ML22276A263
| ML22276A263 | |
| Person / Time | |
|---|---|
| Site: | South Texas  |
| Issue date: | 09/08/2022 |
| From: | Fortner M South Texas |
| To: | NRC/RGN-IV/DORS/OB |
| References | |
| NOC-AE-22003916, STI: 35364630 | |
| Download: ML22276A263 (59) | |
Text
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Nuclear Operating Company South Texas Project Electric Generating Sia/ion P.O Box 2851 Wadsworth. Texas 77483 Regional Administrator, Region IV U.S. Nuclear Regulatory Commission 1600 E. Lamar Boulevard Arlington, TX 76011-4511 South Texas Project Units 1 and 2 March 8, 2023 NOC-AE-23003944 10 CFR 55 STI: 35436735 Docket Nos. STN 50-498 and STN 50-499 Clarification on 2022 Initial Exam Letters
References:
- 1.
Letter; M. Fortner (STP) to Regional Administrator (NRC); "Post-Examination Material;" September 19, 2022; (NOC-AE-22003916) (ML22276A263).
- 2.
Letter; M. Fortner (STP) to Regional Administrator (NRC); "Post-Examination Material;" October 13, 2022; (NOC-AE-22003921) (ML22276A263).
STP Nuclear Operating Company is submitting this letter to provide clarification on previous correspondence. Reference 1 contains personal identifiable information (PII). Once all PII is removed from the correspondence, the correspondence may be released according to NRC processes. Reference 2 was previously marked 10 CFR 2.390 because it contained Exam Related material that was to have a delayed release; however, since the material was related to the challenge questions and has to be released, the material is no longer considered Exam Related material that needs to be delayed from public disclosure.
There are no commitments in this letter.
If there are any questions regarding this matter, please contact Zachary Dibbern at 361-972-4336 or me at 361-972-4523.
~
~
Michael A. Fortner Manager, Operations Training
cc:
ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001 Bryan A Bergeon Senior Operations Engineer U.S. NRC, Region Ill, Division of Operating Reactor Safety (DORS)
NOC-AE-23003944 Page 2 of 2
Nuclear Operating Company South Tews Project Electric Generating Station P.O Box 289 Wadsworth. Tcxas 77483 Regional Administrator, Region IV U.S. Nuclear Regulatory Commission 1600 E. Lamar Boulevard Arlington, TX 76011-4511 South Texas Project Units 1 and 2 Docket Nos. STN 50-498, STN 50-499 Post-Examination Material September 19, 2022 NOC-AE-22003916 STI: 35364630 10 CFR 55 10 CFR 2.390(a)(8)
File No.: D43.02 This letter provides Post-Examination Materials for the NRC License Examinatio that was administered on August 22, 2022, through September 8, 2022, at South Texas Project (STP), in accordance with NUREG-1021, Operator Licensing Examination Standards for Power Reactors.
STP Nuclear Operating Company requests the NRC consider Attachment 2 to this letter as Exempt from Public Disclosure. None of the exam materials are to go to the Public Document Room (ADAMS) for at least two years.
There are no commitments in this letter.
The following Post-Examination material is being sent:
1.
Written examination cover sheet with the original graded answer sheet and 2 clean copies of the answer sheet for each examinee. (Paper Copy) 2.
CD-ROM-1, that includes the following electronic files:
- LOT 26 NRC JPMs
- LOT 26 NRC Simulator Scenarios
- LOT 26 NRC Written Exam
- LOT 26 NRG Written Exam Analysis
- LOT 26 NRC Written Exam Applicant Comments After Exam
- LOT 26 NRC Written Exam Question Challenges by STP
- LOT 26 NRG Written Exam Questions and Clarifications During Exam
- LOT 26 NRC Written Exam Seating Arrangement The completed Form 1.3-1, Examination Security Agreement, will be forwarded as soon as possible.
NOC-AE-22003916 Page 2 of 2 If you have any questions, please contact Arthur Vest at (361) 972-8666 or me at (361) 972-4523.
Michael A. Fortner Manager, Operations Training Attachments:
- 1. Written examination cover sheet with the original graded answer sheet and 2 clean copies of the answer sheet for each examinee. (Paper Copy)
- 2. CD-ROM with Post-Exam Information cc:
Bryan Bergeon Chief Examiner U.S. Nuclear Regulatory Commission 1600 E. Lamar Blvd.
Arlington, TX 76011-4511 Attention: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001 STP Records Management without Attachments 1 or 2 NOC-AE-22003916 Written examination cover sheet with the original graded answer sheet and 2 clean copies of the answer sheet for each examinee. (Paper Copy)
CD-ROM with Post-Exam Information NOC-AE-22003916
STPEGS LOT 26 Written Exam Student Questions and Clarifications 09/08/2022 Question 18 Student - RO: I believe more information is needed to evaluate this question based on how the crew arrived at EC-11. Did the crew go through ES-13? How far did the crew get thru ES-13? Up to step 6 and then transitioned? Was the LBLOCA outside containment?
Proctor Response: Answer the question as written.
Question 24 Student - RO: I believe if Subcooling goes below due to operator action, the use of charging is directed but the availability of manually starting an SI pump is always available and that both answers are technically correct.
Proctor Response: Answer the question as given.
Question 51 Student - RO: Does it mean the ability to trip breaker or the auto trip functions?
Proctor Response: Answer the question as given.
Question 62 Student - RO: Has the breaker for the standby pump been verified inoperable?
Proctor Response: Answer the question as given.
Question 68 Student - SRO: How much are we extending the Administrative Limit? It affects the approval requirement.
Proctor Response: Contacted Chief Examiner. We agreed to supply a value of 500 mRem to the candidates. This was added to the end of the stem on the second part of the question and placed on the white board for the duration of exam. All candidates were still in the room and had access to this information.
Question 82 Student -SRO/SRO: The picture provided is unclear if LED for Rod M4 is at the Rod Bottom or 6 steps line.
Proctor Response: Contacted Chief Examiner. We agreed to provide clarification that Rod M4 is below the 6 step line. This was placed on the white board for the duration of exam. All SRO candidates were still in the room and had access to this information.
STP LOT 26 NRC WRITTEN EXAM POST-EXAM APPLICANT COMMENTS 09/08/2022 Question 6 Student Comment: How do we know what RWST Level is? TS is 33,000, it wont drain at this level.
