ML20148L400
| ML20148L400 | |
| Person / Time | |
|---|---|
| Site: | Limerick  |
| Issue date: | 03/24/1988 |
| From: | Gallo R NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| To: | Kemper J PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC |
| References | |
| NUDOCS 8804010265 | |
| Download: ML20148L400 (47) | |
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G a MAR 141088 Docket Nos. 50-352 50-353 Philadelphia Electric Company ATTN: Mr. J. S. Kemper Senior Vice President, Nuclear 2301 Market Street Philadelphia, Pennsylvania 19101 Gentlemen:
Subject:
MEETING
SUMMARY
A meeting was held with members of your staff on January 29, 1988 at the Region I office to discuss a proposal to license currently licensed operators at Limerick Unit 1 to operate Limerick Unit 2. The details of this discussion along with informatien provided by your staff are included in the Meeting Summary enclosed with this letter.
In accordance with Section 2.790 of the NRC's "Rules of Practice" Part 2, Title 10, Code of Federal Regulations, a copy of this letter and the enclosed report will be placed in the NRC's Public Document Room.
No reply to this letter is required. Should you have any questions concerning this matter, we will be pleased to discuss them with you.
Sincerely, ROBERT M. GALLO Robert M. Gallo, Chief Operations Branch Division of Reactor Safety
Enclosure:
As stated cc w/ enc 1:
Graham M. Leitch, Vice President, Limerick Generating Station Troy B. Conner, Jr. , Esquire Eugene J. Bradley, Esquire, Assistant General Counsel W. M. Alden, Engineer in Charge, Licensing Section Public Document Room (PDR) local Public Document Room (LPDR)
Nuclear Safety Information Center (NSIC)
NRC Resident Inspector John Hannon, Chief OLB, NRR Commonwealth of Pennsylvania 0FFICIAL RECORD COPY LIM MTG
SUMMARY
- 0001.0.0 02/26/88 es04010265 880324 \\
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S. Joseph Kcwalski, Vice President, Nuclear Engineering !
W. T. Ullrich, Superintendent, Limerick 2 Project J. M. Corcoran, Quality Assurance Manager >
Graham M. Leitch, Vice President, Limeriat Generating Station J. W. Gallagher, Vice President - Nuclear Troy B. Conner, Jr., Esquire +
Eugene J..Bradley, Esquire. Assistant General Counsel P
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SUMMARY
- 0002.0.0 02/26/88 l
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U.S. NUCLEAR REGULATORY COMMISSION REGION I Docket Nos. 50-352 50-353 License No. NPF-39 Licensee: Philadelphia Electric Company 2.301 Market Street Philadelphia, Pennsylvania 19101 Facility Name: Limerick Units 1 and 2
Purpose:
Briefing on Limerick Unit 2 Operator Licensing Based on Differences Between Unit 1 and Unit 2 Introduction A meeting was held at the NRC Region I Office on January 29, 1938 to discuss a proposal by the licensee to train its currently licensed operators at Limerick Unit 1 on differences between Limerick Units 1 and 2 in order for these operators to be licensed on Limerick Units 1 and 2. The meeting was requested by the licensee.
NRC Attendees R. Fuhrmeister, Resident, Limerick, Unit 2 R. Gallo, Chief, Operations Branch, DRS A. Howe, Senior Operations Engineer DRS D. Lange, Chief, EWR Section, DRS J. Linville, Chief Projects Section 2A, DRP C. Sisco, Operations Engineer, DRS Licensee Attendees W. Barnshaw, Operations Department, Limerick 2 E. Firth, Traiaing Coordinator, Limerick J. Hutton, Startup Manager, Limerick 2 W. Ullrich, Superintendent, Limerick 2 Project Summary The licensee presented its program for achieving dual unit licenses for the currently licensed Limerick Unit 1 operators. The agenda disctssed is included as Attachment I to this enclosure, OFFICIAL RECORD COPY LIM MTG SUHMARY - 0003.0.0 02/18/88
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Specific Items Discussed
- 1. The licensee described its program for identifying differences, evaluating those which affect operations, and forwarding this information to the training department. When asked by the NRC how setpoint differences were treated, the licensee stated that these are handled the same way as dcsign differences.
, The licensee also stated that where possible the plant differences would b3 minimited. The criteria for evaluating the effect of a design difference on the operator is given in Attachment 2 of this enclosure.
Attachment 3 of this enclosure is a current summary of the differences I which affect operator transparency. Attachment 4 of this enclosure lists 4 all differences identified to this date.
- 2. The licensee stated that the Technical Specifications for Unit 2 would be a separate document. The licensee also stated that Technical Specifications for systems common to both units would be contained in the Unit 1 Technical Specifications. The licensee stated that a draft of Unit 2 Technical Specifications would be submitted to the NRC in April',
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- 3. The licensee stated that all operating procedures for Unit I are being revised. All efforts to develop operating procedures which can be used i
by either unit are being made. The prucedures for surveillance and l
testing will be unit specific.
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- 4. The licensee described its proposed training program and training
] schedule. This plan is Attachment 5 to this enclosure.
J l S. The licensee described its proposed schedule for rotating personnel between units and into training. This schedule is Attachment 6 to this
! enclosure.
- The licensee also discussed its projected operator manpower status and is Atta:hment 7 to this enclosure.
I Summary of Licensee Commitments i
April 1988 Submittal of letter to the NRC with a description of plant differences and the training plan for acquiring Unit 2 licenses for those Unit 1 personnel.
August 1, 1988 Submittal to NRC Region I the training raterial used for j instruction of the Unit 1 personnel and a draft copy of the Unit 2 Technical Specifications.
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1 0FFICIAL RECORD COPY LIM MTG
SUMMARY
- 0004,0.0 1 02/18/88 I
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3 Summary of NRC Comments The NRC advised the licensee of the applicable regulations (i.e.10 CFR 55.47) and NUREG 1021 ES 106 (Examiner Standards). The NRC highlighted tha requirement that these personnel will need extensive operating experience and advised the licensee that staff engineers may not meet this requirement.
The NRC notified the licensee that action on an individual's Unit I license would not be excluded if significant weaknesses were identified on the differences exaninations.
Attachments:
- 1. Meeting Agenda '
- 2. Criteria for evaluating effect of design difference on the operator
- 3. Summary of differences affecting operator transparency
- 4. List of differences identified to date
- 5. Proposed training program
- 6. Rotation schedule
- 7. Projected manpower needs l
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SUMMARY
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NRC/ LGS Unit i vs Unit 2 Differences Information Meeting January 29, 1988 Agenda o Background -
HUREG 1021, major players, intent to discuss tentative dates for submittal, training, and exams. (E. G. Firth /D. 8. Lange) o Unit 1/2 Design, System, and Operational Characteristics Differences -
S/U group plan to define and assimulate for training use.
(J. A. Hutton/W. T. Ullrich) o Tech Specs Differences -
Expected differences between Unit 1, 2, and common expectations.
(W. T. Ullrich /J. A. Hutton) o Procedural Differences -
Major expected changes between Unit 1 and 2. (J. A. Hutton/W. T. Ullrich) o Control Room Design and Instrument Location -
Plan on how training tours will be utilized to identify these to operators. (E. G. Firth /J. A. Hutton) o Training Plan and Tentative Exam dates desired for Unit R0/SR0 Licenses -
(E. G. Firth) o Expected method of rotating , arsonnel between units and ref amiliarization to be corducted before responsibility on new unit is assumed -
(W. H. Barnshaw/W. T. Ullrich) o NRC/PECo summary discussion of issues / Tentative exam dates scheduled or verified as previously submitted.
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hHachmen4 2.
PHILADELPHIA ELECTRIC COMPANY
, MECHANICAL ENGINEERING DIVISION 2301 Market Street PECo Engineering shall review proposed Unit #1 design changes and Bechtel Engineering shall review proposed Unit #2 design changes for potential impact the change will have with respect to the plant operators. The following criteria should be used to determine if the proposed design change involves an operator interface:
- 1) The design change requires a difference between Technical Specifications on Unit il and Unit f2.
- 2) The design change affects how a system or a piece of equipment responds to operator actions in the Control Room or at the Remote Shutdown Panel or at any local panel including response to emergency procedures, or safe or alternative shutdown procedures.
- 3) The design change af fects how controls are configured including physical differences in layout, shape or feel.how information is displayed to the operators in the Control Room or at the Remote Shutdown Panel (i.e., switches, alarms, indicators) or at any local panel including response to emergency procedures, l or safe or alternative shutdown procedures.
- 4) The design change affects the sequence in which an operator performs system operations in the Control Room or at the Remote Shutdown Panel or at any local panel or within the plant if improper performance of these actions can result in significant system upsets or spills or safety concerns.
- 5) The design change affects the way you test for operability of the system.
If a review of the proposed design change against the above criteria indicates that the change involves an operator interface, the following steps must be taken:
- 1) All mod requests should be reviewed by the station manager against these criteria prior to submittal to Engineering. If it it determined to be an operator transparency issue, the station manager should note on the mod request that it is an operator interface and is or is not needed prior to Unit #2 commercial operation. If it is not needed prior to Unit #2 commerical operation, it should be noted and still sent to Engineering where it will be put on 2 Unit #1 deferred mod request list.
