ML20076K101
| ML20076K101 | |
| Person / Time | |
|---|---|
| Site: | Prairie Island  |
| Issue date: | 06/30/1983 |
| From: | Musolf D NORTHERN STATES POWER CO. |
| To: | Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML20076K105 | List: |
| References | |
| NUDOCS 8307080198 | |
| Download: ML20076K101 (22) | |
Text
Northem States Power Company 414 Nicollet Mall Mint.eapohs, Minnesota 55401 Telephone (612) 330-5500 June 30, 1983 Director Office of Nuclear Reactor Regulation U S Nuclear Regulatory Commission Washington, DC 20555 PRAIRIE ISLAND NUCLEAR GENERATING PLANT Docket Nos. 50-282 License Nos. DPR-42 50-306 DPR-60 Submittal of Revision No. I to the Updated Safety Analysis Report (USAR)
Pursuant to 10CFR 50.71(e) we are submitting 13 copies of Revision No.1 to the Updated Safety Analysis Report (USAR) for the Prairie Island Nuclear Generating Plant. This revision updates the infonnation in the USAR for tne period from January 1,1982 through December 31, 1982.
Exhibit A contains a description and a summary of the safety evaluation for changes, tests and experiments made under the provisions of 10CFR 50.59 during the period January 1,1982 to December 31, 1982.
In previous years this information was reported in the Annual Operating Report.
Exhibit B contains the USAR page changes and instructions for entering the pages.
Included in Exhibit 8. for inclusion in the USAR, is Northern States Power Company's Operational Quality Assurance Plan in compliance with 10CFR 50.54.
(Refer to our May 25, 1983 letter to the Regional Administration, Region III).
Past Annual Operating Reports have described changes up to and including Revision 6 to the Plan.
Changes included in Revisions 7 and 8 to the plan are described in Exhibit A (Item 22 page' A-6 ) of this letter.
DO Mw s l
David Mesolf l
Manager - Nuclear Suppor Services DMM/TMP/js cc: Regional Administrator-III, NRC NRR Project Manager (w/o enclosure)
NRC' Resident Inspector G Charnoff Attachments na' m a" e m e b
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EXHIBIT A PRAIRIE ISLAND NUCLEAR GENERATING PLANT ANNUAL REPORT OF CHANGES, TESTS AND EXPERIMENTS January 1, 1982 to December 31, 1982 The following sections include a brief description and a summary of the safety evaluation for those changes, tests and experiments which were carried out without prior NRC approval, pursuant to the requirements of 10CFR 50.59(b).
1.
Containment / Auxiliary Building Chilled Water System (76Y002)
A closed loop chilled water system consisting of two 1100 ton centri-fugal chillers, 25 new unit coolers /six handlers and the associated piping was added to the containment and auxiliary building heat removal system. This system supplies chilled water to the Contain-ment Fan Coil Units and various unit coolers in the auxiliary building during normal operation in an attempt to reduce temperatures for equipment protection and personnel access.
If an "S" signal is received the chilled water system is isolated to both Units 1 & 2 and the heat removal source is returned to the plant cooling water sytem.
2.
Hot I & C Shop Air Conditioning (76YO35)
A unit cooler / air handler with a chilled water supply from the Administration Building Chiller was installed in the Hot Instrument Shop to reduce temperatures.
3.
_ Security Facility Upgrade (76YO51)
The plant security system was upgraded to meet the requirments of USNRC RG1.17, ANSI N18.17, 10CFR73.55 and UL-752. Controlled, protected and vital areas were established. The central and secondary alarm stations, the security computer, security MCC's, security power system (including diesel generator), weapons storage and personnel &
vehicle portal c;ntrol systems were installed.
4.
Noise Abatonent for Power Operated Relief Valves (76YO53)
Noise silencers (mufflers) were installed on the outlet of each of the steam generator power operated relief valves. These silencers reduce noise levels to ao sce=rtable value and help promote community relations.
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1 5.
Replace Unit 1 Inverters (78YO68)
The Unit 1 Westinghouse Instrument Inverters have been replaced with four SKVA uninterruptible power systems (UPS) manufactured by Solid-state Controls, Inc (SCI). Each UPS includes an inverter portion and a transfer switch portion. The inverter portion has two sources of power which are the station battery and a 480V AC source. This 480V AC source is rectified and filtered to DC. The transfer switch portion includes an automatic static transfer switch and a manual bypass switch. The autoratic static transfer switch is designed to transfer the' instrument bus load from the inverter, if it fails, to an AC source.