STP Response: The question required the students to select the right valves to be isolated for secured/tripped RHR pumps in POP04-RH-0001 when in RCS reduced inventory and why the valves are isolated. A note prior to step 3 of 0POP04-RH-0001 states the cold leg injection isolation valves on secured/tripped trains must be closed to prevent draining the RWST to the RCS. The contents of the RWST would not be in the RX cavity during a typical drain down to mid-loop. The only time this may be true is when using the temporary head with the Reactor defueled. The note is based on plant OE. No changes to the exam are warranted. The step and note were covered in the training material presentation for 0POP04-RH-0001.
Question 80 Student Comment: Why not apply 0POP04-RC-0003?
STP Response: The purpose of 0POP04-RC-003 is to locate and isolate RCS leakage within the capacity of the Normal Reactor Makeup System (Charging Pumps) for the conditions given in the question stem the leak is outside of the capacity of the charging pumps and 0POP04-RC-0006, Shutdown LOCA is the correct procedure to enter. No changes to the examination are warranted. The entry conditions of both of the procedures in discussed adequately in the training materials.
Question 81 Student Comment: TAA (FRH1) shows safety limit exceeded, C/D could be right.
STP Response: There is not TAA less for FRH1. The training only covers the procedure and the Basis document. The TAA that the student is referring to is the Design Basis Document for Loss of Feedwater and that document shows that based on the analysis of that RCS pressure will not exceed 2400 psig and is within the capacity of the PZR PORVs. The question asked for the operational implication of establishing for why RCS Bleed and Feed must be established within several minutes of meeting the criteria. Per the WOG Basis document for FRH1 there is only one answer and that is to minimize core uncovery. No changes to the examination are warranted. The entry conditions of both of the procedures in discussed adequately in the training materials.
Question 83 Student Comment: The answer or instead of and/or.
STP Response; The question required the candidates to know the power supply requirements for a Source Range NI channel in MODE 6 with fuel movement in progress, the effect of loss of power to the Audio Count Rate amplifier and any action that needed to be taken for the condition. The candidates were aware of the power supply requirements and the effect of losing the Audio Count Rate amplifier but did not select the correct actions required. A comment was made by a candidate in the post exam review that the second part of the action should have read AND instead of OR. However, OR is used in TS 3.9.2. No changes to the exam are warranted. Training materials covering the Tech Spec adequately covered the action.
Question 89 Student Comment: 0POP04-AF-0001 calls out 115ºF and 200ºF.
STP Response: 0POP04-AF-0001 uses 115ºF as an entry criteria, the same as 0PSP-03-ZQ-0028, which is the value that the question asked for in the stem. 200ºF is mentioned but only in the sense that an alarm will come in at that temperature. No changes to the exam are warranted. The procedure is adequately training in POP04 training.
Question 93 Student Comment: 0PGP03-ZF-0018 talks about compensatory measures, the Main Transformer supports Technical Specifications. If you lose the Main Transformer you are in 3.8.1.1 initially.
STP Response: The 2nd half of the question required the students to determine if a Fire Watch would be required if the Main Transformer deluge system was isolated.
0PGP03-ZF-0018, Fire Protection System Functionality Requirements, step 4.3 states:
The SPRINKLER or SPRAY SYSTEMS identified in Addendum 2 SHALL be functional whenever the equipment protected by them is required to be operable by Technical Specifications:
During the post-exam review, the candidates stated that they chose D because a loss of the Main Transformer would result in an entry into Technical Specifications, thus a Fire Watch would be required.
The Main Transformer is required to be in service to consider the Unit Auxiliary Transformer as an offsite source, as required by Technical Specification 3.8.1.1, AC Sources. If the Main Transformer was not available, it would result in entry into Technical Specification 3.8.1.1.e, for the loss of 2 offsite sources.
Additionally, 0PGP03-ZF-0018, Addendum 2, Halon, Sprinkler, and Fixed Water Spray Systems, contains the areas that would require a Fire Watch but does not include the Main Transformer. Since the candidates would not be required to memorize Addendum 2 or the equipment not listed in Addendum 2, the procedure step shown above caused the students to conclude that the Main Transformer would require a Fire Watch since its loss would result in a Technical Specification entry.
To answer this question correctly, additional information in the stem of the question would be necessary to correctly answer this question on a closed book Initial License NRC Written Exam. STP is challenging this question and recommending that it be removed from the exam.
Question 96 Student Comment: Can you field change a surveillance? Change procedure described in UFSAR?
STP Response: Yes, a field change can be made to a surveillance if it meets the conditions of 0PAP01-ZA-0102. The stem stated that this was not an intent change. This would mean that the change did not change the procedure as described in the UFSAR which is part of the standard of an intent change. Field changes are very infrequent but are still a valid methodology for making a procedure change if you meet certain conditions. No changes to the exam are warranted. This procedure is trained on during the Administrative Procedure training.