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- 2) If the proposed design change is for Unit #1 and is not needed for continued operations, Bechtel shall be requested by the responsible branch to process a Project Change Request for Unit
- 2. If the PCR is approved, the Responsible Engineer may proceed with the Unit il modification. If the PCR is disapproved or deferred, a letter will be sent to the station manager with justification or explanation as to why the Hod on Unit #1 will not go in due to operator transparency. This decision and the basis should be documented on the PCR and approved by the Division Chief Engineer.
- 3) If the proposed design change is for Unit #2, a PCR is generated and reviewed against the operator interface criteria. The PCR will document if an operator interface is involved. If the PCR is approved and identified as an operator interface, the Responsible Engineer should notify Electric Production in writing that the change is being made to Unit #2. A letter of concrrrence from the Station Hanager must be received to proceed with a similar design change on Unit #1.
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SUMMARY
OF DIFFERENCES AFFECTING OPERATOR TRANSPARENCY 01-1
- 1. In Unit 1 the steam supply for the RFP turbine and the gaseous radwaste recombiner preheater comes off main steam line "B" while Unit 2 comes off main steam line "C".
- 2. In Unit 1 the steam supply for the air ejectors comes off main steam line "C' while Unit 2 comes off main steam line "B".
The effect or operation is small since the motor operated valves in the lines retain their corresponding valve numbers. (i.e. RV-01-108 and EV-01-208 are in the supply line from main steam to gaseous radwaste recombiner preheater and RFP turbines on both Units; only the main steam line tapped off is different.
01-3 The Unit 2 turning gear employs two motors to minimize gear clash. The low speed torque motor engages the jack gear smoothly then stalls on high torque at which time the main motor starts and jacks the main turbine and generator. The Unit 1 turning gear has a main motor only which provides a less smooth transition to turning gear operation.
05-1 r Installed restricting orifices in the condensate reject control valves by-pass line to allow manual throttling of the condensate reject by-pass valve 05-1033 for Unit 1.
Before this mod, the 05-1033 could not be used since during Unit 1 Startup it was found unsuitable either r
thcott.ed or. full.open.
On Unit 2, valve 05-2033 will not be able to be used until the restricting orifices are installed to reduce the pressure drop across the valve.
Rev. O Page 2 of 12 05-2 By pass line with isolation valve and restricting orifices around the condensate minimum recirculation valve FV-C-05-103 for Unit 1 has been installed to allow maintenance of the condensate minimum recirculation valve without affecting plant operation by providing a manually operated bypass which can be used instead of the FV-C-05-103. This change has been deferred on Unit 2.
07-1 Installs a hotwire anemometer at mechanical vacuum pump discharge to provide main condenser in-leakage detection to be able to determine the SCFM in-leagage to the main condenser during mechanical vacuum pump operation prior to SJAE operation. Installed on Unit 2 to assist in condenser leak identification during Startup.
07-3 Deletes electrical wiring and instrument air supply to the radwaste decant pump discharge valve to Unit 2 condenser hotwell HV-67-232. This line was originally intended for use during Startup and will not be used on Unit 2 since I
the condensate phase seperators are contaminated from l operation in support of Unit 1. The line is capped at the Unit 2 hotwell.
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For Unit 2, an isolation valve will be added on the auxiliary steam supply piping between the condenser hotwell heating coil and the restricting orifice to prevent debris clogging the orifice and entering the condenser during flushing. Also, this will allow use of the hotwell heating coils without sending auxiliary steam condensate (which contains boiler water treatment chemicals) to the hetwell. The condensate can be dumped to the drain system if desired. '
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12-1 The present arrangement is; Unit 1 Unit 2 Loc. of Control Loc. of Control Equip. No. and indication Equip. No. and indication HV51-157A 1AC240 - same - HV51-257A 2AC240 HV51-156B 1AC240 HV51-256B 2BC240 HV51-157M 1BC240 - same - HV51-257B 2BC240 HV51-15f,A 1BC240 HV51-256A 2AC240 On Unit 2 design; the operator will be operating an equipment tagged "A" on a Control Panel tagged "A".
Status lights will also be indicated on a Control Panel tagged "A". Likewise, equipment tagged "B" will be operated and status indicated on Control Panel tagged "B".
Four Unit 2 RER Heat Exh. Remote Lay-Up Valves will be operated as described above.
On Unit 1 design; two valves are operated and status indicated the same way as Unit 2 above. But the other two valves (HV51-156A & B) are operated & indicated on a control <
panel with different tag number, i.e. EV51-156A is operated status indicated on 1BC240 and HV51-156B is operated &
status indicated on LAC 240.
35-1 and 35-2 Unit 2 Main Unit Transformers are 500 KV, and a different design from Unit 1 (220 KV).
r 36-1 Alternate feed from TSC/UPS to RPS/UPS.
Unit 1 has installed an alternate feed to the RPS/UPS power supply from the TSC/UPS power supply for operational flexibility. This alternate feed is not yet provided on Unit 2.
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Rev. 0 Page 4 of 12 38-2 Plant Monitoring System The Unit 1 Process Computer and ERFDS are separate systems with the Process Computer's CPU located in the Auxiliary Equipment Room and the ERFDS CPM located in the TSC. The Process Computer CPU is a Honeywell system whereas the ERFDS CPU is a VAX supplied by Digital Equipment Corp (DEC).
Unit 2 uses a Plant Monitoring System (PMS) which combines the process computer and ERFDS functions. PMS utilizes VAX CPU's which are located in the TSC along with the Unit 1 ERFDS CPU.
Differences will exist between the process computer function display formats and keyboard layouts for the two units. A new Plasma display will show the current status of 3 chosen points, new printers and color copiers for the Toshiba displays.
The measured points ID's were retained from Unit 1, but the Unit 2 system allows greater database manipulation / changes and trend recording on the Toshiba screens (in addition to the Bailey recorders).
The Reactor Engineers will have their own office terminal and printer. They will see improvements in process function run times and expanded versatility in reactor status displays and ucer interaction. The Rod Worth Minimizer function is now functicnally performed by a remote chassis which itself allows greater user interaction for information processing and display.
The SPDS displays are repeated for Unit 2 as are all of the basic functions of ERFDS. Upgrades include additional aids to the technicians for calibrating loops and spectrum analysis for pipe vibration testing.
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. 41-5 Startup Sources Unit 2 will utilize Californium-252 sources as opposed to the Antimony-124 sources used for the Unit 1 initial fuel load.
Besides being more economical, the main advantage of using Cf-252 is that its half life is 2.65 years in comparison to the 60.2 day half life of Sb-124. This provides assurance that the source strength will still be adequate in the case of unexpected along delays in the initial startup test program. Cf-252 undergoes spontaneous fission as well as decays by alpha emission. There will be no neutron contribution from an alphaberyllium reaction due to Cf-252 encapsulation into a stainless steel pin. The Sb-124, on the other hand, decays only by alpha and gamma emission. The total activity of the seven Cf-252 pins used is expected to be approximately 1.7 Curies compared with about 16,000 Curies for the 14 Sb-124 pins used in Unit 1. The same source holder will be employed for the loading of the Californium
! sources. However, the Californium pins, having the same diameter as the Antimony pins, are only 3 inches in length compared to the 19.95 inch Antimony pins. Therefore, a Cf-252 pin will be loaded between two unirradiated Antimony pins in a source holder. To handle the shorter Cf-252 source pins, some special tools different from those used to handle the Antimony pins may be needed.
The RPV flange and adjacent shell are required to be warmed to a minimum temperature of 80 degrees F for Unit 1 and 70 degrees F for Unit 2 before the RPV head studs are tensioned.
The difference in the minimum temperature reflects a i; difference in the limiting component of each vessel. The limiting component in the Unit i vessel is the shell plate l which connects to the closure flange. The limiting component l for the Unit 2 vessel is the closure flange forgings.
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1 41-10 Initial Fuel Loading l i
Initial fuel loading will be accomplished without the use of fuel loading chambers. This method is expected to save 4 to 5 days in the fuel loading process since the numerous movements of the fuel loading chambers will not be necessary.
The startup sources will be. loaded into their alternate locations which are closer to the SRM's. Fuel loading will start between a SRM and a source and continue in a spiral pattern until the core is fully loaded. A Special Test Exception will be proposed (supported by analysis) which requires no minimum SRM count rate for the first 16 fuel bundles loaded. After 16 bundles have been loaded, one SRM will have the required minimum count rate of at least 0.7 cps. The SRMs in the other quadrants will be verified to be operable at a frequency of at least once every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by using a portable neutron source (also part of the proposed Special Test Exception). Fuel loading will continue in this manner. As during the Unit 1 initial fuel load, a partial core shutdown margin demonstration will be performed after the first 144 bundles have been loaded.
44-1 Filling and Venting of the RWCU Pumps Vents have been provided for the system piping high points. However, in the present system no vents were provided for the portion of the piping which is isolated during normal RWCU recirculation pump maintenance. Air entering this portion of pipe during maintenance could not be completely vented before placing the pump back in service. Vents have been installed on Unit 1 for air removal. Corresponding vents are not installed on Unit 2.
Th!.s affects returning a RWCU pump to service after maintenance which could have drained the pump.
J' 44-4 RWCU Regenerative Heat Exchanger Bypass The connections for the Unit 2 RWCU regenerative heat exchanger bypass line are four inch as opposed to the two inch connections in Unit 1. When the bypass line is in use as a part ,of a shutdown alternative cooling method, the operator will experience a higher flow and more effective cooling with the Unit 2 system.