6.
Expand the fToor suce at Elevation 755' in the Auxiliary Building (78YO77)
The floor system in the Auxiliary Building at elevation 755' modified to provide a complete floor system between the following boundaries:
1.
Column line J on the North 2.
Column line L.3 on the South 3.
Column line 7 on the East, and 4.
Column line 9 on the West.
The modified floor system provides additional laydown and decontamin-ation areas outside the Units 1 and 2 containment maintenance accesses.
Additionally, the hot machine shop was relocated from its location at 695' in the Auxiliary Building to the northeast corner of the floor at elevation 755'.
The stairway from 735' to 755' was relocated from 'its location along column line L.3 to a location along column line 7.
Block-outs were provided in the modified floor along column line L.3 to permit installation of laundry chutes from elevation 755' to elevation 735'.
Additional lighting was provided for the area under the modified floor. A power distribution panel was provided above the modified floor for the hot machine shop equipment and miscellaneous electrical uses.
A blockout was provided in the proposed floor and a removable hatch installed.
This hatch is required in the event that an RHR heat exchanger must be removed.
l The previously installed trolleys under the existing 755' floor were extended so that all existing removable hatches in the 735' floor may be removed.
The floor system is Design and Quality Assurance Type I.
It was anlayzed and designed to be consistent with the static and dynamic loading requirments of auxiliary building structural system.
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7.
Air Ejector Reroute (79YO88)
This design change reroutes the air ejector discharge from the Turbine Building roof to the suction of the Auxiliary Building Normal and Special Exhaust Fans. A cross connect line is installed in the Turbine Building between Unit 1 and Unit 2 to compensate for periods when only one exhaust fan is operating. Check dampers are installed between the Auxiliary Building Normal and Special Exhaust Fans to prevent backflow from the secured fan. An office in the duct to the Auxiliary Building Special Exhaust System will limit flow into the system to 50 cfm.
This design change will provide about ih hours delay time in the releases via the air ejector during normal operations and will allow continous on scale indication of radioactive material released through the Auxiliary Building Stack and Shield Building Stack during an accident.
8.
Acoustical Valve Monitoring of Pressurizer Power Operated Relief Valves (PORV) and Safety Valves (79YO90)
An acoustic monitoring system was installed on the common discharge of the pressurizer safety valves, and the inlets for each pressurizer PORV. This system provides a rapid means of detecting flow through the above valves. The system has outputs to a common alarm on the reactor control panel, to individual status lights and to the plant computer.
9.
Redesign of ET-30B (79L553)
Heat trace circuit ET-30 cable routing was changed such that low flow portions of the piping are on one circuit and high flow portions of the piping are on a separate circuit.
- 10. Manipulator Crane Air Cylinder Gripper Modification (81L661)
Both manipulator cranes were modified such that the air cylinders use pressurized air to engage in addition to gravity. This results in a more positive method of latching onto a fuel assembly. The modification involves replacing the air hoses take-up reel going to l
the cylinders and changes to the pneumatic system in the control i
console.
- 11. Unit 2 Cycle 7 - Reload Summary (82L694)
During the Prairie Island Unit 2, Cycle 6-7 refueling, 39 spent Westinghouse fuel assemblies (39 Region 6, 1 Exxon Region 8) will be replaced with 40 fresh Exxon fuel assemblies. The composition of the core during Cycle 7 will be 1 thrice burned Region 6 Westinghouse assembly, 40 twice burned Region 7 Exxon fuel assemblies, 40 once l
burned Region 8 Exxon fuel assemblies and 40 new Exxon TOPROD (TWO LOOP REOPTIMIZED DESIGN) fuel assemblies.
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The Exxon TOPROD assemblies are a new PWR design' fuel which utilizes a natural uranium blanket in the upper and lower 6 inches of the core.
This design concept was developed by Exxon as a means of achieving a more economical fuel loading by saving on enrichment costs.
In addition, by utilizing gadolinia burnable poison, the lifetime of the cycle can be increased. This cycle is projected to be 12, 450/ MWD /MTV (or 3.42 EFPD).