Bank #
Question #
Answer A
B C
D Total Missed
% Missed RO/SRO (11 Candidates) 3118 1
D 0
0 3123 2
A 1
2 3
27.3 3124 3
D 0
0 3125 4
A 1
1 9.1 3126 5
B 2
2 18.2 3212 6
C 4
4 8
72.7 2393 7
A 1
1 9.1 2949 8
D 0
0 2568 9
A 1
1 9.1 2562 10 C
1 1
9.1 3235 11 A
0 0
3236 12 B
1 1
9.1 3205 13 D
0 0
3132 14 B
1 1
2 18.2 3133 15 A
0 0
3135 16 C
0 0
3136 17 C
0 0
3237 18 A
1 1
9.1 3138 19 B
0 0
3134 20 C
2 2
18.2 2167 21 A
0 0
1593 22 D
1 1
9.1 3141 23 C
0 0
3142 24 B
1 1
9.1 3149 25 A
0 0
3234 26 D
1 1
9.1 3144 27 C
0 0
3145 28 B
0 0
3146 29 C
1 2
3 27.3 3147 30 D
0 0
3148 31 C
0 0
3150 32 A
0 0
2755 33 D
0 0
3152 34 B
0 0
1117 35 A
0 0
3153 36 C
0 0
3154 37 D
0 0
3155 38 B
0 0
1668 39 A
1 1
9.1 2677 40 C
2 2
18.2 3233 41 C
0 0
3232 42 D
0 0
3213 43 B
0 0
1488 44 A
0 0
Bank #
Question #
Answer A
B C
D Total Missed
% Missed 3159 45 C
0 0
2586 46 C
0 0
2685 47 A
1 1
9.1 2824 48 D
1 1
9.1 3161 49 B
2 2
18.2 3231 50 B
1 1
9.1 3230 51 C
1 1
9.1 2220 52 B
0 0
3180 53 B
1 1
2 18.2 3215 54 D
2 1
3 27.3 3208 55 A
2 2
18.2 3229 56 D
0 0
3165 57 B
1 1
9.1 3166 58 B
1 1
9.1 3167 59 D
0 0
3228 60 C
1 1
9.1 3227 61 B
1 1
9.1 3169 62 C
1 1
9.1 3170 63 A
2 2
18.2 3171 64 C
2 2
18.2 3172 65 B
0 0
3210 66 B
0 0
2848 67 D
0 0
3226 68 C
1 1
9.1 2946 69 C
0 0
3174 70 A
0 0
3209 71 B
1 1
9.1 3176 72 C
0 0
3177 73 B
0 0
3178 74 C
2 2
18.2 3179 75 B
1 1
9.1 SRO ONLY (8 Candidates) 3218 76 B
0 0
3219 77 D
2 2
25 3186 78 C
2 2
25 3199 79 D
0 0
3200 80 B
2 1
3 37.5 3203 81 C
3 3
37.5 3220 82 A
0 0
3211 83 A
4 4
50 2783 84 C
1 1
12.5 3221 85 C
1 1
12.5 2774 86 A
1 1
12.5 3202 87 A
0 0
3239 88 C
0 0
Bank #
Question #
Answer A
B C
D Total Missed
% Missed 3193 89 A
3 1
4 50 3194 90 B
1 1
12.5 3222 91 C
0 0
3196 92 B
0 0
3224 93 C
8 8
100 3198 94 A
1 1
2 25 2862 95 D
0 0
3190 96 B
2 2
25 2935 97 B
0 0
2847 98 B
0 0
3188 99 D
1 1
12.5 3189 100 D
0 0
Question 6 4 candidates selected B, 4 candidates selected D. The correct answer is C.
The question required the students to select the right valves to be isolated for secured/tripped RHR pumps in POP04-RH-0001 when in RCS reduced inventory and why the valves are isolated. Four candidates did not know the required valves or the reasons why. The other 4 candidates did not know why the valves are required to be closed. Step 3 lists the required valves to be closed and a note prior to the step states the reason why they need to be closed. The note is based on plant OE. No changes to the exam are warranted. The step and note were covered in the training material presentation for 0POP04-RH-0001.
Question 83 4 candidates selected B. The correct answer is A.
The question required the candidates to know the power supply requirements for a Source Range NI channel in MODE 6 with fuel movement in progress, the effect of loss of power to the Audio Count Rate amplifier and any action that needed to be taken for the condition. The candidates were aware of the power supply requirements and the effect of losing the Audio Count Rate amplifier but did not select the correct actions required. A comment was made by a candidate in the post exam review that the second part of the action should have read AND instead of OR. However, OR is used in TS 3.9.2. No changes to the exam are warranted. Training materials covering the Tech Spec adequately covered the action.
Question 89 3 candidates select C. 1 candidate selected D. The correct answer is A.
The question required the candidates to know the maximum AFW discharge header temperature and the action to correct the problem if the temperature were exceeded. The candidates did not know the maximum discharge temperature and 1 candidate did not know the correct action. The maximum temperature and action to restore to normal is discussed adequately during POP04 training which uses the current revision of the procedure for the discussion of entry conditions and actions for POP04-AF-0001. No changes to the exam are warranted for this question.
Question 93 All 8 candidates selected D. The intended answer was C.
The 1st half of the question required the students to recall the automatic start feature for the Fire Pumps. With pressure dropping to below 110 psig, all 3 Fire Pumps would start. The 2nd half of the question required the students to determine if a Fire Watch would be required if the Main Transformer deluge system was isolated.
0PGP03-ZF-0018, Fire Protection System Functionality Requirements, step 4.3 states:
The SPRINKLER or SPRAY SYSTEMS identified in Addendum 2 SHALL be functional whenever the equipment protected by them is required to be operable by Technical Specifications:
During the post-exam review, the candidates stated that they chose D because a loss of the Main Transformer would result in an entry into Technical Specifications, thus a Fire Watch would be required.
The Main Transformer is required to be in service to consider the Unit Auxiliary Transformer as an offsite source, as required by Technical Specification 3.8.1.1, AC Sources. If the Main Transformer was not available, it would result in entry into Technical Specification 3.8.1.1.e, for the loss of 2 offsite sources.
Additionally, 0PGP03-ZF-0018, Addendum 2, Halon, Sprinkler, and Fixed Water Spray Systems, contains the areas that would require a Fire Watch but does not include the Main Transformer.
Since the candidates would not be required to memorize Addendum 2 or the equipment not listed in Addendum 2, the procedure step shown above caused the students to conclude that the Main Transformer would require a Fire Watch since its loss would result in a Technical Specification entry.
To answer this question correctly, additional information in the stem of the question would be necessary to correctly answer this question on a closed book Initial License NRC Written Exam.
Per NUREG-1021, Rev. 12, ES-4.4 C.3.c first bullet:
- A question with an unclear stem that confused the applicants or did not provide all the necessary information (to assist in determining whether an unclear stem confused the
applicants, closely evaluate any applicant questions asked during the examination; also evaluate the question stem to determine whether the information provided could reasonably result in the applicant misunderstanding the intent of the question or the validity of the answer choices)
Based upon this information and NUREG-1021, Rev. 12, ES-4.4, A.5-6, Question 93 (Bank Question 3224) is recommended to be removed from the exam. The question will be deactivated and revised prior to reuse.
POST-EXAM QUESTION CHALLENGE BY STP STP LOT 26 NRC WRITTEN EXAM 09/09/2022 Question 93 The Unit 1 MAIN TRANSFORMER deluge system inadvertently actuates and can NOT be reset.
Fire Protection System pressure lowers to 98 psig.
15 minutes later the crew isolates the deluge system and Fire Protection System pressure rises to its normal value.
Complete the following:
____(1)____ Fire Pumps started.
Per 0PGP03-ZF-0018, with the MAIN TRANSFORMER deluge system isolated, a Fire Watch
____(2)____ be established.
A. (1) 2 (2) does not have to B. (1) 2 (2) must C. (1) 3 (2) does not have to D. (1) 3 (2) must Answer: C The 1st half of the question required the students to recall the automatic start feature for the Fire Pumps. With pressure dropping to below 110 psig, all 3 Fire Pumps would start.