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, Page 7 of 12 45-1 RWCU System - RECW Pressure at Main RWCU Pumps In Unit 1 the low RECW cooling water trip to the RWCU pumps has been changed from an instantaneous trip to a time delayed trip. Unit 2's RWCU pump circuitry still reflects an instantaneous trip of the RWCU pumps.
51-3 Unit 2 RHR intertie Tees off Downstream of flow elements Unit 1 Tees off Upstream.
For Unit 1, when the intertie is used, FE IN014C&D do not see pump total flow, causing control logic to open the associated min flow line valves. For Unit 2 this will not occur since the interties from the C loop to A loop and from D loop to B loop tee off downstream of the C and D loop flow elements. For example, flow from the C pump, through the intertie; to the A heat exchanger would be sensed by the C flow element on Unit 2.
51-5 Eliminate False RHR Out of Service Annunciation During normal plant shutdown reactor pressure is reduced to below the RER pump discharge piping pressure; the sensed differential pressure goes negative causing the transmitter output to go below the normal minimum of 4 MA.
Eventually the sensed differential pressure will go far enough negative to drive the transmitter output to sense a low signal gross failure condition actuating a false RRR out-of-service annunciation.
The Unit 2 differential pressure instrument range was increased for PDT-51-2N058A,B,C, and D. Unit 1 has not been changed. r Because of the re-calibration of the instrument to a larger pressure range and resulting accuracy change, several TECH. SPEC. setpoints and allowable values related to RHR injection valve differential pressure are affected and must be changed for Unit 2. Also, the alarm will not come up on Unit 2 when the reactor is de pressurized as it
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, Page 8 of 12 51-8 RER System RERSW Ultimate Cooling Flowpath
- a. Unit 1: The RHRSW connection for ultimate cooling taps into the B loop of RHR via the B RER heat exchanger piping. (M-51 Sheet 4)
- b. Unit 2: The RHRSW connection for ultimate cooling taps into the A loop of RHR via the A RHR heat exchanger piping. (M Sheet 6) 51-12 RER Head Spray Deletion The RHR Head Spray from RHR to the Vessel was not '
installed on Unit 2. Difficulty in disassembling and reassembling for refueling activities is not justified by the limited use of the spray nozzle. The operator will not have this mode available for use on Unit 2. The containment penetration is capped and associated piping valves and controls removed. It is still installed on Unit 1, although a modification to delete Unit 1 Head Spray is being developed.
51-14 RER System FPCC Flowpath
- a. Unit 1: FPCC mode uses the B and D RHR pumps and discharges to the FPCC system via the B RHR loop. (M-51 Sheet 3)
- b. Unit 2: FPCC mode uses the A and C RHR pumps and discharges to the FPCC system via the A RER loop. (M-51 Sheet 5) f 53-3 Spent Fuel Pool Underwater Work Table The Fuel Pool Underwater Work table for Unit 1 was modified by attaching a permanent support / lift frame to
_. .. . allow for above wate.r adjustment / removal of the table
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without divern or immersing the overhead crane houk. The Unit 2 change will not be done until prior to the 1st Unit 2 refueling.
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Rev. O Page 9 of 12 53-4 Install Wire Mesh Screen Over Spent Fuel Pool Surge Tank Weir Opening.
For Unit 1 a wire mesh screen was installed over the Weirs between the spent fuel pool and the skimmer surge tank.
This addition prevents foreign material from inadvertently entering the skimmer surge tank. Also, a gasket was installed between Weir plate and fuel pool wall to make fuel pool level control easier.
This change was deferred for Unit 2.
55-1 CRD Friction Test Station The CRD friction test station consists of additional piping and manual valves installed downstream of the CRD system flow control valve. The station eliminates the need for repetitive instrumentation setups while friction testing the CRDs during startup testing and refueling outages. This station is provided on Unit 2 but not yet implemented on Unit 1.
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. Page 10 of 12 56-1 Rod Worth Minimizer The RWM used in Unit 2 is a hardware based device in comparison to the software base "Honeywell" RWM. The hardwr,re concept allows significant performance improvements including speed, reliability and accuraev.
The MUMAC design concept significantly reduces system maintenance, calibration, and surveillance time.
The following is a comparative description of the Unit 1 and Unit 2 RWMs Unit l_
The Unit 1 "Honeywell" rod worth minimizer is a passive display system which provides the operator in the main control room the decisions that the process computer has made relative to control rod positions.
- a. Unit 1 RWM has the following displays that are back-lit by incandescant lamps;
- 1. 2 insert error windows that display the address limit, of the rod (s) that are past the insert
- 2. I withdraw error window that displays the address of the rod that is past the withdraw limit,
- 3. 1 rod group window that displays the number of the currently latched group of control rods.
- b. The Unit 1 Honeywell RNM has no rod bypass function.
- c. The Unit 1 RWM will tolerate up to 2rinsert errors and one withdraw error.
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. Page 11 of 12 Unit 2 The Unit 2 NUMAC RWM is a stand alone active processor that receives rod position information directly from the rod position information system. The RWM compares this rod position information to pre-programmed rod sequences and displays the status of the comparison to the operator in the control room,
- a. Unit II RWM has one electro-luminescent display that can display all parameters that the RWM is monitoring. The display, under contr31 of "soft keys", can display pertinent messages, special rod tests, bypass lists, and substitute rod position information. The normal mode of display operation will include selected rod address and position, reactor power level, RWM mode (operate, bypass, rod test, inop) error status and block status,
- c. The Unit 2 NUMAC RWM will enforce all limits that the Unit 1 RWM enforces, however, the NUMAC RWM will impose blocks before a limit is exceeded.
Therefore, during a normal startup no insert or withdraw errors can occur. Errors will have to be corrected before rod pull can continue.
- d. The reactor power setpoints for both RWMs are
' identical and the function of the RWMs within these levels is similar. However, the operator can activate the NUMAC RWM display at all times whereas the Unit 1 RWM display will be blank at power levels of greater than or equal to 30%
power.
r 73-1 Manual flow control for containment H2 recombiner.
I Unit 2 Containment Hydrogen recombiners will have manual flow control instead of automatic as currently employed on Unit 1. The original automatic flow controller is no longen manufactured and no qualified substitute is
. availabic. Therefore, Unit 1 will also eventually be converted to manual flow control.
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, Page 12 of 12 76-3 Replace Paul Monroes with Limitorques MOD 682 (Unit 1) and PCN 5111N (Unit 2) were issued to replace the Paul-Munroe actuators with Limitorque actuators.
At present, both Unit 1 (EV-76-109 and 110) and Unit 2 (HV-76-209 and 210) have identical actuators. Other Unit 1 PAUL-MUNROE actuators have not been replaced. All Unit 2 PAUL-MUNROE actuators have been replaced by Limitorque operators.
76-5 RERS Filter Cooldown Mode On Unit 2, the RERS filter cooldown mode has been deleted.
This deleted ventilation valves EV-76-284A/B and EV-76-291A/B on Unit 2. A modification is being developed to delete the RERS cooldown mode on Unit 1.
77-2 Addition of a Pressure Indicator to TIP Purge Panel MOD 341 added pressure gauge to the TIP purge panel 10S225 '
of the Containment Instrument Gas System to provide indication of nitrogen purge pressure when the flow meter is on zero, t
The change only increases the system performance by providing visual assurance to the operator that the purge system is still on under zero flow condition (ball valve closed).
This difference is an operator transparency item since local panel operation is affected. This is a minor mod which Startup may be able to install before turnover.
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UNIT 1/ UNIT 2 DIFFERENCES LEGEND FUEL LOAD - "S- - TO SE DONE IN SOTH UNITS SEFORE UNIT STATUS - "C" - CANCEL (FL) UNIT 2 FCEL LOAD (Usl. Us2 STAT) "D" - IN DESIGN "A" - TO SE DONE IN SOTH UNITS AFTER "K" - DEFFERRED UNIT 2 FUEL LOAD esR - DESIGN IN REQUEST STAGE
- N* - NOT TO SE DONE IN SOTH UNITS "MI" - eseF*5 ISSUED WITH SECTION 2 "D* - DIFFERENCE IDENTIFIED AND OISPOSITIONED *F* - FIELD COsePLETE TO LEAVE AS IS N* - NORKING
-C - COnePLETE TRN5 - TRANSPARENCY a
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88/Bl/28 PLGL l' DIFF s MOD PCR F Usl Us2 RESP FROM F . F COORD 1 PROC F TRAIN Ust/Us2 DIFFERENCE EDIT 8
L STAT STAT COOR CDORD / ENGRG / CONCUR R REVW A DATE O/I DATE A DATE A S N O 880120 A 880229 F V 880121 Hv-01-108 COMES Oft u; LINE 8 HV-01-208 I 00001-3 COMES OFF MS LINE C 00001-2 5531 20487 8 F MR O 880205 F M PARTI AL ARC TWO ADMISSION CONVERSION. 2 UNIT 2 WILL BE CONVERTED BEFORE STARTUP.
00003-3 N O 880122 A 880229 F V 880125 UNIT 2 MAIN TURSINE TURNING CEAR IS OF 215 DIFFERENT DESIGN UTILIZING 2 MOTORS 00002-1 N O 880120 A 880229 F N 880121 DEVICES OH UI P&ID NOT ON U2 P&ID. 3 VENT / DRAIN VALVES 00002 2 D 452 20272 8 F w 0 880205 P MODIFY EXTRACTION STEAM CHECK VALVE LIMIT 4 SWITCHES - SCOPE OF PCR IS GREATER THAN DCP g
30003-1 N O 880127 A N DEVICES ON US P&ID NOT ON U2 P&ID. 5
. VENT /0 RAIN VALVES.