This will be equivalent to about a 13-13 month cycle, including the refueling outage.
In addition, the primary source assemblies are being removed and replaced with 2 secondary source assemblies. The primary sources have been found to swell and stick into spent fuel assemblies at some plants. The recommendation to remove the sources came from Westinghouse Nuclear Feel Division. This will now make both units the same, both having only secondary sources.
- 12. #23 Containment Dome Recirculation Fan Support Modification (82L707)
The truss structure supporting #23 Dome Recirculation Fan was changed from a welded truss structure to a bolted truss structure to allow access for maintenance.
- 13. Unit 1 Cycle 8 - Reload Summary (82L722)
During the Prairie Island Unit 1, Cycle 7/8 refueling outage I Westinghouse Region 6, 40 Westinghouse Region 7, & 40 Exxon TOPROD Region 9 fuel assemblies will be removed from the core. The com-position of the core during Cycle 8 will be 1 twice burned Westinghouse assembly from Region 2, 40 new Exxon TOPROD Region 10 assemblies, 40 once burned Region 8 Exxon fuel assemblies and 40 new lower enriched Exxon TOPROD Region 10A assemblies.
Included in the Cycle 8 reload are 240 fuel pins containing 4 w/o gadolina distributed equally among 20 Region 10 assemblies, and 64 fuel pins containing I w/o gadolina distributed equally among 16 Region 10A assemblies. The core loading pattern is projected to produce a full power cycle length of 13,000 300 MWD /MT or 354 8 effective Full Power Days.
During Cycle 7 the activity in Unit l's primary coolant indicated that several fuel pins had failed, and from the radio-chemistry data it was determined that the failed pins were in Region 9 fuel assemblies.
The decision was made to remove the entire region from the core for at least 1 cycle and reconstitute the fuel after the outage. This required 40 additional fuel assemblies of lower enrichment to simulate once-burned fuel, hence region 10A.
Region 10A is then only intended for two cycles of operation.
- 14. Condense Spray System Unit I (80Y121)
A condenser spray system was added to Unit 1 to reduce the dissolved oxygen level in the condensate, provide for condenser cleaning, filter particulates from the condensate, aid in drawing condenser vacuum, reduce rotor bow, and reduce the high temperature gradients in the conderser during startup. The system acts independently of the condensate and feed water systems.
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- 15. Steam Flow Transmitter Replacement (80Y141)
Steam Flow Transmitters for Units 1 and 2 were replaced. The old transmitters had caused numerous reportable occurrences because of instrument drift and maintenance problems.
16, 102 Switchgear Room Unit Cooler Installation (80L576)
Train A heat removal from the Safeguards Chilled Water System was added to the Train B Bus 120 Room. This provides redundancy for heat removal so that Bus 120 Room may be used to house Train A safeguards instrument.
- 17. Containment purge Selector Switch (80LS85)
To maintain train separation between trains A and B, and to maintain the containment ventilation isolation (CVI) valves closed upon reset of the CVI signal, the containment purge control circuit was modified.
The control panel was revised, and the latching circuit was changed to release on reciept of the CVI signal. The valves will not reopen when the CVI signal is reset.
- 18. Provide Telephone System with Uninterruptable power Suoply I.E. Bulletin No. 80-15, possible Loss of Emergency Notification System (ENS) with loss of offsite power, required a safeguards instrumentaiton Bus (safeguards station batteries and inverter) or equally reliable power supply, to prevent loss of communications between Prairie Island and the NRC Operations Center (via the ENS) during a loss of all offsite power. Modifications were made which resulted in an inverter supply to the ENS. Power to the inverter consists of a safeguards, diesel backed, AC supply and safeguards station battery.
- 19. Adding Isolation Valves to the Boric Acid Blender and Suction SI pump Line (80L618)
Isolation, drain vent valves were added to the 21 Boric Acid line from the transfer pumps to the blender and suction of the SI pump lines, for ease of maintenance. The boric acid line to the suction of the SI pumps was downgraded from ASME code class 2 to non l
safety related. One of the isolation valves installed was the boundary interface.
- 20. Installation of Redundant Limit Syftchs on Turbine Building Auxiliary Building and Containment Building Cranes (20L631)
Redundant up travel limit switches were installed on the main and auxiliary hooks of the subject cranes to give added protection against two-block accidents.