The 2nd half of the question required the students to determine if a Fire Watch would be required if the Main Transformer deluge system was isolated.
All 8 SRO candidates incorrectly selected choice D (Fire Watch required). 1 of 2 validators selected choice D also.
0PGP03-ZF-0018, Fire Protection System Functionality Requirements, step 4.3 states:
The SPRINKLER or SPRAY SYSTEMS identified in Addendum 2 SHALL be functional whenever the equipment protected by them is required to be operable by Technical Specifications:
During the post-exam review, the candidates stated that they chose D because a loss of the Main Transformer would result in an entry into Technical Specifications, thus a Fire Watch would be required.
The Main Transformer is required to be in service to consider the Unit Auxiliary Transformer as an offsite source, as required by Technical Specification 3.8.1.1, AC Sources. If the Main Transformer was not available, it would result in entry into Technical Specification 3.8.1.1.e, for the loss of 2 offsite sources.
Additionally, 0PGP03-ZF-0018, Addendum 2, Halon, Sprinkler, and Fixed Water Spray Systems, contains the areas that would require a Fire Watch but does not include the Main Transformer. Since the candidates would not be required to memorize Addendum 2 or the equipment not listed in Addendum 2, the procedure step shown above caused the students to conclude that the Main Transformer would require a Fire Watch since its loss would result in a Technical Specification entry.
To answer this question correctly, additional information in the stem of the question would be necessary to correctly answer this question on a closed book Initial License NRC Written Exam.
Per NUREG-1021, Rev. 12, ES-4.4 C.3.c first bullet:
A question with an unclear stem that confused the applicants or did not provide all the necessary information (to assist in determining whether an unclear stem confused the applicants, closely evaluate any applicant questions asked during the examination; also evaluate the question stem to determine whether the information provided could reasonably result in the applicant misunderstanding the intent of the question or the validity of the answer choices)
Based upon this information and NUREG-1021, Rev. 12, ES-4.4, A.5-6, Question 93 is recommended to be removed from the exam. The question will be deactivated and revised prior to reuse.
Nuclear Operating Company South Texas Proiect Electric Generating Station P.O Box 289 Wadsworth. Texas 77483 Regional Administrator, Region IV U.S. Nuclear Regulatory Commission 1600 E. Lamar Boulevard Arlington, TX 76011-4511 South Texas Project Units 1 and 2 October 13, 2022 NOC-AE-22003921 STI: 35381922 10 CFR 55 10 CFR 2.390(a)(8)
File No.: D43.02 Docket Nos. STN 50-498 and STN 50-499 Post-Examination Material This letter provides supplemental information related to our challenge for the NRC License Examination that was administered on August 22, 2022, through September 8, 2022, at South Texas Project (STP),
in accordance with NUREG-1021, Operator Licensing Examination Standards for Power Reactors.
STP Nuclear Operating Company requests the NRC consider Attachment 1 to this letter as Exempt from Public Disclosure. None of the exam materials are to go to the Public Document Room (ADAMS) for at least two years.
There are no commitments in this letter.
The following Post-Examination material is being sent:
1.
LOT 26 NRC Written Exam Question Challenge Supplement by STP If you have any questions, please contact Arthur Vest at (361) 972-8666 or me at (361) 972-4523.
4
Michael A Fortner Manager, Operations Training
Attachment:
LOT 26 NRC Written Exam Question Challenge Supplement by STP cc:
ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001 STP Records Management without Attachment Bryan Bergeon Operations Branch, Division of Reactor Safety, Region IV U.S. Nuclear Regulatory Commission 1600 E. Lamar Boulevard Arlington, TX 76011-4511
Attachment NOC-AE-22003921 Attachment LOT 26 NRC Written Exam Question Challenge Supplement by STP
LOT26 Written Exam Question Challenge Supplement by STP Question 93 NOC-AE-22003921 Attachment The question is in two parts, all eight students correctly answered the first part which was the impact to the Fire Water system upon the actuation and subsequent isolation of the flow path. The basis of our challenge is that SRO candidates are not required to possess knowledge, from memory, of the safety or non-safety class designation of all plant equipment, which is required on the second part of the question. The candidates were able to apply their knowledge to the question, understanding that a loss of the Main Transformer would require entry into Technical Specifications, however the lack of clarity of the question comes when they are discerning whether the component class status requires a Fire Watch upon its loss. The candidates shared during the review, that all Technical Specifications equipment with impaired fire protection would require a Fire Watch as a compensatory measure. This led to the confusion of requirements of specific components that are non safety class but are necessary to meet the requirements of Technical Specifications. One such example are the Engineered Safety Features (ESF) Transformers which are essential to meet the requirements of Technical Specification 3.8.1.1, AC Sources, but due to being non-safety class, its loss of fire protection would not require a Fire Watch. It is this differentiation that makes it very difficult to determine based purely on the knowledge, from memory, of being required by Technical Specifications.
The question's stem could have been made clear, without handouts, if the SRO candidates were given additional information about the component. The following are a couple of examples that would provide this:
(a) The Unit 1 Non-Safety Class MAIN TRANSFORMER...
OR (b) The Unit 1 MAIN TRANSFORMER (TPNS Z.X151 EMT00 1 B)...
Either enhancement would have allowed the SRO candidates to decide whether a Fire Watch would be required upon the loss of fire protection to the affected component. Without this additional information, the students, without a reference, would not be expected to recall this requirement from memory. Understanding that it was non-safety class, the candidates would know that though an entry into a Technical Specification action statement is required, a Fire Watch is not necessary.
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SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION D0527 STI 35121369 0PSP03-EA-0002 Rev. 41 Page 1 of 37 ESF Power Availability Quality Safety-Related Usage: IN HAND Effective Date: 01/26/2021 Gary Lamberth N/A Crew 2E Operations PREPARER TECHNICAL USER COGNIZANT DEPT.
