144.2E 916.111.071.24.91456.0144-.0E 1017.411.065.85.21486.3143-.2E 1118.510.661.85.61526.8150-.2E 1219.310.558.85.61496.7145-.3D 1320.010.256.95.71446.8140-.4D 1420.710.154.46.11417.1141-.4D 1521.210.352.86.01427.2140-.4D 1621.410.752.86.01427.2136-.3D 1721.410.953.35.91357.2131-.2E 1820.910.855.35.71297.2125-.1E 1919.910.958.64.91276.6121.2E 2019.011.061.84.41246.5116.5E 2118.111.064.64.41326.7119.6E 2217.310.866.24.41346.7122.8F 2316.610.969.94.41426.7132.8F 2415.511.274.94.81446.3125.9FABSOLUTE MAX32.124.8100.015.218.1AVG DAILY MAX21.913.985.47.89.6MEAN17.610.765.64.81436.5136.3ECLIMATIC MEAN17.210.467.24.96.6 AVG DAILY MIN12.46.848.92.13.6 ABSOLUTE MIN .7-7.411.20.0.5STANDARD DEV5.37.422.72.62.9 VALID OBS223521812007261925632124212326112611INVALID OBS645699873261317756757269269 TOTAL OBS288028802880288028802880288028802880 DATA RECOVERY77.675.769.790.989.073.773.790.790.7TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 4 of 13)
CPNPP/FSAR Amendment No. 104MAY (1972 - 1976)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 119.217.083.93.01735.21671.2F 218.816.785.02.91835.21731.3F 318.516.385.83.11905.31801.3F 418.016.386.72.81904.91841.2F 517.616.286.52.81854.91791.3F 617.416.086.02.71964.71811.3F 717.416.185.32.82064.61881.1F 818.517.084.43.12084.6206.3E 919.917.180.53.81875.0197-.1E 1021.117.277.24.21775.5183-.4D 1122.417.271.94.21765.4181-.5D 1223.716.366.34.11715.3180-.5D 1324.315.661.34.11635.3172-.6D 1425.016.660.14.21585.6171-.6D 1525.616.558.64.31505.7158-.6D 1625.816.556.14.41536.0159-.5D 1725.716.757.44.31465.8156-.4D 1825.316.960.04.21415.8147-.2E 1924.317.163.93.71325.5140-.0E 2023.017.269.73.11405.3144.5E 2121.917.475.33.11375.5144.8F 2221.117.679.33.01425.51421.0F 2320.417.582.33.01565.31531.2F 2417.914.879.43.21635.21231.1FABSOLUTE MAX33.825.2100.012.015.4AVG DAILY MAX25.819.293.05.98.2MEAN21.416.773.13.51635.3166.4ECLIMATIC MEAN21.416.473.43.65.6AVG DAILY MIN17.013.653.91.43.0ABSOLUTE MIN 9.6-3.0.70.0.4STANDARD DEV4.85.618.51.92.3 VALID OBS147614311261251023992143153326912691INVALID OBS1476152116914425538091419261261 TOTAL OBS295229522952295229522952295229522952 DATA RECOVERY50.048.542.785.081.372.651.991.291.2TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 5 of 13)
CPNPP/FSAR Amendment No. 104JUNE (1972 - 1975)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 123.621.084.93.21725.9160.9F 223.121.186.13.11745.4154.9F 322.621.088.63.11785.21631.0F 422.321.190.13.01784.71601.0F 522.021.091.32.81804.51511.1F 621.820.992.32.61684.31441.1F 722.021.292.22.61694.11441.0F 823.121.688.03.11794.4157.2E 924.421.784.73.81825.3167-.2E 1025.821.577.34.11835.8166-.5D 1127.121.269.74.21795.8165-.6D 1228.121.164.74.41726.1162-.5D 1328.920.860.34.51676.1162-.5D 1429.720.658.44.71666.1160-.7D 1529.920.457.24.71656.3162-.6D 1630.219.554.74.71656.1155-.6D 1730.420.856.84.71596.0152-.5D 1830.220.958.04.61606.3153-.3D 1929.020.961.24.41576.1146-.1E 2027.821.368.63.81575.7143.6E 2126.621.573.23.51595.8141.7E 2225.721.777.73.51616.1143.8F 2325.021.981.93.41646.1146.9F 2423.921.083.73.41696.2155.9FABSOLUTE MAX34.226.999.812.614.5AVG DAILY MAX30.422.794.85.97.9MEAN25.921.174.03.71685.6154.2ECLIMATIC MEAN25.920.373.43.75.9AVG DAILY MIN21.417.951.91.53.9ABSOLUTE MIN 14.2-2.210.20.0.3STANDARD DEV4.03.516.42.22.6 VALID OBS7146986382768264990469727552755INVALID OBS21662182224211223119762183125125 TOTAL OBS288028802880288028802880288028802880 DATA RECOVERY24.824.222.296.192.031.424.295.795.7TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 6 of 13)
CPNPP/FSAR Amendment No. 104JULY (1972 - 1975)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 125.020.875.32.81744.8176.8F 224.720.978.52.71794.7182.8F 324.121.181.02.61814.4183.8F 423.721.282.72.51884.3189.8F 523.521.082.82.31894.2197.8F 623.220.983.62.01843.9198.9F 723.321.184.32.11843.5199.6E 824.521.882.42.81913.4201-.1E 926.321.976.53.51994.1206-.4D 1027.921.769.53.71974.2201-.5D 1129.021.463.83.71904.4196-.6D 1230.020.957.63.71844.3185-.7D 1330.720.453.53.81724.5171-.7D 1431.420.050.054.51644.8162-.7D 1531.719.649.04.51554.8154-.7D 1631.719.748.54.51515.0149-.6D 1731.619.548.94.21495.0145-.5D 1830.919.750.04.21495.2148-.3D 1930.020.253.64.01515.1149-.1E 2028.820.559.33.51505.2147.4E 2127.620.564.43.31535.4150.7E 2226.620.668.53.11595.3157.8F 2326.020.770.93.01655.1166.8F 2425.420.873.33.11704.9174.9FABSOLUTE MAX38.226.299.814.214.5AVG DAILY MAX32.422.688.76.17.4MEAN27.420.766.33.31694.6172.1ECLIMATIC MEAN27.620.567.43.74.9AVG DAILY MIN22.918.446.11.32.4ABSOLUTE MIN 17.910.219.60.00.0STANDARD DEV4.02.919.12.21.9 VALID OBS204019661837295029082114204229162916INVALID OBS9361010113926688629346060 TOTAL OBS297629762976297629762976297629762976 DATA RECOVERY68.566.161.799.197.771.068.698.098.0TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 7 of 13)
CPNPP/FSAR Amendment No. 104AUGUST (1972 - 1975)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 124.920.576.82.41714.7174.8F 224.420.678.92.31744.5180.8F 323.920.781.02.21764.3184.8F 423.620.883.32.11794.1189.9F 523.220.884.22.01794.01911.0F 622.920.885.51.81723.71881.0F 722.721.086.51.81643.6186.9F 823.921.784.82.21693.3181.0E 925.821.978.83.01893.8196-.4D 1027.821.568.93.61904.4193-.5D 1129.121.161.43.71834.5186-.7D 1230.420.555.53.71764.5177-.7D 1331.120.051.83.81674.6164-.8C 1431.619.648.93.91564.8154-.7D 1531.919.448.34.01585.1160-.6D 1632.119.145.93.81524.8156-.6D 1732.119.146.44.01525.1155-.4D 1831.319.449.64.11515.5151-.2E 1930.319.552.93.81525.5150.2E 2028.719.758.73.21525.5152.6E 2127.619.962.93.11565.5154.8F 2226.620.168.22.81605.3159.8F 2326.120.270.42.51654.9162.8F 2425.520.574.32.51645.0168.8FABSOLUTE MAX38.726.199.912.312.2AVG DAILY MAX32.722.489.85.47.3MEAN27.420.466.33.01664.6170.2ECLIMATIC MEAN27.620.266.93.24.8AVG DAILY MIN22.518.143.91.12.3ABSOLUTE MIN 16.68.218.60.00.0STANDARD DEV4.12.519.21.61.9 VALID OBS237022902183281227942628242329012901INVALID OBS6066867931641823485537575 TOTAL OBS297629762976297629762976297629762976 DATA RECOVERY79.676.973.494.593.988.381.497.597.5TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 8 of 13)
CPNPP/FSAR Amendment No. 104SEPTEMBER (1972 - 1975)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 122.318.577.52.71364.9154.8F 221.818.580.42.71424.8162.8F 321.418.582.22.71414.8161.8F 420.918.583.82.51384.5167.9F 520.518.585.72.41124.3165.9F 620.218.686.42.3564.1160.9F 720.118.587.02.3484.0157.9F 820.619.186.92.4983.9164.3E 922.219.583.33.21534.1182-.2E 1023.919.474.73.81654.9187-.4D 1125.319.168.23.91565.1184-.5D 1226.618.561.74.01545.2180-.6D 1327.518.257.44.11375.2171-.6D 1428.318.053.54.31155.3150-.6D 1528.817.751.44.2815.4131-.5D 1629.017.250.24.3815.5122-.5D 1728.816.949.84.2835.5122-.4D 1828.117.251.84.1835.7118-.2E 1926.817.355.93.4945.5121.2E 2025.517.561.13.11005.8123.6E 2124.417.565.13.0975.7122.7E 2223.617.669.33.01055.5128.8F 2322.717.671.72.91185.3138.8F 2421.717.776.02.81335.1141.7EABSOLUTE MAX37.026.3100.011.414.7AVG DAILY MAX29.620.792.25.57.3MEAN24.218.268.63.31105.0147.2ECLIMATIC MEAN24.518.270.43.35.0AVG DAILY MIN19.515.648.71.22.7ABSOLUTE MIN 8.3-2.019.80.00.0STANDARD DEV5.54.818.81.92.2 VALID OBS189418461715281227481929189228362836INVALID OBS98610341165681329519884444 TOTAL OBS288028802880288028802880288028802880 DATA RECOVERY65.864.159.597.695.467.065.798.598.5TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 9 of 13)
CPNPP/FSAR Amendment No. 104OCTOBER (1972 - 1975)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 116.712.072.52.51705.21651.5F 216.212.173.72.51785.01711.4F 315.912.175.12.41754.81771.4F 415.412.177.82.41824.81851.5F 515.111.879.22.31684.51841.6F 614.811.881.52.31514.31791.6F 714.511.982.92.21634.11771.6F 814.912.583.22.21664.01771.2F 916.613.379.82.81654.1179.2E 1018.613.772.23.41844.7188-.2E 1120.313.666.53.81895.2190-.3D 1221.713.661.34.11865.5188-.5D 1322.713.356.34.11785.5181-.5D 1423.512.952.74.31705.6173-.5D 1524.112.850.44.41675.8167-.5D 1624.212.749.94.31615.6160-.4D 1723.912.651.24.11535.6154-.2E 1822.912.652.63.61445.4145.2E 1921.312.658.13.01355.6136.8F 2020.112.663.22.91405.91401.2F 2119.112.566.32.91476.01431.2F 2218.212.368.42.81505.91491.2F 2317.412.170.02.81615.71541.3F 2417.012.070.72.51625.41601.4FABSOLUTE MAX33.124.8100.011.013.4AVG DAILY MAX24.515.387.75.47.6MEAN19.012.666.63.11645.2165.7ECLIMATIC MEAN19.212.568.63.25.1AVG DAILY MIN13.89.849.61.02.6ABSOLUTE MIN 6.1-.621.20.00.0STANDARD DEV6.06.020.42.02.3 VALID OBS193519091753289727871947193528842884INVALID OBS10411067122379189102910419292TOTAL OBS297629762976297629762976297629762976DATA RECOVERY65.064.158.997.393.665.465.096.996.9TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 10 of 13)
CPNPP/FSAR Amendment No. 104NOVEMBER (1972 - 1975)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 110.25.069.93.42445.72071.2F 29.74.771.03.32455.52021.3F 39.54.771.73.32575.62061.2F 49.24.571.93.22725.42301.3F 59.14.772.93.32575.72251.3F 69.04.674.43.22715.42181.3F 78.94.875.03.12675.42311.1F 89.95.172.43.52725.3241.5E 911.75.566.34.42605.9249-.0E 1013.35.358.64.82346.4229-.2E 1114.95.453.95.02296.6216-.3D 1216.15.051.15.02316.6213-.4D 1316.95.349.65.02226.9208-.3D 1417.24.746.85.12256.6213-.3D 1517.04.446.75.02226.4213-.2E 1616.74.748.34.42156.0192-.0E 1715.64.850.83.61825.5163.4E 1814.45.054.83.31775.7148.8F 1913.35.158.63.31796.01461.1F 2012.65.160.93.31855.91561.2F 2112.04.961.73.52275.91641.2F 2211.65.063.73.52156.11701.3F 2310.94.865.33.42295.91791.3F 249.94.267.53.42375.61981.3FABSOLUTE MAX30.723.2100.013.817.8AVG DAILY MAX17.78.680.96.59.0MEAN12.54.961.43.92315.9202.7ECLIMATIC MEAN12.95.262.94.06.0AVG DAILY MIN8.11.944.81.43.0ABSOLUTE MIN -4.2-16.014.30.00.0STANDARD DEV7.18.922.52.32.8 VALID OBS190218831798286427841903190327852785INVALID OBS978997108216969779779595 TOTAL OBS288028802880288028802880288028802880 DATA RECOVERY66.065.462.499.496.766.166.196.796.7TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 11 of 13)
CPNPP/FSAR Amendment No. 104DECEMBER (1972 - 1975)DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 15.5-1.062.83.42656.22491.5F 25.0-1.164.63.32696.02421.6F 34.6-1.166.13.22696.02481.7F 44.3-1.167.43.22606.02431.7F 53.9-1.169.23.22745.72421.7F 63.8-1.169.03.22825.72551.7F 73.6-1.169.63.22835.62541.7F 84.3-.868.53.42845.62521.2F 96.1-.562.43.92875.4256.3E 107.9-.357.34.52595.9238.0E 1110.0-.251.14.92536.3234-.1E 1211.6-.544.45.02516.5237-.2E 1312.6-.741.15.12546.6236-.2E 1413.1-1.039.65.12566.6243-.2E 1513.5-1.039.15.02526.5231-.1E 1613.1-1.040.04.62366.3218.0E 1711.8-1.043.43.82186.0195.4E 1810.2-.847.73.52226.31741.0F 199.1-.851.23.32396.41831.1F 208.2-.853.83.42766.51941.3F 217.5-.856.33.52676.41911.4F 227.1-.758.13.62596.52101.4F 236.7-.759.43.62616.42191.4F 246.4-.860.13.32726.42301.5FABSOLUTE MAX28.517.599.912.717.7AVG DAILY MAX13.82.574.76.59.3MEAN7.9-.855.83.82626.2233.9FCLIMATIC MEAN8.1-.955.94.06.2AVG DAILY MIN2.5-4.237.11.43.1ABSOLUTE MIN -8.1-16.011.30.00.0STANDARD DEV7.16.820.02.32.9 VALID OBS213721412129280127912093206328902890INVALID OBS8398358471751858839138686TOTAL OBS297629762976297629762976297629762976DATA RECOVERY71.871.971.594.193.870.369.397.197.1TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 12 of 13)
CPNPP/FSAR Amendment No. 104MAY 15, 1972 TO MAY 14, 1976DATA SOURCE:  ON-SITETABLE GENERATED: 10/04/76. 09.29.33.COMANCHE PEAK STEAM ELECTRIC STATIONGLEN ROSE, TEXASTEXAS UTILITIES GENERATING CO.DAMES AND MOORE JOB NO:  4486-025-12METEROLOGICAL PARAMETERS (HEIGHTS IN METERS)DRYBULBDEW POINTREL HUMIDWIND SPEEDWIND DIR.WIND SPEEDWIND DIR.DELTA TEMPSTAB CLASS10.0010.0010.0010.0010.0060.0060.0010.00 60.0010.00 60.00HOURDEG CDEG C  PCTM/SEC  DEGM/SECDEGDEG C 114.99.870.93.31825.61781.1F 214.59.872.53.21885.51841.1F 314.19.773.93.11935.31891.1F 413.79.675.13.01995.21961.2F 513.49.675.93.02035.12001.2F 613.19.576.62.92034.92011.2F 713.09.577.02.92064.82031.1F 813.810.175.83.22044.7205.5E 915.510.571.83.92035.1207-.0E 1017.110.565.44.42015.5203-.3D 1118.510.359.94.61995.8201-.4D 1219.710.055.04.71985.8201-.5D 1320.69.651.24.81926.0195-.5D 1421.29.348.54.91846.0187-.5D 1521.59.247.34.91766.1179-.4D 1621.69.146.84.81666.1169-.3D 1721.19.248.24.51555.9157-.2E 1820.29.350.94.21486.0149.2E 1919.29.554.93.81465.9144.5E 2018.19.758.93.61496.0146.8F 2117.19.762.13.51556.01511.0F 2216.59.765.03.51616.01571.0F 2315.79.566.83.41715.81651.1F 2415.19.568.83.51765.71741.1FABSOLUTE MAX38.726.9100.018.318.1AVG DAILY MAX22.412.983.76.58.5MEAN17.19.762.83.81785.6178.5ECLIMATIC MEAN17.39.764.04.05.7AVG DAILY MIN12.26.644.21.52.9ABSOLUTE MIN -14.3-20.8.70.00.0STANDARD DEV9.410.321.42.42.6 VALID OBS239162348722197331763232324697234913285132851INVALID OBS11124115531284318642717103431154921892189 TOTAL OBS350403504035040350403504035040350403504035040 DATA RECOVERY68.367.063.394.792.270.567.093.893.8TABLE 2.3-16STATISTICS AND DIURNAL VARIATION OF METEROLOGICAL PARAMETERS(Sheet 13 of 13)
CPNPP/FSAR Amendment No. 104TABLE 2.3-17MONTHLY AVERAGE RELATIVE HUMIDITY (PERCENT) AT FORTWORTH (1964-1973)
Hour (CST)Month00061218 January75816059 February72795753 March71805751 April75856055 May80886158 June74865752 July68815146 August70835348 September80896159 October78865659 November76835660 December77816061Annual75845755 CPNPP/FSAR Amendment No. 104TABLE 2.3-18MONTHLY AND ANNUAL MEAN, AND EXTREME MAXIMUM AND MINIMUM DEWPOINT TEMPERATURES (&deg;F) AT FORT WORTH (1970-1975)MonthMean ExtremeMaximumExtremeMinimumJanuary346701 February366308 March447012 April527508 May617636 June677944 July687850 August687851 September667740 October577530 November437202 December376805Annual537901 CPNPP/FSAR Amendment No. 104TABLE 2.3-19MONTHLY AND ANNUAL AVERAGE VALUES IN THE SITE AREA MonthPrecipitation (Inches)(a)a)Based on 30 years of record (1931-1960) at Cleburne, Dublin, Fort Worth, Rainbow, and Stephenville (Period of record at Rainbow and Stephenville varies from 25-31 years).
Number of DaysWith Precipitation Snowfall(Inches)(b)Number of Days With Heavy Fog(b).01 In.(b)b)Based on 20 years of record (1954-1973) at Fort Worth.
.10 In.(c) c)Based on 7 years of record (1954-1960) at Cleburne, Dublin, Fort Worth, Rainbow, and Stephenville.
.50 In.(d)d)Based on 10 years of record (1951-1960) at Cleburne, Dublin, Fort Worth, Rainbow, and Stephenville.Jan2.007311.62Feb2.197410.72 Mar2.017310.41 Apr3.579630.01 May4.788630.0<1/2 June2.846420.0<1/2 July2.065310.00 Aug1.825210.0<1/2 Sept2.807410.0<1/2 Oct2.826520.01 Nov2.21632T1 Dec2.197410.23 Annual31.307947192.911 CPNPP/FSAR Amendment No. 104TABLE 2.3-20MONTHLY PRECIPITATION EXTREMES (Inches) AT SELECTED STATIONSFort Worth(1954-1973)Cleburne(1956-1960)
Dublin(1951-1960)MonthMaximum(a)a)Year of occurrence is given in parentheses.Minimum(a)Maximum(a)Minimum(a)Maximum(a)Minimum(a)January3.60(1968)0.19(1971)2.65(1960)0.11(1959)3.34(1960)0.04(1953)February6.20(1965)0.15(1963)3.34(1959)0.78(1954)2.16(1958)0.52(1953)March6.39(1968)0.10(1972)4.50(1957)0.15(1956)2.63(1953)0.12(1956)April12.19(1957)0.92(1959)12.19(1957)1.38(1951)8.42(1957)1.62(1951)
May12.64(1957)1.06(1961)8.60(1957)2.50(1954)10.89(1956)2.18(1959)June6.94(1962)0.40(1964)7.55(1951)0.03(1952)7.08(1959)0.10(1952)July11.13(1973)0.09(1965)3.22(1960)0.29(1956)7.88(1959)0.22(1956)August6.85(1970)0.01(1973)7.85(1953)0.02(1957)2.54(1953)0.02(1957)September9.25(1964)0.23(1956)6.71(1958)0.15(1956)3.71(1957)0.07(1956)
October9.22(1959)0.20(1955)9.60(1959)0.05(1952)9.42(1959)0.00(1952)November6.23(1964)0.20(1970)8.73(1952)0.12(1955)6.27(1957)T (1955)December6.99(1971)0.21(1955)5.85(1960)0.00(1951)4.11(1960)0.12(1951)
CPNPP/FSARAmendment No. 104TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 1 of 13)JANUARY (1973 - 1976)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N112622126.911.8NNE15179.010.9NE3145.111.0
 
ENEE12256.410.0ESE1122.54.5SE1233.88.7SSE111.35.0S231179.010.9 SSW11133.811.7 SWWSW21145.19.8 W1122.67.5WNW2133.810.3NW2245.110.3 NNW2232911.513.2CALM333.8TOTAL41634163578100.010.4 PERCENT5.120.543.620.53.86.4100.0 CPNPP/FSARAmendment No. 104FEBRUARY (1973 - 1976)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N154221431.113.4NNE2136.77.3NE2136.711.0
 
ENEE112.23.0ESE SE112.26.0SSE2136.77.0S111148.98.5
 
SSWSW112.28.0WSW W224.45.5WNW112.29.0NW1236.720.3 NNW11121613.316.7CALM336.7TOTAL61110647145100.011.0 PERCENT13.324.422.213.38.915.62.2100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 2 of 13)
CPNPP/FSARAmendment No. 104MARCH (1973 - 1976)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N11221711.114.1NNE1123.212.0NE11246.36.5ENE52711.111.4E21146.39.5ESE111.69.0SE122111812.711.0SSE12212812.715.1S13122914.3 13.9SSW111.613.0 SWWSW W111.620.0 WNWNW11134.810.3 NNW11246.316.5CALM446.3TOTAL61019109963100.011.7 PERCENT9.515.930.215.914.314.3100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 3 of 13)
CPNPP/FSARAmendment No. 104APRIL (1973 - 1976)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N12144.99.3NNE12144.99.8NE2244.97.5ENE11133.79.3E22267.39.7ESE22156.19.4 SE2244.914.5SSE1153521720.713.2S473622226.812.7 SSW111.26.0SW111.212.0WSW111.25.0WWNW333.714.7NW1122.415.5
 
NNWCALM556.1TOTAL715261612682100.011.0 PERCENT8.518.331.719.514.67.3100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 4 of 13)
CPNPP/FSARAmendment No. 104MAY (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N3149.311.8NNE11137.012.7NE1124.710.5 ENE1124.712.0 E112.33.0ESE1124.77.5SE112.310.0SSE11249.311.3S413818.612.6 SSW131511.613.0 SWWSW W1237.09.0WNWNW1124.716.0 NNW12149.39.8CALM224.7TOTAL3716106143100.010.9 PERCENT7.016.337.223.314.02.3100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 5 of 13)
CPNPP/FSARAmendment No. 104 JUNE (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED
 
N113.15.0NNENE113.17.0ENE113.16.0E121412.511.8ESE1211515.612.6 SE142721.912.0SSE11139.414.3S1126.312.5 SSW113.17.0SW113.129.0WSW113.15.0W11139.49.7 WNWNW NNW113.17.0CALM113.1TOTAL11011315132100.011.2 PERCENT3.131.334.49.43.115.63.1100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 6 of 13)
CPNPP/FSARAmendment No. 104JULY (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N1126.78.5NNE11111516.79.8 NE ENEE113.35.0ESE113.38.0SE113.33.0SSE1211516.711.6S22413.37.8SSW113.35.0SW1126.77.5WSW1126.714.0 W113.321.0WNW1126.718.5NW113.38.0NNWCALM226.7TOTAL571022430100.09.5 PERCENT16.723.333.36.76.713.3100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 7 of 13)
CPNPP/FSARAmendment No. 104AUGUST (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N2139.710.3NNE2139.711.3NE113.212.0ENE113.29.0E11139.79.3ESE113.23.0SE32516.17.2SSE121412.910.3S2139.712.7 SSW113.28.0SWWSW113.23.0W11139.711.0 WNWNW NNW1126.513.5 CALMTOTAL291351131100.09.8 PERCENT6.529.041.916.13.23.2100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 8 of 13)
CPNPP/FSARAmendment No. 104SEPTEMBER (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N2282242026.312.4NNE6179.211.0NE331211013.211.2 ENE111145.39.8E132179.28.1ESE2133.98.3SE12145.35.5SSE11133.910.3S12145.313.3 SSW2133.96.7SWWSW111.39.0W111.36.0WNW1122.67.0NW2133.99.3 NNW333.99.3CALM111.3TOTAL62029106576100.010.1 PERCENT7.926.338.213.27.96.6100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 9 of 13)
CPNPP/FSARAmendment No. 104OCTOBER (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N21146.813.3NNE1235.18.3NE1235.18.7ENE111.718.0E12146.89.8ESE3146.86.3SE2246.88.0SSE14211915.311.9S51610.210.8 SSW111.78.0SW111.73.0WSW111.710.0W111.79.0WNW111146.811.0NW111.716.0 NNW43711.97.1CALM558.5TOTAL7132756159100.09.0 PERCENT11.922.045.88.510.21.7100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 10 of 13)
CPNPP/FSARAmendment No. 104NOVEMBER (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N1123.314.0NNE1123.312.0NE111.65.0ENE12146.69.5 E223.36.5ESE1458.25.4SE12258.27.2SSE831118.010.5S3113813.111.5
 
SSWSW111.66.0WSW W1234.911.0WNW1346.612.3NW2134.912.3 NNW311169.813.3CALM446.6TOTAL619171341161100.09.6 PERCENT9.831.127.921.36.61.61.6100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 11 of 13)
CPNPP/FSARAmendment No. 104DECEMBER (1972 - 1975)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N1112111621.111.1NNE1471215.87.9NE431810.57.9 ENE21145.310.0E12256.66.2ESE111.33.0SE3145.36.5SSE222179.210.4S3145.314.5
 