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- 21. Test Valve on the Boric Acid Tanks (81L681)
A test valve was added to each Boric Acid Stroage Tank low level tap for eate of calibrating the tank level.
- 22. Changes to the Operational Quality Assurance Plan Revision 7 to the NSP Operational Quality Assurance Plan was internally reviewed and approved on February 15, 1982.
Revision 8 was internally reviewed and approved on April 13, 1983. We have concluded that these changes do not decrease the effectiveness of NSP's Operational Quality Assurance Program. A summary of significant changes resulting from both revisions, i.e., the net change from Revision 6 to Revision 8, is presented below. The Operational Quality Assurance Plan, Revision 8, is included in Section 13 of the USAR.
SUMMARY
OF SIGNIFICANT, NET CHANGES A. Change: Corporate Organization with Operational Quality Assurance Responsibilities Descriotion:
The organization description was reformatted and changed to reflect several reorganizations that have occurred since Revision 6 to the plan was approved in February,1981. Significant changes include:
1.
The elimination of the Vice Presidnet Power Systems and Operation and the Vice President Power Production. These positions have been restructured into the Director System Production, Operation and Maintenance and the Directer Nuclear Generation, both reporting directly to the Senior Vice President Power Supply.
2.
The quality assurance organizations at the corporate level, previously under the Vice President Plant Engineering and Construction and the Vice President Power Production, have been combined under the Director Power Supply Quality Assurance.
This position reports directly to the Senior Vice President Power Supply.
3.
The positions under the Vice President Plant Engineering and Construction were reorganized to include the General Manager Nuclear Engineering and Construction and other non nuclear and support positions. The construction and engineering
.?
resources for nuclear plants have been consolidated under the general manager.
Other changes have been incorporated for the various staffs reporting to the above mentioned positions. These include reassignment of responsibilities and personnel.
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B.
Change: Program Administration
==
Description:==
The administrative control directive and instruction system has been revised to reflect the corporate reorganizations. This involved going to a single level corporate directive and instruction system where previously there had been two levels.
C.
Change: Modification Control (.formerly Design Control)
==
Description:==
Nuclear Engineering and Construction has been placed under the uniform modification control system. Previously Plant Engineering and Construction and Power Production had separate pregrams based on the same corporate commitments. The uniform system now directly implements ANSI N45.2.11-1974, QA Requirements for the Design of Nuclear Power Plants.
D.
Change:
Inspections
==
Description:==
Direction for Plant Engineering and Construction to implement a separate inspection program has been deleted. This is associated with the combining of the medification control programs (see change 3). Performances of inspection activities by a quality engineer has been changed to a qualified person in accordance with NSP's NRC submittal of August 4, 1981. This submittal has replaced ANSI N45.2.6-1973 and Regulatory Guide 1.58 of August,1973,.s NSP's commitment with respect to qualification of inspection, testing and examination personnel.
E.
Change: Records
==
Description:==
Specific listings of records that had been extracted from other commitments and regulations were removed.
Replacing these listings are requirements that records required by commitments and regulations be identified in implementing documents.
F.
Change: Fire Protection
==
Description:==
Fire protection requirements (from the "NSP Fire Protection Outline" I
submittal to the NRC of November 1,1979) written into Revision 6 of I
the plan have been extracted and made into a plant appendix.
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Exhibit B PRAIRIE ISLAND NUCLEAR GENERATING PLANT Revision 1 to the Updated Safety Analysis Report The attached instructions should be followed when making this revision to the Updated Safety Analysis Report.
If you have any questions concerning this revision call:
Betty Dean (612) 330-6763 Terry Pickens (612) 330-5671 6
g ev _
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1.2-17 1.2-17 0
1.2-18 1.2-18 1
- 2. Plant Site and Environs 2-111 2-111 1
2-iv 2-iv 0
2-v 2-v 1
2-vi 2-vi 0
2.3-1 2.3-1 1
2.3-2 2.3-2 0
2.6-2 2.6-2 0
2.7-1 2.7-1 1
2.10-1 2.10-1 1
TBL 2.2-1 TBL 2.2-1 0
TBL 2.7-1 TBL 2.7-2
- 3. Reactor Core Remove this tab and insert the tab titled "3.