Table of Contents Page
1.0 Purpose and Scope
.......................................................................................................................... 2 2.0 Prerequisites.................................................................................................................................... 3 3.0 Notes and Precautions..................................................................................................................... 4 4.0 Pretest Verification.......................................................................................................................... 7 5.0 Procedure......................................................................................................................................... 8 6.0 Acceptance Criteria....................................................................................................................... 12 7.0 Documentation.............................................................................................................................. 15 8.0 References..................................................................................................................................... 16 9.0 Support Documents....................................................................................................................... 18 Addendum 1, 345 KV Switchyard Normal Operation.................................................................. 19 Addendum 2, Two Physically Independent Circuits..................................................................... 20 Data Package, Data Package Cover Sheet.................................................................................... 22 Data Sheet 1, 345 KV Switchyard Alignment.............................................................................. 24 Data Sheet 2, Required ESF Power Train A................................................................................. 25 Data Sheet 3, Required ESF Power Train B................................................................................. 26 Data Sheet 4, Required ESF Power Train C................................................................................. 27 Data Sheet 5, Channel I, 120 VAC and 125 VDC Vital Bus Availability.................................... 28 Data Sheet 6, Channel II, 120 VAC and 125 VDC Vital Bus Availability.................................. 29 Data Sheet 7, Channel III, 120 VAC and 125 VDC Vital Bus Availability................................. 30 Data Sheet 8, Channel IV, 120 VAC and 125 VDC Vital Bus Availability................................. 31 Data Sheet 9, Bus and Charger Voltage Data............................................................................... 32
0PSP03-EA-0002 Rev. 41 Page 2 of 37 ESF Power Availability
1.0 Purpose and Scope
1.1 This procedure satisfies Surveillance Requirements (Modes 1, 2, 3 and 4) 4.8.1.1.1.a 4.8.2.1.a and 4.8.3.1 of the following Technical Specifications:
1.1.1 Determination of two physically independent circuits between the offsite transmission network and the onsite Class 1E Distribution per Technical Specification 3.8.1.1.a, by verifying breaker alignments and indicated power availability in Modes 1 through 4.
1.1.2 Determine proper energization of ESF buses per Technical Specification 3.8.3.1, by verifying correct breaker alignment and bus voltages in Modes 1 through 4.
1.1.3 Determine operability of ESF battery bank associated chargers per Technical Specification 3.8.2.1, by verifying correct breaker alignment and voltages in Modes 1 through 4.
1.2 This procedure determines the availability of the 138 KV Emergency Transformer for possible use during a Loss of Offsite Power by verifying the Voltage and Breaker Lineup per Data Sheet 2 and 9. This meets commitments made for the SDG, ECW and Essential Chilled Water Technical Specification Change. (Reference 8.12) 1.3 This procedure determines Technical Specification 3.8.1 LCO entry requirements during planned (preventative or corrective maintenance) 345 KV Switchyard North or South Bus outages.
1.4 This procedure determines Technical Specification LCO 3.8.1.1.e entry requirements due to low voltage condition existing on the offsite power system, or a potential low voltage condition that could exist on the offsite power system following a trip of both Units.
1.5 This procedure satisfies the surveillance requirement 4.8.2.1.a at least once per 7 days by verifying that total battery terminal voltage is greater than or equal to the minimum established float voltage.
1.6 This procedure satisfies the surveillance requirement 4.8.2.3.a at least once per 7 days by verifying the float current for each battery is d 2 amps when battery terminal voltage is greater than or equal to the minimum established float voltage of Surveillance Requirement 4.8.2.1.a.
0PSP03-EA-0002 Rev. 41 Page 3 of 37 ESF Power Availability 2.0 Prerequisites 2.1 EVALUATE current plant conditions, and note in the Remarks Section of the Data Package any changes in Operational Risk Assessment due to special plant conditions.
2.2 IF recording battery charge current and total battery terminal voltage in Data Sheet 9, THEN OBTAIN the following M&TE (or equivalent):
M&TE DESCRIPTION RANGE TOLERANCE Fluke 187 Multimeter/Digital 0 - 500 VDC r0.1% Reading + 0.02 VDC Amprobe AC/DC 1000 OR Multimeter/Clamp-On 0 - 199.9 Amps DC r1% Reading + 5 Digits Yokogawa CL255 Multimeter/Clamp-On 0 - 400 Amps DC r1.5% Reading + 0.5 Amps 2.3 IF recording battery charge current and total battery terminal voltage in Data Sheet 9, THEN RECORD M&TE on Data Sheet 9.
0PSP03-EA-0002 Rev. 41 Page 4 of 37 ESF Power Availability 3.0 Notes and Precautions 3.1 Breaker positions SHALL NOT be changed without authorization from the Unit Supervisor or Shift Manager.
3.2 Failure to meet the Acceptance Criteria of this test may require entry into one or more of the following LCO Action Statements:
x Technical Specification 3.8.1.1 x
Technical Specification 3.8.2.1 x
Technical Specification 3.8.3.1 3.3 Loss of one 345 KV Switchyard North or South Bus, including a planned (preventative or corrective maintenance) outage, constitutes loss of one required offsite source.
(Reference 8.14) 3.4 Loss of one 13.8 KV Standby Bus to 4.16 KV ESF bus line constitutes loss of one required offsite source. (Reference 8.2) 3.5 Loss of two 13.8 KV Standby busses to 4.16 KV ESF bus lines constitutes loss of two required offsite sources. (Reference 8.2) 3.6 Addendum 2, Two Physically Independent Circuits, provides a drawing of rights of way and offsite circuits to aide in the definition of two physically independent circuits.
3.7 Refer to 0PSP03-EA-0003, ESF Power Availability Shutdown, for Modes 5 and 6.
3.8 TDSP no longer supports maintaining STP Switchyard minimum voltages of greater than 339 KV (e.g., 356 KV). This requires entering the appropriate Technical Specification (i.e., 3.8.1.1.a or 3.8.1.1.e) whenever an Alternate Lineup is entered. The requirement to notify TDSP when entering or exiting an Alternate Lineup still exists.
3.9 NORMAL LINEUP: All three 4.16 KV ESF Busses are energized through an automatic load tap changing transformer with the respective LTCs in AUTO. In a NORMAL LINEUP, minimum switchyard voltage is 339 KV.
3.10 ALTERNATE LINEUP: Any electrical bus alignment other than a NORMAL LINEUP. Placing the UAT LTC or Train B ESF LTC in MANUAL is considered an ALTERNATE LINEUP. Entry into an ALTERNATE LINEUP requires entry into the applicable Technical Specification (i.e., 3.8.1.1.a or 3.8.1.1.e).
0PSP03-EA-0002 Rev. 41 Page 5 of 37 ESF Power Availability 3.11 When in an ALTERNATE LINEUP, the applicability of Technical Specification LCO 3.8.1.1.a or 3.8.1.1.e should be determined as follows:
3.11.1 IF ONLY ONE 4.16 KV ESF bus is NOT connected to a transformer with a LTC in AUTO, THEN ONE offsite source should be considered inoperable, and Technical Specification 3.8.1.1.a should be applied.