SSWSWWSW111.35.0WWNW1122.65.5NW222.610.5NNW4121810.514.9CALM222.6TOTAL61934961176100.09.5 PERCENT7.925.044.711.87.91.31.3100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 12 of 13)
CPNPP/FSARAmendment No. 104 ANNUAL (5/72 - 4/76)SPEED GROUPS IN MPHAVGDIR 0-3 4-78-1213-1516-1819-2425-3132-3839 & GRTOTALPERCENTSPEED N21146191289814.512.0NNE21128721517.59.9NE11616422416.19.2 ENE251154274.010.4E41614711436.48.7ESE414921304.47.8 SE41719115477.09.1SSE2112918877511.111.8S11330131958112.012.1 SSW74411172.59.8SW123171.010.4WSW15411121.88.7 W8642203.010.2WNW226821213.111.4NW57633243.612.8 NNW1131474821507.412.7CALM32324.7TOTAL59156246105604631676100.010.3 PERCENT8.723.136.415.58.96.8.4.1100.0TABLE 2.3-21PRECIPITATION WIND ROSE FORT WORTH, TEXAS(Sheet 13 of 13)
CPNPP/FSAR Amendment No. 104TABLE 2.3-22MONTHLY AND ANNUAL STABILITY CLASS PERCENT FREQUENCY DISTRIBUTIONS AT FORT WORTH (1957-1971)Stability Class (a)a)Definition of Pasquill Stability ClassesMonthABCDEF and GJanuary0.01.55.568.313.411.2 February0.12.46.166.914.210.4 March0.02.45.669.913.78.4 April0.52.98.868.410.88.6 May0.85.412.359.211.910.5 June1.16.916.148.016.311.5 July1.610.519.333.019.616.2 August1.910.817.332.220.717.1 September0.97.011.143.319.018.6 October0.14.210.247.617.620.3 November0.02.98.256.315.816.8 December0.01.46.863.315.213.3 Annual0.64.910.654.615.713.6PasquillStability Class Identified inTable as Definition1AExtremely Unstable 2BUnstable 3CSlightly Unstable4DNeutral5ESlightly Stable 6FStable7GExtremely Stable CPNPP/FSARAmendment No. 104TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 1 of 13)Stability Persistence SummaryJanuary (1973 - 1976)Diurnal Distribution of StabilityJanuary (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)(a)NUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL2641445685132743600006413132110330 536168121736110005452938117 410129256314630120006452740118500 024746610024630008413038117600021139371203400010402938117 7000181330471685000104226391178000160277301366000134226361179000140230171067000133925391161000013119087980001646223211611000125159258900031589161141200011913404010112495183115 1300011411202411227594122115140001099401112377613331115150001057903133610613321116 160001026600142111663421117170001005500151066444301181800098470016001496540119 1900096410017000179570119200009435001800095546911921000923000190007385024119 220009026002000073644321192300088230021000738393511924000862100220007393241119>24000842000230007433039119  169 INVALID HOUR(S).ALL12174458810845265362807 169 INVALID HOUR(S).
CPNPP/FSARAmendment No. 104Stability Persistence SummaryFebruary (1973 - 1976)Diurnal Distribution of StabilityFebruary (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL2255103748714042420100339402110431614271704284191110024236291104110119659519915120002463626110 580013750813711630004453823110650089438968840103443824110720052382676550006433625110 810031330464560003414026110900018285313170005384225110100001324719208000861251611011000921010139010276410811012000717656102114257611101300061462311326603360110 140005123011254105930011091500041040013767612430108160003880014744652620108 170002750015634633110108180001650016232534720109190000560017110218510109 20000048001811067920210921000042001910016034131092200003700200004454317109 23000032002101034246171092400002700220002424322109>2400002300232002404322109  96 INVALID HOUR(S).ALL39283450511045913182619 96 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 2 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryMarch (1973 - 1976)Diurnal Distribution of StabilityMarch (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL22841038110763012100000255292511131812272900188163100055126281104100018577311312821002542826111 5500125674689931004522824109620077590407640005562722110710044518255650005543120110 8000244551740600064738191109000114001226700035434191101000063518148001156619911011000530864920033666411112000427240100044653711111300032422011275553651111 140002214101246362322111015000118800139485435211131600001620014925623112112 170000141001582560352211418000012300163435150311151900001090017212327620115 200000960018000169460116210000850019000184264115220000760020000164437115 23000067002100016037151132400006000220001524219114>2400005400230001553225113  287 INVALID HOUR(S).ALL41263652313124762752689 287 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 3 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryApril (1973 - 1976)Diurnal Distribution of StabilityApril (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL26013113261154273103000046028151073384122910081867110004613113109422101698921305120002573713109 51100127791893530002603314109660091703582440002583217109720062625331550002553715109 800041562197600025437161099000275081237000469241110810000164599181012267134108110009413609103425472109120005372301045443464210813000333310111018434032107 1400022960012126841383010815000126400131563463540109160000235001415106403430108 17000021100151853434000109180000192001688937472011119000017700174212375430112 200000165001811131771011221000015400192101090901122200001450020310376253111 23000013800211302693421112400001310022011266329111>24000012400230004633012109  262 INVALID HOUR(S).ALL95505946813704321502624 262 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 4 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryMay (1973 - 1976)Diurnal Distribution of StabilityMay (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL237213051983232015900000382613773259836865621211110000524320115416402635341397720000504026116 59201834359248300004843251166400129359652940101493826115710085295431650000484125114 80005624525860000523428114900032204164700025239201131000012173918100177421111411000214340910247594111412000012110103536736001141300001010011477742200114 140000840012510973150011215000072001311101364140011216000061001413720581400112 1700005200151211176014001141800004500166715681800114190000400017359712800116 200000360018101644910116210000330019001337750116220000310020000087204111 2300002900210001674351162400002700220000554714116>2400002500230000564119116248 INVALID HOUR(S).ALL60639770010744862272707248 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 5 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryJune (1973 - 1976)Diurnal Distribution of StabilityJune (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL2917246157824018401001505291133720946461229361100035351811545803343492223432010153529116 54700253408167303020050511311663800182345122204200154431511573100131288831252000534416115 824008723553761011494320115919005318732472003653311114101600271471528200296610311011130081168092006346401151211002905010713822110115139000683011867771800116 14700048201212512758111141550003510131251571101111516300026001414111170810115 171000180015161147112101151800001200161239701810113190000100017937692700115 200000800187216438301152100006001951043598011622000040020300492151115 2300002002110027039311524000010022100158497116>240000000230002535110116128 INVALID HOUR(S).ALL119418080310315541272755128 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 6 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryJuly (1973 - 1976)Diurnal Distribution of StabilityJuly (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL219561358581941030010016444711731603142263430416110026845512141282031150722192100262533121 59810231401162731003625141216700017032311754102260515121748001252578135101353576121 82800892015126001250634120913005915529172011753931211060033116150820154585112111300108740943583251012112100263001017358314001221300004400112563751200122 14000030001230936316001211500001900133141359141012216000010001434512581121123 1700005001532686015111231800003001626512631511123190000100172148681930123 2000000001891474323012321000000019100516641123220000000201002100172122 2300000002110016849312224000000022100068475121>2400000002310007043712160 INVALID HOUR(S).ALL2444679810109758060291660 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 7 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryAugust (1973 - 1976)Diurnal Distribution of StabilityAugust (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL21881719464847486470200168464121314735324691355251110365477124411401221580258142100462534124 58700165487179730005545961246610012340812334002259529124741009134181250013525315124 823006428954161102535413124911004124333072002486571241040019207190820038731011241120041741009122468362012412100114540101816781900122130000121001127917531600122 140000101001227191348150012215000087001339715481020121160000750014341114421570123 17000069001527101448175112218000065001623666219601221900006100171724702721123 200000580018642654322124210000550019200229063123220000530020100184361123 230000520021000264544124240000510022000165516124>24000050002310025856412129 INVALID HOUR(S).ALL2447398670111266888295329 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 8 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummarySeptember (1973 - 1976)Diurnal Distribution of StabilitySeptember (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL2821213483108028011000000782712117356333519091887812001762911119436112597821276022001723211118 5230019467783483110072331111961300142583553840010742816119750099500333150001683416119 810063428202560003682820119900035361121971001732519119100001630471480011282178120110007257499011625222120120003221341052870331011913000218821111097672210116 140001160101212101168170011815000013400132277601910116160000114001419812601900118 17000098001518367020101181800008400161128732320119190000730017706752910118 200000650018500456611118210000600019211695141120220000560020201171423120 2300005300212001644481192400005000222000693810119>240000480023100171371012036 INVALID HOUR(S).ALL12444706781333438160284736 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 9 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryOctober (1973 - 1976)Diurnal Distribution of StabilityOctober (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL21681858271737139500006384034118381745256823731910006413637120420234746714925720005413044120 500126438796205300054133411206000198324591614000736354312170001432733612650007402648121 800099231189360004432846121900067196106770005413144121100005616674480001350203812111000511394289000396119212112000461152151000866415112113000419406110811673221121 1400037740212868732220119150003356001395127618001201600029440014799791700121 1700026340015279911300122180002327001621108425001221900020210017100724720122 2000017180018000169790122210001415001900046449512222000121300200005405720122 23000101100210005385227122240008900221007384629121>24000670023000541443112180 INVALID HOUR(S).ALL303667747965566491290280 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 10 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryNovember (1973 - 1976)Diurnal Distribution of StabilityNovember (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL21071454280643931600001432392811336264186463282541000153836311204404319524242200200014383731120 52022484351821583000114239281206101192365141124400010414029120700014630410997500010433629118 8000119249857560001041383011990001012016556700014443328119100008716850418100186423121181100077139392991015054112119120006711534181025563375111813000589431911349672931116 140004976283126386825301131500042632501334474242111216000375022014116812220113 1700033401901501070424011718000293318016010288641120190002528170170001281252120 20000232316018000105249912021000221815019000124050181202200021151402000010414326120 230002012130210001043382912024000199120220009463629120>24000187110230001045333212048 INVALID HOUR(S).ALL1719336901050629397283548 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 11 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryDecember (1973 - 1976)Diurnal Distribution of StabilityDecember (1973 - 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL2430124397884554470300102426349733804348640310359130093634401224340027553221629423008373242122 53000224456149240320083432471236270018338810119142007333545122726001553276714852008293845122 82500135270481176100930394312292400124227348871009343048122102300116190256582001538392812211220010816517469211335617101201221001011469331021155441531211320009412952211224545072121 141900881122111224135046611221518008297141320958466112216170077830014305614761123 171600727000153005556711221815006960001620028845112019140066510017200981272121 20130063440018200745541512321120060380019100102861221222211005733002010011285527122 231000542800211001129473412224900512300222109353936122>2480048200023300831354512280 INVALID HOUR(S).ALL499335421001692573289980 INVALID HOUR(S).TABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 12 of 13)
CPNPP/FSARAmendment No. 104Stability Persistence SummaryMay 15, 1972 - May 14, 1976)Diurnal Distribution of StabilityMay 15, 1972 - May 14, 1976)NUMBER OFCONSECUTIVEHOURSNUMBER OF HOURSPASQUILL STABILITY CLASSTIMEOF DAY(LST)aNUMBER OF HOURSPASQUILL STABILITY CLASS-A--B--C--D--E--F--G--A--B--C--D--E--F--G-ALL27811041885767106334472258608004858742823413053587275542828669310920191810556284432671402443681331827270217115982810476174572751405 532033240061601511125135305060147027514046227011789525910559744525506044482891403715700131644847127515502555804592991400 81020097038184735686312555704683011400967007103242309417780162632420274139710490053427571942918110425774522415313941140004172343116192925817578631924713981234003591997711181061255074445252121396132900323169346651196639175135129101391 1426002951428342812126891057412972051383152300270121027713163641167322822451386162000250102222014158691157422782651393 1717002348731901514349867553392551402181500220758180169540756664973041407191400207668170176718485536497351413 201300197596160183299407727195381417211200188536150191432200791316911417221100180489140201111497644401431409 231000172447130216404665252218214122490016440912022821396335022271412>24800156378110238004262647525614071490 INVALID HOUR(S).ALL10744527307724*53366383402335531490 INVALID HOUR(S).a)LOCAL STANDARD TIMETABLE 2.3-23STABILITY-PERSISTENCE AND DIURNAL DISTRIBUTION AT CPNPP (BASED ON 10-60 METER DELTA TEMPERATURE)(Sheet 13 of 13)
CPNPP/FSAR Amendment No. 104TABLE 2.3-24MEAN MONTHLY MIXING DEPTHS FORT WORTH(a) (May1972-April1976)a)Based on surface observations at Fort Worth and upper air observations at Carswell AFB, Fort Worth from 5/72-10/73 and at Stephenville from 11/73-4/76.
Morning(b)(meters)b)Determined from intersection of 1200 GMT RAOB temperature profile and the potential temperature based on the surface RAOB pressure at 1200 GMT and the minimum surface temperature between 0200 and 0600 LST plus 5.0&deg;C (P, C, and M cases excluded).Afternoon (c)(meters)c)Determined as in b) except using surface temperature at 1500 LST. January409771February4491023 March5451057 April5471203 May5191323 June6191515 July6892120 August6622042 September6781451 October4811355 November578995 December414804 CPNPP/FSAR Amendment No. 104TABLE 2.3-25COMPARISON OF 4- AND 15-YEAR WIND AND STABILITY CONDITIONS AT FORTWORTHWind Frequency Distribution (%)Wind Direction4-Year (a)a)May 1972 through April 1976, concurrent with onsite meterological record.15-Year(b)b)January 1957 through December 1971.N9.08.4NNE4.36.1NE2.63.9ENE2.13.0 E4.04.4ESE3.96.0SE6.87.9 SSE10.910.4S22.519.6SSW8.69.3 SW3.13.4WSW2.02.5W2.32.2 WNW2.11.8NW3.83.3NNW5.85.4 Calm6.42.5PasquillStability Class Frequency Distribution and Mean SpeedStability4-Year (a)15-Year(b)ClassFrequency(%)Mean Speed (knots)Frequency(%)Mean Speed (knots)A1.12.40.63.1B5.85.24.95.4C10.58.310.68.8D49.511.554.612.3 E14.67.115.77.5F & G18.53.513.64.1 All Classes100.08.6100.09.7 CPNPP/FSARAmendment No. 104TABLE 2.3-26METEOROLOGICAL INSTRUMENTATION COMANCHE PEAK PREOPERATIONAL METEOROLOGICAL PROGRAM MeasurementLevel (meters)InstrumentManufacturerModel NumberAccuracyThreshold Instrument RangeWind Speed10 & 606 cup AnemometerWeatherMeasureW103/6L/A
+/-1% or .15mph.45 m/s (a)a)m/s = meters per second1-100 mphWind Direction (b)b)Wind direction variability at the 10-meter level uses this sensor10 & 60Wind VaneWeatherMeasureW104-2
+/-1%.75 m/s (a)0-540&deg;Temperature 10, 30 & 60 Thermistor CompositeAspirated Shield (Temp., Dewpoint,
& T)WeatherMeasure WeatherMeasure44018 XIS-6+/-.1&deg;CN/AN/A(c)N/Ac)N/A - not applicable-20 to 120&deg;F N/ADewpoint10 & 60Lithium Chloride DewcellFoxboro2711
+/-.5&deg;CN/A-20 to 120&deg;FDelta Temperature (T)10-30 and 10-60Thermistor CompositeWeatherMeasure44018 X.1&deg;CN/A-20 to 20PrecipitationSurfaceTipping Bucket Rain GaugeWeatherMeasureP 501.01 in.01 in0 - 10 inTotal Solar Radiation1PyranometerWeatherMeasureR 411
+/-2%.05 ly/min-.05 to 2.5 ly/minNet Solar Radiation1Net RadiometerWeatherMeasureR 421
+/-1%.03 ly/min-.05 to 2.5 ly/min CPNPP/FSAR Amendment No. 104TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 1 of 52)January (1973 - 1976):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0000000000000 0.NE0000000000000 0.
ENE0000000000000 0.
E0000000000000 0.
ESE0000000000000 0.
SE0000000000000 0.
SSE0000000000000 0.
S000000000004420.17 SSW000000000004418.10 SW000010000001212.65 WSW0000000000000 0.
W0000000000000 0.
WNW0000000000000 0.
NW0000000000000 0.
NNW000000000002212.35 N0000000000000 0.CALM0 0.TOTAL00010000000111216.92 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS=2976PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0000000000000 0.NE0000001000001 7.00 ENE0000000000000 0.
E0000000000000 0.
ESE0000000000000 0.
SE0000000000000 0.
SSE0000000000000 0.
S0000000000000 0.
SSW000000000012315.43 SW000000000015615.02 WSW000000000001120.40 W000000000002219.45 WNW0000000000001 0.
NW000000000001113.00 NNW000000000001115.40 N0000000010012 9.80CALM0 0.TOTAL00000010102131714.75 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS= 2976 CPNPP/FSAR Amendment No. 104January (1973 - 1976):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0000100001114 9.45NE0000000101002 9.00 ENE0000000000000 0.
E0001000000001 3.90 ESE0000000000000 0.
SE0000000000000 0.
SSE0000000010102 9.75 S000000100002313.23 SSW0000110000024 9.97 SW000001000012411.30 WSW0002200000037 9.14 W000000000102316.57 WNW000000000001117.60 NW000000000002211.50 NNW0000000212106 8.92 N0000000012205 9.70CALM0 0.TOTAL00034213376154410.46 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS= 2976PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000224568661049 8.80NE01111003122012 7.00 ENE0012101210008 5.67 E0111111000107 5.14 ESE0004301100009 4.71 SE00102432101014 6.28 SSE000013336141031 9.90 S00001062241203611.23 SSW00122100230344513.20 SW00321312322203910.92 WSW00110101202111911.95 W00210001011121814.81 WNW0000121130061410.97 NW00142012153423 8.05 NNW01426125414184510211.79 N01142032568275912.37CALM5 0.TOTAL0417262620283339444919949010.66 NUMBER OF INVALID OBSERVATIONS =98TOTAL NUMBER OF OBSERVATIONS= 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 2 of 52)
CPNPP/FSAR Amendment No. 104January (1973 - 1976):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE155442976761167 7.79NE01383205410128 5.72 ENE01233300000012 4.09 E13121101100011 3.88 ESE00166511000020 4.56 SE0154159112722058 5.80 SSE00211098611952485 9.02 S0011171571397111612.47 SSW01122635601497612.74 SW00132164342376311.87 WSW0010015003071710.69 W00211312221132811.61 WNW00034332602427 7.93 NW0116813889532183 9.14 NNW102877141220141011320812.85 N0815257131511147615710.70CALM2.10TOTAL321295769777773977155427105810.36 NUMBER OF INVALID OBSERVATIONS =26TOTAL NUMBER OF OBSERVATIONS = 2976PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE012113101100115.03NE00120100000043.97 ENE02200000100053.46 E01231000010083.99 ESE005612121101205.10 SE0031265753300445.57 SSE01547951111637697.21 S0357510391171028989.22 SSW11540415261123639.61 SW011205130217238.48 WSW025214032124266.72 W021431201213206.57 WNW000514953010286.31 NW114688849021525.94 NNW030744053325366.71 N012321131113196.88CALM0 0.TOTAL219436840613955493434825267.29 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 3 of 52)
CPNPP/FSAR Amendment No. 104January (1973 - 1976):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE012210100102105.83NE02100010000042.85 ENE01210000000042.45 E044210000000112.56 ESE034201130100154.37 SE07111692342100554.09 SSE141117115801000584.01 S195789522400524.68 SSW033064422201275.67 SW0311554432204435.35 WSW147994563112525.17 W091310192100000543.48 WNW0710777320010444.01 NW141078108121230665.28 NNW255124122111274.65 N02112000000062.92CALM8 .37TOTAL668100878852453615156105364.45 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE1999991613151613241437.75NE0561243295421535.70 ENE047643122000294.19 E198942111110383.76 ESE03128108481201674.68 SE08203232202513136301725.24 SSE15182229262420301613422467.46 S21212151526161823282012531210.03 SSW15108111681212111311522211.17 SW04171381412128107761819.73 WSW17141512121010755281267.56 W014191623643363321297.80 WNW071115131616101204111156.44 NW28192427312526201211292347.08 NNW31013192016172630343216738711.25 N01351386111823202510724910.56CALM15.21TOTAL1212320024622921419220120517115275827188.62 NUMBER OF INVALID OBSERVATIONS = 258TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 4 of 52)
CPNPP/FSAR Amendment No. 104February (1973 - 1976):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE00000000000000.
ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE00000000000000.
SSE00000000000000.
S000010000013513.40 SSW00000010211131814.01 SW0001000000181012.51 WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW000000000001115.50 NNW000000000003315.37 N000000000002216.25CALM0 0.TOTAL00011010213303913.81 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2712PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000300038.67NE00000000000000.
ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE00000000000000.
SSE00010000000129.20 S000000100103515.00 SSW000002001003612.63 SW000000001002313.17 WSW000000000020210.35 W00000000000000.
WNW00000000000000.
NW000000000003312.43 NNW000000000011212.30 N000000000002216.65CALM0 0.TOTAL00010210513152812.52 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2712TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 5 of 52)
CPNPP/FSAR Amendment No. 104February (1973 - 1976):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000000000100110.00NE00000000000000.
ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE000000000001114.00 SSE000000000003314.70 S00010102111077.54 SSW00000000100018.20 SW000000000012314.57 WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW000000000103411.35 NNW0000000000381113.93 N000000000003313.57CALM0 0.TOTAL00010102235203412.12 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2712PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE003161031111186.10NE001122313010146.38 ENE001131412000135.88 E01324310000014 4.07 ESE00111320031113 7.85 SE00013251111419 8.38 SSE00032120333112810.51 S01015243773316412.14 SSW01012134461507313.85 SW00101032422213612.13 WSW00002100032152313.69 W000000001003412.55 WNW00060100000142112.52 NW00113200133435714.14 NNW00120200148335113.08 N00111312128325213.17CALM5 0.TOTAL0313223525281729353425950511.68 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2712TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 6 of 52)
CPNPP/FSAR Amendment No. 104February (1973 - 1976):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE011552140012225.84NE006362420012265.55 ENE0210351220001264.13 E023741310001225.03 ESE012331102201166.33 SE0044411546212436.67 SSE0125544211108348610.58 S0007382756119214113.93 SSW000234464656910314.61 SW01210322104284411.79 WSW00100211220233214.47 W0011301112192012.46 WNW01130043311264312.13 NW002576985275510612.37 NNW021261181819221410721012.43 N0102535771398713913.53CALM140.TOTAL012365359595668666863539109311.72 NUMBER OF INVALID OBSERVATIONS = 11TOTAL NUMBER OF OBSERVATIONS  = 2712PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE125320200100163.87NE023250000000123.48 ENE01201200000176.59 E00121000000267.12 ESE034231030002185.44 SE0135129452114476.33 SSE03510149686335726.16 S0120824812114338510.05 SSW02321836327337010.09 SW1122000432116329.84 WSW010311121025178.28 W000103031311138.45 WNW011222392427358.39 NW0044912627628607.73 NNW036456453107447.17 N050804400219337.52CALM9.22TOTAL2264150645937554036241335767.78 NUMBER OF INVALID OBSERVATIONS = 15TOTAL NUMBER OF OBSERVATIONS  = 2712TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 7 of 52)
CPNPP/FSAR Amendment No. 104February (1973 - 1976):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE01112010000063.92NE10000000000011.00 ENE01110000000032.53 E11200000000041.95 ESE123220000001114.11 SE1251451110000303.72 SSE019992210124405.60 S1267105530120424.93 SSW222583433021355.40 SW244621000112234.34 WSW005111321201175.91 W054624200010244.10 WNW045424201001234.50 NW034777320008417.15 NNW00012011000278.89 N00012400000074.91CALM1 .20TOTAL928516554322413558203155.11 NUMBER OF INVALID OBSERVATIONS =3TOTAL NUMBER OF OBSERVATIONS  = 2712PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE141010153474323665.45NE12106134733022535.21 ENE0414594632002494.85 E1491194410003464.74 ESE1610895332515585.97 SE13122424231511943111406.21 SSE05162830161411201716582318.37 S148162718162325272216234911.45 SSW255101418151918151616930612.25 SW36910345895107915110.45 WSW01644555476449111.43 W0558573435313618.32 WNW0671547912653481229.68 NW0311172627181213121212127210.93 NNW05891319132423272616132811.83 N061128141098171813523812.41CALM29.08TOTAL11691411932131781471551491491401016259010.08 NUMBER OF INVALID OBSERVATIONS = 122TOTAL NUMBER OF OBSERVATIONS  = 2712TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 8 of 52)
CPNPP/FSAR Amendment No. 104March (1973 - 1976):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000111039.47NE00000001000017.40 ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE000000000100110.00 SSE00001000101148.70 S00000000000111117.46 SSW000000000008822.56 SW00000000000000.
WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00000000000000.
NNW0010000110181214.62 N00000010000016.10CALM0 0.TOTAL00101012323284115.48 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000010019.10NE0000000000000 0.
ENE0000000000000 0.
E0000000000000 0.
ESE00000000000000.
SE000000001002310.80 SSE000000001001210.70 S000000000002215.45 SSW000000000006616.90 SW000000000010110.40 WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW000000000001111.50 NNW0000100000181014.79 N00000000000000.CALM0 0.TOTAL00001000212202614.04 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 9 of 52)
CPNPP/FSAR Amendment No. 104March (1973 - 1976):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000001000017.90NE00000000000000.
ENE00000100000015.10 E00000000100018.70 ESE00000100000015.90 SE000000000020210.20 SSE000010001012311.13 S000000000005517.80 SSW000000000013413.17 SW000000000004414.52 WSW0000001100002 7.05 W00000000000000.
WNW00000000000000.
NW00001000002149.62 NNW000000000026814.01 N00000000000000.CALM0 0.TOTAL00001212108213612.39 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00001100122121911.85NE001101110251138.67 ENE002440012101155.69 E01013100003096.20 ESE002134311536298.52 SE000552634108256810.66 SSE00101040783164010.83 S00011030147537015.40 SSW00000002123364416.20 SW00021312242254212.89 WSW00000011016142314.16 W00000010001182014.69 WNW0100101001091312.24 NW00111110121253413.56 NNW00010442120274113.69 N00001020121293615.37CALM00.TOTAL027172217281322464529751612.73 NUMBER OF INVALID OBSERVATIONS = 7TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 10 of 52)
CPNPP/FSAR Amendment No. 104March (1973 - 1976):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00322232168295810.87NE014812347514406.80 ENE01044216887344 8.01 E00083752487650 7.97 ESE003759657893291 9.93 SE0065665167105710910.97 SSE0013438468612116414.22 S002232331061115419616.39 SSW00001120315496217.51 SW00000011210162114.39 WSW00000012212212914.65 W01102450110213612.19 WNW00012305311365212.51 NW01230645265619512.92 NNW020244726569713514.17 N200242934387411113.78CALM10.TOTAL26224741536345727586781129413.04 NUMBER OF INVALID OBSERVATIONS = 18TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE011132110021136.38NE013230000021125.34 ENE011512120100144.91 E014611122202225.82 ESE01511113221010374.64 SE013111010443414556.29 SSE01282956791016758.92 S11221125247457312.60 SSW01101102100243116.84 SW00210121111102010.08 WSW000020252102148.38 W010113410001126.11 WNW011332240111196.11 NW004132401120185.84 NNW022336032102246.31 N032351401329338.44CALM1.10TOTAL1163358504434382328291184738.49 NUMBER OF INVALID OBSERVATIONS = 3TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 11 of 52)
CPNPP/FSAR Amendment No. 104March (1973 - 1976):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE01001000112288.57NE00220000010054.32 ENE01201000000043.00 E02021000000053.16 ESE00041200000074.33 SE023758120003315.76 SSE016431332006297.77 S011322141027249.50 SSW050410011019228.83 SW0436111222310357.41 WSW032212314112226.11 W023123041003196.24 WNW033252200000173.85 NW040202400200145.08 NNW0213100210071710.88 N0210000003181513.03CALM1 .50TOTAL033274225231519131010572757.29 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE02537746411154811210.11NE021013455791487847.12 ENE03513115210101074806.70 E04418101195811108986.90 ESE02102521211310121414411838.19 SE361629282821141724241023129.15 SSE0412171215231624262217834911.62 S12587691214152728238815.06 SSW06143235641013517916.01 SW045925567876512311.16 WSW032232810859399111.27 W0442510105211438710.63 WNW054611759332471029.83 NW0577511136913119318011.46 NNW064991411101191116425813.26 N25351041636121212019813.02CALM3.20TOTAL663971701481531571341501801901376282711.48 NUMBER OF INVALID OBSERVATIONS = 149TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 12 of 52)
CPNPP/FSAR Amendment No. 104April (1973 - 1976):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000010131105129.97NE00000111000036.30 ENE00001110000035.60 E00000100010027.65 ESE000000000203513.84 SE000000001011310.17 SSE01000000000161720.76 S000000000006620.38 SSW000000000004420.77 SW000000000003318.33 WSW00000000000000.
W000000000003317.73 WNW000000001003414.10 NW00000000001121313.93 NNW0000000001091014.22 N000000000115714.17CALM0 0.TOTAL01002334363709514.90 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000001100014712.91NE0000000001001 9.20 ENE0000000000000 0.
E000000000010110.80 ESE0000000003003 9.60 SE000000001107912.86 SSE000000000007716.29 S000000000007719.34 SSW0000000000000 0.
SW00000000000000.
WSW000000000005518.66 W000000000001121.70 WNW00000001010139.73 NW000000000001117.10 NNW000000000002215.75 N000000000003316.17CALM0 0.TOTAL00000111162385014.91 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 13 of 52)
CPNPP/FSAR Amendment No. 104April (1973 - 1976):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000000000011214.05NE00000210000036.13 ENE00000100000129.10 E00000001000017.20 ESE00001001101047.80 SE000000001305912.68 SSE000000000007717.50 S000000000005519.72 SSW00000000000000.
SW000000000015613.95 WSW00000000000000.
W000000000002225.00 WNW000001000002312.30 NW000000000102312.87 NNW000000001008914.91 N000000010002311.13CALM0 0.TOTAL00001413343405913.82 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00015121113520 8.33NE00012110222011 7.48 ENE00022102201717 9.54 E00031115205112910.12 ESE0001036620493110.35 SE001001336911367011.75 SSE00031021312506314.73 S00013001312485916.16 SSW00000110101151914.39 SW00000111000151813.29 WSW000000000002216.45 W0000010001081017.13 WNW0000012013071413.10 NW00031020211172714.91 NNW00010112225425614.73 N00000012120131912.68CALM00.TOTAL001161513232428233728546513.12 NUMBER OF INVALID OBSERVATIONS = 3TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 14 of 52)
CPNPP/FSAR Amendment No. 104April (1973 - 1976):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE004128424002276.61NE0302871146731526.76 ENE0135960862311547.55 E030510679511625879.53 ESE0121810121111121010318113.24 SE012210816121217167817410.77 SSE0041556512121618224814.32 S0006657848810715913.16 SSW00223315122133410.28 SW012331300025207.42 WSW011012301115168.86 W002011020115139.41 WNW015215122024256.85 NW00336623633437811.67 NNW10177658115156212811.86 N0204551057547548.03CALM20.TOTAL114314485848884888692653135211.45 NUMBER OF INVALID OBSERVATIONS =18TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE013311211000134.58NE024301100101134.51 ENE025613103011234.86 E016742122142325.96 ESE0371066441427546.22 SE01815910393114645.65 SSE034612343118367.19 S000431233523268.30 SSW001215101227228.48 SW01112200000185.10 WSW00400101000064.03 W020231100001104.73 WNW113334210100194.62 NW0052111791007437.27 NNW004137620111265.90 N000344143220236.71CALM3.43TOTAL117556842613540211916434216.18 NUMBER OF INVALID OBSERVATIONS =11TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 15 of 52)
CPNPP/FSAR Amendment No. 104April (1973 - 1976):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE01000000000011.70NE00100000000012.50 ENE00101000000023.65 E00000000000000.
ESE01103001001075.13 SE022823400002234.97 SSE101442400000164.67 S022254101000174.42 SSW020241211100145.41 SW03011010001074.31 WSW00322000000073.31 W01330001010094.09 WNW02020111000074.41 NW102204467102297.03 NNW00100221100076.21 N01000010001036.13CALM00.TOTAL215172622172011103341505.16 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE+27591310772617857.84NE0556111215581152856.42 ENE0391315122101125201027.14 E04615151091791316381528.86 ESE0510121819222316211812228611.28 SE041325212226242434291353579.76 SSE14914119151018141927039413.71 S022131710101211141217728013.24 SSW023681056455399310.41 SW0535645100429629.63 WSW0182333111112368.76 W03554313031204810.47 WNW14874126545217757.95 NW101010821151816658419410.65 NNW1099101714131592112424211.82 N03011109141211108301188.93CALM5.26TOTAL4471071581701861721671551501571136261410.74 NUMBER OF INVALID OBSERVATIONS =266TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 16 of 52)
CPNPP/FSAR Amendment No. 104May (1972 - 1976):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000004111201107.93NE00000130100056.90 ENE00010020100046.15 E00000001100027.65 ESE00000111221088.17 SE00000011210389.85 SSE00000021201068.23 S00000002100038.13 SSW00000000000000.
SW00000000000000.
WSW00000000000000.
W00000000100018.70 WNW00000020100037.30 NW000000003023810.90 NNW00000000000000.
N00000000200028.40CALM0 0.TOTAL00010612718547608.44 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2955PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00020200100055.34NE00000100000026.65 ENE00011000000024.05 E00000110000026.20 ESE001102621000136.22 SE00001022100066.92 SSE000001005131119.43 S00000110222199.04 SSW00000001120048.77 SW00000000000000.
WSW00000000000000.
W00000001000018.00 WNW00000000000000.
NW000001000112510.58 NNW00000001000018.00 N00000110000026.05CALM0 0.TOTAL001421011811664637.68 NUMBER OF INVALID OBSERVATIONS = 0TOTAL NUMBER OF OBSERVATIONS  = 2955TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 17 of 52)
CPNPP/FSAR Amendment No. 104May (1972 - 1976):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00021320010095.72NE00002011000156.72 ENE00011200001056.08 E00012100000044.35 ESE000112321110126.86 SE001002220001107.05 SSE000112132213168.29 S000000133323159.41 SSW00002001112299.14 SW00000010000017.00 WSW00000000010019.20 W00000000000000.
WNW00000001000018.00 NW000000000011211.50 NNW00001000200037.40 N00010100000024.90CALM0 0.TOTAL001711131113119811957.59 NUMBER OF INVALID OBSERVATIONS = 2TOTAL NUMBER OF OBSERVATIONS  = 2955PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE010255436121306.93NE001373221116277.43 ENE023353515112315.99 E011685133212336.07 ESE014776852418537.95 SE001187810127414728.53 SSE00447139586825899.41 S00126562171376011910.57 SSW000220125210325611.09 SW0112213411211299.27 WSW001410031112147.05 W001301101117169.65 WNW00100101002499.87 NW00100111312112111.19 NNW0103211655414429.85 N0003831665210448.42CALM1.60TOTAL072045685551547651492096869.00 NUMBER OF INVALID OBSERVATIONS = 14TOTAL NUMBER OF OBSERVATIONS  = 2955TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 18 of 52)
CPNPP/FSAR Amendment No. 104May (1972 - 1976):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0033544214614469.02NE032751525124376.64 ENE014540332301265.65 E220576130225356.57 ESE0555954341119618.00 SE02359141611103618977.85 SSE03351522252522172048058.84 S11171116172426242183329.67 SSW0602432549328669.53 SW022321220205216.99 WSW010210020022107.66 W002111001034138.33 WNW002110024119219.69 NW1215446358431749.68 NNW00231053452514538.66 N0121210922118397.94CALM11.24TOTAL42932609092979391787729310478.59 NUMBER OF INVALID OBSERVATIONS = 27TOTAL NUMBER OF OBSERVATIONS  = 2955PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE10211002010084.82NE032411000000113.23 ENE049302000000182.86 E0251161011001284.08 ESE01711112210100364.24 SE03716149123100564.51 SSE054101281035215655.82 S05771012844623685.96 SSW113411150314257.81 SW114342111013225.78 WSW115310121011174.95 W012211002452207.97 WNW003354011011195.37 NW113477500417406.77 NNW003371330000204.84 N012133222201196.22CALM5.20TOTAL529688684543427202413284775.42 NUMBER OF INVALID OBSERVATIONS =9TOTAL NUMBER OF OBSERVATIONS  = 2955TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 19 of 52)
CPNPP/FSAR Amendment No. 104May (1972 - 1976):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE02101000000042.47NE00200000000136.00 ENE00031010010064.98 E022330020000124.02 ESE051321010000133.45 SE0261140200000253.56 SSE0461063101000313.93 S003331300001144.99 SSW322450000001173.74 SW122311000001113.85 WSW123221201000144.03 W03410000000193.12 WNW213520000000133.19 NW129527322000334.43 NNW01213010000083.99 N01110000000368.22CALM5.24TOTAL8294755351413541082243.98 NUMBER OF INVALID OBSERVATIONS = 3TOTAL NUMBER OF OBSERVATIONS  = 2955PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE136101318118998161127.40NE0671415711672312906.46 ENE0717171271148523935.16 E27826261431054381165.50 ESE0121828301924151094271966.81 SE07183336323228301210362746.96 SSE012173041494837452834824238.12 S161219303636355349341514629.18 SSW49512144414111716671779.19 SW26911957723320847.05 WSW2491151373245565.81 W0497231155914607.78 WNW2199852561414667.06 NW3514141320156131411551838.37 NNW027102378141279281278.12 N0357131813101283221147.77CALM22.25TOTAL179417025829024522920723117515756026557.67 NUMBER OF INVALID OBSERVATIONS =300TOTAL NUMBER OF OBSERVATIONS  = 2955TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 20 of 52)
CPNPP/FSAR Amendment No. 104June (1972 - 1975):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000202011289.15NE0001010012231010.03 ENE00000010100027.15 E00001110020057.42 ESE00000001200149.30 SE00001000000015.00 SSE00001110222101911.96 S00000115562113110.17 SSW0000102324572410.01 SW00012001000268.67 WSW00001300100056.40 W00001000000015.00 WNW00000000000000.
NW00000010000017.00 NNW00000000000000.
N00001000000014.60CALM0 0.TOTAL000299712141712361189.75 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000100000015.80NE00000020010037.93 ENE00000000000000.
E00000202000046.65 ESE00001011110169.13 SE00000120011057.92 SSE000000000010113.00 S01000011110389.04 SSW0000001200341010.60 SW00000001011039.50 WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00000000000000.
NNW00000000000000.
N00000000000000.CALM0 0.TOTAL010014772559419.03 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 21 of 52)
CPNPP/FSAR Amendment No. 104June (1972 - 1975):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000000000002214.10NE00011000400288.85 ENE00000012030068.60 E00000001110038.83 ESE000010133110108.09 SE00001210210187.87 SSE00000021420098.56 S000001502014139.18 SSW0000001102251110.69 SW00010000201048.02 WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00000000000000.
NNW00000000000000.
N00001000011149.30CALM0 0.TOTAL0002431181811615789.03NUMBER OF INVALID OBSERVATIONS =2TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE011406522214287.24NE101440453102256.72 ENE011522642200256.26 E024757736332496.45 ESE1083581359433626.77 SE1156576165111110847.95 SSE0243121216181814134515710.00 S032991017191313187118411.05 SSW00311134367376611.79 SW0224114437813499.16 WSW01211001000175.23 W023232011000144.49 WNW00001000000015.00 NW00000000000000.
NNW010201104006158.99 N012414111100165.26CALM00.TOTAL3173855506183837064641947829.06NUMBER OF INVALID OBSERVATIONS =21TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 22 of 52)
CPNPP/FSAR Amendment No. 104June (1972 - 1975):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE010113550002186.92NE022221322222226.89 ENE262211210312235.45 E235946841312485.56 ESE23681413830101595.13 SE171921151816131296111486.35 SSE3882017212012171416572139.14 S16851011141219241514827311.90 SSW1234256888106712411.47 SW0144301101010258.08 WSW01010001000368.12 W01102010100065.02 WNW11100001000156.00 NW204231011001154.65 NNW010310011116159.87 N012033101124188.05CALM1.40.TOTAL154465827883856563675431710199.03 NUMBER OF INVALID OBSERVATIONS =12TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE021011312010126.04NE122115110010154.63 ENE02121000100073.80 E103441000000133.77 ESE13422710100022524.62 SE1714161210944013814.95 SSE27121121147766251005.66 S07710814161612108341428.41 SSW133344431336387.07 SW433201131312245.66 WSW220430210000144.04 W116100000004136.04 WNW20101011000063.97 NW302241000000123.42 NNW212210000011104.41 N20002010010064.63CALM10.TOTAL2340618070614637272320575466.04 NUMBER OF INVALID OBSERVATIONS =8TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 23 of 52)
CPNPP/FSAR Amendment No. 104June (1972 - 1975):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE02000000000021.70NE00000000000000.
ENE11110000000042.15 E12000000000031.53 ESE01000000000011.70 SE133203000000123.17 SSE013320000100104.01 S033001110010104.65 SSW136111100001153.91 SW01131002000084.69 WSW043120000000103.00 W246200000000142.34 WNW04300000000072.26 NW034210000000102.80 NNW24010100000082.35 N00000000000000.CALM3.53TOTAL8363316762301111173.13 NUMBER OF INVALID OBSERVATIONS =10TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0626213131043410737.20NE25598710810659846.97 ENE310610431074812685.68 E4712201417161089441255.81 ESE47183328312413157681945.86 SE419424534413435232219253436.34 SSE5192737554846384839331185138.70 S12020242738555453554527166310.63 SSW38159911182114233012728810.39 SW4710157261261211271197.87 WSW285875231006475.34 W38175631121012595.93 WNW355020131004245.61 NW5310682111001383.83 NNW4728221151213487.20 N234487312435466.54CALM5.40TOTAL4914220023922123024121819719016364227378.22 NUMBER OF INVALID OBSERVATIONS =143TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 24 of 52)
CPNPP/FSAR Amendment No. 104July (1972 - 1975):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000021231010107.16NE000024302100126.46 ENE00000000101029.60 E00102040100085.69 ESE002111332546288.57 SE000010534643268.86 SSE002111548444348.84 S000101629114296311.68 SSW00001002171324413.95 SW000001000001210.95 WSW00000001000018.00 W00000101000026.60 WNW00000000000000.
NW00000010000016.20 NNW00000010200038.17 N00001011121188.32CALM0 0.TOTAL0053111031203236207624410.14 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00110120000055.24NE000000000010110.10 ENE00000000000000.
E000000000010110.90 ESE00000001121169.65 SE000000120112710.13 SSE000000010212610.55 S000000000124711.49 SSW000000000022412.30 SW000010000022510.04 WSW00000000000000.
W00001001000026.40 WNW00010000000013.40 NW00000000000000.
NNW00000000000000.
N00000010000017.00CALM0 0.TOTAL00122145161113469.62 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 25 of 52)
CPNPP/FSAR Amendment No. 104July (1972 - 1975):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000101100037.30NE00010011000036.13 ENE00000012010047.97 E00011000000024.10 ESE0000001014141110.32 SE00011001111398.32 SSE000001311014119.80 S0000000121241011.18 SSW0000102010441210.03 SW00000001101149.70 WSW00010100010036.33 W00001000001027.45 WNW00001000000014.30 NW00000000010019.20 NNW00010000000013.60 N00000100000016.00CALM0 0.TOTAL00055488891120789.09 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE011664566310396.29NE011021328244288.29 ENE003200283212237.43 E000502860110236.50 ESE0033071269235507.49 SE002155512811914728.91 SSE00347111316201614401449.08 S0123861317212729401679.89 SSW0001812141318106201029.11 SW000347743426407.62 WSW000152443130237.12 W003722406224326.95 WNW000001143210128.12 NW001210131021127.66 NNW010423140102186.39 N010242342014237.44CALM1.70TOTAL05194454659610911184791428098.49 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 26 of 52)