REACTOR" 3-vii 3-vii 1
3-viii 3-viii 1
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- 3. Reactor 3.3-4 3.3-4 1
3.3-5 3.3-5 1
3.5-3 3.5-3 1
3.5-4 3.5-4 0
TBL 3.2-3 TBL 3.2-3 0
TBL 3.2-4 TBL 3.2-4 1
TBL 3.2-5 TBL 3.2-5 1
TBL 3.2-6 TBL 3.2-6 1
TBL 3.2-7 TBL 3.2-7 1
TBL 3.3-1 TBL 3.3-1 1
TBL 3.3-2 TBL 3.3-2 1
TBL 3.3-3 TBL 3.3-3 1
TBL 3.3-4 TBL 3.3-4 1
TBL 3.4-1 TBL 3.4-1 0
FIG 3.1-1 FIG 3.1-1 1
FIG 3.3-1 FIG 3.3-1 1
FIG 3.3-2 FIG 3.3-2 1
FIG 3.3-3 FIG 3.3-3 1
FIG 3.3-4 FIG 3.3-4 1
FIG 3.3-5 FIG 3.3-5 1
FIG 3.3-6 FIG 3.3-6 1
- 4. Reactor Coolant System 4-1 4-1 0
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- 4. Reactor Coolant 4.2-2 4.2-2 0
System 4.2-3 4.2-3 1
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4.2-5 4.2-5 1
4.2-6 4.2-6 1
4.3-1 4.2-7 1
4.2-8 1
4.3-1 1
4.3-8 4.3-8 0
4.3-9 4.3-9 1
4.4-5 4.4-5 0
4.4-6 4.4-6 1
4.4-)
4.4-7 1
4.5-1 4.5-1 1
4.8-3 4.8-3 1
TBL 4.1-1 4.8-4 1
(1 of 2) 4.8-5 1
TBL 4.1-1 0
(1 of 2)
TBL 4.3-5 TBL 4.3-5 0
TBL 4.3-6 TBL 4.3-6 1
TBL 4.3-13 1
TBL 4.3-14 1
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- 5. Plant Containment Systems 5-1 5-1 0
5-11 5-11 1
5.2-8 5.2-8 1
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5.2-15 5.2-15 1
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- 5. Plant Containment Systems 5.2-16 5.2-16 1
5.2-17 5.2-17 1
5.2-18 5.2-18 1
5.2-19 5.2-18a 1
5.2-18b 1
5.2-19 1
5.3-14 5.3-14 0
5.3-15 5.3-15 1
5.3-20 5.3-20 0
5.3-21 5.3-21 1
TBL 5.2-1 TBL 5.2-1 (1 of 17 thru (1 of 17 thru 17 of 17) 17 of 17) 1 TBL 5.2-2 TBL 5.2-2 0
- 6. Engineered Safeguards 6-iii 6-111 1
6-iv 6-iv 0
6.2-3 6.2-3 0
6.2-4 6.2-4 1
6.2-31 6.2-31 0
6.2-32 6.2-32 1
6.2-32a 1
6.2-32b 1
6.4-7 6.4-7 1
6.4-8 6.4-8 0
TBL 6.2-5 TBL 6.2-5 (2 of 2)
(2 of 2) 1 TBL 6.2-6 TBL 6.2-6 0
TBL 6.3-1 TBL 6.3-1 0
TBL 6.3-2 TBL 6.3-2 1 F m _.