3.11.2 IF MORE THAN ONE 4.16 KV ESF bus is NOT connected to a transformer with a LTC in AUTO, THEN TWO offsite sources should be considered inoperable, and Technical Specification 3.8.1.1.e should be applied.
3.12 The preferred 13.8 KV electrical bus alignment is the lineup shown in Drawing No. 0-E-AAAA-01, Main One Line Diagram Unit 1 and 2.
3.13 ALTERNATE LINEUPs are considered to be unit specific (i.e., one unit being in an ALTERNATE LINEUP has no impact on the other unit). Each units electrical bus configuration is considered independently with regard to ALTERNATE LINEUPs and associated required compensatory actions.
3.14 Condition Report Engineering Evaluation (CREE) CR# 00-500-25 states that operability is based upon the existing state of the 345 KV system voltage as well as the potential voltage condition in the event that the STPEGS Unit(s) were to trip. Due to combinations of conditions existing on the grid, the loss of load from a trip of the STPEGS Unit(s) could be the event that creates a degraded voltage condition on the grid. According to General Design Criteria 17, Regulatory Guide 1.93, and STPEGS UFSAR Section 8.0, the offsite power grid must be capable of supplying acceptable voltage levels for operation of the ESF related equipment on the STPEGS site.
3.15 Technical Specification LCO Action 3.8.1.1.e is entered per 0POP04-AE-0005, Offsite Power System Degraded Voltage, when notified by the STP Coordinator or Transmission Distribution Service Provider (TDSP) that a combination of conditions exist on the 345 KV system that could lead to a degraded voltage condition (less than 339 KV) in the 345 KV Switchyard subsequent to a trip of both units (i.e., loss of all STPEGS generation).
3.16 Based on the analysis in CREE 03-16063-3 from the review of the design, licensing documents, NRC criteria and IEEE standards, STPs offsite power system is in accordance with GDC-17 provided that two separate paths of power are available from the transmission system to the ESF busses. However, adherence to GDC-17 covers the transformers, switchyard and transmission lines as compared to what is provided in STPs Technical Specifications Section 3/4.8.1. LCOs for the two independent transmission circuits should include electrical bus lineups, switchyard issues that could cause a loss of offsite power and transmission lines. Should all the electrical safety buses be lined up to one of the three supply transformers, a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> LCO should be entered since there would be a delay in restoring power if the onsite power systems were unavailable (as described in IV.2). A delay in restoring power to a safety bus in this situation would be considered an unanalyzed condition. (Reference 8.18)
0PSP03-EA-0002 Rev. 41 Page 6 of 37 ESF Power Availability 3.17 LCOs for switchyard problems should be entered when equipment failures could cause the loss of one or all offsite power sources. An example of an equipment failure would be the loss of the battery chargers which ultimately provide tripping power for the 345 kV switchyard breakers for the transmission lines. An LCO would not need to be entered immediately since the stored energy in the batteries will provide enough energy to trip breakers for longer than 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> after the loss of the battery chargers. Notification of the loss of control of the breakers would have to come from our Transmission Service Provider. (Reference 8.18) 3.18 LCOs for transmission lines should be entered when one or both of the required transmission lines is lost. The write up in CREE 99-1981-1 is still valid for the transmission system and switchyard busses. (Reference 8.18) 3.19 When performing 345 KV Switchyard North or South Bus outages, Acceptance Criteria Step 6.2 applies and requires entry into Technical Specification LCO 3.8.1.1.a.
Technical Specification LCO 3.8.1.1.a entry is a requirement of CREE 99-1981-1, HL&P Final Report on STP 345 KV Switchyard Transient Stability Impact on Existing CREE 97-4343-8. (Reference 8.14) 3.20 IF 345 KV Switchyard North or South Bus planned (preventative or corrective maintenance) outages are in progress, THEN ENSURE Technical Specification LCO action 3.8.1.1.a has been entered. (Technical Specification 3.8.1.1.a, 4.8.1.1.1.a, References 8.14, 3.18) (Addendum 1) 3.21 IF notification has been received from the MQSE or TDSP that a degraded voltage condition could exist on the 345 KV system following a trip of both units, THEN ENSURE Technical Specification LCO action 3.8.1.1.e has been entered.
(Technical Specification 3.8.1.1.e, References 8.8, 8.17, 3.15) 3.22 IF notification has been received from the TDSP that power has been lost to both Switchyard battery chargers, THEN ENSURE Technical Specification LCO action 3.8.1.1.e has been entered within 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> of notification.
(Technical Specification 3.8.1.1.e, References 8.2, 8.18, 3.17) 3.23 IF ALL three ESF 4.16 KV busses are energized from the same Aux or Stby XFMR, THEN ENSURE Technical Specification LCO action 3.8.1.1.a has been entered.
(Technical Specification 3.8.1.1.a, References 8.2, 8.18, 3.16) 3.24 Charger and DC Switchboard readings are based on a 59 cell battery. For configurations less than 59 cells, consult the Electrical Setpoint Index.
3.25 Minimum battery terminal voltage Acceptance Criteria on Data Sheet 9 is for a 59 cell battery. For configurations less than 59 cells, the value is 2.17 VDC times the number of connected cells.
3.26 Battery terminal voltage Acceptance Criteria on Data Sheet 9 is based on float voltages.
There is not a Technical Specification for equalize voltage. (References 1.5, 6.11)
0PSP03-EA-0002 Rev. 41 Page 7 of 37 ESF Power Availability 3.27 As delineated within UFSAR Section 8.2.1.1, The Hillje transmission lines cross under the Elm Creek transmission lines at the Hillje substation. Since the Hillje lines are below the Elm Creek line, the Hillje lines are not allowed to be credited with being an offsite source of power in accordance with GDC 17 (i.e., Hillje Ckt. 44 and Hillje Ckt. 64 SHALL NOT be utilized to satisfy Technical Specification requirements for an offsite transmission network).