2ND CYCLE MOD FEEDwATER HTR LVL CNTRL 6 30003-2 5007 2F419 8 MR MR O 880205 F INST RESPONSE TO TRANSIENT LVL CHANGES 30004-1 N O 880120 A 880229 F N 880121 DEVICES ON UI P&IO NOT ON U2 P&ID. 7 VENT / DRAIN VALVES.
30005-1 5198 20341 A F K O 880120 A 880219 F V 880123 ADO RESTRICTION ORIFICES DOWN STREAM OF 8 COND REJECT MANUAL SVPASS VALVE. UNIT 2 MANUAL VALVE CANNOT BE USED UMTIL ORIFICES INSTALLED.
30005-1 5198 891 A F K O 880320 A 880219 F V 880321 ADD RESTRICTION ORIFICE DOWN STREAM OF 9 COND REJECT MANUAL SVPASS VALVE. UNIT 2 MANUAL VALVE CANNOT BE USED UMTIL ORIFICES INSTALLED.
30005-2 5197 20340 A F K O 880320 A 880219 F V 880121 CONDENSATE PUMP RECIRC MODIFICATION. 30 MANUAL SVPASS LINE INSTALLED ON UNIT 2.
30005-2 5197 f .*O A P K O 880120 A 880219 F V 880121 CONDENSATE PUMP RECIRC MODIFICATION. 'e t MANUAL SVPASS LINE INSTALLED ON UNIT 3.
)0005-3 5732 #
2s486 8 MR MR O 880127 A N TCA380 STRAINER ALARM NOT TRIP COND PUMPS 12 10005-4 653 20138 A F C \t O 880120 A 880219 F N 880321 ADO AIR /VAC VALVE AND ADDITIONAL PIPE 13
$UPPORTS ON COND. TRANSFER. HYDRAULIC PROBLEM WAS RELATED TO PUMP START CONTROLS.
e
- PAGE 2' 88/31/23 .
PCR F Usl Us2 RESP FROM F . F COORD T PROC F TRAIN Ust/Ua2 DIFFERENCE EDIT DIFF 0 MOD a
L STAT STAT COOR COORD / ENGRG / CONCUR R REVW A DATE O/I DATE A DATE A S W O 880120 A 880229 F M 880128 NO UNIT 1 MOD TO bt Iv,uto. ADD 02 14 00005-3 NOME 20155 N INJECTION POINTS AT Int COND PUMPS SUCTIONS SO THAT IMPL EMLNTATION OF H2 WATER CHEM IS EASIER. 17 DONE LATER.
5205 PASE 8 MI W O 880127 A N PUMP BEARING OIL PRESSURE 8ELOW NORMAL 15 00006-1 SWITCH 20476 8 MR MR O 880205 F N TCA 90 - HT SUILDUP PANEL 10C668 16 00006-2 5751 W W O 880205 F M TCA 528 - JdMPER SIGNAL CONTACT 17 00006-3 5142 20231 8 W N TCA 1021 FEEDWATER LEVEL CONTROL WIRING 18 00006-4 842 20085 8 D O 880127 A
- . CHANGES NONE 20358 N W O 880120 A 880229 F V 880121 PROVIDES MAIN CONDENSER IN LEAKAGE 19 00007-1 DETECTION OURING MECH. VACUUM PUMP OPERATION.
00007-3 NOME 20419 N W O 880120 A 880229 F V 880123 ABANDON VALVE HV-67-232 IN PLACE NO UNIT 21 1 MOD WILL BE DONE 30007-4 S282 20397 8 MR W O 880205 F VACUUM SENSOR RELOCATION 22 30007-S NONE 20417 N W O E80120 A 880229 F V 880121 ADOS ISOLATION VALVE IN HOTwELL HEATING 188 COIL UPSTREAM OF FLOW ORIFICE AND HOTwELL.
30008-1 M O 880120 A 880229 F N 880121 DEVICES ON US P&ID NOT ON U2 P&ID. 23 VENT / DRAIN VALVES 30009-01 N O 880120 A 880229 F N 880321 DEVICES ON Un P&ID NOT ON U2 P&ID. 24 APPEARS TO BE COMMON EQUIPMENT.
30009-C2 874 20157 8 D W O 880205 F N TCA 463 ADD DIFF PRESS ALARM ON INTAKE 25 SCREENS 30009-G4 5712 2DS43 8 MR W O 880205 F M TCA 898 TTA CHEMICAL INSTALLATION 27 20009-05 742 20422 8 MR MR O 880205 P N 2ND CVCLE MOD. RELOCATE COOLING TWR 28 MAKEUP AND BLOWDOWN SAMPLE LINES.
30003-C0 5079 20421 8 MR MR O 880205 F 2ND CYCLE MOD ON LINE COND TUBE LEAK 29
\
t LOCATION 30033-C7 822 20420 8 MR MR O 880205 F 2ND CVCLE MOD PROVIDE ALT DRAIN PATH FOR 30 COND
VCGE 3 .
82/31/23 F Us1 Us2 RESP FROM F F COORD T PROC F TRAIN Ust/Us2 DIFFERENCE EDIT 3IFF 0 MOO PCR .
L STAT STAT COOR COORD / ENGnG / CONCUR R REVw A DATE O/I DATE A GATE A S N O 880205 F FvC-US-103 CLOSES t a est HI LEVEL. 216 30009-12 FVC-09-203 DOES NOT.
30009-11 N O 880205 F UNIT 2 ACID FEED TANKS HAVE DRAIN VALVES. 217 UNIT 1 DOES NOT
)IOO3-12 N O 880205 F 09-1147 IS OPEN. 09-2147 IS CLOSED & 218 09-1346 IS CLOSED. 09-2146 IS OPEN.
300ll-1 N O 880120 A 880229 F N 880121 VALVE 13-1067 HAS DIFFERENT s OM UNIT 2 31 2079A (PRESSURE TEST VALVE) 30011-2 N O 88012G A 880229 F M 880121 VALVE 1066 FOR UNIT 1 IS NOT THE SAME FOR 32 UNIT 2 (DRAIN VALVE) 30311-3 N O 880120 A 880229 F N 880121 TEST TAPS ON UNIT I DIFF # THAN ON UNIT 2 33 30011-4 NOt:E 20381 A D 0 880120 A 880229 F N 880121 ADO PITOT TUSE FLOW METERS TO SERVICE 34 WATER SYSTEM FOR FLOW SALANCE ON UNIT 2.
20031-5 9045 20793 8 w w 0 880205 F N ADD FLUSH CONNECTION TO ESw SUPPLY LINE 35 TO U2 TURS ENCL COOLING WATER 30311-4 970 20448 8 F MR O 880205 F V RHR OUTLET VALVE TIME DELAY RELAY 36 30311-7 5063 20103 8 MR D 0 880205 F 2ND CYCLE MOD CHANGE PGIC COMP COOLING 37 WATER SUPPLY FROM SW TO RECW 20011-8 5060 20102 8 D w 0 880205 F 2ND CYCLE MOD RELOCATE ON/OFF SWITCH. 38 SEPARATE FEEDS FOR DESSICANT DRYER PACKAGE
) 011-9 5139 20150 A F K O 880120 A 880210 F N 880120 ADDITION OF PRESSURE TEST CONNECTIONS TO 120 DG ESw PIPING. ALSO RELOCATES FLOW ORIFICE.
)0012-1 5050 A w 0 880120 A 880203 F Y 880120 EXCHANGE PANEL LOCATION OF CCNT SWITCHES 39 AND INDICATION LIGHTS FOR HV-53-2568 AND HV-St-258A 10012-2 5352 20438 8 MR D 0 880205 F M 2ND CYCLE MOD REPLACE EXISTING RHR Sw RAD 40 MONITORING CAR 8ON STEEL PIPING WITH SS PIPING s
10313- t 5470 63tlN 8 MR w ~O 880205 F 2ND CYCLE MOD ISOLATION SIGNALS FOR di DCw/RECW ISOLATION VALVES
y 98/DI/23 91.GE 4 JIFF 0 MOO PCR F Usl Us2 RESP FROM F . F COORD T PROC F TRAIN Us t /es *2 DIFFEREtats EDIT L STAT STAT COOR COORD / ENC &G / CONCUR R REVW A DATE a O/T DATE A DATE A S 30043-2 N O 880120 A 880229 F M 880121 DEVICES ON US P&Ib 8 JB dN U2 P&ID. TEST 42 VALVES ON A LINE TO Poe t asARY CONT.
20014-2 108 8ASE 8 w W O 880205 F N VALVE HV-13-206.207 RECEIVE CONT 43 ISOLATION SIGNAL 20014-3 N O 880120 A 800229 F N 880921 DRAIN VALVE 14-1063 IN UNIT I SUT NOT IN 44 UNIT 2 20015-2 5063 ;O099 8 asR D 0 880205 F 2ND CYCLE MOD PROVIDE INST AIR FOR TIP 45 ORIVE PURGE 10015-3 5730 2Q432 8 O D 0 880205 F N TCA 841 - 2ND BACK UP SERVICE FOR 46 REFUELING SEALS 30085-4 5503 2C434 8 F MR O 880205 F N 2ND CVCLE MOD OPEN EXISTING WALL PENE & 47 ROUTE AIR / WATER / ELECT LINES THRU PENE 30315-5 365 20332 8 D W O 880205 F low PRESS AIR SLOWER DRAIN ROUTING 48 10310-3 5575 20458 C F W O 880205 F N INCREASE THE SIZE OF IHLET/ OUTLET TUSING 51 TO SQ ROOT CONVERTERS 30083-4 5185 20294 8 w F 0 880927 A N TCA 18 - REMOVE AUTO START FOR LOW PRESS 52 AIR BLOWER 60018-l D53d N O 880820 A 880229 F M 880121 MANUAL ISOLATION VALVES IN UNIT I RFPT 53 LUBE OIL PURIFICATION SYSTEM.