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- 7. Plant Instrumentation and Control Systems 7-ix 7-ix 1
7-x 7-x 0
7-xi 7-xi 1
7-xii 7-xii 1
7-xiii 7-xiii 1
7-xiv 7-xiv 1
7.5-2 7.5-2 1
7.5-3 7.5-3 1
7.5-4 7.5-4 1
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7.5-7 7.5-7 1
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7.5-10 7.5-10 0
7.5-11 7.5-11 1
7.5-14 7.5-14 0
7.5-15 7.5-15 1
7.5-16 7.5-16 1
7.5-17 7.5-17 1
7.5-18 7.5-18 1
7.5-19 7.5-19 1
7.5-20 7.5-20 1
7.6-1 7.6-1 0
7.9-5 7.9-5 0
7.10-1 7.10-1 1
7.10-2 7.10-2 1
7.10-3 7.10-3 1
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- 7. Plant Instrumentation and Control Systems TBL 7.4-5 TBL 7.4-5 0
TBL 7.5-1 TBL 7.5-1 (1 of 3)
(1 of 4) 1 TBL 7.5-1 TBL 7.5-1 (2 of 3)
(2 of 4) 1 TBL 7.5-1 TBL 7.5-1 (3 of 3)
(3 of 4) 1 TBL 7.5-2 TBL 7.5-1 (4 of 4) 1 TBL 7.5-3 TBL 7.5-2 (1 of 2) 1 TBL 7.5-2 (2 of 2) 1 TBL 7.5-3 1
TBL 7.6-2 TBL 7.6-2 (2 of 2)
(2 of 2) 0 TBL 7.10-1 TBL 7.10-1 1
TBL 7.10-2 TBL 7.10-2 (1 cf 2)
(1 of 2) 1 TBL 7.10-2 TBL 7.10-2 (2 of 2)
(2 of 2) 1 FIG 7.2-3 FIG 7.4-3 FIG 7.4-3 1
FIG 7.4-5 FIG 7.4-5 1
FIG 7.4-8 FIG 7.4-e 1
FIG 7.4-9b FIG 7.4-9b 1
FIG 7.4-10 FIG 7.4-10 1
FIG 7.4-14 FIG 7.4-14 1
FIG 7.4-15 FIG 7.4-15 1
FIG 7.4-16 FIG 7.4-16 1. _ _ _..
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- 8. Plant Electrical 8-1 8-i 0
8-11 8-11 1
8.1-1 8.1-1 1
8.1-2 8.1-2 0
8.2-1 8.2-1 1
8.2-2 6.2-2 1
8.2-3 8.2-3 1
8.2-4 8.2-4 0
8.2-5 8.2-5 0
8.3-1 8.3-1 1
8.3-2 8.3-2 1
8.3-3 8.3-3
,0 8.3-4 8.3-4 1
8.3-5 8.3-5 1
8.4-1 8.4-1 1
8.4-2 8.4-2 0
8.4-3 8.4-3 0
8.4-4 8.4-4 1
8.5-1 8.5-1 0
8.6-1 8.6-1 1
8.7-3 8.7-3 1
8.7-4 8.7-3a 1
8.7-3b 1
8.7-4 0
8.9-1 8.9-1 1
8.10-1 8.10-1 1
FIG 8.2-2 FIG 8.2-2 1
FIG 8.2-3 FIG 8.2-3 1
FIG 8.3-1 FIG 8.3-1 1
FIG 8.3-2 FIG 8.3-2 1
FIG 8.5-1 FIG 8.5-1 1
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- 9. Plant Radioactive Waste Control Systems 9.3-4 9.3-4 0
9.4-1 9.4-1 1
- 10. Plant Auxiliary Systems 10.3-2 10.3-2 1
10.3-3 10.3-3 0
10.3-8 10.3-8 1
10.3-9 10.3-9 0
10.3-22 10.3-22 1
10.3-23 10.3-23 0
10.6-1 10.6-1 0
10.6-2 10.6-2 1
IV
- 11. Plant Power 11-1 11-1 0
Conversion Systems 11-11 11-11 1
11.3-2 11.3-2 1
11.4-1 11.4-1 1
11.7-3 11.7-3 1
11.8-1 11.8-1 0
11.9-4 11.9-4 1
11.9-5 11.9-5 1
11.9-8 11.9-8 1
11.9-9 11.9-9 0
11.9-12 11.9-12 1
11.9-13 11.9-13 0
FIG 11.1-11 FIG 11.1-11 1
- 12. Plant Structures and Shielding 12-vii 12-vii 0
12-viii 12-viii 1
12-ix 12-ix 1
12-x 12-x 1
12-xi 12-xi 0
12-xit 12-xii 1
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- 12. Plant Structures and Shielding 12 xiii 12-xiii 0
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12.2-60 12.2-60 1
12.2-61 12.2-61 0
12.2-100 12.2-100 1
12.2-101 12.2-101 1
12.2-102 12.2-102 1
12.2-103 12.2-103 1
12.2-104 12.2-104 1
12.2-105 12.2-105 1
12.2-106 12.2-106 1
12.2-107 12.2-107 1
12.2-108 12.2-108 1
12.2-109 12.2-109 1
12.3-3 12.3-3 1
12.3-4 12.3-4 1
12.3-5 12.3-5 1
12.3-6 12.3-6 0
12.4-3 12.4-3 1
12.5-1 12.5-1 0
12.5-2 12.5-2 1
TBL 12.2-1 12.5-3 (1 of 12) 1 12.5-4 1
TBL 12.2-1 (1 of 12) 0 TBL 12.3-6 Blank Side FIG 12.1-2 FIG 12.1-2 1
FIG 12.1-3 FIG 12.1-3 1. - -. - -.