CPNPP/FSAR Amendment No. 104July (1972 - 1975):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE031321210222196.28NE085456411010354.27 ENE031533520001235.12 E156976201000373.90 ESE0871149362010514.76 SE0810192224191514107121606.37 SSE04151823252924312120382487.77 S127912181722233119582199.44 SSW03668121196610391168.90 SW0433662555414578.40 WSW013132121102176.56 W014214200000144.29 WNW003632210101195.11 NW031631320001204.81 NNW014462101112235.53 N035532541413366.11CALM3.27TOTAL257811011211231089486826617310977.30 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE145040000000142.78NE023120201000113.97 ENE282232000000192.74 E212421000000123.02 ESE01011711201000332.98 SE08148117730000584.16 SSE0920112024241310061285.31 S01111015131779102865.67 SSW23610710887297796.92 SW067454703121405.12 WSW039552111000273.74 W038100200000142.93 WNW036600000100163.17 NW026921010001224.20 NNW01121000000053.22 N103002220000104.84CALM6.37TOTAL864114807867723523511175804.80 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 27 of 52)
CPNPP/FSAR Amendment No. 104July (1972 - 1975):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE00000000000000.
ENE01000000000011.90 E00000000000000.
ESE01210000000042.37 SE00210000000033.03 SSE040220101001114.84 S114313210002185.52 SSW00221010000175.57 SW01000100000137.53 WSW00110000000137.53 W11000010000033.23 WNW000000000100110.00 NW00001110000035.70 NNW00100100000023.80 N00000000000000.CALM1 .70TOTAL29121056611106605.04 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE1981014811118542915.77NE01196131214412364945.89 ENE313710659124323775.32 E36101913101562120874.78 ESE019261317182319171410161926.26 SE016303142363937272922343436.81 SSE018413753627559624340955857.60 S262428364155506472561395739.15 SSW281419263436323326321063689.13 SW011111016191610121011271537.44 WSW04139138685333755.76 W15151067926234705.42 WNW0391343353511705.26 NW0691773661123615.19 NNW0461196343214535.57 N14878712114638796.57CALM12.42TOTAL1314324025028327933227626322519844929637.37 NUMBER OF INVALID OBSERVATIONS =13TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 28 of 52)
CPNPP/FSAR Amendment No. 104August (1972 - 1975):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE01102020000064.50NE00210112011096.32 ENE00000301000046.17 E010214137200216.84 ESE011273592600366.53 SE0002427116610397.27 SSE010132466621327.64 S000315642223287.34 SSW001114434474338.81 SW00000102001158.60 WSW00131001100074.73 W00001220000055.76 WNW00112000000043.85 NW00000001000017.40 NNW01012100200075.39 N00000221010067.22CALM1.50TOTAL057172530344430281492447.05 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE00001200000035.13 ENE00000000000000.
E00000101000026.65 ESE00000322101097.26 SE00001122110087.05 SSE000010123522169.12 S0000001034541710.22 SSW0000001022141010.58 SW000000100121510.24 WSW00000010000016.40 W00000000000000.
WNW00000000000000.
NW00000000000000.
NNW00000000000000.
N000000000001112.20CALM0 0.TOTAL0000379710131112728.97 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 29 of 52)
CPNPP/FSAR Amendment No. 104August (1972 - 1975):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000100010103611.37NE00010001000249.80 ENE000000000001112.00 E00001211010066.68 ESE00000222010077.09 SE000012330010106.91 SSE000001201313119.20 S000010304146199.76 SSW000003223227219.82 SW00001101010158.18 WSW00000101000026.50 W00000000000000.
WNW00001000000014.20 NW00000000000000.
NNW000000000001111.80 N00011000000024.50CALM0 0.TOTAL00036121312810824968.85 NUMBER OF INVALID OBSERVATIONS =2TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE001120446768399.26NE004035722519388.13 ENE000243232121206.80 E013355052010255.51 ESE00124129118101496.76 SE032397887446617.01 SSE01197141012691015947.79 S01029910149996013210.12 SSW00012717141416144112610.08 SW110235674436427.58 WSW002322110000114.60 W00022010000054.66 WNW00000200000025.95 NW00110000000023.20 NNW00210010110065.63 N001020130024158.79CALM00.TOTAL171832547177846159521516678.42 NUMBER OF INVALID OBSERVATIONS =3TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 30 of 52)
CPNPP/FSAR Amendment No. 104August (1972 - 1975):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE046412221202265.33NE129351112100264.10 ENE216341101000193.60 E0568104011102384.66 ESE05121516121164312875.15 SE0983429162413118151585.61 SSE06111826313234172416292447.39 S2371610202121341926622418.90 SSW12792141217181413241338.51 SW024479583414516.67 WSW033231101001154.45 W02210100010073.96 WNW030122002000104.58 NW112322011011155.23 NNW000232212123187.50 N005121110202155.93CALM2.45TOTAL7488812412211911310698806113711056.96 NUMBER OF INVALID OBSERVATIONS =7TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE532201000000132.01NE125200000000102.33 ENE14210000000082.01 E345430010000203.05 ESE1181017162002000663.28 SE112292821125200011113.81 SSE01112182416131250101124.80 S411819161718671111094.96 SSW1713898762416725.52 SW038304341011285.01 WSW035221121001184.50 W03100100000052.72 WNW024023100000123.69 NW033722401000224.24 NNW134010100000102.67 N244401100000162.84CALM29.36TOTAL2093115115966855331954106614.08 NUMBER OF INVALID OBSERVATIONS =7TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 31 of 52)
CPNPP/FSAR Amendment No. 104August (1972 - 1975):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE00000000000000.
ENE01000000000011.20 E00000000000000.
ESE01100000000021.90 SE045202100000143.15 SSE03200120000083.52 S001023310000105.75 SSW01100011000156.26 SW01210211000084.52 WSW11101000000042.60 W00000000000000.
WNW04200000000061.77 NW023132100100134.17 NNW11102000000052.64 N10000000000011.00CALM11 .44TOTAL319194810930101883.37 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE581085387710613906.90NE24207999647211906.12 ENE368687343122534.88 E31114172016212104121125.12 ESE1252536433429301711232565.27 SE12844696542503925197124015.46 SSE022264661656466405032505226.97 S6151640395462465936481365578.36 SSW210221914364443444238874018.58 SW171411112316238108141466.71 WSW17121096453002594.53 W053334300100224.25 WNW097277102000353.78 NW1691276522111534.52 NNW257483415224475.49 N3410654550527565.92CALM43.39TOTAL3117224729631431930928922919915134429436.66 NUMBER OF INVALID OBSERVATIONS =33TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 32 of 52)
CPNPP/FSAR Amendment No. 104September (1972 - 1975):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000044311203188.12NE00021000000033.97 ENE01122000010185.14 E00023021100095.43 ESE001337701200245.84 SE01000200010045.67 SSE000015213034198.41 S002112302234208.53 SSW000000001002311.23 SW00001020000036.07 WSW00011000000024.35 W00000000000000.
WNW00000000000000.
NW00010000000013.50 NNW00110000000022.90 N00022010010176.39CALM1.70TOTAL025151920203996151246.91 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0100010110171211.57NE000000000010110.80 ENE00000000000000.
E00000000000000.
ESE00010001010036.87 SE00010100000024.80 SSE00000010222189.52 S000000100103511.54 SSW000000000002213.75 SW00000000000000.
WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00000000000000.
NNW00000000100018.40 N000000121330109.32CALM0 0.TOTAL01020234577134410.07 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 33 of 52)
CPNPP/FSAR Amendment No. 104September (1972 - 1975):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE000010000303711.73NE00011000000024.20 ENE01002001000044.90 E00000000100018.70 ESE00010110021067.47 SE00000000101029.15 SSE000010321203128.61 S00010001001369.85 SSW01000000001249.72 SW00000110100148.47 WSW00000200100036.50 W00000000000000.
WNW00000000000000.
NW00000201030178.87 NNW00000101000026.60 N00001100105199.36CALM1.40TOTAL02036856610914708.52 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE1123232523320479.45NE023366663104406.48 ENE020723965528497.74 E107144323100265.25 ESE0365958711200565.94 SE012749733653506.76 SSE010426510612622749.33 S0315135101051255110 10.83 SSW00101165188316211.61 SW000111201214139.71 WSW00102001001056.28 W01002001010055.70 WNW00030011110076.17 NW000333024324248.16 NNW00125001541203911.23 N04233463472286610.63CALM5.12TOTAL2182647474860635961431996788.93 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 34 of 52)
CPNPP/FSAR Amendment No. 104September (1972 - 1975):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE04813144189161011281358.18NE128791011599513897.53 ENE1345712621236526.49 E0771387610100504.28 ESE32616119641210614.76 SE1291222231818115351296.14 SSE2371014263020192313432108.14 S2448411612181622461539.29 SSW11120242656306010.43 SW202011103230156.72 WSW103334010100164.47 W00110000000135.93 WNW042232312000194.83 NW1357291153123525.98 NNW13117375557117727.82 N26711161316201699752009.65CALM14.38TOTAL184485117117140141105110937926713307.71 NUMBER OF INVALID OBSERVATIONS =3TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE160021120020154.53NE272225000001213.84 ENE051432000001163.94 E2337102000000273.61 ESE3711841000000342.90 SE0513131119622000714.43 SSE14946191362010655.15 S025662477623506.81 SSW121100021210115.68 SW02010010000043.52 WSW02200000000042.12 W03100002000063.48 WNW00300000000032.70 NW137342541200324.82 NNW157667200101364.34 N444333010000223.28CALM20.33TOTAL16606958576332261311664374.35 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 35 of 52)
CPNPP/FSAR Amendment No. 104September (1972 - 1975):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE02000000000022.00NE01000000000011.80 ENE00002000000025.00 E00101101000045.15 ESE00011000000024.40 SE011642100000154.26 SSE015641010000183.73 S01212110100094.57 SSW01220000010063.78 SW00000001000017.70 WSW01100000000022.25 W02410000000072.56 WNW362020000000132.18 NW2274511846200515.51 NNW043111110000123.64 N02200000000042.00CALM11.18TOTAL5243022221711873001603.96 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE214101623132418201817612368.42NE31213151921171112106181576.64 ENE1126181817159685161316.49 E3101823261411552001174.50 ESE612243628232212139201875.03 SE1102539415632231712982735.71 SSE39212428575440333925734067.74 S2101422141920303830401143539.30 SSW255513109916166714810.34 SW222233715445407.52 WSW137466021110324.51 W066220030101214.05 WNW3107552423100424.08 NW481918142724161411481676.03 NNW212231715168811123381657.51 N6161519252124262220191053189.23CALM52.30TOTAL4115121526526829827221520919415151428457.30 NUMBER OF INVALID OBSERVATIONS =35TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 36 of 52)
CPNPP/FSAR Amendment No. 104October (1972 - 1975):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE00000000000000.
ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE00000011100037.70 SSE0000000112651510.52 S00000002010369.73 SSW00001010021058.28 SW00000000000000.
WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00000000000000.
NNW000000000001115.70 N00000000000000.CALM00.TOTAL000010242579309.88 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE00000000000000.
ENE00000000000000.
E00000000000000.
ESE00000010100027.85 SE00000100000015.30 SSE000022000125129.41 S00000001311289.82 SSW000001000032610.35 SW000000000001112.60 WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00000000000000.
NNW000000000102313.20 N00000010110038.23CALM0 0.TOTAL0000242154612369.76 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 37 of 52)
CPNPP/FSAR Amendment No. 104October (1972 - 1975):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000211000046.30NE00000120000036.67 ENE00000000000000.
E00002000000024.30 ESE00003010110066.33 SE00001001000025.90 SSE0000101011361310.32 S00002112210096.92 SSW00010020001378.86 SW00010100100147.40 WSW00000010100027.60 W00000000100019.00 WNW00000000000000.
NW00000000000000.
NNW000000010017913.04 N00000010112058.94CALM0 0.TOTAL00029510584717678.63 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE003469245128447.67NE005456100017296.76 ENE104453220000214.50 E066433131100284.30 ESE025396748200465.73 SE031711171148412696.12 SSE01459581210101119948.89 S1111113768101185313010.14 SSW20033545742296410.34 SW013021231215217.62 WSW010251130011156.07 W021042130000135.19 WNW013010011111106.36 NW054412210344306.39 NNW121330458111266610.31 N01105145424366311.92CALM4.35TOTAL5265244856856636343471917478.38 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 38 of 52)
CPNPP/FSAR Amendment No. 104October (1972 - 1975):  10-Meter Leve lPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE1352509200218479.29NE053634211000254.14 ENE008520000000153.20 E014734110010224.54 ESE0347104677010495.54 SE359814221315127341156.25 SSE1918612827182016611879.54 S034182161991368716811.24 SSW00125672710205110.01 SW012202100002106.00 WSW021342100000134.23 W022211102100125.01 WNW010222121102146.72 NW125765173436506.77 NNW0258810710127521958.08 N027431091143225809.17CALM11.24TOTAL64161748086831047657392469648.27 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE02131100000083.55NE15300000000091.86 ENE376000000000161.85 E123420000000123.00 ESE17111794112010544.03 SE24818197830012724.66 SSE241122151723241334141526.35 S03654715128728777.25 SSW060337122013286.01 SW134013100000133.46 WSW01201100000053.30 W03111000000062.60 WNW10301000000052.70 NW031647643202386.20 NNW011832341100245.34 N113463222301285.92CALM19.36TOTAL135264917059605231169305665.27 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 39 of 52)
CPNPP/FSAR Amendment No. 104October (1972 - 1975):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE03010000000042.15NE12200000000051.64 ENE2000000000002.90 E12300000000062.15 ESE197412200000262.94 SE4121923106310000783.32 SSE4161515136810001793.61 S5412894872115665.21 SSW184546311000333.93 SW040221001000103.75 WSW13320000000092.22 W1710420000000242.50 WNW569241300000302.94 NW3812446780100534.36 NNW083310000000152.55 N232110100001113.48CALM40.31TOTAL3195101745132351842174913.37 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE189101212127514261077.81NE2121310811511017714.85 ENE6718973220000543.22 E2111615107241110703.97 ESE221273132161812193201834.83 SE9243757565336252111583425.21 SSE7303250474248664337421135577.76 S6113315362146513435181584649.28 SSW314514162518101778571948.43 SW199558433219595.84 WSW1767104331011444.49 W11414783233100563.79 WNW6815483432213594.40 NW4182221152016206107121715.83 NNW113102215121420211117572138.59 N371391514181812108631909.25CALM74.32TOTAL5521427928630025424824818913111651429086.93 NUMBER OF INVALID OBSERVATIONS =68TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 40 of 52)
CPNPP/FSAR Amendment No. 104November (1972 - 1975):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000001000017.70NE00001300010056.36 ENE00000000000000.
E00000000000000.
ESE00000100000015.70 SE000000000001111.90 SSE00000000000000.
S00000000100018.40 SSW000000000104518.90 SW00000000000000.
WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00001000000014.20 NNW00000000110029.15 N00000000000000.CALM00.TOTAL0000240123051710.74L NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000100000015.70NE00000001000017.60 ENE00000000000000.
E00000000100018.70 ESE000000000120310.13 SE000000000102312.10 SSE000000000010110.50 S00000000000000.
SSW000000000001118.00 SW00000000000000.
WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW000000000010111.00 NNW000000000105611.38 N00001000000014.50CALM0 0.TOTAL0000110113481910.58 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 41 of 52)
CPNPP/FSAR Amendment No. 104November (1972 - 1975):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000110000026.15NE00000211000046.32 ENE00000000000000.
E00000000000000.
ESE00000200000025.55 SE000000000102311.10 SSE000000000011210.75 S00000000000000.
SSW000000000010111.00 SW000000001111410.00 WSW00000001010139.77 W00000000000000.
WNW00000000000000.
NW00000010010028.00 NNW000000000143810.61 N00000000011029.95CALM00.TOTAL000005321688339.23 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0036569155713608.03NE004586650210375.48 ENE013023443100216.09 E021242200100144.81 ESE120225521110225.72 SE000147698967578.22 SSE1001610578517 517.92 S01203435334356312.58 SSW02101000032374614.03 SW00101130534193711.53 WSW001011331017189.54 W022001424028259.11 WNW001116311203197.87 NW010133142211634 11.76 NNW010233585756310212.74 N001318735119348210.58CALM2.60TOTAL2122024456666545155442496909.94 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 42 of 52)
CPNPP/FSAR Amendment No. 104November (1972 - 1975):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE025475422224396.29NE043411100000143.49 ENE045722000000203.24 E035442100000193.57 ESE12310114001000324.08 SE05381214121312112181107.44 SSE130713142277511561469.62 S013113461111178113912.94 SSW00210415347416812.57 SW00210301021172712.41 WSW012121102303167.91 W002112230015178.49 WNW0010485562111438.90 NW01144457710127613113.30 NNW10232467919137414012.57 N00257328685398511.14CALM4.42TOTAL326416171746664667772425105010.36 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE053234101000193.85NE033210100000103.07 ENE042400000000102.69 E124501000000132.97 ESE003752210000204.30 SE04610187557745786.36 SSE2766515161415113261267.91 S1021411121293712748.28 SSW016255454538487.47 SW03111500103153010.05 WSW021112211001125.88 W001112100122117.63 WNW0212581061102386.14 NW012139141412436697.72 NNW030236452337387.72 N022060331202216.16CALM12.33TOTAL439434761777566543728866296.94 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 43 of 52)
CPNPP/FSAR Amendment No. 104November (1972 - 1975):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE01000000000011.50 ENE10300000000042.17 E04100000000051.74 ESE065223000000183.16 SE241310136122110554.13 SSE1289128942303615.45 S0281058524100454.84 SSW141140036100215.61 SW334201401000183.66 WSW163643110010263.83 W197553020000323.35 WNW254712330010284.15 NW0288116133310465.03 NNW10310020000185.04 N01010020000044.80CALM22.21TOTAL1349686257402820189443944.20 NUMBER OF INVALID OBSERVATIONS =3TOTAL NUMBER OF OBSERVATIONS  = 2880PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0711121517154879171226.77NE0810111112970310724.84 ENE110131345443100584.11 E111111185401100533.74 ESE210112120179322301004.60 SE213222947342430293114353106.84 SSE512142336475232322417963908.22 S14151314262425281828128324 10.61 SSW1710510105131314139119210.98 SW3684210718695211610.08 WSW1978877644212756.64 W111127787741515856.63 WNW2771011242115852181307.04 NW051114222222292420189828510.33 NNW2458815172117322515330711.67 N0351017121415122215752010.08CALM40.29TOTAL2212717219924027124121219319116179028598.62 NUMBER OF INVALID OBSERVATIONS =21TOTAL NUMBER OF OBSERVATIONS  = 2880TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 44 of 52)
CPNPP/FSAR Amendment No. 104December (1972 - 1975):  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000000000.NE00000000000000.
ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE00000000000000.
SSE000000000002215.50 S00100200020278.89 SSW0010000100191211.86 SW000000110002412.00 WSW00000001000129.90 W01030000000043.12 WNW01111001000054.00 NW001021011410117.89 NNW00000110000026.50 N00000000000000.CALM00.TOTAL0244342516216498.89 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00100000010138.13NE00000100000015.30 ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE00000000000000.
SSE0000000000000.0.
S00000000000000.
SSW0000000000000.0.
SW00001000000015.00 WSW00000000000000.
W00000000000000.
WNW00000000000000.
NW00000000200028.95 NNW000000000011211.90 N00000000000000.CALM0 0.TOTAL00101100211298.49 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 45 of 52)
CPNPP/FSAR Amendment No. 104December (1972 - 1975):  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE00000000300038.60NE00000000000000.
ENE00000000000000.
E00000000000000.
ESE00000000000000.
SE00000000000000.
SSE00000000000000.
S00000010020038.47 SSW000000000001111.20 SW00000000100018.60 WSW00000001000017.70 W00000001000017.60 WNW00000002000139.30 NW00000110002159.16 NNW000000100212611.57 N000001001106913.20CALM0 0.TOTAL00000234553113310.55 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE001469343615427.45NE00023010110085.75 ENE005121001000104.02 E00200000000022.80 ESE001435300000164.76 SE000118620200206.20 SSE0125146234110397.78 S00004231123294511.90 SSW00022001112354413.72 SW00000130001182313.57 WSW0000020001191311.85 W000033002113138.51 WNW00112002003142310.76 NW00113042423163610.40 NNW00002823724639114.77 N00010122545345413.34CALM00.TOTAL0113223244331928262523647911.09 NUMBER OF INVALID OBSERVATIONS =63TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 46 of 52)
CPNPP/FSAR Amendment No. 104December (1972 - 1975):  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE001486213006317.21NE003323310101165.07 ENE044431110000183.52 E026701100100183.61 ESE105354111001224.75 SE113279541301375.71 SSE00442811941174510510.29 S210224889789514613.15 SSW02011334361578113.94 SW00112140361193810.98 WSW00113002302183010.52 W014210412205227.26 WNW002217539327418.10 NW12325118882107613611.13 NNW01363109710989916512.20 N01023774666408211.16CALM00.TOTAL51540464875725462574546998810.67 NUMBER OF INVALID OBSERVATIONS =13TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE016401003011175.53NE040011020302136.50 ENE11300100000174.34 E052132101000153.83 ESE067613000000232.95 SE126121820950310775.05 SSE00459141111813318967.82 S01356911710818281069.49 SSW1033013551310358.91 SW0031023003111249.90 WSW032302632422297.04 W040451141000204.71 WNW1241104210311305.29 NW1115821161576315997.70 NNW01015910793211589.02 N113104254115288.21CALM15.44TOTAL6324752669575655048361056927.24 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 47 of 52)
CPNPP/FSAR Amendment No. 104December (1972 - 1975):  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEED NNE002000332000106.44 NE02010110000053.74ENE041201101000103.60 E25000000000071.16ESE134671000000223.54 SE052425216502000883.91SSE011728219521100854.21 S035875846200485.42SSW035654411102324.98 SW054842521200334.61WSW026873312010334.58 W067663002100313.91 WNW1425134420000354.51 NW047871511155424826.25 NNW154613212121294.95 N120201131000114.95CALM12.43TOTAL65488119995853342612575734.58 NUMBER OF INVALID OBSERVATIONS =0TOTAL NUMBER OF OBSERVATIONS  = 2976PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEED NNE0111121416881472131067.03 NE063666531502435.48ENE11013754212001463.73 E21210833201100423.24ESE2917191613411001833.93 SE2833404743251138112224.81SSE02274233353324162911763287.73 S259151922312026232915435510.73SSW15912881012109711420511.50 SW05810761635113501249.52WSW0591210798756301087.89 W0121115157567418915.56 WNW27101027151111966231376.89 NW271316254940412718211133728.95 NNW177131131251828171817735311.70 N243631412141712128518411.08CALM27.44TOTAL1710519324324927923818117415511784828268.63NUMBER OF INVALID OBSERVATIONS =150TOTAL NUMBER OF OBSERVATIONS  = 2976TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 48 of 52)
CPNPP/FSAR Amendment No. 104May 15, 1972 - May 14, 1976:  10-Meter LevelPASQUILL #A# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE011091191157311688.13NE0024411844533487.07 ENE011334413111236.12 E0114768510500476.50 ESE0146111316149175101067.48 SE0102641416141568868.09 SSE02227914132314194314810.53 S003531116152024127618511.04 SSW002144891019168716012.78 SW00033234002183511.10 WSW001433032001175.98 W010323211003167.59 WNW012230212003167.11 NW00113122444163810.50 NNW01222221621234411.44 N000242523529349.23CALM2.60TOTAL010224474861131021161187431210739.71 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 35043PASQUILL #B# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0123073152212389.29NE000014320220147.32 ENE00011000000024.05 E000004131020117.52 ESE0012151075842457.87 SE0001247645213449.27 SSE00013323111111216610.29 S0100015291110296811.55 SSW000003234410265212.06 SW00002011127112511.50 WSW000000100026915.64 W000010020003613.57 WNW00010001010148.15 NW0000010021281411.48 NNW00001001123202813.12 N0000114234372510.20CALM00.TOTAL02391333393446536015945110.48 NUMBER OF INVALID OBSERVATIONS =1TOTAL NUMBER OF OBSERVATIONS  = 35043TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 49 of 52)
CPNPP/FSAR Amendment No. 104May 15, 1972 - May 14, 1976:  10-Meter LevelPASQUILL #C# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0003374447210449.07NE000445654105347.41 ENE010134250412237.34 E000363133200216.16 ESE0002689871054597.75 SE0011466776513568.82 SSE00013412711109328910.08 S00023312914911329510.37 SSW010144746514297510.01 SW00021422726184410.49 WSW000324242304247.96 W000010011114914.58 WNW000021030004109.89 NW00001321075113010.05 NNW000111144512366512.88 N000234114611134510.05CALM1.40TOTAL0212647616768747882217724 9.68 NUMBER OF INVALID OBSERVATIONS =6TOTAL NUMBER OF OBSERVATIONS  = 35043PASQUILL #D# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE14153446494139463835874358.11NE14222543313527241918332827.03 ENE1623333220353428137212536.56 E11528353834252717915152596.08 ESE28313646647748512416134367.01 SE181533577674736374611216568.38 SSE161941567983869889762709049.56 S1111925634876829698104556117911.38 SSW236132429495057615639774711.81 SW1511161725362927312816338910.31 WSW02812191010187718621739.82 W07121516121281578631759.60 WNW02611714911101075814510.11 NW0611211812131519222214130011.17 NNW179232324223643445634363112.42 N089212826323335444225152911.36CALM23.20TOTAL13102244394533553629616636590569261475169.88 NUMBER OF INVALID OBSERVATIONS =208TOTAL NUMBER OF OBSERVATIONS  = 35043TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 50 of 52)
CPNPP/FSAR Amendment No. 104May 15, 1972 - May 14, 1976:  10-Meter LevelPASQUILL #E# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE2234246563963393433381205357.98NE231485750404828372715274106.06 ENE527495147322125181814253325.69 E636438461513523132717414376.05 ESE73056821128559474029241597307.90 SE64181124165174160121114845721113387.36 SSE7375810014018020317517517415473821419.82 S9213765711071161471751781731084218311.66 SSW31723333163566869626348697411.54 SW2122525262828242027181573929.69 WSW11016142015141112127852179.60 W082412141717910107631919.13 WNW1111723233424273810101013198.88 NW71630535068575850415037585510.61 NNW4123155606867751019381615126211.64 N425314255648178696661440101610.64CALM65.22TOTAL66357611866981106510499559758917894727133979.68 NUMBER OF INVALID OBSERVATIONS =136TOTAL NUMBER OF OBSERVATIONS  = 35043PASQUILL #F# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE9283120191511783621594.40NE533312116145314351414.01 ENE741362710142251141503.60 E1022405837113664472084.25 ESE6598512475371514866124474.22 SE5481141641611256849272010238145.04 SSE7559411513615613611982543211010966.46 S63558768699112969468632019948.18 SSW8274542325433492930421315228.29 SW724362113292016111212672687.31 WSW3203523171416211167161895.71 W1232118151311105109141505.79 WNW5123025333130287116122305.69 NW715425055837553422513475076.65 NNW42330394248333420149353316.48 N112225303126232214177302586.39CALM120.34TOTAL10148745385377876959352937028523071665846.17 NUMBER OF INVALID OBSERVATIONS =54TOTAL NUMBER OF OBSERVATIONS  = 35043TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 51 of 52)
CPNPP/FSAR Amendment No. 104May 15, 1972 - May 14, 1976:  10-Meter LevelPASQUILL #G# (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE0136450533224475.16NE288301200101263.26 ENE41011851201100433.13 E52213761030000572.72 ESE332282519103501111283.57 SE844941257339221062154293.97 SSE7388310787384312862154464.58 S8285252544643251796153555.33 SSW8342832391920131563172345.27 SW631313717141611775182005.10 WSW526383429141711114461994.63 W549613936154732142263.62 WNW13464334362118811212243.77 NW83466504971515224166144415.48 NNW73024181312108623121455.20 N41477555313212686.41CALM115.32TOTAL93459593582473307261171103633812533834.49 NUMBER OF INVALID OBSERVATIONS =19TOTAL NUMBER OF OBSERVATIONS  = 35043PASQUILL ALL (FROM AEC/DELTA-T CRITERIA 10-60 METERS)WINDS AT 10 METERS LEVELWIND FREQUENCY DISTRIBUTION(FREQUENCY IN NUMBER OF OCCURRENCES)WINDUPPER CLASS INTERVALS OF WIND SPEED (MPH)MEANDIRECTION1234567891011>11TOTALSPEEDNNE127398111138132 136106105929025013437.57NE107811111512110910970726541759766.11 ENE1889123127103756768553824538405.47 E229612619215811378715148386310565.56 ESE18131208280272224195149125976222419856.56 SE2314631245347343035929023821214640734896.66 SSE22142260370436471496419411362304125149448.58 S2597170228281317380376427400380199508010.41 SSW21841041231341771761961911892041174277310.50 SW1672105105791031068773817845313588.80 WSW9599892906660684533381828407.50 W69112087866146383531261627897.09 WNW1972999610410183805933251869577.11 NW227415417617723920018314611810361822108.72 NNW16751011391431581351601811631671093253110.81 N197172109130130152142129146128762199010.05CALM327.30TOTAL27814502261280329252906277825032343210818548952334888.50 NUMBER OF INVALID OBSERVATIONS =1555TOTAL NUMBER OF OBSERVATIONS  = 35043TABLE 2.3-27WIND FREQUENCY DISTRIBUTIONS AT CPNPP(Sheet 52 of 52)
CPNPP/FSAR Amendment No. 104TABLE 2.3-28MINIMUM DISTANCE FROM THE REACTOR CONTAINMENT STRUCTURE TO THE EXCLUSION-AREA BOUNDARY DirectionFrom PlantMinimum Distance (meters)N2148 NNE2594 NE2673 ENE2588 E2570 ESE2199 SE2234 SSE2211 S2040 SSW1717 SW1547 WSW1544(a)a)Minimum Exclusion DistanceW1631WNW2056 NW2106 NNW2083 CPNPP/FSAR Amendment No. 104TABLE 2.3-29THIS TABLE HAS BEEN DELETED.
CPNPP/FSAR Amendment No. 104TABLE 2.3-30THIS TABLE HAS BEEN DELETED.
CPNPP/FSAR Amendment No. 104TABLE 2.3-31THIS TABLE HAS BEEN DELETED.
CPNPP/FSAR Amendment No. 104TABLE 2.3-32THIS TABLE HAS BEEN DELETED.
CPNPP/FSAR Amendment No. 104TABLE 2.3-33AVERAGE ANNUAL RELATIVE CONCENTRATION AT CPNPP (SEC./CUBIC METER) PERIOD OF RECORD:  5-15-72 TO 5-14-76BASE DISTANCE IN MILES/KILOMETERS AFTDSECTDESIGNDISTMI.50.801.001.611.502.412.003.222.504.023.505.634.006.444.507.24NNE0.1.3E-053.1E-061.2E-066.5E-074.2E-072.3E-071.8E-071.5E-07NE0.9.2E-062.2E-068.5E-074.6E-072.9E-071.6E-071.3E-071.1E-07ENE0.7.5E-061.8E-066.8E-073.7E-072.3E-071.3E-071.0E-078.4E-08E0.8.9E-062.1E-068.0E-074.3E-072.7E-071.5E-071.2E-079.9E-08 ESE0.9.7E-062.3E-068.8E-074.7E-073.0E-071.6E-071.3E-071.1E-07SE0.1.4E-053.4E-061.3E-067.1E-074.5E-072.5E-072.0E-071.6E-07SSE0.1.1E-052.7E-061.1E-065.8E-073.7E-072.0E-071.6E-071.3E-07 S0.8.6E-062.2E-068.5E-074.7E-073.0E-071.6E-071.3E-071.1E-07SSW0.7.1E-061.8E-066.9E-073.8E-072.4E-071.3E-071.0E-078.6E-08SW0.6.5E-061.6E-066.4E-073.5E-072.3E-071.2E-079.7E-088.0E-08WSW0.7.1E-061.8E-066.9E-073.8E-072.5E-071.3E-071.1E-078.7E-08W0.8.6E-062.2E-068.4E-074.6E-072.9E-071.6E-071.3E-071.0E-07WNW0.1.4E-053.4E-061.3E-067.3E-074.7E-072.6E-072.0E-071.7E-07NW0.2.3E-055.7E-062.2E-061.2E-067.7E-074.1E-073.3E-072.7E-07NNW0.2.5E-056.1E-062.4E-061.3E-068.4E-074.5E-073.6E-073.0E-07 N0.2.0E-054.9E-061.9E-061.1E-066.7E-073.6E-072.9E-072.4E-07BASE DISTANCE IN MILES/KILOMETERS AFTDSECTDESIGNDISTMI6.009.657.5012.0710.0016.0915.0024.1325.0040.2235.0056.3145.0072.4050.0080.45NNE0.9.6E-087.0E-084.6E-082.7E-081.4E-089.5E-097.0E-096.2E-09NE0.6.8E-085.0E-083.3E-082.0E-081.0E-086.9E-095.1E-094.5E-09ENE0.5.5E-084.1E-082.7E-081.6E-088.5E-095.7E-094.2E-093.7E-09 E0.6.5E-084.8E-083.1E-081.9E-081.0E-086.8E-095.0E-094.4E-09ESE0.7.1E-085.2E-083.5E-082.1E-081.1E-087.4E-095.5E-094.9E-09SE0.1.1E-077.8E-085.1E-083.1E-081.6E-081.1E-088.0E-097.1E-09 SSE0.8.4E-086.1E-084.0E-082.3E-081.2E-088.1E-096.0E-095.3E-09S0.6.7E-084.9E-083.2E-081.9E-089.7E-096.4E-094.7E-094.1E-09SSW0.5.5E-084.0E-082.6E-081.5E-087.8E-095.1E-093.8E-093.3E-09SW0.5.1E-083.7E-082.4E-081.4E-087.3E-094.8E-093.5E-093.1E-09WSW0.5.6E-084.0E-082.6E-081.5E-088.1E-095.3E-093.9E-093.5E-09W0.6.7E-084.9E-083.2E-081.9E-089.7E-096.4E-094.7E-094.2E-09 WNW0.1.1E-077.9E-085.1E-083.0E-081.6E-081.1E-087.8E-096.9E-09NW0.1.8E-071.3E-078.5E-085.0E-082.7E-081.8E-081.3E-081.2E-08NNW0.1.9E-071.4E-079.2E-085.4E-082.9E-081.9E-081.4E-081.2E-08 N0.1.5E-071.1E-077.3E-084.3E-082.3E-081.5E-081.1E-089.7E-09 CPNPP/FSARAmendment No. 104TABLE 2.3-34METEOROLOGICAL INSTRUMENTATION COMANCHE PEAK OPERATIONAL METEOROLOGICAL PROGRAM MeasurementLevel(Meters)Instrument TypeThresholdInstrument RangeWind Speed10 & 603 Cup Anemometer0.45 m/s(a)a)m/s = meters per second 0 to 100 mph (b)b)Envelops the range 0-67 mph as proposed by Reg. Guide 1.97 Rev. 2Wind Direction10 & 60Wind Vane0.45 m/s(a)0 to 540&deg;Temperature10Platinum Temp. SensorN/A-20&deg; to +120&deg;F Delta-Temp10 to 60Platinum Temp. SensorN/A-5&deg; to +15&deg;F PrecipitationSurfaceTipping Bucket0.01 in.0-1 in.
CPNPP/FSARAmendment No. 104TABLE 2.3-34AMETEOROLOGICAL INSTRUMENTATION COMANCHE PEAK OPERATIONAL METEOROLOGICAL PROGRAM OVERALL SYSTEM ACCURACIES(a)a)These values are based upon equipment being properly calibrated. ParameterRecording TypeSystem Accuracy (ANSI/ANS-2.5-1984)(b)Actual System Accuracy  Wind SpeedDigital
+/-0.5 mph, WS<5mph
+/-10%, otherwise
+/-0.39mph, WS<25mph 
+/-1.10%, otherwise (c)Analog(d)+/-0.75mph, WS<5mph
+/-15%, otherwise
+/-0.58mph, WS<25mph
+/-1.18%, otherwise (c)Wind DirectionDigital
+/-5&deg;+/-3.4&deg;(c) Analog(d)+/-7.5&deg;+/-4.5&deg;(c) TemperatureDigital
+/-0.9&deg;F+/-0.6&deg;F(c) Analog(d)+/-0.9&deg;F+/-0.9&deg;F(c) Delta TemperatureDigital
+/-0.27&deg;F+/-0.17&deg;F(c) Analog(d)+/-0.27&deg;F+/-0.19&deg;F(c) PrecipitationDigitalRain guage with
+/-0.01 in resolution
+/-10% measured value for total accumulated catch greater than 0.2 inRain guage with
+/-0.01 resolution 
+/-0.011 in or
+/-1.1%(c)Analog(d)Rain guage with
+/-0.01 in resolution +10% measured value for total accumulated catch greater than 0.2 inRain guage with
+/-0.01 resolution 
+/-0.013 in or
+/-1.3%(c)
CPNPP/FSARAmendment No. 104b)Endorsed by Reg. Guide 1.23 Second Proposed Revision 1, April 1986.c)Accuracy values show were calculated for original system. Calculations made for subsequent equipment upgrades computed uncer tainties equal or less. All uncertainties computed are below acceptance criteria of requirements documents.d)Paperless digital recorder replaces previous analog recorders. Uncertainties calculated for paperless digital recorder do not exceed acceptance criteria requirements for digital channels.
CPNPP/FSAR Amendment No. 104TABLE 2.3-34BMETEOROLOGICAL INSTRUMENTATION COMANCHE PEAK OPERATIONAL METEOROLOGICAL PROGRAM DELTA TEMPERATURE SYSTEM ACCURACY (a)a)Measurement of delta temperature is made by comparing two identical sensors after having first calibrated out any difference between them at the reference temperature. The sensor error is then essentially the tracking error between the two sensors. This error includes accuracy and interchangeability and linearity. These errors plus those which are attributed to the signal conditioning electronics and recor ders have been included in the analysis.
Instrument Accuracy1.Sensor AccuracySignal Conditioner Accuracy+/-0.13&deg;F Instrument AccuracyTemperature Coefficient+/-0.08&deg;F+/-0.05&deg;F2.Square Root of the Sum of the Squared Tolerances+/-0.09&deg;F3.Transmitter Accuracy+/-0.04&deg;F4.Receiver Accuracy+/-0.04&deg;F 5.Current Driver Accuracy+/-0.04&deg;F6.Digital Recorder AccuracyInput Resistor Accuracy Input Accuracy+/-0.05&deg;F+/-0.05&deg;F7.Square Root of the Sum of the Squared Tolerances+/-0.071&deg;F 8.Analog Data Reduction Accuracy+/-0.05&deg;F System Accuracy (b)b)These values are well within the +/-0.27&deg;F criteria established by ANSI/ANS-2.5-1984, which is endorsed by Reg. Guide 1.23. Paperless digital recorder replaces previous analog recorders. Uncertainties calculated for paperless digital recorder do not exceed acceptance criteria requirements for digital channels. Calculations made for subsequent equipment upgrades computed uncertainties equal to or less than these uncertainties.Digital RecordingSquare Root of the Sum of the Squared Tolerance of 1, 2, 3, 4, 5 and 6+/-0.17&deg;F CPNPP/FSAR Amendment No. 104TABLE 2.3-35COMPARISON OF ANALOG AND DIGITAL DATA(Sheet 1 of 2)I. WIND DIRECTION COMPARISONWindSectorDIGITAL OCCURRENCESNNENEENEEESESESSESSSWSWWSWWWNWNWNNWNTOTALNNE66NE123ENE1214E134ESE2619SE1252129SSE432137S1447153SSW141924SW1910WSW3710W511521WNW215118NW338142NNW229132N22325Total733673238532112121323413224327 CPNPP/FSAR Amendment No. 104II. WIND SPEED COMPARISON(a)Windspeed(mph)DIGITAL OCCURRENCESCalm1234567891011121314-1617-1920TotalCalm2215162131923312324452413053161963191237124126832321299516211058131171212012315181331311714-163202317-193222520178Total3821282720202829231615191624237327a)All wind speed averages were rounded off to the nearest mph.Note:In a perfect correlation, all occurrences would fall on the single diagonal indicated by the underlined values above.TABLE 2.3-35COMPARISON OF ANALOG AND DIGITAL DATA(Sheet 2 of 2)
CPNPP/FSAR Amendment No. 104TABLE 2.3-36THIS TABLE HAS BEEN DELETED.
CPNPP/FSARAmendment No. 104TABLE 2.3-375-PERCENTILE VALUES(a) OF THE ACCIDENT PERIOD DIFFUSION ESTIMATES AT THE LPZa)10-6 s/m3SectorAffected1 Hour0-8 Hours8-24 Hours1-4 Days4-30 DaysN42.618.712.45.051.40NNE41.216.810.74.041.00NE41.215.99.93.520.80 ENE38.714.58.83.030.65E51.518.911.53.860.81ESE51.119.011.63.980.85 SE47.419.212.24.581.12SSE36.314.89.53.570.88S25.710.76.92.680.69 SSW23.79.66.12.290.56SW22.99.35.92.220.54WSW30.412.07.52.750.65 W29.412.07.72.900.72 WNW42.617.611.34.311.08NW55.623.815.66.221.66NNW51.122.515.06.151.72 CPNPP/FSARAmendment No. 104TABLE 2.3-3850-PERCENTILE VALUES(a) OF THE ACCIDENT PERIOD DIFFUSION ESTIMATES AT THE LPZa)10-6 s/m3SectorAffected1 Hour0-8 Hours8-24 Hours1-4 Days4-30 DaysN9.505.344.002.140.87NNE4.312.551.961.110.49NE1.581.050.850.540.29 ENE0.000.000.000.000.00E0.000.000.000.000.00ESE0.000.000.000.000.00 SE7.043.912.911.540.61SSE3.562.131.650.950.43S2.931.751.350.770.35 SSW1.460.940.750.460.23SW0.000.000.000.000.00WSW0.000.000.000.000.00 W0.100.110.110.110.12 WNW4.722.802.161.220.54NW12.406.815.042.631.03NNW12.807.095.282.781.11 CPNPP/FSAR2.4-1Amendment No. 1062.4HYDROLOGIC ENGINEERING2.4.1HYDROLOGIC DESCRIPTION2.4.1.1Site and FacilitiesThe Comanche Peak Nuclear Power Plant (CPNPP) site is located  approximately 65 miles southwest of the Dallas-Fort Worth, Texas, area, on a peninsula in Squaw Creek Reservoir (for a description of the Reservoir see Section 2.4.8.2
). The Squaw Creek Reservoir (SCR) has a service spillway crest elevation of 775.0 feet. Th e calculated probable maximum flood level of Squaw Creek Reservoir is 789.7 feet. The station, which takes cooling water from one side of the peninsula and discharges to the other, has a site grade elevation of 810.0 feet.The Safe Shutdown Impoundment (SSI) is formed by building a seismic Category I dam across an arm of the reservoir. The water level is  maintained by an equalization channel between the SSI and SCR. Near the south end of the equalization channel, a non-intrusive, floating raft system has been added which bridges from the east bank to west bank of the channel. Details of the SSI Dam are presented in Section 2.5.6
.The Service Water Intake Structure is located on a bank of the SSI. The structure foundation is at elevation 749'0" with the top of slab at elevation 755'0". The operating deck of the structure is at elevation 796'0" with the pump discharge centerline at elevation 800'0". Access to the Service Water Intake Structure is provided by a personnel door and truck bay entrance at elevation 810'6".The Containment Building is a completely closed, water-tight structure  which cannot be affected by exterior flooding. Safety class equipment outside the Containment Building is located in the Safeguards, Fuel,  Auxiliary, and Electrical and Control buildings. All exterior accesses to these buildings are above the 810 ft elevation with the exception of Turbine Building entrances to the Electrical and Control Building. This height is significantly above the maximum probable flood (see section 2.4.2). Protection against flooding of safety-related components and systems is discussed in Section 3.4
.A topographical map of th e CPNPP site is shown in Figure 2.4-4, and  changes made to the natural drainage features are indicated thereon.The stability of the Squaw Creek Dam has been evaluated for construction and operating conditions, including conditions of maximum reservoir elevation and minimum tail water elevation, utilizing engineering properties of all embankment materials and all foundation  materials, by normally recognized procedures such as that used by the Department of the Army, Corps of Engineers, as more fully described in Engineering Manual EM-1110-2-1902, "Stability of Earth and Rock-Fill  Dams."  Squaw Creek Dam is not a seismic Category I structure.Each building is equipped with a roof drainage system designed to  effectively collect, pass and discharge the water volume resulting from a six-inch rainfall in one hour with a maximum intensity two inches in five minutes. The scuppers are in the parapet walls and the scupper invert elevation will not be more than three inches above the roof at the outside wall or not more than five inches above the low point of the roof. The roof drains and drain pipes are designed in accordance with "Roof Drain Design for Nuclear Project Safety Related Buildings" by Southern Services, Inc., dated December 8, 1972. The roofs of all nuclear-safety-related buildings are CPNPP/FSAR2.4-2Amendment No. 106designed to support an eight-inch maximum unifo rm depth of water in addition to the regular live loads considered (see Fig. 2.4-2 and 2.4-3). The parapet walls have relief openings to ensure that the eight-inch level will not be exceeded.The onsite drainage system for the CPNPP site is a natural drainage system as outlined in Figure2.4-4. As this figure shows, the safety-related buildings are located at a high point, with the surrounding grounds sloping towards the Squaw Creek Reservoir (SCR) to the north and the south. The ground east and west of the buildings slopes towards the ditches as indicated on Figures 2.4-40 and 2.4-41. Each ditch discharges into the reservoir on both sides of the peninsula. A possible clogging of any ditch will not affect the system's water removal capacity.In addition, the onsite drainage system is designed to remove the water resulting from a rainfall of six inches in one hour and 7.5 inches in two hours, in such a manner that the runoff is accomplished without ponds forming on the ground.Further, the drainage system is designed to adequately drain a rainfall of 15 inches in one hour and 22 inches in two hours in such a way that t here are no ponds which can back up into the structures and affect safety-related systems.The design bases given above are consistent with the Probable Maximum Precipitation (PMP) as discussed in Section 2.4.3.1
.2.4.1.2Hydrosphere 2.4.1.2.1Regional DescriptionThe Comanche Peak Nuclear Power Plant (CPNPP) site is located in the Squaw Creek catchment. Squaw Creek is a small tributary to the Paluxy River, which is a tributary to the Brazos River. The Brazos River and its tributaries constitute one of the principal river systems in the South-Central United States, extending from New Mexico, through Texas, to the Gulf of Mexico. The Texas portion of the Brazos River basin is illustrated in Figure 2.4-5
.The portion of the Brazos River catchment considered in this study is illustrated in Figure 2.4-6
, a regional topographic map showing the site, existing and possible future reservoirs in the vicinity, and locations of the stream and rainfall gaging stations considered in this study. At gaging station 8-0910, east-southeast of the site, the Bra zos River has a contributing catchment of 15,590 square miles [1].For this study the most significant portion of the Brazos River catchment is that between Lakes Granbury and Whitney. In this reach, the Brazos River Channel is located in incised meanders formed by the river. These meanders may be the result of uplift of the area and/or sea level fluctuations after a mature meandering drainage pattern had been attained.
The meanders eroded through, and are flanked by, rock slopes confining the river within a relatively narrow channel. Immediately adjacent to the channel, within the meanders, is a narrow flood plain. Although accretion and erosion occur within the channel, as is typical of a meandering river, the well-defined meanders indicate that the channel location is closely
 