'0027-1 20177 N w 0 880120 A 880229 F N 880321 FIRE PROTECTION SYSTEM DELETION OF TEST 54 DETECTORS ON UNIT 2.
0022-2 659 20088 8 F w 0 880205 P N FIRE PROTECTION INSTALL A ROTATING RED 55 BEACON INSIDE INVERTER ROOM.
0022-3 860 20425 8 MR w 0 880205 F 2ND CYCLE MOD RACEWAY SHOULD BE PROVIDED 56 w1TH SPRINKLER PROT 0022-4 857 20424 8 MR MR O 880205 F 2ND CYCLE MOD SPRINNLER ISO SUS AND 57
$UPPORT STEEL 0022-5 iM 20426 8 MR MR O 880205 F 2ND CYCLE MOD PROVIDE SPRINKLERS FOR ALL 58 AREAS UNDER THE TURS GEN FLOOR O222-0 5457 2C436 8 F W O 880205 F DISABLE THE FIRE PROTECTION SYSTEM FLOW 59 Sw!TCH INTERLOCK
_______m__.____._ __
98/21/23 PAGE O, ,
MOD PCR F Usl Us2 RESP FROM F . F COORD T PROC F TRAIN Ust/Us2 OIFFERENCE EDIT 31FF s a L STAT STAT COOR COORD / ENGAG / CONCUR R REVW A DATE O/I DATE A DATE A 5 5725 20450 8 MR D 0 880205 F TCA 838 DESIGN SAUPL E ". t r4K DRN TO NORMAL 60 20023-1 WST 20285 8 MR D O 880205 F TCA 506 - CLEAR TUR8 LO FLOW ON FEEDwATER 61 20023-2 5248 30027-5 9051 20301 8 D D O 880205 F M NORTH STACK SAMPLE 8vPASS LINE. THIS MOD 62 IS ON COMMON EQUIPMENT.
30027-2 N I 880120 A 880229 F M 880121 UNIT I ANNUNCIATOR READS SLIGHTLY DIFF 63 THAN UNIT 2. (OFFGAS RAD. MON.
DOWNSCALE).
,9 30023-2 5336 20410 8 O D 0 880205 F TCA 623 FACILITATE CALIBRATION OF LI 65 30028-3 5028 20328 8 MR W O 880205 F N RELOCATION OF GENERATOW CORE MONITOR AND 66 PYROLSATE CONDUCTOR 10031-1 996 A D 0 880205 F TCA 374.996 LIFT / TAPE LEAD FROM TERM PTl2 67 10031-2 5008 20044 8 MR W O 880205 F TCA 325 - COMPTR MONIT HOT SPOT RECORDER 68 10031-3 5373 20478 8 F W O 880205 F TCA 54 - MAIN TURS SHAFT VOLT METER SCALE 69 10031-4 5108 20403 8 MR MR O 880205 F TCA 496.557 - LOOP SEAL IS NOT LARGE 70 ENOUGH W O 880205 F TCA 468- TEMP INSTR FOR CROSS AROUND 73 10031-5 5013 *0309 8 MR RELIEF 30032-1 N O 880122 A 880229 F N 880325 UNIT 2 MAIN GEN. HAS PYROLSATE TAGGING TO 219 AIO IN HOT SPOT LOCATION DETECTION ACTION 60033-1 5714 20409 8 MR W O 880205 F TCA til8 - ACC PRESS DIFF ON STATOR WTR 72 4
SYST 10034-1 8 I 880205 F N UNIT I ANil WINDOW READS DIFF THAN UNIT 2 73 (ISO-PHASE BUS
- COOLER
- VS.
- COMMON *)
SHOULD DE FIXED IN SFR.
Y 880321 2ND CYCLE MOD RELOCATE MAIN TRANS N2 74 10035-1 5441 N MR O 880320 A 880229 F 80TTLES. THIS RESULTS FEON DIFFERENT TRANSFORMERS FOR UNIT 2.
63035-2 N s O 880127 A Y UNIT 2 MAIN TRANS ARE 500KV 7 OIFF DESIGN 389 FROM UNIT 3. THIS DIFFERENCE CAUSES s35-3 DIFFERENCE.
30036-1 308 20013 A F M O 880327 A Y ALTERNATE FEED FROM TSC/UPS TO RPS/UPS. 75 I
t
8 .
38/31/28 PIGE G'
)IFF 0 MOO PCR F Usl Ua2 RESP FROM F . F COORD T PROC F TRAIN Ust/Us2 DIFFERENCE EDIT L STAT STAT COOR COORD / ENGRG / CONCUR R REVw A DATE a O/T DATE A DATE A S 30037-I 584 20253 5 F w 0 880205 F REWIRE LSH 07-156 Asan L>H 07-157 TO 76 NORMALLY CLOSED CONTACTS 10338-1 5241 20333 5 D W O 880205 F ADDITION OF HPCI & RCIC LANYARD FUT FOR 77 PMS (ERFDS) INPUT 10038-2 N O 880822 A 880229 F V 880122 PMS COMP DIFF FOR UNIT 2 190 20039-1 5142 20231 8 W w O 880205 F REACTOR FEED PUMP MIN FLOW RECIRC CNTAL 78 MOD
)OO41-@l 808 20173 8 F w 0 880205 F M ADD EXCESS FLOW CHECM VALVE TEST TAPS 79 30049-88 304 208t3 a F w 0 880205 F M ADD EXCESS FLOW CHECK VALVE TEST TAPS 80 20041-C3 4223 20153 5 F K O 880205 F N FAB OF RPV GUIDE ROD EXTENTION TOOLS 81 30041-04 N O 880120 A 880229 F N 880:21 DEVICES ON UI P&ID NOT ON U2 P&ID. TEST 82 VALVES. VENT / DRAIN VALVES .
t 20031-05 N O 880322 A 880229 F V 880322 RX S/U SOURCE DIFF FOR U2 191
. 10041-03 N O 880205 F PSV HAVE BEEN DELETED FOR UNIT 2 192 I I
20041-@7 N O 880122 A 880229 F V 880122 MIN TEMP FOR HEAD BOLT UP IS 80 FOR Ut 198 '
AND 70 FOR U2 s
N 880122 UNIT 2 CONTROL ROO PIN / ROLLER BALLS USE 206 !
20043-08 0 0 880120 A 880229 F COSALT-FREE MATERIAL .
4 10043-09 0 0 779120 A 880229 F N 880322 UNIT 2 USES 80 MIL FUEL CHANNEL.S 207 ,
10041-19 D 0 880220 A 880322 F Y 880122 UNIT 2 INITIAL CORE LOADING WILL NOT 208 UTILIZE FUEL LOADING NEUTRON DETECTORS.
10042-1 N I 880205 F UNIT I TRANS TAPS DIFF THAN UNIT 2 83 30043-9 N O 880122 A 880229 F N 880125 RECIRC PUMP 2A TEMP ELEMENT 84 sOO43-2 5C78 20483 5 MR MA O 880205 F 2ND CYCLE MOD RECIRCULATION MG SET 85 RETRACTABLE BRUSH HOLDERS 80043-3 5104 20312 8 MR W O 880205 F TCA DUST AND DIRT IN MG SETS 86 60043-4 5735 %'R 8 MR W 'O 880205 F LOGIC AND ANN. DISCREPANCY 87 50 0 S 3 - 1 5001 20.06 A MR D 0 880120 A 880203 F Y 880120 2ND CYCLE MOD FILLING AND VENTING OF RwCU 88 PUMPS. ADDS FILL & VENT CONNECTIONS.
PAGE 7' 98/31/28 .
RESP FROM F . F CDORD T PROC F TRAIN Ust/Us2 DIFFERENCE EDIT 3tFF s MOO PCR F Us1 Us2 a L STAT STAT COOR COORD / ENGAG / CONCUR R REVW A DATE O/I DATE A DATE A 5 W O 880205 F 2ND CYCLE MOD WIDEN THE RX WTR PH LO SET 89 30040-2 2088 20452 8 D POINT D W O 880205 P TCA 826.827.832 CONTR RM I ND F OR RwCU 90 30004-3 5728 20415 8 PUMPS D 0 880120 A 880229 F Y 880322 RWCU RNX BYPASS LINE CONNECTION SIZE 209 30044-4 D 0 630120 A 880229 F Y 880122 ADDITION OF TIME DELAY TO RwCU 95 30045-1 526 2C324 8 MR i RECIRCULATION N O 880127 A N UNIT I P&ID NOT ON UNIT 2 P&ID DEVICES ON 92 20046-1 K O 880120 A 880203 F N 880120 INLET SCRAM VALVE SEAT RING REPLACEMENT 93 30047-1 670 20212 A MR O 880120 A 880219 F M 880120 INSTALL CONTROL ROD DRIVE REMOVAL TRACK 94 20047-2 555 20204 A F C 20195 8 F W O 880205 F INSTR AIR SUPPLY ISO VALVE FOR 95 100C7-3 87 PVC-46-1F002 A/B 30047-4 5326 20331 8 D W O 880205 F REPLACE CRD -O* *4INGS AND ORIFICE PLUGS 96 N O 880205 F UNIT I AND UNIT ? PEID DO NOT MATCH 97 10047-5 60040-3 N O 880205 F UNIT I P&ID DIFF THAN UNIT 2 P&ID 98 806 1567 8 F W O 880205 F SLCS REPLACEMENT OF THE EXISTING SLCS 99 500*8-2 ACTUATION RELAYS HDO43- 3 N O 880255 F 49-1F036 & 49-1F037 LOCATED INSIDE 231 CONTAINMENT. 49-2F036 & 49-2F037 LOCATED OUTSIDE CONTAINMENT N RCIC OUT OF SERVICE ALARM SWITCHES HAVE 801 30050-1 N I 880127 A DIFFERENT POSITION LABELS. SHOULD BE FIXED BY SFR.