3.28 As delineated within CREE 13-1596-2, the 345 KV Blessing transmission line (Blessing 44) has limited capability with respect to providing the required voltage when used as an independent source of offsite power. Due to this limited capability, the Blessing 44 line is not allowed to be credited with being an offsite source of power in accordance with GDC 17 (i.e., Blessing 44 SHALL NOT be utilized to satisfy Technical Specification requirements for an offsite transmission network). (Reference 8.30) 3.29 Switchyard voltage information MAY be obtained from either the CP010 meters OR by contacting TDSP directly, as follows: (Reference 8.31) x WHEN CP010 indications clearly support 345 KV switchyard voltage is within pre-defined limits, THEN CP010 meters MAY be utilized to obtain switchyard voltage information.
x WHEN CP010 indication does NOT clearly support 345 KV switchyard voltage is within pre-defined limits, THEN TDSP SHALL be contacted via the ring-down line (or telephone) to obtain SCADA TELEMETRY STP SWITCHYARD VOLTAGE (SCADA 345A is North Bus and SCADA 345B is South Bus).
x TDSP SCADA TELEMETRY STP SWITCHYARD VOLTAGE MAY be used at anytime in lieu of CP010 to obtain switchyard voltage.
x Regarding the STP Coordinators (NRG) SMART (Scheduling Marketing and Real Time) application (also commonly referred to as Ranger), while this application is a useful tool that STP Control Room personnel can use as additional indication of switchyard voltage, this indication SHALL NOT be used when verifying 345 KV switchyard voltage is within pre-defined limits. This is due to 345 KV switchyard voltages being communicated through a virtual private network (VPN) connection.
4.0 Pretest Verification None
0PSP03-EA-0002 Rev. 41 Page 8 of 37 ESF Power Availability 5.0 Procedure NOTE x IF this surveillance is being performed to satisfy Technical Specification Surveillance Requirement 4.8.1.1.1.a, THEN Data Sheet 1 through 9 SHALL be performed.
x IF this surveillance is being performed to satisfy the requirements of Technical Specification 3.8.1.1 ACTION Items a, b, c, or f, THEN ONLY Data Sheet 1, 2, 3, 4, and 9 are required to be performed.
x Note and Precaution 3.29 should be referred to for additional clarification regarding allowable indication to be utilized when obtaining 345 KV switchyard voltage.
5.1 COMPLETE required Data Sheet 1, 345 KV Switchyard Alignment by performing the following steps.
5.1.1 VERIFY data for Data Sheet 1, 345 KV Switchyard Alignment by performing AT LEAST ONE of the following:
x CONSULT with the STP Coordinator (QSE Ring Down) to verify the switchyard status.
x MONITOR the computer link to Centerpoint Switchyard Status AND VERIFY link is updating.
x PERFORM a combination of the following: (References 8.22 and 8.23) o MONITOR Control Room indication of switchyard breaker status (lack of alarms and position indication lights),
o MONITOR switchyard voltage indication (CP010 or SCADA),
o EVALUATION of any STP Interface Coordination Agreement notifications from Transmission Owners, o CHECK that available communication links with the STP Coordinator indicate no change in switchyard component status, o VERIFY last known status of ALL switchyard breakers as CLOSED.
0PSP03-EA-0002 Rev. 41 Page 9 of 37 ESF Power Availability 5.1.2 RECORD actual breaker/disconnect positions for the 345 KV Switchyard breakers and disconnects.
x RECORD CLOSED breaker/disconnect positions by drawing a line at an angle through the breaker/disconnect.
x RECORD OPEN breaker/disconnect positions by drawing a CIRCLE around the breaker/disconnect.
NOTE Note and Precaution 3.29 should be referred to for additional clarification regarding allowable indication to be utilized when obtaining 345 KV switchyard voltage.
x RECORD 345 KV North and South Bus Voltage (CP010 or SCADA).
x CIRCLE YES or NO for NORTH AND SOUTH BUS IN SERVICE WITH VOLTAGE t 339 KV (Reference Acceptance Criteria Steps 6.1, 6.2 and 6.4):
x CIRCLE YES or NO for each APPROVED 345 KV OFFSITE CIRCUIT (GDC 17) in service.
x CIRCLE YES or NO for AT LEAST 2 RIGHTS OF WAY AVAILABLE (i.e., AT LEAST ONE of the approved 345 KV offsite circuits associated with a right-of-way is required to be in service for the right-of-way to be considered available)
0PSP03-EA-0002 Rev. 41 Page 10 of 37 ESF Power Availability NOTE There are 5 possible lineups on Data Sheet 2, 3, and 4 for 13.8 KV XFMRS in the DESIGNATED Class 1E 4160 VAC Bus Power Source Table that meet Technical Specification requirements for being a power source for the 4.16 KV Buses:
x (1) UAT supplying the AUX BUS and STBY BUS x (2) UAT supplying the AUX BUS and UNIT 1 STBY XFMR supplying the STBY BUS x (3) UNIT 1 STBY XFMR supplying the STBY BUS and the AUX BUS x (4) UAT supplying the AUX BUS and UNIT 2 STBY XFMR supplying the STBY BUS x (5) UNIT 2 STBY XFMR supplying the STBY BUS and the AUX BUS 5.2 COMPLETE Required ESF Power Train Data Sheet 2 through 4 by performing the following steps.
5.2.1 RECORD actual breaker/disconnect positions for the 13.8 KV XFMRs, AUX BUS, STBY BUSES and from the 13.8 KV STBY BUS to the 480 VAC BUSES.
x RECORD CLOSED breaker/disconnect positions by drawing a line at an angle through the breaker.
x RECORD OPEN breaker/disconnect positions by drawing a CIRCLE around the breaker.
This example illustrates:
(3) UNIT 1 STBY XFMR supplying the STBY BUS and the AUX BUS UNIT 1 STBY XFMR UNIT 2 STBY XFMR UNIT AUX XFMR EMER XFMR AUX 1F(2F)
0PSP03-EA-0002 Rev. 41 Page 11 of 37 ESF Power Availability NOTE Unit 1 and Unit 2 control board mimics are different. Mimic locations for UNIT 1 STBY XFMR and UNIT 2 STBY XFMR are opposite.
x In Unit 1, UNIT 1 STBY XFMR is on the left.
x In Unit 2, UNIT 2 STBY XFMR is on the left.
5.2.2 CIRCLE actual breaker positions for the selected XFMR lineup in the DESIGNATED Class 1E 4160 VAC Bus Power Source Table.
5.2.3 RECORD a 9 above the 13.8 KV XFMR lineup designated as the Class 1E 4160 VAC bus power source.
5.2.4 ENSURE the 13.8 KV XFMR lineup designated as the class 1E 4160 VAC bus power source meets the Acceptance Criteria in Steps 6.1 for Modes 1, 2, 3 and 4.