confined. The geometry of the banks is governed closely by their location with respect to the meander pattern. The  bank on the outside of a bend generally is steep, whereas the bank on the inside of the bend usually has a gentler slope.
CPNPP/FSAR2.4-3Amendment No. 1062.4.1.2.2Squaw CreekSquaw Creek is a small, intermittent stream which drains parts of Hood  and Somervell counties and empties into the Paluxy River, upstream of the confluence of the Brazos and Paluxy rivers. Squaw Creek frequently has no flow during dry periods. Squaw Creek Dam impounds SCR for CPNPP cooling water approximately 4.3 stream miles north of the creek's entrance into the Paluxy River. The principal features of the 64-square mile SCR catchment are illustrated in
 
Figure 2.4-1. The  Squaw Creek catchment is hydrologically similar to the Paluxy River basin.The Squaw Creek watershed is underlain by sedimentary rocks of lower Cretaceous age (poorly cemented sandstone, limestone and shale) which dip gently to the east. The topography is influenced by the underlying geology, generally with steeper slopes in the limestone areas than in the shale and sandstone areas. Landforms are gently to steeply rolling. In the lower reaches of Squaw Creek, a small flood plain has developed.Topographic maps prepared by the U.S. Geological Survey show a number of small man-made ponds in the catchment, some of which are in creek  channels and others which are off-channel. The total volume of the on-channel and off-channel storage in these ponds has been estimated to be about 1150 acre-feet. There are three retaining ponds in the catchment for the purpose of
 
mitigating oil spills. See FSAR Section 2.2.3.2.3. Other than these small ponds, there are no known control structures, weirs, or canals.Tolar, with a 1970 population of 312 [2], is the only community in the catchment. The remainder of the catchment is largely ranchland with some cultivated areas.2.4.1.2.3Paluxy River The Paluxy River basin is hydrologically similar to that of Squaw Creek and is used as a basis for developing hydrologic parameters for Squaw Creek and its subcatchments since Squaw Creek is ungaged. At gaging station 8-0915, near Glen Rose, the Paluxy River has a catchment of 410square miles [1].The Paluxy watershed also is underlain by sedimentary rocks of lower Cretaceous age (poorly cemented sandstone, limestone and shale) which  dip gently to the east. The topography, governed somewhat by the geology, is generally stair-stepped in limestone areas and gently rolling in sandstone and shale areas.There are no known control structures on the Paluxy River.
2.4.1.2.4River Control StructuresThe Brazos River is undergoing continuing development of reservoirs and control structures initiated for water supply, recreation and flow  control. Table 2.4-1 lists important on-channel and off-channel reservoirs and dams upstream of Cox Bend. Cox Bend is shown on Figure 2.4-6
. On-channel dams and reservoirs downstream of Cox Bend are  identified on Table 2.4-2
. Reservoir locations are represented on Figure 2.4-5
.Four potential future reservoirs are being considered on the Brazos  between Possum Kingdom Reservoir and Lake Whitney [3]. These are described in Table 2.4-3 and their approximate locations are indicated in Figure 2.4-6
.
CPNPP/FSAR2.4-4Amendment No. 1062.4.1.2.5Surface Water UsersNo water rights have been issued on Squaw Creek, but two potential surface water users (irrigation) have filed claims to withdraw water.
In due course, these claims will be evaluated by the Texas Water Rights Commission and either upheld or dismissed. The points of potential withdrawal are located within SCR limits, adjacent to the  Hood-Somervell county line, and are listed in Table 2.4-4. No surface water users are known on the Paluxy River, downstream of the Squaw  Creek confluence [4]. Cattle are watered from Squaw Creek and also probably from the Paluxy River.There are numerous parties on the Brazos River downstream of the site vicinity who have applied for and/or received water allocations (hereafter called water users for non-irrigational and irrigational  use). Non-irrigational users (municipal, industrial, mining and hydroelectric) are
 
identified in Table 2.4-5 and on Figure 2.4-7
.Irrigational users are summarized by county in Table 2.4-6 and on Figure 2.4-7. The nearest irrigational water user below Squaw Creek  Dam is approximately three stream miles downstream from the Paluxy and  Brazos River confluence. The nearest extraction of water for public supply is at Waco, approximately 109 stream miles downstream of this confluence. There are no other known extractors of water for potable uses between Squaw Creek Dam and Waco.2.4.1.2.6Groundwater EnvironmentMost of the groundwater in the site region occurs in bedrock formations of very low permeability, although some does exist in shallow floodplain alluvium in stream valleys but is not withdrawn for use. The best producing formation is the Twin Mountains Formation which underlies the relatively impermeable Glen Rose Formation on which CPNPP and SCR are being constructed. Groundwater users near the site are described in Section 2.4.13.2 and presented in Tables2.4-24 and 2.4-25.2.4.2FLOODS2.4.2.1Flood History2.4.2.1.1Brazos River The maximum known flood on the Brazos River occurred in 1876 [1] well  before flow monitoring began, and consequently, there is little quantitative data available on this flood. Flood records for the Brazos River at gaging station 8-0910, just upstream from the Paluxy River confluence, have been obtained since 1923 [1, 5, 6, 7]. Gage location is shown in Figure 2.4-6, and the annual maximum stage and discharge measurements for 1924 to 1975 are shown in Table 2.4-7. These records indicate that the highest water level recorded at gaging station 8-0910 was elevation 601.69 feet (May 27, 1957), corresponding to a discharge of 87,400 cubic feet per second (cfs).For comparative purposes, Figure 2.4-8 shows the mean annual, the fifty-year, and the historical peak floods on the Brazos River. These  correspond to flows of approximately 40,000 cfs, 110,000 cfs and 97,600 cfs, respectively, at gaging station 8-0910. The stage reached at station 8-0910 during the 97,600 cfs flood (May 18, 1935) was less than that of the 87,400 cfs flood due to backwater effects from the Paluxy River discharge.
CPNPP/FSAR2.4-5Amendment No. 106The flood of record (elevation 601.69 feet) and the 1876 event are  significantly lower than the CPNPP site grade (elevation 810 feet). Newly filled (1969) Lake Granbury and any subsequent flow-control  facilities erected on the Brazos River watershed will further retard future flood levels.2.4.2.1.2Squaw CreekThere was no monitoring on the Squaw Creek watershed prior to 1966. A crest-stage partial-record station was installed in 1966 on Panter Branch, a tributary to Squaw Creek. Its location is shown in Figure  2.4-1, and the annual maximum stage and peak discharge measurements are presented in Table 2.4-8. In 1973, a continuous recording gage was installed on Squaw Creek at the State Highway 144 bridge, 2.1 miles upstream from the mouth of the creek. Annual peak discharges for the Squaw Creek gage during water years 1974 and 1975 are presented in Table 2.4-9
.2.4.2.1.3Paluxy RiverPeriodic flow records were obtained in the 1920's and continuous monitoring began in 1947 at gaging station 8-0915 at Glen Rose [1, 5, 6, 7]. The gage location is shown on Figure 2.4-6, and the annual maximum stage and discharge measurements are provided in Table 2.4-10
.The maximum flood since 1876 is believed to have occurred on April 17, 1908. Information from a local resident has established the basis for  an estimated stage at Elevation 637 feet at GlenRose, corresponding to a discharge of 59,000 cfs for this event.2.4.2.1.4Flood CausesAll historical floods in the catchment area pertinent to the CPNPP site have been due to precipitation runoff into streams and rivers. The area is not subject to surges, tsunamis, or ice jams, and there have been no floods due to dam failure.2.4.2.2Flood Design ConsiderationsCPNPP safety-related facilities are designed to safely withstand all floods and flood waves which are remotely possible at the site. The crest of the service spillway, elevation 775 feet, has been utilized as the pre-flood condition. The planned design assures that the  safety-related facilities of the CPNPP will not be adversely affected by this event. A summary of the consequences of flooding on all pertinent facilities is contained in Section 2.4.10. The PMF for Squaw  Creek has been determined by imposing the 48-hour probable maximum precipitation (PMP) as obtained from Hydrometeorological Report No. 33 (HMR #33) [9] upon the catchment.Studies show that the maximum sustained wind velocities in one general direction during major windstorms of record in most regions of the United States have averaged approximately 40 to 50 mph for a period of one hour [10]. In accordance with regional precedents set by the Corps of Engineers, wind tide and wave runup have been evaluated by procedures outlined in Engineering Technical Letter No. 1110-2-8 [10] using an overland wind velocity of 40-mph. Detailed analyses are  described in Section 2.4.3.6
.Other events considered include the effect of domino-type failure of Morris Sheppard and DeCordova Bend Dams, and the effect of a 30-minute 80-mph wind coincident with the 10-year return period flood and with the maximum operating pool level. The domino-type failure is shown CPNPP/FSAR2.4-6Amendment No. 106 in Section 2.4.4.3 to have no effect on CPNPP or on Squaw Creek Dam. On SCR wave runup due to an 80-mph wind is shown in Section 2.4.3.6 to be less critical than for a 40-mph wind coincident with the PMF.Events considered, but not applicable to CPNPP facilities include  surge, tsunami, and ice flooding. Landsliding and/or reservoir slope failures are not an expected source of floodwaves. Natural slopes are  3:1 (Horizontal to Vertical), or flatter, except for occasional local portions of slope which are steeper (ranging to 2:1 or 1:1). Slope  failures are improbable, but small localized sloughs conceivably might occur from erosion and/or weathering of the exposed edges of claystone seams from beneath overlying, more resistant rock zones. The small waves resulting from such failures will not adversely affect CPNPP facilities.2.4.3PROBABLE MAXIMUM FLOOD (PMF) ON STREAMS AND RIVERS The PMF is defined by the Corps of Engineers as the "hypothetical flood characteristics that are considered to be most severe 'reasonable possible' at a particular location, based upon relative comprehensive hydrometeorological analyses of critical runoff producing precipitation and hydrologic factors favorable for maximum flood runoff."  The PMF for the SCR catchment has been derived synthetically, using procedures customarily applied by the U.S. Army Corps of Engineers. Results of the evaluations are summarized in Table 2.4-11 and Figure 2.4-9
.The flood routings for Squaw Creek Reservoir and Safe Shutdown Impoundment include allowance for rainfall on the surface of the reservoirs and the rainfall volumes are tabulated in Tables 2.4-11 and 2.4-15.The nearby Brazos River has not been evaluated in detail for PMF because postulated upstream dam breaks are shown in Section 2.4.4 to be harmless to CPNPP facilities.2.4.3.1Probable Maximum Precipitation (PMP)
The PMP is the theoretically greatest precipitation over the applicable drainage area that would produce flood flows which have virtually no risk of being exceeded. From HMR No. 33 [9], it is found that the PMP is 25.5 inches in six hours on an area of 64 square miles in the CPNPP vicinity. Similarly, the PMP is 31.3 inches in 12 hours, 34.7 inches in 24 hours, and 39.1 inches in 48 hours. Table 2.4-11 lists the three hour rainfall increments, as divided for analyses.For comparative purposes, a statistical method for estimating the largest rainfall likely to occur at a gaging station was applied to the nearby gaging stations shown on Figure 2.4-6
. This procedure, developed by Hershfield [11], employs analyses of rainfall records to develop a statistical envelope defining the maximum precipit ation occurrence. The method is applied to rainfall records from a single  station, and a 24-hour estimate of maximum precipitation for that station is found. Results of analyses are compared to the 24-hour PMP and the maximum recorded rainfall in Table 2.4-12
.The amount of moisture present in the soil before the advent of the PMP, commonly referred to as the antecedent condition, is of importance in determining the amount of runoff produced by the PMP. The U.S. Bureau of Reclamation recommends "average" antecedent conditions [12]. Average conditions are defined as "the average of the conditions which have preceded the occurrence of the maximum annual flood on numerous watersheds."  The actual conditions CPNPP/FSAR2.4-7Amendment No. 106assumed become relatively unimportant when considering 48-hour design storms because the initial 24-hour period of light rainfall saturates the ground prior to periods of intense rainfall.The catchment area and site vicinity are gently to steeply rolling in character, with somewhat incised stream and river valleys. Relative relief is modest and does not require modification of the PMP value, or distribution, to account for orographic effects. Sub-basins within the SCR catchment are small; thus, catchment response to precipitation is relatively rapid. Therefore, postulation of storm centering is not of major importance, and the storm can be assumed to have uniform  distribution and intensity over the entire catchment.A comprehensive study of floods in Texas [5] indicates that snowmelt does not contribute significantly to river floods anywhere in the  state. Similarly, no frozen-ground conditions are anticipated.2.4.3.2Precipitation LossesPrecipitation losses are estimated by evaluating the in itial losses and the infilt ration rates of the soils in a watershed. Evaluation of losses reveals that initial losses can be expected to be in the range of 0.5 inches with average antecedent conditions; and infiltration rates after presaturation
 