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- 12. Plant Structures and Shielding FIG 12.2-36 1
FIG 12.2-37 1
- 13. Plant Operations 13-1 13-1 1
13-11 13-11 0
13-111 13-111 0
13-iv 13-iv 1
13.2-2 13.2-2 0
13.2-3 13.2-3 1
13.2-4 13.2-4 1
1 13.3-1 13.3-1 1
13.4-1 13.4-1 1
13.4-2 13.4-2 1
FIG 13.2-2 FIG 13.2-2 1
- Insert tab titled, "13A. Operational QA Plan" between FIG 13.2-2 and tab titled "14. Safety and Accident Analysis".
13A. Operational QA Plan
- Insert the Operational QA Plan Revision 8 (cover sheet, Table of Contents and 78 pages).
- Insert tab titled "13B.
Licensed Operator Requalification Program".
138. Licensed Operator Requalification Program
- Insert the Licensed Operator Requalification Program - Revision 6, 9 pages.
V
- 14. Safety and Accident Analysis 14-1 14-1 0
14-11 14-11 1
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- 14. Safety and Accident Analysis14-111 14-111 1
14-iv 14-iv i
14-v 14-v 1
14-vi 14-vi 0
14-xi 14-xi 1
14-xii 14-xii 0
14.2-1 14.2-1 0
14.2-2 14.2-2 1
14.4-3 14.4-3 1
14.4-4 14.4-4 1
14.4-19 14.4-19 0
14.4-20 14.4-20 1
14.5-17 14.5-17 1
14.5-18 14.5-18 0
14.5-19 14.5-19 0
14.5-20 14.5-20 1
14.5-21 14.5-21 1
14.5-22 14.5-22 1
14.5-23 14.5-23 1
14.5-24 14.5-24 1
14.5-27 14.5-27 1
14.5-28 14.5-28 1
14.6-3 14.6-3 0
14.6-4 14.6-4 1
14.6-5 14.6-5 1
14.7-1 14.6-6 1
14.6-7 1
14.7-1 1
l 14.10-1 14.10-1 0
14.10-2 14.10-2 1
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- 14. Safety and Accident Analysis TBL 14.4-2 TBL 14.4-2 0
TBL 14.5-1 TBL 14.5-1 (1 of 2)
(1 of 2) 1 TBL 14.5-1 TBL 14.5-1 (2 of 2)
(2 of 2) 1 TBL I4.5-2 TBL 14.5-2 (1 of 2)
(1 of 2) 1 TBL 14.5-2 TBL 14.5-2 (2 of 2)
(2 of 2) 1 TBL 14.5-3 TBL 14.5-3 (1 of 2)
(1 of 2) 1 TBL 14.5-3 TBL 14.5-3 (2 of 2)
(2 of 2) 1 TBL 14.5-4 TBL 14.5-4 (1 of 2)
(1 of 2) 1 TBL 14.5-4 TBL 14.5-4 (2 of 2)
(2 of 2) 1 TBL 14.6-1 TBL 14.6-1 (1 of 2)
(1 of 2) 0 TBL 14.6-10 TBL 14.6-10 0
TBL 14.7-1 TBL 14.7-1 1
FIG 14.5-10 FIG 14.5-10 1
FIG 14.5-11 FIG 14.5-11 1
FIG,14.5-12 FIG 14.5-12 1
FIG 14.5-13 FIG 14.5-13 1
FIG 14.5-14 FIG 14.5-14 1
i FIG 14.5-15 FIG 14.5-15 1
FIG 14.6-20
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