N O 880205 P AUX STM HEADER DRM IS 21-30430 AND 102 10050-2 21-2043C N/A 5006N N W O 880120 A 880219 F V 880121 UNIT 2 RHR INTERTIE TEES OFF DOWN STREAM 105 10051-03 OF FE*S. UNIT I TEES OFF UP STREAM
)OO51-04 5716 20477 A MR W O 880205 F TCA 1022.1049.1830 PUMP TRIP ON RHR MOTOR 106 W O 880120 A 880203 F Y 880120 ELIMINATE FALSE RHR OUT OF SERVICE 107 30051-05 522 1455 A MR ANNUNCIATION. RESULTS IN CHANGING RHR INJECTION VALVE D/P SETPOINTS.
i
38/31/28 P.1GE 8'
)IFF 0 MOO PCR F Usl us2 RESP FROM F . F COORD T PROC F TRAIN Usl.*Hs2 DIFFERENCE E0!T L STAT STAT COOR COORD / ENGRG / CONCUR R REVw A DATE a O/I DATE A DATE A 5 20051-06 4442 20423 8 MR MR O 880205 F 2ND cvCLE MOD ADD CHAlts WHEEL OPERATORS 108 TO RHR HIGH POINT VLNT VALVES 20051-07 5579 ?O405 8 D 0 0 880205 F M INSTALL ACCESSIBLE TEST POINTS FOR SURV 109 TESTING 30051-08 N O 880120 A 880229 F V 880122 RHR SERVICE WATER CROSS TIE LINE IS 110 CONNECTED TO 8 LOOP FOR UNIT I A LOOP ON UNIT 2 20051-09 M O 880205 F UNIT I P&lD DOES NOT MATCH UNIT 2 P&lO lit 20051-10 N I 880205 F UNIT 1 DOES NOT MATCH UNIT 2 E625 194 30051-13 N I 880205 F UNIT I DOES NOT MATCH UNIT 2 195 20058-12 5658 20329 N MR w 0 880120 A 880219 F V 880320 RHR HEAD SPRAY DELETION. REMOVES PIPING 100 AND VALVES AND CAPS CONTAINMENT PENETRATION.
30051-13 N O 580120 A 880229 F M 880121 UNIT l HAS MANUAL ISOLATION VALVES. UNIT 49 2 OOES NOTON DEMIN WATER TO RHRSW LA VUP SUPPLY LINE
>O051-14 D 0 880120 A 880229 F V 880122 RHR Sv5 TEM TO FPCC SYSTEM FLOW PATH. UNIT 210 1-8 RHR. UNIT 2 - A RHR 80051-15 N I 880205 F FT-51-2NOO7A. 78 HAVE A SQ ROOT ADOED TO 221 U2 30052-1 N I 880127 A N HPCI OUT OF SERVICE Sw!TCHES HAVE DIFF 112 POSITION LA8ELS. ALARM SHOULD SE FIXEO SV SFR.
nOO53-1 N O 880120 A 880229 F N 880321 DEVICES ON UNIT 4 PEID NOT ON UNIT 2 183 P&ID. VENTS / DRAINS 60053-2 5077 20404 8 MR w 0 880205 F TCA 753.754.582.588 BACNWASH AIR INLET 114 VALVE 60053-3 496 20192 A F K O 880120 A 880219 F V 880120 SPENT FUEL POOL UNDERWATER WORK TABLE 185
>O053-4 276 20162 A F C O 880120 A 880129 F V 8f10120 INSTALL WIRE MESH SCREEN MTL OVER SPENT 116 h FUEL POOL SURGE TANK AND GASMET BETwEEN WEIR PLATE AND WALL TO ALLOW ACCURATE LEVEL CONTROL. U/1 MINOR MOD wHICH SHOULD BE INSTALLED BY S/U ON UNIT 2.
i S8/03/28 CAGE U. .
3IFF 0 MOD PCR P Us1 Us2 RESP FROM F . F COORD T PROC F TRAIN Ust/tla2 DIFFERENCE EDIT L STAT STAT COOR COORD / ENGRG / CONCUR R REVW A DATE a O/I DbTE A DATE A 5
)OO5D-Q 5023 20:08 8 MR D 0 880205 F 2ND CYCLE MOD ADD DNAIN TO FUEL POOL 817 COOLING /RHR INTERTIE LINES 30053-0 5020 20097 8 D D 0 880205 P 2ND CYCLE MOD INSTALL PRESS TRANS ON 118 HBC-103 WITH IND ON PNL 10C223 20053-7 276 20475 8 F W D 880205 F TCA 953 WATER LEAM ON EDGE REACT CAVITY 139 20053-@t 20334 N w 0 880820 A 800219 F V 880320 CRD FRICTION TEST STATION 121 10055-62 N O 880327 A N FLOW ORIFICES NUMBERED DIFFERENTLY. 122 30055-C3 '
N O 880205 F UNIT I P&ID DOES NOT MATCH UNIT 2 P&ID 123 10053-4 N I 880205 F ANNUN WINDOW LABLED DIFF. SETWEEN UNITS 253 3G055-5 N O 880205 F 55-1F014 & 55-IF015 ARE LOCATED INSIDE 214 CONTAINMENT. UNIT 2 VALVES ARE OUTSIDE CONTAINMENT n0055-0 N O 880205 F TEST LINE ISOLATION VALVES LAP.ELED 223 DIFFERENTLY BETWEEN THE UNITS 60056-91 7 N O 880120 A 800229 F V 880328 RWM FOR UNIT 2 DIFF THAN UNIT I 193 60053-C2 N O 880205 F DPAIN VALVE 56-1042 DOES NOT EXIST ON 222
- 41 T 2 80057-3 DCN N O 880326 A N UNIT I SCHEMATIC DIFF THAM UNIT 2 DCN TO 424 SE WRITTEN TO FIX DRw ERROR 0057-2 N O 880205 F DEVICES ON UNIT I P&lD NOT ON UNIT 2 P&ID 825 0057-3 965 20282 8 O W O 880205 F TCA 636 SUPPRESSION POOL INDICATOR 126 0057-4 5380 20336 8 D MR O 880205 F 2ND CYCLE MOD SEPARATE PwR SPPLY FOR 127 TRICKLE HTR 0057-9 5121 20430 8 MR MR O 880205 F 2ND CYCLE MOD PROVIDE MEANS TO CLOSE 328 HV-57-116 (N2 SUPPLY VALVE) 0058-5 N I 880205 F UNIT I TE WIRED DIFF THAN UNIT 2 TE 129 i
0053-1 5062 200b1 8 MR D g O 880205 F 2ND CYCLE MOD PROVIDE MEANS FOR BLOW!NG 130 DOWN PCIG RECEIVERS 005D-2 5117 20427 8 O MR O 880205 F 2ND CYCLE MOD ADDITION OF DESICCANT 133 SREATHERS ON ACID STORAGE TAMKS
58/31/28 . PIGE ID -
- 3IFF s an00 FCR F Usl Ua2 RESP FROM F . F COORD T PROC F TRAIN UsI/Ha2 DIFFERENCE EDIT L STAT STAT COOR COORD / ENCDC / CONCUR R REVw A DATE s O/I DATE A DaTE A 5 ,,
70053-3 N O 880521 A 880229 F M 880123 UNIT I AND UNIT 2 PsIDS DO NOT IsATCH. 132 VENT / DRAINS RDC SHOULD DE ISSUED TO CORRECT U/l P&ID FOR P05-59-IO6A/S asOUNTING.