will be in the range of 0.05 to 0.15 inches  per hour. The PMF selected utilizes an initial loss of 0.5 inches and a conservative infiltration ra te of 0.1 inch per hour as shown in Table 2.4-11
.These losses are based upon Corps of Engineers records for the Paluxy catchment shown below [13]:These values are indicative of the magnitude of precipitation losses expected on the SCR catchment due to its similarity to the Paluxy watershed in regard to general topography, geology, soil types and land usage. The values require evaluation, however, in light of some differences between the two watersheds, including:  1) the SCR catchment is generally not as steep as the Paluxy watershed; 2) the SCR watershed is much smaller; and 3) much of the relatively level,
 
low-lying portion of the SCR catchment will be inundated by the reservoir.Although the first difference described above tends to increase the precipitation losses on the SCR catchment in relation to that of the Paluxy River, the other two differences indicate a decrease in losses. Smaller drainage areas, such as the SCR catchment, generally have lower losses than larger areas, and submergence of much of the creek alluvium removes a section of the catchment which should have the most  infiltration capacity. Thus, it is prudent to adopt lower estimates of losses on the SCR catchment. This conclusion is further supported by the relatively short duration of the available historical storms  studied, in comparison to the 48-hour storm used Losses (inches)
Date ofFloodRainfall(inches)Duration(hours)Initial(1st 3 hrs)BalanceTotalSteady Loss(in/hr)05/23/52 4.19 15 .85 2.243.09 .18704/06/57 2.94 12 .47 1.361.83 .151 CPNPP/FSAR2.4-8Amendment No. 106in computing the PMF. In view of these factors, an initial loss estimate of 0.5 inches and an infiltration rate of about 0.1 inch per hour is considered appropriate for the catchment.2.4.3.3Runoff Model 2.4.3.3.1Description of Squaw Creek Reservoir Catchment Figure 2.4-1 illustrates the 64-square mile SCR catchment and the reservoir limits corresponding to a selected flood-stage at Elevation 780 feet.The pre-flood condition reservoir level is assumed to be Elevation 775 feet.During the PMF, pool level will rise from Elevation 775 feet (area 3,272 acres) to Elevation 789.7feet (area 3,863 acres).2.4.3.3.2Synthetic Hydrographs Synthetic methods for developing a runoff model have been undertaken. Three methods of synthetic hydrograph develo pment were considered:1.Use of Snyder's Unit hydrograph relations presented by the U.S. Army Corps of Engineers (USACE) [14].2.Use of dimensionless hydrographs presented by the Soil Conservation Service (SCS) [14].3.Use of triangular hydrograph techniques presented by the U.S. Bureau of Reclamation [12].The empirical relations developed by Snyder have also been shown to be  reliable through widespread usage. To employ this method, two coefficients which depend upon drainage basin characteristics are computed from hydrologic records for a representative portion of the  drainage area under study, or for nearby catchment of similar characteristics [15]. Snyder's method was adopted for development of a runoff model for Squaw Creek.2.4.3.3.3Hydrograph DevelopmentFor purposes of analyses, the SCR catchment has been divided into three areas, as shown on Figure 2.4-1 and described below:1.The Upper Squaw Creek catchment, which consists of about 38 square miles of land located above the reservoir area.2.The Lower Squaw Creek catchment which consists of about 20.3 square miles of land located around the fringes of the reservoir. This area is actually comprised of a number of very small catchments, which are considered together for reasons of clarity and convenience.3.The Squaw Creek Reservoir Area CPNPP/FSAR2.4-9Amendment No. 106The Corps of Engineers has developed unit hydrographs from gaging station records for two nearby watersheds, the Paluxy River and the  Clear Fork of the Trinity River. The pertinent data from these studies [13] is summarized below:The lower portion of the SCR catchment (see Figure 2.4-1) is generally similar to the Paluxy River watershed. The upper portion is considered to have characteristics falling between those of the Paluxy River and Clear Fork. These considerations lead to the adaptation of the following coefficients for the SCR catchment:All other information needed to apply Snyder's relationships (such as area, length, and center of gravity of the catchments) has been derived  from U.S.G.S. quadrangle maps. These data are
 
summarized in Table 2.4-13
.The unit hydrographs are shown in Figure 2.4-10
.2.4.3.3.4Non-Linearity High rainfall rates associated with intense storms may result in above normal concentrations of runoff (non-linearity) because of a more severe rainfall distribution and increased hydraulic efficiencies.The USACE recommends increasing hydrograph ordinates by 25 to 50 percent during the period of most intense rainfall [14]. In view of this, the hydrograph for the upper SCR catchment was increased by 30 percent during the most intense period of rainfall (See Table 2.4-13
). This magnitude of increase is considered applicable for a drainage basin of 38 square miles.2.4.3.3.5Translation of InflowsThe size and shape of the reservoir in relation to the catchment area suggest that there will be no significant translation time from inflow points to the dam and CPNPP site locations; accordingly, no delay is introduced into the computations.Drainage Area (Sq. Mi.)Paluxy River361.60420 Clear Fork(upper portion)2101.50480 BasisUpper 38.0 Sq. Mi.1.1440 Combination of Paluxy& Clear ForkLower 20.3 Sq. Mi. .3420Paluxy CPNPP/FSAR2.4-10Amendment No. 1062.4.3.4Probable Maximum Flood FlowThe PMF inflow and outflow hydrographs to SCR resulting from the PMP are presented in Figure2.4-9. As explained in Section 2.4.3.1, snowmelt was not considered in establishing the PMP.Except for a few existing small farm ponds, there are no present or planned structures upstream of SCR; therefore, the effect of such structures was not considered in developing the PMF hydrograph.The PMF was routed through the SCR assuming the reservoir level at the beginning of the PMF was at elevation 775, the service spillway crest elevation. All discharge was assumed to occur over the uncontrolled spillways of Squaw Creek Dam.The current SCR operating practice (see Section 2.4.8.2.1) of pumping makeup water to cause a small flow over the service spillway may routinely raise the SCR level. This small SCR level increase and the resulting small flow over the service spillway is negligible when combined with the maximum postulated precipitation and flooding analysis results and has insignificant impact on the PMF peak reservoir level.All streams in the SCR basin empty directly into SCR; therefore no channel routing coefficients were required. The applicability of the stream course response model to handle the PMF is discussed in Section 2.4.3.3.4. The ability of the SCR dam to withstand the PMF and coincident wave action is discussed in Section 2.4.3.6
.2.4.3.5Water Level Determinations The mass curve, the capacity-area-depth curves, and the spillway rating curves (Figure 2.4-9
) are used in routing the PMF through the reservoir to evaluate water level. The resulting peak reservoir level is Elevation 789.7.In routing, the reservoir water surface has been assumed to be nearly horizontal, and the volume of water in the reservoir has been assumed to be directly related to the reservoir elevation. These are  reasonable assumptions in view of the shape and depth of the SCR. These assumptions allow the principle of continuity expressed as a storage equation  where  and  are the average rates of inflow and outflow for the time t, and s is the change in water volume during time t) to be applied directly to the routing problem [16].2.4.3.6Coincident Wind Wave ActivityThe magnitude of the wind tide and wave runup are dependent upon the  wind velocity, fetch and reservoir depth. The wind direction must coincide with the fetch direction. An overland wind velocity of 40 miles per hour has been approved by the USACE for use in determining freeboard requirements in the Fort Worth District. This 40 mph wind velocity is the highest that may reasonably be assumed to occur coincidentally with the probable maximum flood [17].The effective fetch length for wave generation was determined for the center of Squaw Creek Dam (fetch of 1.28 miles) and for the exposed side of the CPNPP plant location (fetch of 1.25 (Itst,=-I CPNPP/FSAR 2.4-11Amendment No. 106miles). It was also determined for the Safe Shut down Impoundment Dam and the protected side of the CPNPP plant location, but freeboard requirements were found to be less than two feet for these locations, so discussion is not included here. Computation of effective fetch considered radial lines at angles up to 42 degrees from the central or primary fetch line, as recommended by the USACE [10].The average depth of the reservoir at PMF, Elevation 789.7 feet, is approximately 55 feet, and the longest theoretical deep-water wave length (for waves reaching the center of Squaw Creek Dam) is 46 feet, so the ratio of water depth to wave length is well over one-half, and the reservoir can be considered to have "deep water" [10].Computation [10] utilizing data for wind velocity, fetch length, and reservoir depth yield the results shown in Table 2.4-14. The Table illustrates the maximum runup and setup of smooth and riprapped banks on the Squaw Creek Dam and at the exposed side of the CPNPP plant area. As can be seen from the Table, wave runup and wind tide at the dam and plant are about 4 and 5.0 feet and elevations reached are 793.7 feet and 794.7 feet, respectively. Due to the much shorter fetch available around the area, water level elevation reached at the SSI is about 791.3 feet. All plant facilities are above the maximum wave runup and setup elevation of 794.7 feet. The Service Water Intake Structure is the only safety-related structure subject to wave action. The
 
elevation at the operating deck is approximately 796, above the maximum expected wave runup.
Section 2.4.10 discusses the effect of wave runup and wind tide on all pertinent safety-related facilities.2.4.3.7Flood Evaluations for Safe Shutdown Impoundment Water can pass freely between the SSI and SCR, and the wat er surface in both water bodies normally will be at the same elevation. Figure 2.4-11 is a graph of the discharge characteristics of the SSI spillway. Table 2.4-15 outlines predicted performance of the SSI during occurrence of  simultaneous Probable Maximum Floods on the overall SCR watershed and  the SSI watershed. The maximum level reached in the SSI during the PMF is computed to be 790.5 feet, leaving a freeboard in the SSI of 5.5 feet. Further details on the Safe Shutdown Impoundment Dam are given in Section 2.4.8.2.2
. Table 2.4-16 gives the unit hydrograph parameters for the SSI watershed, and Figure 2.4-12 shows the unit  hydrograph for the SSI watershed. A non-intrusive, floating raft system has been located near the south end of the equalization channel. This floating raft system bridges from the east bank to west bank of the channel. The raft system is retained at its designated position through the use of bollards on the banks of the channel. These bollards function as bumpers for the raft system. Should the equalization channel experience flooding conditions, the floating raft system is designed to freely float on the water surface, even if the floats are punctured. If the water level exceeds an elevation above approximately elevation 781 feet, the raft system will float over the bollards and, due to the direction of flow through the channel, the raft system will be pushed away from the SSI and into the SCR. As a result, this floating raft system will not affect the design function of the equalization channel to freely pass water to the SCR under flooding conditions up to a PMF.
CPNPP/FSAR2.4-12Amendment No. 1062.4.4POTENTIAL DAM FAILURES (SEISMICALLY INDUCED)There are no impoundments other than small farm ponds on the SCR catchment; therefore, a postulated dam failure upst ream on Squaw Creek is not appropriate for the CPNPP facilities. The farm ponds on the catchment have a combined volume which is less than one percent of the reservoir volume and are insignificant.Failure of Squaw Creek Dam itself presents no danger of flooding the  CPNPP, as the Station is above the PMF water level. The possibility of damage to Squaw Creek Dam by backwater due to flooding on the Brazos River in the event of a postulated domino-type failure of Morris Sheppard Dam and DeCordova Bend Dam is ruled out in Section 2.4.4.3
.2.4.4.1Reservoir Description Present and possible future reservoirs which might be considered to have an influence on the site from a safety or water-supply standpoint are described in Tables 2.4-1 through 2.4-3, and their locations are shown in Figures 2.4-5 and 2.4-6.2.4.4.2Dam Failure PermutationsConsidering CPNPP safety, the most severe dam failure permutation conceivable is the failure of Morris Sheppard Dam and the subsequent domino
-type failure of DeCordova Bend Dam. The 25-year floods of both the Brazos and Paluxy rivers can be added into the effects of the combined dam breaks without significantly intensifying the results. Failure of the Lake Whitney Dam, downstream, would not have an adverse effect on CPNPP.The detailed analysis of the most severe dam failure permutation is presented in Section 2.4.4.3 and the effect of landslides into the reservoir is discussed in Section 2.4.2.2
.There will be no commercial water traffic on SCR, and no possible blockage of any water course in the site region could affect the plant.2.4.4.3Unsteady Flow Analysis of Potential Dam FailuresThe possibility of damage to Squaw Creek Dam due to failure of Morris Sheppard Dam and DeCordova Bend Dam was examined by initiating a number of highly conservative simplified evaluations which would establish conservative water levels. The results of these studies clearly indicate that there is no possibility of flood damage to the CPNPP site and Squaw Creek Dam.
The toe of Squaw Creek is above Elevation 640 feet, approximately 60 to 90 feet higher than the bankfull elevation of the Brazos River at the Brazos River - Paluxy River confluence (Elevation 560 feet). The maximum wave height that could be generated by complete and instantaneous removal of DeCordova Bend Dam is about 37 feet, according to dam break calculations described in Section 2.4.4.3.3
.Prior failure of Morris Sheppard Dam is not expected to increase this wave height significantly due to the modifying effects of 145 miles of river channel between Morris Sheppard and DeCordova Bend Dams. Although calculations (
Sections 2.4.4.3.1) show that a wall of water over 60 feet high would be initiated by the complete and instantaneous removal of Morris Sheppard Dam, routing by the method of coefficients (Section 2.4.4.3.2
) shows that the wall would have decayed during translation to DeCordova Bend Dam. Rather, there would be a flood, CPNPP/FSAR 2.4-13Amendment No. 106the peak of which would arrive some five hours after initial inflow to Lake Granbury reservoir had begun. The break in the DeCordova Bend Dam is postulated to occur when the reservoir level becomes full. Therefore, the reservoir inflow from an upstream dam break would serve to sustain the high rate of outflow through the break in DeCordova Bend Dam rather than to increase the initial outflow (height of water wall) significantly.Even with the ultra-conservative assumption that the combined wave created by the dam breaks remained undiminished in traveling below  DeCordova Bend to the Paluxy River - Brazos River confluence, the flood wave would fall more than 40 feet (elevation) short of reaching the toe of Squaw Creek Dam.In view of the highly conservative assumptions made in the following  flood analyses, the results are regarded as a very conservative upper limit on the river level in the event of the domino-type failure, rather than a refined estimate of the flood to be expected.
2.4.4.3.1Morris Sheppard Dam Break Evaluation assumptions:1.Complete and instantaneous removal of dam.
: 2. 3.Channel is frictionless, rectangular and horizontal.4.No water downstream of dam.5.Vertical accelerations are negligible These highly conservative assumptions a llow the following analysis to be made, using the method shown by Henderson [19] and Chow [20].Crest Velocity=(gy)1/2    *=((32.2 ft/sec
: 2) x (145 ft))
1/2=46.5 mph CPNPP/FSAR2.4-14Amendment No. 1062.4.4.3.2Routing From Morris Sheppard Dam to DeCordova Bend DamTravel times for floods between Morris Sheppard Dam and DeCordova Bend Dam cannot be determined with accuracy because of such factors as incidence of rain and runoff accumulation within the reach. However,  there are some data regarding water movement on the river. It has been found that it takes about two days for normal turbine releases from Morris Sheppard Dam to reach DeCordova Bend Dam [3]. This is equivalent to a velocity of under three mph. Flow travel time studies on the Brazos River between Lake Whitney and Richmond show that velocities vary between 1.6 mph and 3.8 mph. Travel time is greatest for low flows and least for small floods, and then increases again as flows become very large [21]. These data are inconclusive but they seem to indicate that the average velocity of flow from a dam break would be in the order of three
 
or four mph.Trough Velocity (velocity of wave downstream)=2 (gy)1/2=2 x (46.5 mph)=93 mphVelocity of water through dam site=2/3 (gy)1/2=2/3 (46.5 mph)=31 mphDischarge=8/27 (g) 1/2y3/2W=8/27 (32.2 ft/sec 2)1/2 (145 ft) 3/2(1600)=4,700,000 cfsTime of constant discharge (assuming discharge will remain until lake is empty)=600,000 ac-ft/(.0826 ac-ft/cfs-hr) (4,700,000 cfs)
=1.5 hours wheret=length of time interval, in this case one hour.
X=a constant dependent upon channel characteristics.g=acceleration of gravityy=height of water surface exposed upon dam removal CPNPP/FSAR 2.4-15Amendment No. 106The length of river channel required to reach a terminal velocity is not known; therefore, in the evaluations the flow from the Morris Sheppard Dam Break has been conservatively assumed to continue unbated at 31 mph, the theoretical velocity of flow through the dam section.The distance traveled to Lake Granbury is 144.5 miles, and the lake is 33.5 miles long; therefore, travel time is indicated to be on the order of five hours, with one hour of this being flow along the reaches of Lake Granbury.Routing was by the method of coefficients (Muskingum) [22] through a reach using total flood-wave travel equal to 4xt* and an X* of 0.3  (deemed appropriate for a wide rectangular channel where changes in discharges are small) and through a reach using total flood-wave travel equal to t and an X of zero (for reservoir-type storage routing). This evaluation yields an outflow hydrograph having a base time of over 12  hours and a peak flow of about 1,900,000 cfs, well under half of the theoretical initial discharge of 4,700,000 cfs.2.4.4.3.3DeCordova Bend Dam Break Assumptions made:1.DeCordova Bend Dam holds until lake level reaches top of dam.
2.Complete and instantaneous removal of dam.
: 3. 4.Channel is frictionless, rectangular and horizontal.5.No water downstream of dam.6.Vertical accelerations are negligible.
These highly conservative assumptions allow the following analysis to be made: Crest Velocity=(gy)1/2=(32.2 ft/sec 2 (84 ft))1/2=52 ft/sec=35 mph CPNPP/FSAR 2.4-16Amendment No. 106Assuming no inflow, the 2,800,000 cfs discharge would empty Lake Granbury in less than a half hour. But the inflow from Possum Kingdom Reservoir would provide additional water to maintain the 2,800,000 cfs flow for two hours. After the two hour period, flow would diminish until the remaining 65,000 acre feet are discharged.2.4.4.3.4Routing from Decordova Bend Trough Velocity=2 (gy)1/2=2 (35 mph)=70 mphVelocity of water through dam site=2/3 (gy) 1/2=2/3 35
=23 mphDischarge=8/27 (g) 1/2y3/2w=8/27 (32.2 ft/sec 2)1/2(84 ft) 3/2(2200 ft)=2,800,000 cfs Depth of water at dam site=4/9 Y=4/9 (84 ft)=37 ftTheoretical time of discharge
===2 hours2()length of lake
()velocity of wave
()------------------------------------------------
-2()33.5 mi()35 mph--------------------------------
-
CPNPP/FSAR 2.4-17Amendment No. 106 Thus, there is no possibility of dam breaks on the Brazos River affecting the safety of the CPNPP.In the event that other dams are constructed between Morris Sheppard Dam and DeCordova Bend Dam, their presence should in no way endanger the safety of the CPNPP, even in the case of a domino-type failure.
2.4.4.3.5Consideration of Antecedent FlowIn the preceding description of analyses, river channels have been assumed to be dry. Inclusion of water in the river (antecedent flow) would not have a significant effect on the results of the dam break analyses. For example, the 25-year flood on the Brazos River would contribute only about 90,000 cfs (refer to Figure 2.4-13), which is only 3.2 percent of the theoretical flow from the dam breaks.2.4.4.4Water Level at CPNPPThe Station site can in no way be endangered by any dam breaks or series of dam breaks, as it is over 110 feet above postulated maximum water levels.2.4.5PROBABLE MAXIMUM SURGE AND SEICHE FLOODING2.4.5.1Probable Maximum Winds and Associated Meteorological ParametersThe probable maximum sustained over-land wind selected for evaluation of wave action of the maximum operated reservoir elevation is 81 mph. The wind has an estimated return period of 200 years [23].2.4.5.2Surge and Seiche History There are no existing large bodies of water near the site that would allow development of either surge or seiche; therefore, there is no history of surge and seiches in the site vicinity.
CPNPP/FSAR2.4-18Amendment No. 1062.4.5.3Surge and SeicheThe small size, relatively shallow depth and irregular shape of Squaw Creek Reservoir indicates that there is a minimum probability of either surges or seiches occurring in the reservoir.
Therefore, surge and seiche should not be considered significant at this site.2.4.5.4Wave Action The effect of the maximum sustained wind on the reservoir surface has been evaluated in Section 2.4.5.1. This wind is considered coincident with a 10 year return period flood elevation in Squaw Creek (778.1 feet). Results of the wind wave activity calculation are presented in Table2.4-14. With an effective fetch of 1.28 miles, computations indicate that the significant wave height will be approximately five feet with a period of 3.9 seconds. The maximum wave height will be about eight feet with a setup of 0.2 feet and runup of 6.8 feet [10].This will occur at Squaw Creek dam as illustrated in Table 2.4-14
.The wind penetrated waves on the SSI are less than those on SCR due to  the much shorter fetch available around the SSI area (see Figure 2.4-14
, Figure 2.4-15 and Table 2.4-14
).2.4.5.5ResonanceDue to the irregular shape and sloping sides of SCR and SSI, wave resonance will not have any significant effect on the maximum water elevation.2.4.5.6Runup The maximum water elevation reached due to wave runup and setup at the plant site, Squaw Creek dam and SSI dam are 794.7 feet, 793.7 and 791.3 feet, respectively. All plant facilities will be above the maximum wave runup elevation of 794.7 feet.The Service Water Intake Structure will be the only safety-related structure subject to wave action or wave runup. The operating deck will be approximately elevation 796', well above the maximum expected wave runup.2.4.6PROBABLE MAXIMUM TSUNAMI FLOODINGThis site is nearly 300 miles from the Gulf of Mexico and the plant will be over 800 feet above sea level. Therefore, tsunami flooding  will not occur.2.4.7ICE FLOODING The Texas climate is too warm to allow the development of significant ice on any lake. Certainly there are no records of any major river in Texas freezing over at any time, so the possibility of ice
 
flooding can be discounted.
CPNPP/FSAR 2.4-19Amendment No. 1062.4.8COOLING WATER CANALS AND RESERVOIRS2.4.8.1Canals No canals are involved.2.4.8.2Reservoirs 2.4.8.2.1Squaw Creek Reservoir (SCR)SCR is a cooling lake for CPNPP. The location and configuration of the reservoir are shown in Figures 2.4-5 and 2.4-6. Table 2.4-17 gives the area and capacity characteristics of the SCR site, based on planimeter measurements from U.S. Geological Survey quadrangle maps entitled Hill City, Texas, and Nemo, Texas, scale 1:24,000. The volumes and areas indicated are those of the entire reservoir, including the reserve storage within the Safe Shutdown Impoundment (SSI) described in Section 2.4.8.2.2 below. The performance capability of SCR as operational cooling pond was evaluated through mathematical modeling as documented in Reference [40].
During some periods and especially in summer months, the pumping of makeup water may be utilized to raise the level of SCR above the crest of the service spillway to keep a small flow of SCR water going over the crest of the service spillway even in the absence of rain. This practice enhances the cooling capacity of the reservoir.1.Squaw Creek Dam 2.Spillways
 
CPNPP/FSAR 2.4-20Amendment No. 106 Design bases for the service spillway at Squaw Creek Dam are as follows:Design for rip-rap lining on the sides of the discharge channel of the service spillway was determined using U.S. Army Corps of Engineers EM  1110-2-1601 (1 July 1970) and supplemental ETL 1110-2-120 (14 May 1971) along with U.S.A.E.W.E.S. Hydraulic Design Chart 712-1 (Revised  September 1970). Unit weight used for rip-rap stone was 145 pcf. Average velocities of water flow were determined from backwater analyses starting at the confluence of the discharge channel with Squaw Creek and progressing through the channel to the stilling basin.Velocities ranged from 16.2 fps in the lower reach of the channel to five fps just below the stilling basin. The termination of the rip-rap at the end of the discharge channel was designed based on the possibility that future stream bed degradation in Squaw Creek could cause critical depth of flow at the end of the rip-rap lining with a corresponding local flow velocity of 18.5 fps. Rip-rap bedding beneath the stone layer was designed as a filter to prevent migration of soil or bedding material through the slope protection layer. The bottom of the channel is sound limestone and did not require rip-rap protection.The emergency spillway discharges into a tributary of Squaw Creek whose confluence with Squaw Creek is 7,000 feet downstream of the dam. A water surface profile in Squaw Creek showed that the water level at the toe of the dam will reach Elevation 656.0 during a Probable Maximum Flood. The tributary, through which the emergency spillway discharge will flow, is separated from the dam by a large hill composed of a thin overburden overlying limestone. The Squaw Creek Dam embankment will not be endangered by flows through the emergency spillway.a.Spillway width:b.Design Head:
c.Crest elevation:
d.Depth of approach channel below crest:
e.Slope of upstream face of weir:
f.Type of spillway crest:
g.Manning's "n" of approach channel:(Ref:  EM  1110-2-1603)h.End contraction effects from Engineering Manual Part CXVIi.Entrance loss assumed to be 0.1 V**2/2g for approach channel j.Coefficients of Discharge from Figure 251, Design of Small Dams, 1973 Edition CPNPP/FSAR 2.4-21Amendment No. 106Design bases for the emergency spillway at Squaw Creek Dam are as  follows:The emergency spillway at Squaw Creek Dam is not lined. A concrete wall at Elevation 783.0 on the emergency spillway crest serves as the spillway's erosion control structure. Its purpose is to maintain a uniform elevation for the entire length of the crest. The wall is anchored in limestone.
The maximum velocity along the emergency spillway during a Probable Maximum Flood is 10fps. Velocities at the downstream edge of the spillway will be higher. These velocities will cause some erosion damage. The erosion will not be severe since the emergency spillway cut is into limestone. In places, surface materials (up to 2 feet thick) overlying the limestone consist of softer materials, graded for drainage. The frequency of operation of the emergency spillway is in excess of 100 years. The erosion damage will not endanger the dam or reduce its storage capacity.
Location of the spillways are indicated on Figure 2.1-2
.3.Flood LevelsRouting of the PMF through the reservoir has been discussed in detail under Section2.4.3. The maximum high water level during the PMF would be Elevation 789.7, leaving a freeboard allowance of 6.3 feet, which is more than adequate to accommodate wave runup and wind tide on rip-rapped slopes as shown in Section 2.4.3.6
.In order to evaluate the probable frequen cy of flows through the emergency spillway cut, inflow hydrographs were also computed for  floods having 50-year and 100-year probable recurrence intervals, using rainfall data dev eloped for those frequencies by the U.S. Weather Bureau [24]. It was found that the 100-year flood would involve less total runoff than the volume of surcharge storage available between the crest of the service spillway and the crest of the emergency spillway, and that the 100-year storm would, therefore, not cause flow through the emergency spillway.4.Brazos River Diversion SystemSupplemental water from Lake Granbury on the Brazos River will be conveyed by pipeline to SCR when required.
The pipeline is 48 inches in diameter, with a design delivery capability of 65.1 million gallons per day (MGD). To allow for one pumping unit a.Spillway width:b.Crest elevation c.Length of level section at elevation 783.0:d.Slope of spillway downstream from level section:e.Manning's "n" of spillway channel:(Ref:  Chow:  Open-Channel Hydraulics)f.Side slopes:1 vertical on 3 horizontalg.Entrance loss assumed to be 0.1 V**2/2g.
CPNPP/FSAR 2.4-22Amendment No. 106being temporarily out of service, the station includes four pumps with 21.7 MGD of rated capacity each, for a total installed name-plate capacity of 86.8 MGD.5.Service Outlet Service outlet facilities are located at the right (south) abutment of the dam and consist of an intake tower and outlet conduit. The tower has ports at various levels in the reservoir to allow selective taking of water. Backup closure facilities are provided to protect against loss of storage due to inability to close a valve or a gate.2.4.8.2.2Safe Shutdown Impoundment (SSI)A portion of the arm of the reservoir that is formed by the channel of Panther Branch is utilized as a Safe Shutdown Impoundment, holding  water for normal and emergency cooling use. The area and capacity characteristics of this cooling water pond are given in Tables 2.4-18 and 2.4.19. The secondary reservoir is separated from the main body of the reservoir by a rock-fill dam. An open channel was excavated through the narrow ridge to the southwest of the SSI Dam to connect the SSI with the main body of the reservoir. The floor of the channel is at elevation 769.5, six inches below the normal minimum operating level, and under normal operating conditions water will pass back and forth to keep the large and small reservoir surfaces at the same elevation. If the level in the main reservoir should drop due to some emergency, the SSI Dam will hold back between 284 acre-feet and 367 acre-feet of reserve water to allow continued cooling and safe shutdown of the plant.Details of the SSI Dam embankment are shown in Figure 2.4-21. The  middle zone is of select, impervious material, wetted and rolled and ca rried down to impervious foundation material for effective cut-off.
Design bases for the spillway at the Safe Shutdown Impoundment are as follows:The spillway channel is in limestone and is unlined. The velocity through the spillway will reach 10.3 fps. A concrete erosion slab was constructed in the channel to maintain the control  level at elevation 769.5.a.Spillway width:b.Side Slopesc.Slope of Spillway channel:
d.Manning's "n" of spillway channel:(Ref:  Chow:  Open-Channel Hydraulics)e.Entrance loss assumed to be 0.1 V**2/2gf.Exit loss assumed to be V**2/2g CPNPP/FSAR2.4-23Amendment No. 106The rock used to construct the outer zones of the SSI dam was selectively quarried and processed from planned plant site excavations to produce a reasonably well graded product conforming to the limits shown on Figure 2.5.6-12
. Basic consideration in selecting the rock gradation were seismic performance and protection of the interior filters. Normal construction techniques for the rock fill resulted in larger rock sizes accumulating on t he outer edges of the slopes. Analysis of wave protection requirements was based on an average over-water wind of 81 mph (probable maximum wind - 200 year frequency) over the effective fetch distance. The method of computing the effective fetch distance set forth in Department of Army, Office of the Chief of Engineers ETL 1110-2-221, 29 November 1976, was adopted. Comparison of the as constructed conditions with conventional rip rap protection requirements as set forth in EM-1110-2-2300 (1 MARCH 1971) indicates adequate protection. To assure continued performance of the SSI, the planned annual inspection (see Section 2.5.6.8.1) of the dam will specifically include observations of slope protection.Estimated sediment production from the Panther Branch watershed above the SSI during the 40-yr projected service life of CPNPP was derived based on analytical procedures for small watersheds as described in Reference [38]. The anticipated reduction in storage capacity of the SSI during that period due to accumulation of sediment was found to be 91 ac-ft, of which 85ac-ft would be below elevation 770.0 and the remaining 6 ac-ft between elevations 770.0 and 775.0. Comparative plots of area and capacity characteristics before and after sedimentation are
 
shown in Figure 2.4-22
. Table 2.4-19 outlines the predicted area and capacity values at the end of the 40-year period.Inspections of the service water intake channel for sedimentation buildup will be performed at the frequencies stated in Regulatory Guide 1.127. This inspection will consist of a direct measurement of sediment depth at the bottom of the intake channel at a minimum of five locations along its length. Measurements will be taken at approximately the same location each time the inspection is performed. If it is determined that, as a result of these inspections, the sediment has accumulated enough to increase the bottom elevation one and one-half (1.5) feet over the entire length of the inspection area,  then measures will be employed to remove the sediment from the intake channel. At that time, procedures will be developed and approved to accomplish this task. A detailed layout of the SSI design features is given in Figure 2.4-23
.Seismic Design Criteria for the SSI are discussed in Section 3.7
.The ability of the SSI to meet criteria of Regulatory Guide 1.27 is  discussed in Section 9.2.5
.2.4.9CHANNEL DIVERSIONS
 
The SCR catchment has developed streams with distinct valleys and has sustained numerous farm ponds. Therefore, diversion of water from the catchment appears impossible. The reservoir is formed in the Glen Rose formation, a predominately limestone sequence. Information developed regarding this formation indicated it is relatively impermeable and free of sinkholes and solutioning. Thus, sign ificant loss of water is improbable.Lake Granbury, which is on the Brazos River, will be a major source of makeup cooling water.
The loss of Lake Granbury makeup water due to t he diversion of the Brazos River is highly CPNPP/FSAR2.4-24Amendment No. 106improbable. Above Lake Granbury, the Brazos River channel is cut into bedrock which precludes any reasonable possibility of the river changing its channel significantly within the life of the CPNPP and thus affecting the supply of water.Extraction of groundwater, oil, and gas from the region is relatively nominal. It is concluded that subsidence sometimes associated with these extractions will not occur in the vicinity of the CPNPP. The potential of subsidence at the site is discussed in detail in Section 2.5.1.2.6
.2.4.10FLOODING PROTECTION REQUIREMENTSSafety-related structures, except the Service Water Intake Structure and the Electrical and Control Building, are not subject to flooding, wave action, or wave runup and do not require flood or wave protection. The plant grade is at elevation 810 ft, and the peak SCR level is at elevation 789.7 ft for the probable maximum flood (PMF).  (See Section 2.4.3.3.1
)The Service Water Intake Structure is protected from the effects of  wind wave activity on the Squaw Creek Reservoir by the Safe Shutdown Impoundment (SSI) Dam. An overland 40-mph wind is assumed to occur coincidentally with the SSI PMF level of 790.5 ft. Since the wind wave activity at the Service Water Intake Structure is negligible, there are no significant dynamic forces to be considered.  (See Section 2.4.5.)  The design hydrostatic load includes the maximum runup elevation (see Section 2.4.3.6) caused by the 40-mph wind coincident with the PMF.Design criteria for the Service Water Intake Structure are discussed in Section 3.8.4.1.4. The Electrical and Control Building would be subject to flooding if flood protection measures were not taken. These measures are described in Sections 3.4 and 13.5. It is not necessary to implement any other flood protection measures or emergency procedures.2.4.11LOW WATER CONSIDERATIONSThe SCR provides the cooling water for plant operation. In general, the combined amounts of natural and induced evaporation, plus releases for control of chemical quality, are more than the available runoff from Squaw Creek. Supplemental water will be brought from Lake Granbury on the Brazos River, in accordance with an agreement by and between Brazos River Authority and TP&L, TESCO, and DP&L, to hold the  reservoir at the required operating elevation [39]. This agreement has no limitations which could be plac ed on the water that wo uld have an adverse effect on safety-related makeup.2.4.11.1Low Flow In Rivers And Streams Low flow in Squaw Creek or in the Brazos River is not of concern to plant safety because station cooling water is obtained from SCR. Thus, low flow considerations are significant in terms of successful over-all plant operations, but are not safety-related.
CPNPP/FSAR2.4-25Amendment No. 106A study by the Texas Water Development Board indicated that from 1891 to 1960 Texas experienced 11 significant drought periods of vary ing severity and areal extent. Their ranking and time of occurrence are listed below:The 1954-1956 drought was the most severe and was immediately preceded by the fifth and seventh ranked droughts, comprising a continuous series of years of rainfall deficiencies. This series, 1950 through 1956, comprises the most intense seven-year drought period that the State as a whole has experienced within the 70-year period of rainfall records. Dendrochronological studies in the southwestern part of the United States suggest that the 1950-56 drought period ranks among the most severe droughts of the past 400 years. Results of the studies indicate that records of stream flows during the 1950-56 period provide a basis for evaluation of the dependable amounts of water which can be obtained from existing and proposed reservoirs [37].Detailed analysis of performance of SCR under the critical drought conditions of 1950 through 1956 [25] indicates a potential need for diversions from Lake Granbury ranging from 52,450 acre-feet per year. Of these amounts, an estimated 26,400 acre-feet per year would be returned at a steady rate to Lake Granbury in order to maintain proper balance of water quality in the two reservoirs. Thus, the net volumes of water taken from Lake Granbury during the drought would average 33,100 acre-feet per year and would range from a minimum of 26,050 acre-feet per year to a maximum of 38,260 acre-feet per year.Substantially more than the required amounts will be available to SCR from Lake Granbury under terms of an existing agreement with the Brazos River Authority. This agreement covers total use from Lake Granbury and/or Lake Possum Kingdom of 70,000 acre-feet per year. The dependable yield of Lake Granbury [26] has been evaluated as at least 69,200 acre-feet per year, exclusive of the additional yield which could be made available by releases from Lake Possum Kingdom. The 70,000 acre-feet per year of potential supply is more than adequate to provide the necessary net diversions to SCR, plus anticipated requirements of other facilities which might also draw on Lake  Granbury.1.Most Severe1954-19562.Second1916-19183.Third1909-1912 4.Fourth19015.Fifth19536.Sixth1933-1934 7.Seventh1950-19528.Eighth1924-19259.Ninth1891-189310.Tenth1937-193911.Eleventh1896-1899 CPNPP/FSAR2.4-26Amendment No. 106As a further check on the adequacy of the basic water supply for CPNPP, additional yield studies were carried out for Lake Granbury and Possum Kingdom Reservoir based on the years 1950-1957 and the following assumptions:1.Historical inflows to Possum Kingdom Reservoir during the years in question were reduced to reflect:a.Total exclusion of runoff that originated above Hubbard Creek Dam, White River Dam, Salt Creek Dam, and Millers Creek Dam. These are the projects which either have been completed since the drought years or are expected to be completed in the foreseeable future.b.Maximum utilization by the City of Abilene of the increase in diversion rights on the Clear Fork of the Brazos, granted by the Texas Water Rights Commission since the drought years.2.Releases of water from Possum Kingdom Dam for generation of hydroelectric power were reduced to a rate of 50,000 acre-feet per year, as compared with an average of approximately 350,000 acre-feet per year during the years of the study.3.Runoff originating above Lake Palo Pinto was excluded from inflows to the Brazos between Possum Kingdom and Lake Granbury.4.Historical losses of water in transit between Possum Kingdom and  the site of Lake Granbury were assumed to still occur, although  the releases from Possum Kingdom were substantially reduced.5.Reservoir storage capacities were reduced to reflect predicted siltation to about the year 2006.6.The studies were started with Lake Possum Kingdom assumed to be at the same elevation as actually experienced at the beginning of  1950, and Granbury was assumed to start at elevation 688.0, or five feet below the top of conservation storage.7.The seasonal pattern of hydroelectric releases from Possum Kingdom was based on the actual pattern of such releases during the years of the study. The seasonal pattern of demand at Lake Granbury was based on the combined requirements of Squaw Creek Reservoir and the fossil-fueled power plants which will also derive their cooling water
 
supply from the lake.Under these conditions, which are believed to be highly conservative, the studies show that Lake Granbury would provide a firm yield of 70,000 acre-feet per year by utilizing only the upper 51percent of the available conservation storage volume.2.4.11.2Low Water Resulting From Surges, Seiches or Tsunamis Not applicable (See Sections 2.4.5 and 2.4.6).
CPNPP/FSAR2.4-27Amendment No. 1062.4.11.3Historical Low WaterThe extreme variability of flow in the Brazos River is depicted through a flow probability curve (Figure 2.4-24
), which shows that the average discharge of 1,555 cfs at gaging station 8-0910 is equalled or exceeded only about 17 percent of the time [27]. This flow is modified by regulation of water by upstream reservoirs which tend to decrease the variability. The impact that upstream control has had upon flow extremes is indicated from data which show that the Brazos River was
 
known to dry up completely before construction of Possum Kingdom Reservoir and from Figure2.4-25 which shows the lessening of annual flood events subsequent to Possum Kingdom Reservoir.Squaw Creek has not been gaged long enough to allow a direct measure of flow variability, but indirect generalization of variability is gained by comparison with the Paluxy River. A flow probability curve for the Paluxy River is illustrated in Figure 2.4-25, which shows that the average discharge of 70.8 cfs was exceeded only about 11 percent of the time. Since the SCR catchment size is only about 16 percent that of the Paluxy watershed at gaging station 8-0915, this
 
variability will be much more pronounced. Thus, inflow from Squaw Creek will be extremely variable.
Lake Granbury and SCR will serve to regulate the naturally variable flows and provide suitable minimum water levels on a dependable basis.
The Lake Granbury yield discussed in 2.4.11.1 above is based on not  drawing that reservoir below elevation 675.0 [26]. The normal operating level in SCR will be held not less than elevation 770.0 feet.2.4.11.4Future ControlDevelopment of additional control on the upriver sections of the Brazos River is possible; an initial study of potential reservoirs by the Brazos River Authority [40] identified three possible sites between Possum Kingdom Reservoir and Lake Granbury. These sites are briefly outlined on Table 2.4-3. Any one of these possible developments would increase storage availability and should strengthen water availability.Downstream of DeCordova Bend Dam there is a possible reservoir site at Bee Mountain. The water at maximum level would be elevation 609 feet  [40] and would impound the Brazos River channel almost to DeCordova Bend Dam. It would be technically feasible to withdraw water from that lake also, offering an additional source of makeup water.Under the Water Rights system of the State of Texas, issuance by the Texas Water Rights Commission of the permit to build and operate SCR precluded any further significant development and control upstream on  Squaw Creek watershed itself.2.4.11.5Plant Requirements The single source of safety-related cooling water and the ultimate plant heat sink for the Comanche Peak Nuclear Power Plant (CPNPP) is the SSI. This reservoir contains a volume of water, including evaporative contingency, that is sufficient to provide cooling for a period of over 30 days without makeup to safely limit the effects of an accident in one unit, to permit the safe shutdown of the other unit, or simultaneous shutdown of both units and maintaining them both in CPNPP/FSAR2.4-28Amendment No. 106a safe shutdown condition. The available volume of water is determined during postulated 100-yr drought conditions as specified by NRC Regulatory Guide 1.27 and after a postulated 40 years of sedimentation. The minimum safety-related cooling water flow required for the two units during accident operation is 34,000gpm, which represents the cooling water requirements of
 
17,000 gpm for post-LOCA cooling of one unit and 17,000 gpm for safe shutdown of the other unit. Expected safety-related cooling water flow is 51,000 gpm, which represents 17,000 gpm for post-LOCA cooling of one unit and 34,000 gpm for safe shutdown of the other unit. Plant water requirements for all modes of operation are given on Figures 2.4-26
, 2.4-27, 2.4-28, and 2.4-29.Cooling water for both units is withdrawn from the SSI and delivered by four 17,000-gpm-capacity station service water pumps enclosed in a seismic Category I structure, the Service Water Intake Structure. The Service Water Intake Structure sump descends to elevation 755 ft 0 in, and the service water pump impeller blades descend to elevation 758 ft  0 in. Each pump is designed to operate with a minimum submergence  requirement of 4 feet - 6 inches above the bellmouth flare (El. 757 ft). As a result, a minimum water  elevation of at least 761ft6in is necessary for service water pump operation. The minimum water elevation, considering no makeup of water and the most severe period for evaporation described in Section2.3.1.2.10, is 766 ft 4 in. at 30 days and 765 ft. 4 in. at 39 days. Therefore, substantial margin for submergence is provided.Cooling water is returned to the SSI through the Service Water Discharge Structure. Water from this structure enters the SSI at a point remote enough from the Service Water Intake Structure and at a velocity high enough to ensure adequate mixing, dispersion, and evaporative cooling of the effluent. The station service water pumps, Service Water Intake Structure, and Service Water Discharge Structure  are described in Section 9.2.1
.The SSI is formed from an inlet of the Squaw Creek Reservoir (SCR) and is separated from the reservoir by a seismic Category I dam. The surface elevation of both bodies of water is a minimum 770 ft 0 in during normal operation. The seismic Category I dam, however, will maintain the SSI at a surface elevation of 769 ft 6 inches in the event of an accident involving water loss from the SCR. The ultimate Heat Sink is described in Section 9.2.5
.The SSI is constructed specifically to serve as the ultimate heat sink for the CPNPP. Except for a backup source for auxiliary feedwater (Section 10.4.9.3), there are no other uses of this water during accident and safe shutdown operations. Water rights to the SSI are guaranteed by the Texas Water Rights Commission. For use of water near the plant site, see Subsection 2.4.13
.2.4.11.6Heat Sink Dependability Requirements The source of plant cooling water for the CPNPP is the SCR. This reservoir is formed by a dam structure extending across the Squaw Creek and creating a cooling water impoundment in the Squaw Creek Basin behind it (see Figure 2.4-4
). The impoundment is normally supplied with makeup water from Lake Granbury. In addition, water is exchanged, as necessary, between Lake Granbury on the Brazos River and the SCR to reduce total dissolved solids levels.The single source of safety-related cooling water is the SSI, which functions as the ultimate heat sink for the CPNPP. The SSI is formed from an inlet of the SCR and separated from it by a seismic Category I dam. A canal connects the SSI with the SCR and maintains an equal water level between the two bodies of water. The seismic Category I dam and canal maintain the water level of the SSI at 769 ft 6 inches in the event of accidental water loss from the SCR. Waterflow CPNPP/FSAR2.4-29Amendment No. 106through the canal will stop at this elevation. A simultaneous failure of both the SCR dam and the SSI Dam is considered unlikely since the SSI Dam is a seismic Category I structure.Cooling water for normal plant operation is withdrawn from the SCR by  eight 275,000-gpm-capacity circulating water pumps. Each pump is a 25-percent-capacity unit, and all pumps are located in the Circulating  Water Intake Structure. Each pump has impeller blades which extend to elevation 758 ft 0 in and to a minimum submergence requirement of 12 ft. The circulating water pumps are not required for plant shutdown.Cooling water is returned to the SCR via the Circulating Water Discharge Structure. The structure discharge is located at an adequate distance from the Circulating Water Intake Structure to ensure sufficient water mixing and evaporative cooling.Safety-related cooling water is withdrawn from the SSI by four 17,000-gpm-capacity service water pumps. All pumps are located in the Service Water Intake Structure, a seismic Category I building. Safety-related cooling water is returned to the SSI through the Service Water Discharge Structure. The discharge structure is located at a sufficient distance from the Service Water Intake Structure to ensure adequate water mixing and evaporative cooling.The minimum water level of both the SCR and the SSI during normal plant operation is 770ft0in. This water level is adequate for both circulating water pump and station service water pump operation. During postulated 100-year drought conditions, and after 40 years of sedimentation, the SSI is determined to have 284 acre-ft of water.
Figures 2.4-26 through 2.4-29 describe cooling water requirements for  the various modes of plant operation.
Section 9.2.5 discusses design bases and safety functions of the SSI as the CPNPP ultimate heat sink.The anticipated loss from the SSI caused by evaporation is 92 acre-feet. The seepage and drift loss is negligible in comparison to the evaporation losses. Instrumentation, which is read in the Control Room, is provided to measure the SSI water level as shown on Figure 9.2-1. An alarm is provided in the Control Room for low SSI water level and high differential level across the travelling screens. The low level alarm is set at or above the normal low SSI water level as desired by the operator as an aid for lake level management. The SSI will be dredged as required.The CPNPP design of the SSI as the single ultimate heat sink complies  with the intent of NRC Regulatory Guide 1.27 as discussed in Chapter 1, Appendix 1A(B)
.The SSI is the source of fire protection storage tank emergency fill water. SSI level changes caused of the Fire Protection System are insignificant since the system is used infrequently and for periods of short duration. Refer to Section 9.5.1 for a description of the Fire Protection System.Cooling water is withdrawn from the SSI at the Service Water Intake Structure. Elevations of intake structure pump deck and channel floor are established with due consideration for pump minimum submergence requirements and reservoir level fluctuations. For elevations and layouts of Service Water Intake Structure components, see Section 9.2. Plant water requirements for various modes of operation are given in Figures 2.4-26
, 2.4-27, 2.4-28, and 2.4-29.
CPNPP/FSAR 2.4-30Amendment No. 1062.4.12DISPERSION, DILUTION, AND TRAVEL TIME OF ACCIDENTAL RELEASES OF LIQUID EFFLUENTS IN SURFACE WATERS2.4.12.1Introduction It was conservatively assumed that all the liquid radwaste (24,000  gallons, or 7.36 x 10
-2 acre-feet) is spilled into Squaw Creek  Reservoir
. Minimum dilution in Squaw Creek Reservoir would occur at  minimum pool elevation 770.00 feet (msl), corresponding to a storage volume of135,062 acre-feet. Assuming complete mixing, the minimum dilution factor is 135,062(7.36x10-2) or 1.84 x 106. The instantaneous concentrations in Squaw Creek Reservoir are calculated by dividing the concentrations in the tank by the dilution factor. Due to the decay characteristics of the radionuclides, most concentrations decrease with time, however, some radionuclides build up in the reservoir as decay products. A computer code, RADIOISOTOPE, described in Appendix15BSection 15B.6, was used to calculated the decayed concentrations. The concentrations of each radionuclide in Squaw Creek Reservoir at the end of 1 day, 1 month and 1 year is shown in Table2.4-21. Since the intent of the analysis is to demonstrate that the concentrations of radionuclides in the reservoir do not exceed the effluent concentrations for unrestricted areas given in 10CFR20 Appendix B, the total effluent concentration fraction is also given for each of the above time periods. The results demonstrate that the water volume of the reservoir provides sufficient dilution, and that most of the activity would decay away after one
 
month.The water usage pathways involving Squaw Creek Reservoir indicate that a portion of the reservoir inventory may be transferred to Lake Granbury and Lake Whitney. This transfer would provide for additional dilution of radionuclides due to the added water volumes, and it is expected that the concentrations of radionuclides in Lake Granbury and Lake Whitney would be much lower than those in Squaw Creek Reservoir. The flow pattern which exists among these bodies of water, and the overall potential for further dilution of Squaw Creek Reservoir concentrations provided by those other two lakes is more fully addressed in Appendix 11A
.2.4.13GROUNDWATERThe investigation of groundwater features included:
1.A review of groundwater information obtained from public agencies and from literature.2.A field inventory of all wells used for water supply within two miles of the site and reservoir fringe.
CPNPP/FSAR2.4-31Amendment No. 1063.A review of municipal, industrial, and irrigation wells within 20 miles of the site.4.Measurements of water levels in several exploratory borings which were drilled to obtain geologic, geohydrologic, and foundation data.5.The evaluation of the probable influence SCR and CPNPP will have on the quality and piezometric level of groundwater in the site vicinity.[General References 29, 30, 31, 32].2.4.13.1Description and On-Site Use2.4.13.1.1General Groundwater Features The CPNPP site is located within the Great Plains Physiographic Province, about 4 1/2 miles north of Glen Rose, Texas, and approximately four miles west of the Brazos River. The power plant  site is on a relatively narrow ridge which trends east-southeast and is flanked on the north and south by the SCR (Figure 2.1-2). Topography in the site vicinity ranges from slightly undulating to stair-stepped. Ground surface near the site ranges from elevations 600 to 700 feet
 
(Mean Sea Level Datum) in valleys to elevations 900 to 1000 feet on ridges. The Brazos River channel a few miles east of the site is at approximate elevation 560.The site is underlain by a sedimentary rock sequence which, at the surface, has been weathered to a clayey, silty, sandy overburden soil  with some rock fragments. Overburden on the ridges and slopes ranges in thickness from a few inches to a few feet and rock outcrops are  common. The soils and much of the rock are relatively impermeable. In valley bottoms, rock is overlain by a combined thickness of alluvial sediments and underlying residual soil. Total overburden ranges from 10 to 15 feet in depth. The sediments are of minor thickness and vary from slightly permeable to essentially impermeable.In the site area, including the floodplain, infiltration into  subsurface formation is retarded because of low permeability of the strata. Most precipitation flows across the surface and drains away as surface runoff or returns to the atmo sphere by evaporation and transpiration. Water-bearing strata in the area are mainly recharged in their outcrops areas.Data from a nearby gaging station on the Paluxy River indicate that the net surface runoff and base flow (which is derived from shallow groundwater) together total some two inches annually.
Evaporation from a free water surface, such as a lake, is approximately 72 inches per year [33].
Most of the groundwater in the site region occurs in bedrock. Some  water does exist in shallow floodplain alluvium in stream valleys, but  is not withdrawn for use. Regional bedrock aquifers in order of increasing age are the Paluxy, Glen Rose and Twin Mountains formations, of the Comanche series, Cretaceous age [34]. Locally, CPNPP and SCR are on the Glen Rose outcrop, which, in turn, is underlain by the Twin Mountains Formation. The Paluxy Formation is absent at the CPNPP location, and within the limits of the reservoir; the Glen Rose Formation is the upper stratigraphic unit exposed in these areas.The structure, stratigraphy, and composition of the three strata are described in detail in Section2.5.1. A geologic cross section representing the approximate orientation of these strata near the site is shown on Figure 2.5.1.2-5 (see upper right portion of cross section). The CPNPP/FSAR2.4-32Amendment No. 106approximate limits of formation outcrops in the counties surrounding the site are shown on Figures 2.4-30
, 2.4-31 and 2.4-32.The Paluxy, Glen Rose, and Twin Mountains formations are large in area. Their outcrops form a strip of land tens of miles wide that extends south from Central Oklahoma, strikes westward in Central Texas, and extends into Mexico [35]. The formations in the site region dip eastward.The Twin Mountains and Paluxy formations are principally sandstone, but also have shale, limestone, claystone, and siltstone inclusions. Limestone is the dominant rock type within the Glen Rose Formation, but it also contains significant quantities of shale, siltstone and claystone.
In these formations, groundwater percolates slowly along bedrock joints and fractures, and through interstices in the rock fabric.The Twin Mountains is the only relatively productive bedrock zone in the site vicinity. The Paluxy Formation has nominal pumpage near the site and the Glen Rose Formation yields very little water in the site area and is usually less productive than the other formations.At distances of 20 to 50 miles downdip from th e outcrop, the groundwater becomes saline and the formations lose their importance as sources of fresh water [36]. The three formations are
 
discussed individually in succeeding sections.2.4.13.1.2Twin Mountains FormationA detailed description of the lithology, stratigraphy, and structure of the Twin Mountains Formation is given in Section 2.5.1. The formation is predominantly sandstone with subsidiary shale, claystone, siltstone, and limestone.The principal origins of the groundwater within the Twin Mountains Formation are rainfall and streamflow occurring in the outcrop area (Figure 2.4-32
).Downdip from the outcrop, groundwater in the Twin Mountains Formation is confined by fine-grained materials in the overlying Glen Rose Formation. Hydrostatic pressure in the Twin Mountains is great enough to create static water levels which rise above the formation and, sometimes, great enough to cause flowing wells. The piezometric level measured in this formation at the site in Boring P-10 is approximately elevation 670, about 60 feet above the
 
formation surface.Groundwater is discharged in the outcrop area by evapotranspiration and localized springs and seeps along drainages incised below the water table. Downdip (where the formation is confined, such as at CPNPP site), natural discharge is limited to a minimal upward movement into overlying formations.Although the Twin Mountains Formation is a moderately productive stratum in the site vicinity, two packer pressure tests of 60 feet of this rock in a boring at the CPNPP site did not result in water take. This test indicates that there are essentially impermeable rock zones  within this formation.
CPNPP/FSAR2.4-33Amendment No. 1062.4.13.1.3Glen Rose Formation This formation is predominantly limestone, but significant amounts of shale, siltstone and claystone are also present. A full description of the geology of the Glen Rose Formation is presented in Section 2.5.1
.The principal origins of groundwater in the Glen Rose Formation are rainfall on the outcrop area and minor seepage from the overlying Paluxy Formation and underlying Twin Mountains Formation. The Glen Rose Formation outcrop area is shown on Figure 2.4-31
.CPNPP and SCR is constructed on the Glen Rose Formation; thus the character and rate of groundwater movement in this formation is of special interest. The Glen Rose limestones are essentially impermeable due to slight amounts of argillaceous impurity and are thus resistant to solution effects. Open voids, caverns, joints, collapse features, and frequent fractures common to some limestones are notably absent in the Glen Rose Formation at the site; therefore, the groundwater moves very slowly through and into the Glen Rose Formation, principally through the joints and fractures that do exist. Occasional isolated sand lenses also contain groundwater.Detailed examination of cores from borings revealed no solutioning features and minimal fractures. Packer pressure tests in the Glen Rose Formation performed in most borings at the station, SSI Dam and spillway, and Squaw Creek dam and spillway incurred essentially no "water take" in rock beneath the upper, usually thin, weathered zone. Pressure tests were performed within the rock in many borings to evaluate jointing and/or the absence of solutioning features and to evaluate general permeability characteristics. Tests employed single and double packers and gage pressure ranging to 80 psi. The results of packer tests are presented on Table 2.5.6-1
. Only zones at a depth range of 194 feet to 214 feet (elevation 649.04 to 629.04 feet) recorded
 
any water loss. Upon review of the Log of Boring for Boring P-10, the cause of the water losses can be attributed to a zone of sandstone and sand lenses.Drill water occasionally was lost while drilling through the upper weathered zone. A relatively thick pervious zone was encountered in Borings DI-8 and DI-9, approximately 1 1/4 miles southeast of the station. These borings are at the middle to outer extremity of a peninsula which will form the south abutment for Squaw Creek Dam. There, a large amount of drill water was lost while advancing Boring DI-8 to 56 ft and DI-9 to shallower depth through some zones of weathered, fractured rock. Indications were that water loss occurred principally within the upper 20 to 30 feet of each boring. There is no evidence of solutioning in the zone of water loss. Boring DI-10, drilled farthest from the peninsula point, incurred no drill water loss, thereby indicating that conditions improve southward along the peninsula.Northwest of the site, where the Glen Rose Formation is covered by outliers of the Paluxy Formation, a few domestic water wells are  comp leted in the Glen Rose Formation. These wells produce potable water and they are reliable during droughts; this reliability is due to the slow release of groundwater to the Glen Rose Formation from the overlying Paluxy Formation. Elsewhere, wells completed in the Glen Rose Formation are often unreliable during droughts.In its outcrop areas, the Glen Rose Formation discharges water naturally through springs and seeps. In the confined portions of the formation, when differential hydraulic pressures occur, there is very minor transfer of water into overlying and underlying formations from the Glen Rose Formation.
CPNPP/FSAR2.4-34Amendment No. 1062.4.13.1.4Paluxy FormationThis formation is predominately sandstone, but shale, siltstone, claystone and limestone are also present. A detailed description of the lithology, stratigraphy and structure of the Paluxy Formation is given in Section 2.5.1. The Paluxy Formation is not present at the CPNPP and SCR locations.Recharge to the Paluxy Formation occurs in the outcrop areas as a result of infiltration of rainfall and of seepage from streams.It also receives water from water-bearing units under greater hydraulic head which adjoin the Paluxy Formation. Figure 2.4-30 shows the outcrop area of the Paluxy Formation. South of the CPNPP site, across the Paluxy River, the formation is confined by overlying fine-grained bedrock strata. These strata are not of significance to CPNPP.Groundwater discharges from the Paluxy Formation as springs and seeps  in some outcrop areas. Where the formation is confined, there is  limited water movement into overlying confining units if those units are at lower hydraulic head.2.4.13.1.5Onsite Water TableFollowing the subsurface exploration program, a number of the borings were used to determine water levels. Of these borings, P-10 was completed in the Twin Mountains aquifer; the piezometric water level in that boring is elevation 670. The remainder of the borings monitored for groundwater were completed in the Glen Rose Formation. Static water levels observed in these borings are presented in Figure 2.5.5-77 and range from ele vation 749 to 830.As indicated in Section 3.8.5.1.5
, groundwater is not expected to reach higher than elevation 775.0 feet. All piezometric levels recorded on Figure 2.55-77 were measures of perched water in the upper zone of the Glen Rose Formation in the immediate area of each piezometer. The resulting elevation range of 749 to 830 feet is attributed to surface run-off and not a true measure of permanent groundwater in the Formation.Water levels in the Glen Rose Formation are expected to show some  variation in response to seasonal climatic changes; those in the Twin Mountains Formation will be much less influenced by seasonal conditions because of the distance from the recharge area.
Piezometers which measured the levels recorded in Figure 2.5.5-77 were installed during preliminary design work at the site, before the site was excavated to plant grade (elevation 810). A permanent system of piezometors has been installed in order to monitor ground water levels at the site. This program is described in Section 2.5.4.13. A Groundwater Monitoring Program is established and incorporates several sentinel wells in various locations throughout the plant site for prompt identification of potential radiological release source locations. 2.4.13.1.6Water QualityPotable groundwater occurs in the Twin Mountain s, Glen Rose and Paluxy formations. The results of chemical analyses of groundwater obtained from wells drawing from these formations are summarized in Table 2.4-22.  (Well locations are shown on Figure 2.4-33
).
CPNPP/FSAR2.4-35Amendment No. 106Water in the Twin Mountains Formation is a sodium bicarbonate type with a dissolved solids content varying generally from 200 to 900 mg/1. In and near the outcrop areas, Twin Mountains water is used for irrigation. At the site, however, the water is unsuitable for  irrigation due to the local soil conditions and the increased sodium content of the water. The results of physical and chemical analyses  performed on the samples taken from the production and observation wells during the years of 1975-76 are presented and discussed in the Environmental Report/Operating License Stage (ER/OLS). The sodium content of the water samples ranges from 100 to 150 mg/1, with  dissolved solids content varying from 300 to 500 mg/1. The temperature of groundwater follows the seasonal atmospheric av erage temperature values, and ranges from 20&deg; to 26&deg;C (68&deg; to 79&deg;F). The conductivity values vary between 550 to 1300 mhos.The quality of water obtained from the Glen Rose Formation is variable; in localized areas it is not potable. Northwest of the site, water is produced from the Glen Rose Formation where it is capped by an outlier of Paluxy Formation. The analysis from well No. 48 is an example of the water quality obtained from this area. The chemical analysis from well No. 48 is presented in Table 2.4-22
.The Paluxy Formation is tapped by some domestic water wells south of the Paluxy River. The chemical analysis of water from a well five miles east of Walnut Springs in Bosque County is shown in Table 2.4-22. This well is located close to the outcrop area of the Paluxy Formation, where the water is typically a hard calcium bicarbonate type. Further downdip, the water becomes a progressively softer, sodium bicarbonate type.2.4.13.1.7Onsite Water UsesGroundwater usage on the site is presented in Table 2.4-23. Continuous usage will be about 127gpm and the peak plant requirement is estimated to be 330 gpm. Alternate source of supply of water for  this usage will be from the surface water pre-treatment system.2.4.13.2Sources2.4.13.2.1Regional Use 1.Paluxy and Glen Rose FormationsGroundwater is pumped from the Paluxy and Glen Rose formations by small-capacity wells for livestock and rural domestic use. Pumpage is not metered within the region. Withdrawals from both formations, however, are estimated to be less than 100 acre-feet per year. Water extraction from these formations has no identifiable effect on regional piezometric levels. Groundwater use is not expected to increase significantly in the future because these formations are poor aquifers and will probably not be developed for water
 