>O059-4 N O 880321 A 880229 F M 880123 UNIT I AND UNIT 2 P& IDS DC NOT asATCH. 133 DRAIN VALVE.
s0060-1 5553 24SE s neR D 0 880205 P ALARM ANNUNCIATION FOR DRYWELL CHILLER 134 60060-2 5730 20433 s MR asR O 880205 F 2ND CYCLE 8000 - APP J tsOD FOR LLRT 135 80060-3 5283 20462 8 MR w O 880205 F 2ND CYCLE 9800 TERRA SPARE wtRES froes 136 TE-37-125 AT DfiVwELL PEN
+0060-5 5875 20402 B MR D 0 880205 F TCA 584 SET POINT ADJUST MMOS COVER 138 0061-2 258 A O 880522 A 860229 F N 880225 REw0RM DRYWELL SL*MP DI SH PIPE I40 i 0065-3 T78 20413 8 MR D 0 880205 F TCA 356.359 UNIT I CONDENSATE SWRT TO 141 -
UNIT 2 COND ,
0065-4 955 20089 8 F D 0 880205 F INSTALLATION OF OIL REL'OVING SELTS IN THE 142 Rw FLR DRM SUtIPS 0068-9 N O 880219 F HV-61-202 DELETED - HV-61-2Cl STILL 199 INSTALLED 0068-1 5703 203C7 8 teR D 0 880205 P TCA 700 PLUSH SAMPLE CHAte8ER DENTIN 843 0068-2 495 20Wse 8 D 88R O 880205 F TCA 238 AIR JUesPER NEEDED AROUND SUCT & 144 DISCH 0068-3 144 6938 8 F W O 880205 F TCA 3 SERVICE WTR THRU WINTER BY PASS 145 LINE 0068-5 5433 20460 e aan asR O 880205 F 2ND CYCLE 8000 - PROVIDE FUSED PWR SUPPLY I46 FOR REFUEL FOR VENT RAD asON1 TOR 0069-1 5053 20113 8 F W O 880205 F TCA 427 CONDENSER AIR COOLER DRAIN 147 0G69-2 650 20092 A F K O 880120 A 880289 F M 880420 OFFGAS AFTER COOLER COND TUSE CHANGE OUT I48 0063-3 5475 20451 a esR asR % 0 880205 F 2ND CVCLE MOD - FLOW TOTALIZERS FOR 549 SAMPLE PUMPS GASEOUS RELEASE PATH 0069-4 N O 880205 F DEVICES ON UNIT I P&ID NOT ON UNIT 2 P&ID 150 0371-1 604 20279 8 F W O 880205 F TCA 294 DISCOLORED WIRE AT TPCC-F37-2 151
PAGE l l' 18/08/23
- F TRAIN Ust/Us2 DIFFERENCE EDIT
)IFF 0 MOD PCR F Udl Ud2 RESP FROM F . F COORD T PROC a L STAT STAT COOR COORD / ENGAG / CONCUR R REVW A DATE O/I DATE A DATE _A 5 N SCALE CHANGE F1-70-250. SHOULD SE FIXED 153
)OO72-1 C 0 880126 A SV SFR #728-2.
TCA 170 MSL BVPASS LEANAGE SARRIER VENT 154 10072-2 5733 20454 8 D D 0 880205 F VALVE TCA T16 TEhP ELEMENT RELOCATION RWCU 155 10072-3 746 20084 8 D w 0 880205 F SYSTEM TCA 927 RwCU REGEN HT EXCH RM TEMP 856 10072-4 20084 8 w 0 880205 F CONTROL INSTALLATION OF TEST CONNECTION TO OUT 557 30072-0 5257 20117 8 MI w 0 880205 F 80ARD MSIV PMEUMATIC SUPPLY 2ND CYCLE MOD MSRV STM CUTTING PROSLEM 858 B0072-0 5546 23438 8 MR MR O 880205 F 10072-7 974 20214 8 MR MR O 880205 F 2ND CVCLE MOD M*AV PILOT DISC REPLACEMENT 159 V 880325 MANUAL FLOW CONTROL FOR CONTAINMENT H2 160 30073-1 5278 2Ct36 8 ha W O 880122 A 880229 F RECONSINER 4
N TCA 705 FULL CORE DISPLAY FAN CONTROL 161 30073-2 5173 A MR O 880127 A CIRCU TCA 501 CLEAR CRD HYD HI TEMP ALARM 167 30073-3 5326 26031 8 D W O 880205 F 30074-1 20278 A W I 880205 F M REACTOR RECIRC FLOW UNITS UPGRADING NEUTRON MONITORING FLOW UNITS 60074-2 N O 880219 F FUEL CYCLES CAUSE DIFF TRIPS FOR APRM e,4 DOO75-1 5308 20043 8 F W O 880205 F 800% BYPAS5 OF THE TURS EXHAUST SYSf*M FILTERS TCA 578 ORN LINE COOLING COIL TO 865 60073-1 5120 20401 8 MR w O 880205 F ORw/ PLUGGED N TCA 850 FANS TRIPPING LOW TEMP CUT OFF 166 80073-2 5716 8 0 0 880827 A 880121 REPLACE PAUL MONROES WITH LIMITORQUES 167 80073-3 682 5ttlN A W W O 880205 F 880219 F V 2NO CYCLE MOD - RX AIR ROLL FILTER 368 80073-4 997 20/23 8 D D 0 880205 F h SECOMES CLOGGED DURING SNOW STORMS V 880125 RERS FILTER COOL DOWN MODE DELETED ON 208 50073-5 N O 880122 A 880219 F UNIT 2
e PAGE 12, ,
58/01/23
- F TRAIN Ust/Ua2 OIFFERENCE EIIT DIFF 0 MOD PCR F ust us2 RESP FROM P . F COORO T PROC a L STAT STAT COOR COORD / ENGRG / COceCUR R REVW A DATE O/I DATE A DATE A $
TCA 597 LOSS OF LOCAL INDICATION OF 869 30077-t 5329 20409 8 MR O O 880205 F POI-42-IRD 880121 ADDITION OF A PRESS IND TO TIP PURGE PNL. 170 a
30077-2 341 20I63 A F K O 880120 A 880219 F V MINOR 8000 SHOULD SE INSTALLED DV S/U.
2ND CYCLE MOD - PROVIDE ACCESS DOORS FOR 378 30073-l 5667 20478 8 MR MR O 880205 P CONTROL RM HVAC ISOLATION VALVES 859 A O 880127 A N 2ND CVCLE MOD - PROVIDE FIRE STOP FOR THE 172
'l30073-2 CABLE PEN AT CONTRCh STRUCTURE. MOD MILL COVER BOTH UNIT I & UNIT 2 CASLE PENETRATIONS.
J BLADE BEARING REPLACEMENT FOR 873
! 30081-1 296 20393 8 w w 0 880205 F CONTROLLABLE PITCH FAN BLADES N 2ND CYCLE MOO - PROVIDE ADOITIONAL PA 374 30085-1 794 A O O 880827 A HANOSETS ANNUNCIATOR DIFFERENCE FOR ORY MELL 175 30087-1 5553 DCN N D w 0 880205 F CHILLERS GEN CORE MONITOR & PYROLYSATE COLLECTOR 176 10092-1 5028 .20328 8 MR C 0 880205 F N FUSE s5 DIFFERENT 177 30092-2 N O 880127 A N FUSE as DCFFERENT 578 30092-3 N O 880327 A 2ND CYCLE MOD - DIESEL GEN CONTROL FUSES 879 30092-4 5599 .8583M 8 MR W O 880205 F APPR 880121 UNIT I AND UNIT 2 ALARM MINDOW WORDING E80 30092-5 N O 880320 A 880219 F M SLIGHTLY DIFFERENT FOH SAFEGUARD BUS UN DERVOLTAGE.
UNIT 2 ELECT. LOADS ON UNI ( I SYSTEMS. 202 30092-0
- N O 880219 F N UNIT 2 TURBINE SUPERVISORY RECORDER IS 183 30093-5 N O 880127 A NEMER MOOFL.
W TCA 3057 REFUEL PLAT-STRAIN RELIEF FOR 882 30097-1 5727 723 A C O 880205 F HOIST C
%' 2ND CVCLE MOD - RELIEVE STRAIN ON MAIN 883 30097-2 480 6723 8 0 W O 880205 F HOIST ELECT CABLE PROVIDE SOUNDRV ZONE INTERLOCKS FOR 884 30097-3 134 625 8 F D O 880205 F REFUELING BRIDGE
l 98/31/29 PAGE IP.
- i RESP FRose F . F COORO T PROC F TRAIM Ust/Us2 DIFFE'ENCE CIT 31FF s H00 PCR F Usl Us2 a L 5(AT STAT COOR COORD / ENGRG / CONCUR R REvW A DATE O/I DATE A DATE A 5 O O 880205 F TCA 825.R88.892.893.958.959 INSTALL 385 30100-5 5579 2C405 8 esR ACCESSISLE TEST POINTS FOR SURV TEST W O 880120 A ObMI9 F M 880321 REPLACE RCIC PUese ACCELER0esETERS WITH 186 30100-2 2n050 N VELOCIYY PROSES O 880205 P UNIT 2 SEISMIC INSTR. PROVIDED SY UNIT I 134 30300-3 M N O 880219 F YOLTAGE RELAYS DIFF. 203 33100-4 O 880822 A 880229 F M 880125 HIGH ENERGY LINE SREAst DIFF. 204 30100-9 N O 880122 A 880229 F M 880125 SMUSSER REDUCTION PROGRAM FOR UNIT 2 205 13100-0 N
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TRAINING PLAN FOR UNIT 1/ UNIT 2 OlFFERENCES
-Back ground :
NUREG 1021 requires that for an RO or SRO to be eligible to hold simultaneous valid licenses on more than one nuclear f acility, the utility must justify to the commission that the differences between the units are not so significant that they impact the ability of the licensed personnel to operate safely and competently both facilities. Further, the utility must submit for NRC review the details of the training and certification program.
The analyses and sumary of the differences that must be performed will include:
(1) Facility design and systems relevant to control room personnel (2) Tech Specs (3) Procedures (primarily ON/0T/ TRIPS)
(4) Control room design and instrument location (5) Operational Characteristics The utility should also describe the expected method of rotating personnel between units and the ref amiliarization to be conducted before responsibility on a new unit is assumed.