supply by either cities or industries or for large scale irrigation. More favorable water supplies are available from surface sources or from the Twin Mountains Formation.The regional movement of water in the Paluxy and Glen Rose formations is downdip to the east. The hydraulic gradient in the Paluxy is about 20 feet per mile in downdip areas.
The rate of regional groundwater movement is estimated to be on the order of one foot per day or less in the Paluxy Formation.
CPNPP/FSAR2.4-36Amendment No. 106Because groundwater in the Paluxy is used only for domestic and  livestock purposes in rural areas, wells are usually of small pumping capacity, typically under 10 gallons per minute or less. It is estimated that maximum potential well yield in the region is probably under 50 gallons per minute.There are few wells withdrawing water from the Glen Rose Formation. This formation typically is not capable of supplying more than about 10 gallons per minute to wells.
Water levels in the Glen Rose fluctuate in response to precipitation, and some wells in the Glen Rose are reported to have failed during certain droughts.Generally, water use from the Paluxy and Glen Rose formations is small and individual wells are of very limited capacity. The aquifers are variable in their hydraulic characteristics and also in the quality of wa ter they yield. As a result, no significant development of these sources of groundwater is anticipated.2.Twin Mountains FormationPrior to 1880 there was relatively little groundwater development from  this formation. Since the early 1900's pumpage has increased to include wells from municipal, industrial and irrigation purposes.The Twin Mountains Formation is the primary source of groundwater used  in the region although this use is not extensive.Principal wells in the area, i.e., public supply, irrigation and  industrial, which are within 20miles of the site, are listed on Table 2.4-24 and locations are shown on Figure 2.4-33
. Texas Water Development Board studies [37] indicate that current annual pumpage from the Twin Mountains Formation is about 100 a cre-feet per year within a 20-mile radius of the site. By the year 2020, the total pumpage is projected to be not more than 200acre-feet per year.The groundwater movement is downdip to the east (Figure 2.4-34), at a rate of approximately two feet per day. The current piezometric gradient is about 20 feet per mile. Permeability of the formation ranges from 90 to 240 gallons per day per square foot[34].The recharge area (outcrop area) is shown on Figure 2.4-32. Because the site is near the recharge area and because of the relatively small projected amount of future pumping, no significant change in groundwater level is expected in the site vicinity during the life of the plant.2.4.13.2.2Local UseAll water wells within a two-mile radius of the site were inventoried. In ad dition, information was gathered on water wells in and adjacent to the pla nned impoundment. The locations of wells in the vicinity are shown on Figure 2.4-35. The well data are listed on Table 2.4-25. All wells in the site vicinity are of small capacity and are used for individual rural home and livestock requirements. With few exceptions, all are deep wells, completed in the Twin Mountains aquifer.
CPNPP/FSAR2.4-37Amendment No. 106To the north of the site, a few wells are completed in the Glen Rose Formation. The presence of adequate and reliable supplies of  groundwater in the Glen Rose Formation is dependent on a sandstone cover (the Paluxy Formation). This sandstone cap results in prolonged percolation to the Glen Rose and results in relatively high water levels, even during drought conditions.Data collected on local water levels has permitted mapping of the Twin Mountains piezometric surface in the site area; this map is shown on Figure 2.4-36, which is more detailed than the regional map, Figure 2.4-33
.Two production wells (PW-1 and 2), and three observation wells (OB-1, 2 and 4) are constructed onsite and their locations are shown in Figure 2.4-37
. Observation well No. 3 was an existing well in the plant property. All these wells tap water from Twin Mountain Formation. Pumping tests were run PW-2 as the pumped well and PW-1 as observation well. From these tests a coefficient of transmissibility of 12,000 gpd/ft and a storage coefficient of 0.00005 were calculated.Using these aquifer characteristics and a pumping rate of Q = 100 gpm,  a series of drawn-down curves in relation to distance and time are plotted (
Figure 2.4-38
).To satisfy water demands during construction, pumpage has occurred in the production wells. The pumpage rates for 1975 are presented in Table 2.4-26. These figures show that the average pumping rate was about 150 to 160 gpm. The hydrographs of observation wells during this pumpage are shown in Figure 2.4-39. The early measurements made in OB-4 indicate an abnormally high water level and sudden change in the level from August to September. This abnormality and change may be due to incomplete development of the well after completion. Each of these wells is sampled by pumping once a month as part of the quality monitoring program. Therefore, OB-4 may have been further developed by the pumpage and by the removal of any obstruction.The average effect on the water levels of the observation wells due to plant pumpage is approximately nine feet. The hydrograph of the observation wells indicates that water levels from September to December have remained fairly constant. This constancy begins after approximately 200 days of pumpage, which conforms to the distance  draw-down curves where the greatest amount of draw-down occurs in the first 180 days.Operational pumpage of the plant will be 127 gpm on continuous basis. The peak plant requirement is estimated to be 330 gpm for a short time period. The alternate source of water supply is the surface water pre-treatment system taking raw water from Squaw Creek Reservoir.
This minimizes the effects of operational pumpage on draw-down. The nearest boundary line of the project area to the production wells is more than one mile. From the draw-down curves presented in Figure 2.4-38, it can be estimated that draw-down due to 34.5 gpm continuous pumpage during the life of the plant (40 years) will not be more than 2.5 feet at the boundary line. In case of 330 gpm peak pumpage rate, the temporary draw-down will be 3.3 feet for one day pumpage and 7.25 feet for three days pumpage at the same location.Historical groundwater levels around the plant site can be estimated  from the records of four Texas Water Development Board observation wells in Somervell County. The locations of these
 
wells are also shown in Figure 2.4-37 and their records are presented in Table 2.4-27. The records indicate a fluctuation of levels and also localized cones of depression.
CPNPP/FSAR 2.4-38Amendment No. 106Based upon the geohydrologic characteristics at the site, it is estimated that the piezometric level in the Twin Mountains Formation will be depressed locally due to pumpage from the production wells, but without adverse effect on the station or the existing wells withdrawing water from the formation. Within the Glen Rose Formation, water levels will not be affected due to this pumpage.All wells and borings in the impoundment area are grouted and sealed to insure no direct intrusion of reservoir water into subsurface aquifers.2.4.13.3Accident Effects 2.4.13.3.1Introduction The Auxiliary Building is founded in the Glen Rose limestone which is an essentially impermeable formation (see section 2.4.13.1.3
). No ground water was encountered during excavation into the Glen Rose limestone for the plant foundations. However, during design validation efforts, it was determined that perched water may exist at elevations higher than 775'-0". This condition was created by the excavation and backfill process associated with buried piping ductbanks and the service water intake structure when backfill was placed using pervious material. This arrangement allows surface runoff to be trapped in the pervious zone (backfilled area) thus raising the local water level (called perched water level) above elevation 775'-0". This ground water therefore, is not hydraulically connected to the Twin Mountains aquifer which is approximately 200 feet below plant grade. Design Basis groundwater level for lateral forces on the plant structures is conservatively taken as 810'-0" except at the Service Water Intake Structure. It is expected that the ground water gradient will be from the reservoir toward the plant site, thus restricting the movement of any released liquids above elevation 810'-0" to predominantly vertical flow. A build up in the ground water level through percolation of rainfall over the plant site into the essentially impervious limestone is considered unlikely. Therefore, because mounding due to percolation is highly unlikely, it is correspondingly improbable that recharge in the plant area would increase the potential for outward horizontal flow toward the reservoir. If the released liquid could travel horizontally through the Glen Rose limestone, it would enter Squaw Creek reservoir. The ability of the surface water regime to dilute and disperse such releases is discussed in Section 2.4.12
.In order to evaluate the effect of a postulated accident on the Twin Mountains aquifer, a conservative mathematical model with simplifying assumptions was used to model the dispersion of the liquid through the Glen Rose limestone down to the top of the Twin Mountains aquifer.
CPNPP/FSAR2.4-39Amendment No. 1062.4.13.3.2Description of the ModelThe dispersion and decay of the radionuclides within the Glen Rose limestone was evaluated using the model described briefly below.The governing equation employed in this one-dimensional dispersive and convective model may be written as follows:
This governing equation is solved by a numerical model which employs a partly implicit solution procedure to predict chemical species concentrations as a function of space and time.The discretized form of the governing equation is obtained by integration over control volumes defined by a numerical grid set up for the region of interest.2.4.13.3.3Selection of Parameters1.Initial and Boundary ConditionsInitial and boundary conditions must be supp lied to the numerical model in order to complete the mathematical specification of the problem. The initial conditions designate the distribution of radionuclides over the entire solution domain at the commencement of the analysis. In this problem, zero concentrations were specified everywhere initially.
whereCjis the concentration of the chemical species j; Rjis the retardation factor for the species j, comprising adsorption, ion exchange, precipitation, colloid filtration and irreversible mineralization;Uis the groundwater velocity in the x-direction; Sjis the source term for chemical species j; Dxjis the dispersion coefficient for species j is the x direction;is the decay coefficient for species j (also given by 1n2/T 1/2 where T1/2 is the radionuclide half-life);xis the distance in the x-direction; andtis the elapsed time.tRjCj()x------UCj()Sjx------Dxj  Cjx--------Rj jCj-+=+j CPNPP/FSAR2.4-40Amendment No. 106Boundary conditions represent variations of the concentrations, the concentration fluxes, or a combination of these, at the boundaries of the domain. In the case being considered, the lower boundary condition was specified as a zero gradient boundary. That is, the radionuclide concentrations just within the upper part of the Twin Mountains aquifer were considered to be identical to those just within the lower part of the Glen Rose  limestone; i.e., the radionuclides are transported by convection alone. The upper boundary coincides with the base of the storage tank. The upper boundary condition was therefore the radionuclide source of the concentration contained in the tank.2.Reduction FactorThe reduction factor was conservatively assumed to be equal to 1, implying that no retardation in movement or interaction between radionuclides and soil occurs.3.Initial Flow VelocityThe initial flow velocity of radionuclides out of the base of the tank is limited by the capacity of the soil to absorb the flow; i.e
., the saturated vertical permeability of the Glen Rose limestone. The permeability value was estimated from packer-test data to be: 4.Dispersion CoefficientThe equation given by Fried and Combarnous (43) can be utilized in the calculations:
where d50 is the mean particle size (ft), U x is the groundwater velocity (ft/day), and D o is the molecular diffusion in bulk water (ft 2/day). D o is equal to approximately 9.7 x 10-4 ft2/day. Letting the groundwater velocity go the zero, and changing units yields:Another value reported for the soils similar in dispersion characteristics is the value given in Reference 44, which is:Taking the geometric average of these two values as a conservative approximation of the dispersion coefficient yields:5.Decay Coefficientk=2.8 x 10
-2 ft/day.Dx=Do [0.67 + 0.5(U xd50/Do)1.2]Dx=0.0004 cm 2/minuteDx=0.0028 cm 2/minuteDx=0.001 cm 2/minute = 1.6 x 10
-3 ft2/day.
CPNPP/FSAR2.4-41Amendment No. 106The decay coefficient,  j, is calculated from known half-life values for each of the radionuclides of concern.6.Source TermThe source term, S j, is calculated from the known curie content of the tank, and the volume of fluid within the tank, assuming that the entire base of the tank ruptures instantaneously.2.4.13.3.4Computation Results The analysis showed that only one radionuclide, CS-137, penetrated the entire 150-foot depth of the Glen Rose Limestone to reach the Twin Mountains aquifer below. To illustrate the dispersion of the major radionuclides of concern, the results for those with the greatest release concentrations and longest half-lifes have been tabulated in Table 2.4-28. This table illustrates the maximum depth to which significant concentrations penetrate. Concentrations of less than 10-13 &#xb5; Ci/ml (2.83 x 10
-15 Ci/ft3) were considered insignificant.CS-137 is shown to penetrate the entire 150 feet in 400 years; therefore, more detailed results are presented for this radionuclide in Table 2.4-29. This table shows the concentrations of CS-137 throughout the limestone as a function of time. This conservative analysis calculates themaximum concentration of any radionuclide anywhere in the groundwater to be 4.8 x 10-12 &#xb5;Ciml as a result of the postulated accident.2.4.13.4Monitoring or Safeguard RequirementsNo planned releases to the ground water environment will take place at the plantsite. However a Groundwater Monitoring Program exists for early detection of inadvertent releases of radioactive material. Pertinent information is provided in Section 6.1 of the Environmental Report.2.4.13.5Design Bases for Subsurface Hydrostatic LoadingThe lateral pressure () caused by the groundwater at a given point is equal to the unit weight of water () times the vertical distance from the water table to the point at which the pressure is computed (H):Uplift pressures are similarly computed as H, where H is the vertical distance from the water table to the surface on which the uplift is computed.No ground water was encountered during excavation and construction of the plant structures. However, during design validation efforts it was determined that ground water or perched water may exist at elevations higher than 775'-0". Therefore, safety-related plant structures are conservatively designed for hydrostatic loads with the design basis ground water level at elevation 810'-0", except for the Service Water Intake Structure. Hydrostatic loads on the SWIS are determined with a design basis ground water level at elevation 793'-0".=H CPNPP/FSAR2.4-42Amendment No. 106There is no dewatering at the site during or after construction.2.4.14TECHNICAL SPECIFICATION AND EMERGENCY OPERATION REQUIREMENTSThe most adverse hydrological conditions detailed in the preceding sections do not affect the operation of safety-related facilities. Emergency procedures are required, however, if Squaw Creek Reservoir elevation exceeds 778 feet to ensure that the Electrical and Control  Building is not flooded via the Circulating Water System. See Section 13.5 for a discussion of these procedures.The maximum predicted normal SSI temperature for two unit full power operation is 102&deg;F. Therefore, this is the initial condition assumed in the Station Service Water System (Section9.2.1), Component Cooling Water System (
Section 9.2.2), and Containment Heat Removal (Section 6.2.2) analyses and specified in the Technical Specifications.The lowest normal SSI elevation is 770 ft. 0 in. as described in Section 2.4.11.5. This elevation is the initial condition assumed in the ultimate heat sink analysis described in Section 9.2.5
.REFERENCES1.Water Resources Data for Texas," Part 1, Surface Water Records, U. S. Geological Survey, annual publications, water years 1966-70.2."Number of Inhabitants, 1970 Census of Population, Texas," U. S. Department of Commerce, Bureau of the Census, 1971.3.Letters from Burke G. Bryan, Chief Engineer, Brazos River Authority, dtd, 22 May 1972.4.Digital Computer Printouts entitled, "River Order List of The Water Rights Master File," Texas Water Rights Commission, 1972.5."Bulletin 6311, Floods in Texas, Magnitude and Frequency of Peak Flows," Texas Water Commission, 1973.6."Geological Survey Water-Supply Paper 1682, Magnitude and Frequency of Floods in the United States," Part 8, U. S. Geological Survey, 1969.7."Geological Survey Water-Supply Paper 1922, Surface Water Supply of the United States 1961-1965," Part 8, Volume 1, U. S. Geological Survey, 1970.8."Flood Stages and Discharges for Small Streams in Texas," U. S. Geological Survey Texas District Open File Report, 1971.9."Hydrometeorological Report No. 33, Seasonal Variation of the Probable Maximum Precipitation East of the 105th Meridian for Areas of 10 to 1000 Square Miles and Durations of 6, 12, 24, and 48 Hours."  Hydrometeorological Section, Hydraulic Services Division, U. S. Weather Bureau in Cooperation with the U. S. Corps of Engineers, 1956.
CPNPP/FSAR2.4-43Amendment No. 10610."Engineering Technical Letter No. 1110-2-8, Computation of Free- board Allowances for Waves in Reservoirs," Department of the Army, Office of the Chief of Engineers, Washington, D.C., 1966.11.Hershfield, D. M., "Extreme Rainfall Relationships," Journal of the Hydraulics Division, Proceedings of the American Society of Civil Engineers, November, 1962.12."Design of Small Dams," U. S. Department of Interior, Bureau of Reclamation, 1960.13.Corps of Engineers data provided by Freese, Nichols and Endress, Fort Worth, Texas.
14."EM 1110-2-140S Flood-Hydrograph Analyses and Computations," Corps of Engineers, U. S. Army, August, 1959.15."Report 33, Symposium on Consideration of Some Aspects of Storms and Floods in Water Planning," Texas Water Development Board, 1966.16.Linsley, R. K., and Franzini, J. B., Water Resources Engineering, McGraw-Hill, 1964.17.Letter from Fort Worth Corps of Engineers Office, dated 1972.18."Report 48, Dams and Reservoirs in Texas, Historical and Descriptive Information," Texas Water Development Board, 1967.19.Henderson, R. M. Open Channel Flow, MacMillan, 1966.20.Chow, Ven Te, Open-Channel Hydraulics, McGraw-Hill, 1969.21.21."Report 115, Time of Travel of Translatory Waves on the Brazos, Leon and Little Rivers, Texas," Texas Water Development Board, 1970.22."EM 1110-2-1408, Routing of Floods through River Channels," Corps of Engineers, U. S. Army, 1960.23.Thom, H. C. S., New Distributions of Extreme Winds of the United States, published in the Journal of Structural Division, Proceedings of the ASCE, July 1968.24.U. S. Department of Commerce, Weather Bureau:  Technical Paper No. 40, "Rainfall Frequency Atlas of the United States For Durations From 30 Minutes to 24 Hours and Return Periods From 1 to 100 Years," Washington May 1961.25.Freese, Nichols and Endress:  "Engineering Report on Squaw Creek Reservoir," prepared for Texas Utilities Services Inc., 1972.26.Forrest and Cotton, Inc.:  "Report on Yield of De Cordova Bend Reservoir if Operated for Water Supply Purposes," prepared for Texas Electric Service Company, February 1965.27."Streamflow Characteristics of the Brazos River Basin, Texas," U. S. Geological Survey, Open File 87, 1965.
CPNPP/FSAR2.4-44Amendment No. 10628."The Texas Water Plan," Texas Development Board, 1968.29.Interview with Mr. Paul R. Gillette, Chief, Flood Plain Management Branch, Texas Water Development Board, Austin, Texas.30.Interview with Mr. Robert L. Bluntzer, Director, Water Availability Division, Texas Water Development Board, Austin, Texas.31.Interview with Mr. Herbert Wolf, Publications Editor, Texas Water Development Board, Austin, Texas.32.Interview with Mrs. Beth Willard, Librarian, Water Resources  Research Center Archives, University of California, Los Angeles.33.Texas Board of Water Engineers (1960), "Monthly Reservoir Evaporation Rates for Texas, 1940 through 1957," Bulletin 6006.34.Texas Water Development Board (1974), "Ground-Water Resources of Part of Central Texas with Emphasis on the Antlers and Travis Peak Formations".35.Sellards, E.H., Adkins, W. S., and Plummer, F. B., (1932), "The  Geology of Texas, Volume I, Stratigraphy," University of Texas Bulletin 3232, Bureau of Economic Geology.36.Cronin, J. C., Follett, C. R., Shafer, G. H., and Bettman, P. L.,  (1963), "Reconnaissance Investigation of the Ground-Water  Resources of the Brazos River Basin, Texas," Texas Water Commission Bulletin 6310.37.Texas Water Development Board (1968), "The Texas Water Plan".38.U. S. Department of Agriculture, Soil Conservation Service:  "Guide to Sedimentation Investigations," South Regional Technical Service Area, Fort Worth, Texas, March 1965, Revised October 1965 and July 1968.39.Agreement By and Between Brazos River Authority and Texas Power & Light Company and Texas Electric Service Company.40.Ambursen Engineering Corporation:  "Plan of Development by Brazos River Authority for Water Conservation, Flood Control and Power, Brazos River, Texas," October 1955.41.Nuclear Regulatory Guide, 1.113, May, 1976.42.Deleted.43.Fried, J.J. and Combarnous, M.A., "Dispersion in Porous Media," Advances in Hydroscience, edited by Ven Te Chow, Academic Press,  1971.44.Ahlstrom, S.W. et al., Methods for Estimating Transport Model Parameters for Regional Groundwater Systems, Bettelle Nort hwest  Laboratories - 1717, 1974.
CPNPP/FSAR Amendment No. 104TABLE 2.4-1PRINCIPAL DAMS AND RESERVOIRS UPSTREAM OF COX BEND(Sheet 1 of 4)
White River Dam and White River ReservoirLocation - on White River in Crosby CountyCatchment - 172 sq. Mi.
Capacity - 38,600 ac-ft.
Owner- White River Municipal Water District Use - municipal, industrial, mining Sweetwater Dam and Lake Sweetwater Location - on Bitter and Cottonwood Creeks in Noland County Catchment - 104 sq. miles Capacity - 11,900 ac-ft.
 
Owner - City of Sweetwater Use - municipal and industrial Fort Phantom Hill Dam and Fort Phantom Hill ReservoirLocation - on Elm Creek in Taylor County Catchment - 478 sq. mi.
Capacity - 74,310 ac-ft.
 
Owner - City of Abilene Use - municipal and recreational
 
CPNPP/FSAR Amendment No. 104Stamford Dam and Lake Stamford Location - on Paint Creek in Haskell CountyCatchment - 360 sq. mi.
Capacity - 53,070 ac-ft.
Owner - City of Stamford Use - municipal and industrial Hubbard Creek Dam and Hubbard Creek ReservoirLocation - on Hubbard Creek in Stephens County Catchment - 1,107 sq. mi.
Capacity - 317,800 ac-ft.
Owner - West Central Texas Municipal Water District Use - municipal, mining and industrial Gonzales Creek Dam and Lake DanielLocation - on Gonzales Creek in Stephens County Catchment - 115 sq. mi.
Capacity - 10,000 ac-ft.
 
Owner - City of Breckenridge Use - municipal and industrial TABLE 2.4-1PRINCIPAL DAMS AND RESERVOIRS UPSTREAM OF COX BEND(Sheet 2 of 4)
CPNPP/FSAR Amendment No. 104 Graham Dam and Lake Graham Location - on Salt Creek in Young CountyCatchment - 205 sq. mi.
Capacity - 53,680 ac-ft.
 
Owner - City of Graham Use - municipal and industrial Morris Sheppard Dam and Possum Kingdom ReservoirLocation - on Brazos River at River Mile 687 in Palo Pinto County Catchment - 13,310 sq. mi. contributing area.
Capacity - 600,000 ac-ft. (original capacity was 724,700 ac-ft., but sedimentation had reduced capacity to 600,000 ac-ft. by 1966.)
Owner - Brazos River Authority Use - municipal, mining, irrigation, power and recreation Palo Pinto Creek Dam and Lake Palo PintoLocation - on Palo Pinto Creek in Palo Pinto County Catchment - 471 sq. mi.
Capacity - 44,100 ac-ft.
Owner - Palo Pinto County Municipal District No. 1 Use - municipal and industrial TABLE 2.4-1PRINCIPAL DAMS AND RESERVOIRS UPSTREAM OF COX BEND(Sheet 3 of 4)
CPNPP/FSAR Amendment No. 104 DE Cordova Bend Dam and Lake GranburyLocation - on Brazos River at River Mile 542.5 in Hood CountyCatchment - 15,451 sq. mi. contributing area.
Capacity - 155,000 ac-ft.
 
Owner - Brazos River Authority Use - municipal, industrial, irrigational and recreational.
 
==Reference:==
"Report 48, Dams and Reservoirs in Texas, Historical and Descriptive Information," Texas Water Development Board, 1967.TABLE 2.4-1PRINCIPAL DAMS AND RESERVOIRS UPSTREAM OF COX BEND(Sheet 4 of 4)
CPNPP/FSAR Amendment No. 104TABLE 2.4-2PRINCIPAL DAMS AND RESERVOIRS DOWNSTREAM OF COX BENDWhitney Dam and Whitney Reservoir (Lake Whitney) Location - on Brazos River at River Mile 442.4 in Hill and Bosque CountiesCatchment - 16,930 sq. mi. contributing area Capacity - 435,000 ac-ft.
Owner - U.S. Army Corps of Engineers
 
Use - Power and Flood Control Note:Although there are many reservoirs downstream of Cox Bend on tributaries of the Brazos River, there are no other structures on the Brazos River.
 
==Reference:==
"Report 48, Dams and Reservoirs in Texas, Historical and Descriptive Information," Texas Water Development Board, 1967.
CPNPP/FSAR Amendment No. 104TABLE 2.4-3POSSIBLE FUTURE RESERVOIRS ON BRAZOS RIVER BETWEEN POSSUM KINGDOM RESERVOIR AND LAKE WHITNEYNameLocationWater Elevation When Filled (feet)Storage Volume(acre-feet)Turkey CreekDownstream from Possum Kingdom Reservoir884159,000Inspiration PointBetween Turkey Creek and Hightower820203,000HightowerUpstream of Lake Granbury752520,000Bee MountainBetween Lake Granbury and Lake Whitney609306,000 CPNPP/FSAR Amendment No. 104TABLE 2.4-4SURFACE WATER CLAIMS FILED (IRRIGATIONAL) - SQUAW CREEK (a)a)This list was derived from the "Water Rights Master File" of the Texas Water Rights Commission. There are no permits for non-irrigational water users on Squaw Creek.ApplicantLocation of Applicant Amount Requested (Ac-ft/yr)Dean WilliamsWithin Squaw Creek Reservoir in Somervell County near Somervell-Hood County line 30Carlisle CravensWithin Squaw Creek Reservoir in Hood County near
 
Somervell-Hood County Line 150 CPNPP/FSAR Amendment No. 104TABLE 2.4-5MUNICIPAL, INDUSTRIAL, MINING AND HYDROELECTRIC WATER USERS ON THE BRAZOS RIVER (a)(Sheet 1 of 2)UserCounty Amount Allocated(ac-ft/yr)User (b)Brazos River AuthorityPalo Pinto1,500,000HBrazos River AuthorityHood10,000M Brazos River AuthorityHood70,000IGeneral Portland Inc.Johnson250MiHarles WilliamsJohnson75Mi Texas Power & Light Co.McLennan12,000I Young Brothers, Inc.McLennan20ICity of WacoMcLennan5,510M City of WacoMcLennan3,537RCity of MarlinFalls3,500MCity of MarlinFalls2,000I Texas A&M UniversityBurleson500IRichmond Rice Assoc.Ft. Bend12,000IBrazos River AuthorityFt. Bend50,000I Brazos River AuthorityFt. Bend25,000M General Crude Oil,and Dow ChemicalFt. Bend20,000ITurner Lumber Co. Brazoria265R Dow Chemical Co.Brazoria260,000I CPNPP/FSAR Amendment No. 104Troy DacosBrazoria160RRobert P. YorkBrazoria1,500R City of FreeportBrazoria31,360Ma)This list includes all applications, claims and certified filings which appeared on the "Water Right Master File" of the Texa s Water Rights Commission in 1976.b)Explanation of symbols:H - Hydroelectric, Mi - Mining, I - Industrial, R - Recreational, M - Municipal.TABLE 2.4-5MUNICIPAL, INDUSTRIAL, MINING AND HYDROELECTRIC WATER USERS ON THE BRAZOS RIVER (a)(Sheet 2 of 2)UserCounty Amount Allocated(ac-ft/yr)User (b)
CPNPP/FSAR Amendment No. 104TABLE 2.4-6IRRIGATIONAL WATER USAGE FROM BRAZOS RIVER BY COUNTY(a)a)This list includes applications, claims and certified filings derived from the "Water Right Master File" of the Texas Water Rights Commission during 1976.
CountyAmount Allocated(ac-ft/yr)Palo Pinto4,400 Parker 3,000Hood: Brazos River Authority Other20,0002,300Somervell500Bosque6,900Johnson30Hill1,400McLennan9,100Falls6,200Robertson13,600Milan1,500Burleson6,200Brazos7,200Waller1,300Grimes6,000Washington50Austin90Ft. Bend258,000Brazoria2,600 CPNPP/FSAR Amendment No. 104TABLE 2.4-7ANNUAL FLOODS AT BRAZOS RIVER GAGING STATION 8-0910 (NEARGLENROSE)(Sheet 1 of 3)
Location.4.4 miles upstream from Paluxy River c onfluence. 6 miles northeast of Glen Rose at Brazos River Mile 511.
Catchment area.24,830 sq. mi., approximately; of which about 15,590 sq. Mi. contributes directly to surface runoff.
Gage. Nonrecording at site 2.5 miles downstream prior to May 8, 1931; recording thereafter. At site 2.4 miles downstream May 9, 1931, to S ept. 30, 1957. Present gage used as supplementary flood gage for 1957. Datum of gage is 567.82 ft. above mean sea level, datum of 1929.Stage-discharge relation. Defined by current-meter measurements.Bankfull Stage. 20 ft.Remarks. Stages affected by backwater from Paluxy River at times and, since 1945, by medium-water bridge 2.5 miles downstream. Peaks partly retarded by Possum Kingdom Reservoir since March, 1941.Average Discharge.1,555 cfsWater YearDateGage Height(Feet)Discharge (cfs)1924Oct. 17, 192313.037,500 1925May 8, 192515.145,7001926June 21, 192613.238,3001927Oct. 19, 192614.041,400 1928May 20, 192810.427,7001928Sept. 12, 192913.4238,4001930June 17, 193019.668,300 1931Oct. 7, 193012.1831,7001932Sept. 10, 193216.3749,3001933May 27, 193313.1936,600 1934Mar. 4, 19344.115,240 1935May 18, 193523.6897,6001936Sept. 27, 193619.4267,3001937June 9, 19379.9322,200 1938Mar. 29, 193815.1245,2001939June 23, 19399.8522,600 CPNPP/FSAR Amendment No. 104Water YearDateGage Height(Feet)Discharge (cfs)1940Aug. 19, 194013.6238,3001941Nov. 25, 194014.9044,2001942Apr. 26, 194219.2366,400 1943Oct. 18, 194217.4754,1001944May 2, 194410.2124,1001945Mar. 30, 194513.8539,200 1946Sept. 27, 19468.2411,5001947Dec. 12, 194616.8938,9001948Feb. 25, 19488.6812,500 1949May 17, 194926.774,000 1950July 28, 195011.9220,7001951June 18, 19515.055,6801952May 24, 195214.1927,900 1953May 17, 19535.215,9201954May 15, 195417.3425,6001955Sept. 30, 195519.7442,300 1956Oct. 9, 195515.7830,6001957May 27, 195733.87(a)87,4001958May 2, 195821.0036,1001959July 8, 195911.508,9001960Oct. 5, 195928.1065,5001961June 19, 196116.8021,700 1962July 29, 196225.3250,5001963Apr. 30, 196313.3713,1001964Sept. 22, 196411.018,110 1965May 20, 196517.4323,5001966May 3, 196625.9049,8001967July 22, 196714.1915,000TABLE 2.4-7ANNUAL FLOODS AT BRAZOS RIVER GAGING STATION 8-0910 (NEARGLENROSE)(Sheet 2 of 3)
CPNPP/FSAR Amendment No. 104Water YearDateGage Height(Feet)Discharge (cfs)1968Mar. 21, 196819.0128,4001969May 9, 196921.2035,7001970Dec. 30, 197016.6521,300 1971Sept. 2, 197112.6611,4001972Oct. 20, 197113.0512,2001973Apr. 23, 197313.6113,600 1974Oct. 15, 197311.949,1901975Nov. 1, 197425.4246,800
 
==Reference:==
  "Bulletin 6311, Floods in Texas, Magnitude and Frequency of Peak Floods", Texas Water Commission in 1963."Geological Survey Water Supply Paper 1682, Magnitude and Frequency of Floods in the United States", Part 8, U.S. Geological Survey
."Geological Survey Water Supply Paper 1922, Surface Water Supply of the United States 1961-65", Part 8, Volume 1, U.S. Geological Survey
."Water Resources Data for Texas", Part 1, Surface Water Records, U.S.GeologicalSurvey
, annual publications, water years 1966-70.a)Peak flood level of record (Elevation 601.69 fe et). Peak flood occurred in 1876; no data are available for this flood.TABLE 2.4-7ANNUAL FLOODS AT BRAZOS RIVER GAGING STATION 8-0910 (NEARGLENROSE)(Sheet 3 of 3)
CPNPP/FSAR Amendment No. 104TABLE 2.4-8ANNUAL FLOODS AT GAGING STATION 8-0917 ON PANTER BRANCH OF SQUAW CREEK Location(a)  -- 4.6 miles southeast of Tolar at culvert on State Highway 51.a)Location shown on Figure 2.4-1
.Catchment area. -- 7.82 sq. mi.Type of gage. --Crest --StageWater YearDateMax. Discharge (cfs)1966April 29, 1966880 1967May 20, 19671,650 1968May 9, 19683,800 1969May 7, 1969610
 
==Reference:==
"Flood Stages and Discharges for Small Streams in Texas" by E.E.Schroeder, a U.S. Geological Survey Texas District Open-File Report.
CPNPP/FSAR Amendment No. 104TABLE 2.4-9ANNUAL FLOODS AT GAGING STATION08091750 ON SQUAW CREEK NEAR GLEN ROSE Location - Lat. 32&deg;16'12", long. 97&deg;43'56", Somervell County, on left bank at downstream side of bridge on State Highway 144, 2.1 miles upstream from mouth, and 2.8 miles northeast of Glen Rose Catchment Area
- 62.5 mi.
2Type of Gage - Water-stape recorder. Datum of gage is 569.02 ft. above sea level.Water YearDateMax. Discharge (cfs)1974October 12, 1973730 1975April 8, 19759,030
 
==Reference:==
U.S. Geological Survey.
CPNPP/FSAR Amendment No. 104TABLE 2.4-10ANNUAL FLOODS AT GAGING STATION8-0915 ON PALUXY RIVER NEAR GLEN ROSE(Sheet 1 of 2)
Location.  --On left bank of Paluxy River at downstream side of pier of bridge on U.S. Highway 67, 1 mile upstream from Cross Branch, 1.2 miles southwest of Glen Rose, Somervell County, and 4.7 miles upstream from the mouth.
Catchment area.  --410 sq. mi.
Gage.  --Nonrecording at site 1.8 miles downstream at datum 13.62 ft. lower prior to May14, 1947; recording thereafter. Datum of gage is 609.66 ft. above mean sea level, datum of 1929, Fort Worth supplementary adjustment of 1942.Stage-discharge relation.  --Defined by current-meter measurements below 150 cfs 1923-25; defined by current-meter measurements below 32,000 cfs and extended to 59,000 cfs by logarithmic plotting subsequent to May, 1947.Historical Data.  --Flood of April 17, 1908, was the greatest since at least 1877, from information by local resident.Average Discharge.  --70.8 cfsWater YearDate Gage Height (Feet)Discharge (cfs)1908Apr. 17, 190827.2 Est.
(a)59,000 est.1919Nov.  , 19182653,0001922May 21, 19222653,0001947Sept. 15, 19477.162,580 1948Feb. 25, 194813.9211,000 1949May 17, 1949 25.148,5001950Oct. 24, 19499.184,5701951June 3, 1951  8.804,130 1952May 23, 195222.336,2001953May 15, 19538.643,9301954April 12, 195410.05,510 1955May 19, 1955  22.537,0001956May 1, 1956 16.617,3001957Apr. 26, 195724.1244,000 1958July 6, 1958 9.54,9001959Apr. 19, 19598.223,530 CPNPP/FSAR Amendment No. 1041960Oct. 4, 1959 25.450,0001961July 17, 19618.634,100Water YearDate Gage Height (Feet)Discharge (cfs)1962Oct. 9, 1961 17.4819,800 1963Oct. 8, 196218.2321,9001964Apr. 21, 196413.139,9601965May 10, 1965  12.799,480 1966Apr. 30, 196612.388,8401967July 19, 196711.397,2401968May 20, 196815.9215,500 1969Apr. 17, 196914.0512,700 1970Oct. 12, 197011.978,1501971May 29, 19718.143,7401972Oct. 19, 197114.4912,500 1973Apr. 24, 197319.0524,6001974Sept. 20, 19747.092,8201975Oct. 31, 197410.756,450
 
==References:==
Same as for Table 2.4-7
.a)Maximum flood, since 1877 (based upon information from local resident), corresponding to Elevation 637 feetTABLE 2.4-10ANNUAL FLOODS AT GAGING STATION8-0915 ON PALUXY RIVER NEAR GLEN ROSE(Sheet 2 of 2)
CPNPP/FSARAmendment No. 104TABLE 2.4-11SQUAW CREEK RESERVOIR PROBABLE MAXIMUM FLOOD(Sheet 1 of 2)
HoursProbable Maximum Storm Rainfall (Inches)Losses (Inches)Rainfall Excess (Inches)
Probable Maximum Flood Hydrograph Rainfall on Reservoir(ac-ft)  Cumulative Inflow (ac-ft) (cfs)(ac-ft)3.5.5.000158158 6.5.3.2951118158434 9.6.3.32,3584101891,03312.7.3.43,7747602212,014  15.8.3.55,1401,1052533,37218.8.3.56,0021,3822535,00721.9.3.66,8641,5952846,88624.9.3.67,4731,7782848,948272.3.3 2.014,4242,58572612,259305.5.35.234,3705,6651,73719,661 3320.0.319.7121,90714,9586,31740,936 363.5.33.2142,57633,9621,10576,003 39.6.3.366,91425,258189101,450 CPNPP/FSARAmendment No. 10442.5.3.221,54510,402158112,01045.5.3.27,7963,281158115,449 48.5.3.24,0791,389158116,996512,118768117,76454907375118,139 57329153118,292 6011555118,347634019118,36666157118,373 6942118,375 7221118,376Totals:39.15.034.1TABLE 2.4-11SQUAW CREEK RESERVOIR PROBABLE MAXIMUM FLOOD(Sheet 2 of 2)
HoursProbable Maximum Storm Rainfall (Inches)Losses (Inches)Rainfall Excess (Inches)
Probable Maximum Flood Hydrograph Rainfall on Reservoir(ac-ft)  Cumulative Inflow (ac-ft) (cfs)(ac-ft)
CPNPP/FSARAmendment No. 104TABLE 2.4-12COMPARISON OF PROBABLE MAXIMUM PRECIPITATION MAXIMUM RECORDED RAINFALL AND MAXIMUM RAINFALL LIKELY TO OCCUR AT SELECTED GAGING STATIONS NEAR CPNPPStationPeriod of Record AnalyzedPMP(a) (Inches)a)24-hour point PMP as obtained from HMR #33 (Reference 9) is approximately 39.5 inches for all gaging stations. 24-hour point rainfall was converted to 48-hour 64-square mile rainfall (38.7 inches) for PMF determination.Maximum Recorded in 24 Hours (Inches)Maximum Likely to Occur in 24 Hours(b) (Inches)b)24-hour maximum rainfall likely to occur as computed through use of a statistical envelope technique developed by Hershfield (Reference 11).Iredell1964-197139.54.4522.4Kopperl1952-197139.54.9020.2 Rainbow1936-197139.56.0023.6 Stephenville1952-197139.57.7529.6 CPNPP/FSAR Amendment No. 104TABLE 2.4-13UNIT HYDROGRAPH CHARACTERISTICS Lower SCR Catchment Upper SCRCatchment (Except Maximum Six Hours)Upper SCR Catchment (During Maximum Six Hours) 1.A (Sq. Mi.)20.338.038.02.L (Mi.)4.4(a)a)Typical values for adjoining areas.13.113.13.Lca (Mi.)2.7(a)6.06.04.(LLca).32.1(a)3.73.75.Ct.611.11.1 6.tp=Ct(LLca).3 (hours)1.264.074.077.ta=tp/5.5 (hours).23.74.748.tr (hours)3.003.003.009.tpr=tp+.25(tr-ta) (hours)1.954.644.6410.tpr+.5tr (hours)3.456.146.1411.Cp640420440440 x 1.3 (b)b)For the most intense 6-hour rainfall period, the unitgraph ordinate is increased by 30 percent of the Upper SCR Catchment.12.4,3703,6004,680 (b)QprCp640xA=tprcfs()-----------------------------------------
CPNPP/FSARAmendment No. 104TABLE 2.4-14COINCIDENT WIND WAVE ACTIVITIESPMF (elev. 789.7) and 40 mph Overland Wind10 Year Return Period Flood (elev. 778.1) and PMW(81 mph Overland Wind)
WIND &WAVECHARACTERISTICS PLANTSITESQUAWCREEKDAMSAFESHUTDOWNIMPOUNDMENT PLANTSITESQUAWCREEKDAMSAFESHUTDOWNIMPOUNDMENTEffective Fetch1.25 mi1.28 mi0.36 mi1.25 mi1.28 mi0.36 mi Average Depth88 ft.88 ft.68 ft.78 ft.78 ft.58 ft.
Wind Ratio1.1551.181.051.1551.1581.05Set-up0.04 ft.0.06 ft.0.01 ft.0.20 ft.0.21 ft.0.06 ft.Significant Wave2.25 ft.2.5 ft.1.1 ft.4.7 ft.4.8 ft.2.3 ft.
Maximum Wave3.76 ft.4.17 ft.1.84 ft.7.85 ft.8.01 ft.3.84 ft.
Wave Period2.8 sec.3.0 sec.1.9 sec.3.8 sed.3.85 sec.2.6 sec.
Wave Length40.14 ft.46.1 ft.18.48 ft.74.71 ft.75.9 ft.34.6 ft.
Wave Steepness0.0940.090.10.1050.1060.11 Relative Runup1.3 (Smooth1:3 Slope)0.95 (rip-rap1:2 Slope)0.85 (rip-rap1:2 1/2 Slope)1.3 (Smooth1:3 Slope)0.85 (rip-rap 1:2 Slope)0.85 (rip-rap1:2 1/2 Slope)Runup4.9 ft.3.96 ft.1.56 ft.10.20 ft.6.81 ft.3.26 ft.
Runup + Setup5.0 ft.4.0 ft.1.6 ft.10.40 ft.7.0 ft.3.3 ft.Elevation Reached794.7 ft.793.7 ft.791.3 ft.788.5 ft.785.1 ft.781.4 ft.
CPNPP/FSARAmendment No. 104TABLE 2.4-15 SAFE SHUTDOWN IMPOUNDMENT PROBABLE MAXIMUM FLOOD(Sheet 1 of 2)Time in HoursIncremental Rainfall (Inches)Incremental Rainfall Excess (Inches)PMF Hydrograph Rainfall on SSI Surface (ac-ft)Cumulative Inflow (ac-ft)SSI Surface ElevationSSI Spillway Flow (cfs)(cfs)(ac-ft)3.5.00011775.006.5.211114217775.360 9.6.320039258775.513012.7.4285603121775.720015.8.5354793203776.0270 18.8.5368893295776.532021.9.6431993397777.035024.9.64421084509777.5370 25.6.5504394552777.838026.8.7851554611778.1380271.21.11,311884703778.6830 282.22.12,10314010853779.31,900292.62.53,586231111,095780.33,000302.92.84,683340111,446781.54,20030-1/22.42.355,151203101,659782.14,600312.62.555,883227111,897782.94,90031-1/25.95.857,451275252,197784.26,200329.39.2510,079361402,598785.58,400 CPNPP/FSARAmendment No. 10432-1/21.61.5515,82852673,131787.511,600331.51.4520,84979963,936790.117,60033-1/21.0.9517,31079844,738790.518,40034.9.8513,32163345,375789.815,40034-1/2.7.6510,12448335,861789.210,20035.4.357,78337026,233789.57,20035-1/2.3.256,10728516,519789.75,60036.2.154,78722516,745789.84,600 37.2.12,83231417,060789.73,500 38.2.11,53817817,239789.22,000 39.2.18389717,337788.51,500 42.5.217810127,440786.4600 45.5.21454027,482784.9300 48.5.21463617,519783.9100 51.0.028227,541783.310054.0.0347,545782.910044.939.9TABLE 2.4-15 SAFE SHUTDOWN IMPOUNDMENT PROBABLE MAXIMUM FLOOD(Sheet 2 of 2)Time in HoursIncremental Rainfall (Inches)Incremental Rainfall Excess (Inches)PMF Hydrograph Rainfall on SSI Surface (ac-ft)Cumulative Inflow (ac-ft)SSI Surface ElevationSSI Spillway Flow (cfs)(cfs)(ac-ft)
CPNPP/FSAR Amendment No. 104TABLE 2.4-16UNIT HYDROGRAPH CHARACTERISTICS FOR THE PANTHER BRANCH WATERSHED ABOVE THE SAFE SHUTDOWN IMPOUNDMENT1.A = 3.47 Square Miles2.L = 4.15 Miles 3.Lca = 2.05 Miles4.(LLca).3 = 1.905.Ct = .66.tp = Ct(LLca).3 = 1.14 Hours7.tr = tp/5.5 = .21 Hour8.tR = .5 Hour9.tpR = tp + .25(tR - tr) = 1.21 Hours10.tpR = .5tR = 1.46 Hours11.Cp640 = 42012.QpR = Cp640 x A / t pR = 1,200 cfs13.qpR = Cp640/tpR = 347 cfs per Square Mile14.W-50 = 1.4 Hours15.W-75 = .8 Hour CPNPP/FSARAmendment No. 104TABLE 2.4-17SQUAW CREEK RESERVOIR AREA AND CAPACITY CHARACTERISTICS(Sheet 1 of 3)Elev.0123456789 650-----05111722Acres-----03112545Ac-ft660283438435159697991104Acres70101137177224279343417502599Ac-ft670118132146158172188204216232250Acres7108359741,1261,2911,4711,6671,8772,1012,342Ac-ft680268292316344368396420448472500Acres2,6012,8813,1853,5153,8714,2534,6615,0955,5556,041Ac-ft690524536548562573586598611624637Acres6,5537,0837,6258,1808,7489,3289,92010,52511,14311,773Ac-ft CPNPP/FSARAmendment No. 104700652670691712733755776797820842Acres12,41713,07813,75814,46015,18215,92616,69217,47818,28619,117Ac-ft7108668929249569881,0181,0501,0811,1141,147Acres19,97120,85021,75822,69823,67024,67325,70726,77327,87129,002Ac-ft7201,1801,2101,2441,2761,3101,3441,3781,4141,4471,482Acres30,16531,36032,58733,84735,14036,46737,82839,22440,65542,120Ac-ft7301,5161,5541,5921,6301,9671,7051,7431,7811,8191,857Acres43,61945,15446,72748,33849,98551,67253,39655,15856,95858,796Ac-ft7401,8951,9331,9692,0072,0442,0802,1172,1542,1922,230Acres60,67262,58664,53766,52568,55170,61372,71274,84877,02179,232Ac-ft7502,2682,3082,3482,3902,4312,4732,5162,5582,6002,642Acres81,48183,76986,09788,46690,87693,32895,82298,359100,938103,559Ac-ftTABLE 2.4-17SQUAW CREEK RESERVOIR AREA AND CAPACITY CHARACTERISTICS(Sheet 2 of 3)Elev.0123456789 CPNPP/FSARAmendment No. 104 Note:Based on sedimentation survey range sestablished pursuant to the requirements of the Texas Water Rights Commission.7602,6842,7242,7642,8032,8432,8842,9242,9643,0043,045Acres106,222108,92611,670114,454117,277120,141123,045125,989128,973131,998Ac-ft7703,0843,1223,1623,1953,2343,2723,3083,3293,3543,380Acres135,062138,165141,307144,485147,700150,953154,243157,562160,903164,270Ac-ft7803,4113,4453,4893,5343,5783,6243,6723,7223,7723,823Acres165,665171,093174,560178,072181,628185,229188,877192,574196,321200,119Ac-ft7903,8743,9253,9764,0304,0794,1304,0824,2354,2864,339Acres203,967207,867211,818215,821219,875223,980228,136232,345236,606240,919Ac-ft8004,391---------Acres245,284---------Ac-ftTABLE 2.4-17SQUAW CREEK RESERVOIR AREA AND CAPACITY CHARACTERISTICS(Sheet 3 of 3)Elev.0123456789 CPNPP/FSARAmendment No. 104TABLE 2.4-18SAFE SHUTDOWN IMPOUNDMENT AREA AND CAPACITY CHARACTERISTICSElev. 0123456789730------0.00.10.20.4Acres------0.00.00.20.55Ac-ft7400.71.11.62.22.83.44.04.65.25.9Acres123581115192429Ac-ft7506.67.48.29.110.011.012.113.214.315.5Acres36435059697991103117132Ac-ft76016.717.919.220.521.823.224.726.227.729.2Acres148165184204225247271297324352Ac-ft77030.832.534.336.137.939.841.743.645.647.6Acres382414447482519558599642686733Ac-ft78049.751.853.956.058.160.362.564.867.169.4Acres7818328859409971,0561,1181,1811,2471,316Ac-ft79071.7---------Acres1,386---------Ac-Ft.
CPNPP/FSARAmendment No. 104TABLE 2.4-19PREDICTED AREA AND CAPACITY CHARACTERISTICS OF THE SAFE SHUTDOWN IMPOUNDMENT AFTER FORTY YEARS OF SEDIMENTATIONElev0123456789740000.50.31.111.722.343.06AcresAc-Ft7503.794.513.15.318.06.2247.1308.1389.24610.35611.46712.679AcresAc-ft76013.89215.010716.312217.613918.915720.317721.819823.322024.824426.3270AcresAc-ft77027.929730.532533.135735.439137.842839.846741.750843.655045.659547.6642AcresAc-ft78049.769051.874153.979456.084958.190660.396562.5102764.8109067.1115669.41225AcresAc-ft79071.71295AcresAc-ft CPNPP/FSAR Amendment No. 104TABLE 2.4-20CONCENTRATIONS OF RADIONUCLIDES IN POSTULATED ACCIDENTAL RELEASE(a)(Sheet 1 of 3)IsotopeFloor Drain Tank ConcentrationuCi/ccHalf Life(Year)Br-835.4-32.73-4 Br-843.0-36.05-5 Br-853.4-45.45-6 I-1302.3-31.41-3 I-1312.8-12.20-2 I-1321.1-12.63-4 I-1334.0-12.37-3 I-1345.3-29.99-5 I-1352.1-17.55-4 Rb-868.9-55.11-2 Rb-882.3-13.39-5 Sr-893.6-41.38-1 Sr-901.0-52.92+1 Sr-917.0-41.08-3 Y-901.2-67.30-3 Y-91M4.1-49.47-5 Y-916.5-51.60-1 Y-933.7-51.15-3 Zr-956.1-51.76-1 Nb-955.1-59.64-2 Mo-998.7-27.53-3 CPNPP/FSAR Amendment No. 104Tc-99M5.2-26.87-4Ru-1034.6-51.08-1 Ru-1061.0-51.01+0 Rh-103M5.1-51.07-4 Rh-1061.1-59.47-7 Te-125M2.9-51.59-1 Te-127M2.8-42.99-1 Te-1279.2-41.07-3 Te-129M1.4-39.20-2 Te-1291.8-31.32-4 Te-131M2.6-33.42-3 Te-1311.2-34.76-5 Te-1322.8-28.93-3 Cs-1342.6-22.05+0 Cs-1361.4-23.59-2 Cs-1371.9-23.00+1 Ba-137M1.8-24.85-6 Ba-1402.2-43.51-2 La-1401.6-44.59-3 Ce-1417.1-58.90-2 Ce-1434.2-53.76-3TABLE 2.4-20CONCENTRATIONS OF RADIONUCLIDES IN POSTULATED ACCIDENTAL RELEASE(a)(Sheet 2 of 3)IsotopeFloor Drain Tank ConcentrationuCi/ccHalf Life(Year)
CPNPP/FSAR Amendment No. 104Ce-1443.3-57.79-1Pr-1435.1-53.72-2 Pr-1443.8-53.29-5 H-31.0+01.23+1 Cr-511.9-37.58-2 Mn-543.1-48.55-1 Fe-551.6-32.60+0 Fe-591.0-31.23-1 Co-581.6-21.95-1 Co-602.0-35.27+0 Np-2391.2-36.45-3a)Note:  5.4-3 = 5.4 x 10
-3TABLE 2.4-20CONCENTRATIONS OF RADIONUCLIDES IN POSTULATED ACCIDENTAL RELEASE(a)(Sheet 3 of 3)IsotopeFloor Drain Tank ConcentrationuCi/ccHalf Life(Year)
CPNPP/FSAR Amendment No. 104TABLE 2.4-20ACONCENTRATIONS OF RADIONUCLIDES IN POSTULATED ACCIDENTAL RELEASE(a)(Sheet 1 of 2)
Radionuclide Release (Curies)
Half Life (Years) H-33.18 E+21.23 E+1Br-843.91 E+06.10 E-5 Rb-883.36 E+23.40 E-5 RB-899.99 E+03.00 E-5 Sr-893.00 E-11.40 E-1 Sr-901.54 E-22.60 E+1 Sr-911.73 E-11.10 E-3 Sr-926.72 E-22.97 E-4 Y-901.82 E-27.33 E-3Y-915.54 E-11.61 E-1Y-926.54 E-24.11 E-4 Zr-956.36 E-21.78 E-1 Nb-956.27 E-29.59 E-2 Mo-994.81 E+27.64 E-3 I-1312.27 E+22.20 E-2 I-1328.18 E+12.62 E-4 I-1333.63 E+22.40 E-3 I-1345.45 E+19.99 E-5 I-1352.00 E+27.64 E-4 Te-1322.36 E+18.90 E-3 Te-1342.63 E+08.00 E-5 Cs-1342.73 E+12.05 E+0 CPNPP/FSAR Amendment No. 104Cs-1361.36 E+13.56 E-2Cs-1371.36 E+23.01 E+1 Cs-1388.90 E+16.10 E-5 Ba-1403.91 E-13.51 E-2 La-1401.36 E-14.60 E-3 Ce-1443.09 E-27.78 E-1 Pr-1443.09 E-23.30 E-5 Cr-518.64 E-27.62 E-2 Mn-547.18 E-28.30 E-1Mn-562.73 E+03.00 E-4Co-582.36 E+01.95 E-1 Co-606.99 E-25.26 E+0 Fe-591.00 E-21.24 E-1a)E-5 = 10
-5TABLE 2.4-20ACONCENTRATIONS OF RADIONUCLIDES IN POSTULATED ACCIDENTAL RELEASE(a)(Sheet 2 of 2)
Radionuclide Release (Curies)
Half Life (Years)
CPNPP/FSAR Amendment No. 104TABLE 2.4-21MAXIMUM CONCENTRATIONS IN SURFACE WATER DUE TO POSTULATED RELEASES FROM THE LIQUID RADIOACTIVE WASTE STORAGE TANK(Sheet 1 of 3)Concentration in Squaw Creek Reservoir (uCi/cc) Based on Time After Tank RuptureIsotopeInstantaneousOne DayOne MonthOne YearBr-832.94-09(a)2.78-120.00+000.00+00Br-841.64-093.92-230.00+000.00+00 Br-851.85-100.00+000.00+000.00+00 I-1290.00+004.03-207.39-191.58-18 I-1301.25-093.26-103.45-270.00+00 I-1311.53-071.40-071.15-083.28-21 I-1326.00-081.28-082.68-113.20-42 I-1332.18-079.80-088.22-180.00+00 I-1342.89-081.61-160.00+000.00+00 I-1351.15-079.27-092.00-400.00+00 Rb-864.85-114.68-111.59-116.26-17 Rb-881.25-075.57-320.00+000.00+00 Sr-891.96-101.94-101.30-101.30-12 Sr-905.45-125.45-125.44-125.32-12 Sr-913.82-106.61-115.37-330.00+00 Y-906.54-131.75-125.44-125.33-12 Y-91M2.24-104.20-113.42-330.00+00 Y-913.54-113.73-112.68-115.07-13 Y-932.02-113.87-126.37-330.00+00 Zr-953.33-113.29-112.41-116.46-13 Nb-95M0.00+004.04-141.78-134.79-15 CPNPP/FSAR Amendment No. 104Nb-952.78-112.79-112.79-111.40-12Mo-994.74-083.69-082.45-114.83-48 Tc-99M2.84-083.44-082.36-114.66-48 Ru-1032.51-112.46-111.48-114.03-14 Ru-1065.45-125.44-125.15-122.74-12 Rh-103M2.78-112.22-111.33-113.64-14 Rh-1066.00-125.44-125.15-122.74-12 Te-125M1.58-111.56-111.11-112.04-13 Te-127M1.53-101.52-101.26-101.50-11 Te-1275.02-102.11-101.27-101.50-11 Te-129M7.63-107.48-104.11-104.07-13 Te-1299.82-104.87-102.67-102.65-13 Te-131M1.42-098.14-108.41-170.00+00 Te-1316.54-101.82-101.88-170.00+00 Te-1321.53-081.23-082.60-113.10-42 Cs-1341.42-081.42-081.38-081.01-08 Cs-1367.63-097.24-091.56-093.17-17 Cs-1371.04-081.04-081.03-081.01-08 Ba-137M9.82-099.80-099.78-099.58-09 Ba-1401.20-101.14-102.36-113.10-19 La-1408.72-119.72-112.72-113.57-19TABLE 2.4-21MAXIMUM CONCENTRATIONS IN SURFACE WATER DUE TO POSTULATED RELEASES FROM THE LIQUID RADIOACTIVE WASTE STORAGE TANK(Sheet 2 of 3)Concentration in Squaw Creek Reservoir (uCi/cc) Based on Time After Tank RuptureIsotopeInstantaneousOne DayOne MonthOne Year CPNPP/FSAR Amendment No. 104Ce-1413.87-113.79-112.04-111.60-14Ce-1432.29-111.38-116.11-180.00+00 Ce-1441.80-111.80-111.67-117.39-12 Pr-1432.78-112.73-116.57-122.45-19 Pr-1442.07-111.80-111.67-117.39-12 H-35.45-075.45-075.43-075.16-07 Cr-511.04-091.01-094.89-101.11-13 Mn-541.69-101.69-101.58-107.52-11 Fe-558.72-108.72-108.54-106.68-10 Fe-595.45-105.37-103.44-101.99-12 Co-588.72-098.64-096.51-092.47-10 Co-601.09-091.09-091.08-099.56-10 Np-2396.54-104.87-109.49-141.30-56 Pu-2390.00+004.47-171.75-161.75-16Total Effluent0.220.190.040.02 Concentration Fraction
 
(10CFR20)a)Note:  2.94-09 = 2.94 x 10
-9TABLE 2.4-21MAXIMUM CONCENTRATIONS IN SURFACE WATER DUE TO POSTULATED RELEASES FROM THE LIQUID RADIOACTIVE WASTE STORAGE TANK(Sheet 3 of 3)Concentration in Squaw Creek Reservoir (uCi/cc) Based on Time After Tank RuptureIsotopeInstantaneousOne DayOne MonthOne Year CPNPP/FSARAmendment No. 104TABLE 2.4-22GROUNDWATER CHEMICAL ANALYSESWell Number(a)OrLocation a)See Table 2.4-25Values are milligrams per literSilica (SiO2)Calcium(Ca) Magnesium (Mg) Sodium(a)(Na) Potassium (K) Bicarbonate(HCO3)Sulfate (SO4)Chloride (Cl) Fluoride(F) Nitrate (NO3)Dissolved Solids Total HardnessCaCO391513.58.21425.937228.035.00.20.262067.5111516.97.21616.036056.052.50.40.267571.7131513.510.31736.030261.31050.40.168675.9 141518.69.51947.535474.91050.40.177985.3 371516.97.22046.825090.11581.00.0574971.1391511.85.11705.540025.552.50.30.0150450.4421011.88.22016.732664.21230.40.0775163.1 48151078.2841.936336.21050.30.5721301City of Glen Rose--2118107--39021.017.00.30.4377129 State Well 3259501 5 miles East of Walnut Springs (Paluxy Aquifer)13462960--37917.022.00.16.8386234 CPNPP/FSAR Amendment No. 104TABLE 2.4-23ESTIMATED WATER USAGE AT CPNPP (a)a)To be supplied by water wells or surface water pre-treatment system or both.
Annual Usage(gallons)Avg. Annual flow (gpm)Max. Dailyflow (gpm)Makeup water required55,713,600106305 Potable and Sanitary11,037,6002125 Total water required66,751,200127330 CPNPP/FSARAmendment No. 104TABLE 2.4-24PUBLIC SUPPLY, INDUSTRIAL AND IRRIGATION WELLS, 0-20 MILES(Sheet 1 of 2)WellNumber(a)PiezometricElevation (ft)and DateYield(gpm)Drawdown(b)(feet)Use (c)17013/15/6810090PSCity of Walnut Springs2---13590PSCity of Walnut Springs 36288/24/66-110Irr James Smith 489010/14/65690IrrLee Manning 59743/27/691500IrrJ. W. Waldie 699210/14/651500IrrJ. W. Waldie 7---5500IrrTriangle Ranch 8----0IrrTriangle Ranch 984510/26/651200IrrStanley Allen 108343/27/69460IrrStanley Allen 118683/26/69-30IrrE. L. Huffman 1285510/15/65 -30IrrE. L. Huffman 136159/13/60-40IrrRoy Kenedy 146201960614100PSCity of Glen Rose 156279/21/60250100PSCity of Glen Rose CPNPP/FSARAmendment No. 104166206/19/3050100PSYoung Women's Christian Ass.176119/14/60-90IrrSquaw Creek Cemetery Ass.
185087/20/66222190IndTexas Lime Company 195759/15/60100140IndTexas Cedar Oil Company 204816/06/68-210PSU.S. Army Corps of Engineers 21----0PSCity of Tolar 22----0PSCity of Tolar 23---650IrrCity of Granbury (9 wells) 24----25IrrL. L. Williams 25----100PSCamp El Jesoma)Well locations are shown on Figure 2.4-33
. b)Estimated drawdown, based on original stat ic, piezometric level, before 1900. c)Use:  Ind, Industrial; Irr, Irrigation; PS, Public Supply.TABLE 2.4-24PUBLIC SUPPLY, INDUSTRIAL AND IRRIGATION WELLS, 0-20 MILES(Sheet 2 of 2)WellNumber(a)PiezometricElevation (ft)and DateYield(gpm)Drawdown(b)(feet)Use (c)
CPNPP/FSARAmendment No. 104TABLE 2.4-25LOCAL WATER WELLS(Sheet 1 of 3)CasingWater LevelWellOwnerDrillerDateCompleted Depthof well(ft)Diameter(in)Depth(ft)Water-bearingUnitAltitudeof landsurface(ft)Below landsurfacedatum(ft)Date ofMeasure-mentMethodofLiftUseofWater1John StufflebemeMorris Pollack________Twin Mtn660____ED2do well 2do________do700____WS3do well 3do____6__do825____C,ES4do well 4do____6__do680____WS 5do well 5do____6__do760____WS6do well 6do____6__do700____WS7do well 7do____6__do850____WS8do well 8do____6__do690____WS9Mary Lou StrawnMorris Pollack10/68292 (?)____do670____S,ED,S 10-- Miller__5/72201____do710765/31/72S,ED,S11Charles Branham Well 1Morris Pollack__200 (?)____Twin Mtn710____J,ED,S12Unknown__________Twin Mtn690____ES13A. H. WeeksMorris Pollack8/683604364.5Twin Mtn9052508/24/68S,ED,S14Carlisle Cravens Well 1__1920 (?)138____Twin Mtn750____S,ED15do well 2__1950 (?)320____Twin Mtn810____C,WS16do well 3__1920 (?)320____Twin Mtn885____WS17do well 4__1920 (?)320____Twin Mtn915____WS 18do well 5__1920 (?)150____Twin Mtn760____WS19Carlisle Cravens Well 6__1920 (?)320____Twin Mtn925____WS20do well 7__do150____Twin Mtn925____WS}}

Latest revision as of 22:04, 9 January 2025

FSAR Amendment 107, Text - Chapters 1 and 2
ML16180A431
Person / Time
Site: Comanche Peak  Luminant icon.png
Issue date: 02/01/2016
From:
Luminant Generation Co
To:
Office of Nuclear Reactor Regulation
Shared Package
ML16042A346 List:
References
txx-16006, CP-20160003
Download: ML16180A431 (678)
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