Plan:
Unit 2 Startup Manager staff presently assimilating those pertinent Unit 1 vs Unit 2 differences using Bechtel and PECo Engineering support. Jim Hutton will provide all pertinent information to LGS Nuclear Training no later than April 1, 1988. Superintendent-Training will assign lead instructors in Licensed Operator Requal (LOR) training to develop training material to cover these differences in LOR training during 1988. This training will consist of 2 weeks of systems, procedures, location, and Tech Spec instruction.
Schedule (tentative):
- 1) Receive all Unit 1 vs Unit 2 differences from Unit 2 Startup group no later than April 1, 1988.
- 2) Draft letter for submittal to NRC for their review of dif ferences and LO/ SLO training plan for acquiring Unit 2 license for those finit 1 personnel.
- 3) Training to develop all training materials needed between April and August 1988.
- 4) Pending NRC ** siew and approval, NTS will provide 2 weeks of instruction for all 6 '. of operators and all SRO licensed Engineers between August 29, ..a and October 14, 1988. Differences training will consist of classroom instruction and plant tours with both a utility administered comprehensive written exam and plant-oral exam administered at end of the 2nd week of instruction.
e
- 5) HRC Region I to administer some type of exas (either written, plant-oral, or both) to all Unit 1 LO/ SLO personnel the weeks of 10/10, 10/24, and 11/07/88 for about 23-24 people each week.
- 6) All LO/ SLO personnel will have acquired Unit 1/2 dual licenses no later than December, 1988. This is approximately 6-7 months prior to fuel load and prior to start of Unit 1/ Unit 2 tie-in outage.
- 7) Any failures of HRC exams will be re-trained and re-examined as required.
NOTE: A meeting to discuss this process with NRC Region ! 8WR Examination personnel has been scheduled for January 27, 1988. At this meeting, tentative approval / disapproval of this plan will take place and prospective exam dates will be addressed. Attending this meeting will be appropriate representatives of Unit 2 Startup group, Operations, and Training.
E. G. Firth Superintendent-Training Limerick Generating Station 01/29/88 f
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- .. ~ ANachmewf 7 PHILADELPHIA ELECTRIC COMPANY LIMERICK GENERATING STATION
',- OPERATIONS GROUP Operator Manpower Operations Group Operator Manpower to Support Unit 2 Staffing and Budget Concerns (8 graphs):
- 1. Total Operator Staffing
- 2. Staffing by Classification (Operators on Shift Excluding Helpers)
- 3. Number of Helpers
- 4. Operators in Training
- 5. Staffing by Classif'. cation (Operators on Shift, Including Helpers)
- 6. SRO Licenses
- 7. RO Licenses
- 8. Excesc NLO Ouslifications
~ Limerick Gonoration Station 12/87 PcgG 1
,. Total Operator Staffing This graph represents total operator staffing. It is broken down into three parts: (1) Staffing by Classification (operators on shift excluding Helpers) (2) in Training. The series of graphs which follow further Number of Helpers (3) Operators delineates these three parts. A graph representing all operators on shift including Helpers is also included. Three (3) additional graphs analyze license and non-license operator availability, staffing plans and requirements and excess qualifications.
These additional graphs also depict the ability to handle attrition and training failures.
TOTAL OPERATOR STAFFNG (rsimmc. wrteres a cussinCAriow) su u,- .. .._
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At the end of December, there were 110 total operators that were on shift, working as Helpers or in training with increases to 136 scheduled by early 1988. This includes recently added postings plans.
for 18 additional Helpers and reflects revised personnel In late November 1987, 12 Helpers were added in response to an earlier posting and are presently in Auxiliary Operator training. Plexibility in the staffing and training program has been achieved by increasing both new hires and excess qualifications.
- Licarick Ganorotion Stotion 12/87 Pago 2
. Staffing by Classification (Operators on Shift Excluding Helpers)
This graph represents present and long range plans for shift operator staffing by classifications worked, excluding Helpers on shift. The trend in overall staffing size is reflected by this bar chart as well as relative increases in classifications worked. Long range plans reflect increases to 105 operators on shift by 1989 to support Unit 2 and 1988 budget concerns.
STAFFNG BY CLASSIFICATION (OPfBAt091 ON $wirT (ICL'C WCLPCPS)
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Two (2) Chief Operators (CO's) remain dedicated to Unit 2.
By 3/88, the Unit 2 staffing goals of 18 CO's and one (1)
Supervisor will be met, one month ahead of schedule. The 18 CO's will work the Unit 2 CO position on a rotating basis. Unit 2 staffing goals are being achieved and, in most cases, are earlier than originally requested. This graph does reflect our plans to pursue schedule advanced training programs. This is necessary to provide excess qualifications which will allow a margin for attrition for various reasons.
Limerick Ganoration Station 12/87 Pago 3
'. Number of Helpers This graph represents the number of Helpers available on shift. This number, assuming timely training and qualification, reflects flexibility in responding to operator classification vacancies due to attrition and the need to fill vacancies as a result of training.
NUMBER OF HELPERS tL 15
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At the end of December, there were 12 Helpers available. The recently added 12 Helpers will be in training through January.
Recently added postings for 18 Helpers, and their incorporation into the personnel plan, will maintain a minimum of 12 Helpers available on shift through 8/89.
Limarick G3norction Station 12/87 Page 4 Operators in Training This graph represents the number of operators in non-license and license training and those in on-the-job training. These numbers do not include the training week which is a part of the normal operator shift rotation or any other incidental training.
Non-license operator (NLO) progression classes are 11 weeks long.
License operator training classes are 40 weeks long. The training schedule reflects efforts to upgrade operator qualificatioris in anticipation of shif t vacancies (license and non-license), meet minimum requirements for accelerated progression training, staff Unit 2 and minimize temporary vacancies due to training.
OPERATORS IN TR AINING N0h-UC(N$C AND UO(NSC 30 - -
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At the end of December, there were five (5) operators in licensed operator training (2 SRO's, 3 ko's) and 19 in NLO training. There will be eight (8) operators (2 SRO's, 6 RO's) in the license operator training class which is scheduled to start in 9/88.
Lim 0 rick Generation Station 12/87 Page 5
- Staffing by Classification s
(Operators on Shift Including Helpers)
This graph represents present and long range plans for shift operator staffing by classification worked, including Helpers on shift. Those Helpers on shift and other operators qualified for higher classifications reflect the flexibility in responding to operator classification vacancies due to attrition and the need to fill vacancies as a result of training.
STAFFING BY CLASSlFICATION (ortsators ow swin iwet c wrteres) 12, _ .: 00/, f,%"*
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At the end of December, there were 86 operators on shift, 12 of which were Helpers.
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- Licorick Generation Station 12/87 Pcgo 6 e'
I SRO Licenses s
This graph represents the number of available Senior Reactor Operator (SRO) licenses with respect to planned staffing and Technical Specification (Tech Spec) requirements. Tech Spec requires two (2) SRO's per shift or 12 total, based upon a six (6) shift rotation for either one (1) or two (2) unit operation.
The number of licenses available above the requirement lines represent excess licenses with respect to that requirement.
Excess licenses reflect the flexibility needed to respond to vacancies in license positions (Chief operator and Supervision).
This graph also depicts the ability to handle attrition and training failures.
SRO LICENSES AVAlt. VS, IS & Pt ANNIII $1 AIIlNG 30 t6 ~
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At the end of December, there were two (2) excess licenses with respect to planned staffing requirements and nine (9) excess licenses with respect to Technical Specifications. Revised training plans will increase excess licenses with respect to planned staffing to four (4) by 8/89.
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LicGrick Conoration Station 12/87 pago 7 o'
, RO Licenses This graph represents the number of available Reactor Operator (RO) licenses with respect to planned staffing and Technical Specification (Tech Spec) requirements. Presently Tech Specs require two (2) RO's per shift for one (1) unit operation and three (3) for two (2) unit operation for a total of 12 and 18 respectively, based upon a six (6) shift rotation. The number of licenses available above the requirement linet represent excess licenses with respect to that requirement, hcess licenses reflect the flexibility needed to rn poid to vacancies in the Chief Operator license position. This graph also depicts the ability to handle attrition and training failures.
RO LICENSES AYA;L. V . is & yt ANN (D $1Af flHO
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At the end of December, there were nine (9) excess licenses
, with respect to Technical Specifications. Increased training '
1 efforts will provide three (3) excess licenssa avai3able in 8/*S with respect to planned staffing. This is an response ti the
- creation of ten (10) additional RO license positions byf mid-19893 i
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- Lim 9 tick G3neration Station 12/87 Pcgo 8 l Excess NLO Qualifications This graph represents the number of excess non-licensed operator (NLO) qualifications for Auxiliary Operator ( AO),
Auxiliary Plant Operator (APO) and Plant Operator (PO). This excess number reflects the flexibility needed to respond to vacancies in non-license positions and is based upon presently planned position increases. This graph also depicts the ability to handle attrition and training failures.
EXCESS NLO OUALIFICATiONS AC/APO/PC e A$tD UPON PLANNCD PO$1710N$
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At the end of vecember, there were 16 excess AO-qualified,
, nine (9) excess APO-qual!.fied and 18 excess PO-qualified operators. During December 2967, five (5) additional operators ucre qualified AO, as pla.7ned. Excess qualifications will increase beyond mid-1988 based upon increased hiring efforts and accelerated training schedules.
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