5.2.5 CIRCLE actual breaker positions in the REQD BREAKER/DISC POSITION column for the Technical Specification electrical lineup from the 13.8 KV STBY BUS to the 480 VAC BUSES.
5.2.6 ENSURE the Acceptance Criteria in Steps 6.3 for Modes 1, 2, 3 and 4 is met by VERIFYING that ALL breakers in the REQD BREAKER/DISC POSITION column are circled.
5.3 COMPLETE ESF Power Availability Data Sheet 5 through 8 by circling OR recording actual breaker/disconnect positions (e.g., OPEN, CLOSED, ON, OFF, etc.).
5.4 RECORD indicated voltages on Data Sheet 9, Bus and Charger Voltage Data.
DESIGNATE (99)
Class 1E 4160 VAC Bus Power Source (note 2)
(1)
(2)
(3) 9 (4)
(5)
(1) UNIT AUX XFMR (2) UNIT 1 STBY XFMR (3) UNIT 1 STBY XFMR (4) UNIT 2 STBY XFMR (5) UNIT 2 STBY XFMR UAT TO AUX BUS 1F(2F)
SUPLY CLOSED CLOSED OPEN CLOSED OPEN STBY XFMR 1 TO STBY BUS 1F(2F) SUPLY OPEN CLOSED CLOSED OPEN OPEN STBY XFMR 2 TO STBY BUS 1F(2F) SUPLY OPEN OPEN OPEN CLOSED CLOSED AUX TO STBY BUS 1F(2F) TIE CLOSED OPEN CLOSED OPEN This example illustrates:
(3) UNIT 1 STBY XFMR supplying the STBY BUS and the AUX BUS
0PSP03-EA-0002 Rev. 41 Page 12 of 37 ESF Power Availability 6.0 Acceptance Criteria NOTE x Addendum 2, Two Physically Independent Circuits, provides a drawing of rights of way and offsite circuits to aide in the definition of two physically independent circuits.
x Loss of one 13.8 KV Standby Bus to 4.16 KV ESF bus line constitutes loss of one required offsite source. (Reference 8.2) x Loss of two 13.8 KV Standby busses to 4.16 KV ESF bus lines constitutes loss of two required offsite sources. (Reference 8.2) x The preceding notes also apply when the 4.16 KV ESF bus is not energized by the 13.8 KV XFMR.
x Step 6.1 applies during standby diesel inoperability.
x Step 6.2 applies during offsite independent circuits inoperability.
x Note and Precaution 3.29 should be referred to for additional clarification regarding allowable indication to be utilized when obtaining 345 KV switchyard voltage.
6.1 Two physically independent circuits exist between the offsite transmission network and onsite Class 1E Distribution System as determined from Data Sheet 1, 2, 3, 4, and 9.
(Technical Specifications 3.8.1.1.b, 3.8.1.1.f, and 4.8.1.1.1.a )
x North and South Bus in service with bus voltage t 339 KV x Two of the following Rights of Way with a 345 KV line are available:
o NW Right of Way 1 (ANGSTR_STP1 / ANGSTR_WHITE_1) o NW Right of Way 2 (Elm Creek 27 OR WA Parish 39 OR Elm Creek 18) o Eastern Right of Way (Refuge 27 OR Jones Creek 18) x Two of the following 13.8 KV XFMRs are available:
o Unit Aux XFMR o Unit 1 Stby XFMR o Unit 2 Stby XFMR x Three 13.8 KV Standby Buses energizing the 4.16 KV ESF bus lines.
0PSP03-EA-0002 Rev. 41 Page 13 of 37 ESF Power Availability 6.2 One circuit exists between the offsite transmission network and onsite Class 1E Distribution System as determined from Data Sheet 1, 2, 3, 4, and 9. (Technical Specification 3.8.1.1.a, 3.8.1.1.c, 4.8.1.1.1.a) x North or South Bus in service with bus voltage t 339 KV x One of the following Rights of Way with a 345 KV line is available:
o NW Right of Way 1 (ANGSTR_STP1 / ANGSTR_WHITE_1) o NW Right of Way 2 (Elm Creek 27 OR WA Parish 39 OR Elm Creek 18) o Eastern Right of Way (Refuge 27 OR Jones Creek 18) x One of the following 13.8 KV XFMRs is available:
o Unit Aux XFMR o Unit 1 Stby XFMR o Unit 2 Stby XFMR x Three 13.8 KV Standby Buses energizing the 4.16 KV ESF bus lines.
6.3 Each ESF 4.16 KV bus E1A, E1B and E1C (E2A, E2B and E2C) is energized and supplying its respective 480V Load Centers E1A1, E1A2, E1B1, E1B2, E1C1 and E1C2 (E2A1, E2A2, E2B1, E2B2, E2C1 and E2C2) via its respective load center transformers as determined from Data Sheet 1, 2, 3, 4, and 9.
(Technical Specification 3.8.3.1a, b, and c, 4.8.3.1)
NOTE IF notification has been received from the STP Coordinator or TDSP that a degraded voltage condition (less than 339 KV) could exist on the 345 KV System following a trip of both units, THEN Technical Specification LCO 3.8.1.1.e SHALL be entered per 0POP04-AE-0005, Offsite Power System Degraded Voltage. (References 3.15, 8.8, 8.17 and 8.18) 6.4 Notification has NOT been received from the STP Coordinator or TDSP that a degraded voltage condition (less than 339 KV) could exist on the 345 KV system following a trip of both units (i.e., loss of all STPEGS generation). (Technical Specification 3.8.1.1.e, References 3.15, 8.8, 8.17 and 8.18) 6.5 IF notified by the TDSP that switchyard battery chargers are not operating, THEN LCO 3.8.1.1.e has been entered within 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br />. (Technical Specification 3.8.1.1.e, Reference 8.2, 8.18, 3.17)
0PSP03-EA-0002 Rev. 41 Page 14 of 37 ESF Power Availability 6.6 IF notified by the TDSP that equipment failures could cause the loss of one or all offsite power sources, THEN LCO 3.8.1.1.e has been entered. (Technical Specification 3.8.1.1.e, Reference 8.2, 8.18, 3.17) 6.7 ALL three ESF 4.16 KV busses are NOT energized from the same Aux or Stby XFMR.
(Technical Specification 3.8.1.1.a, Reference 8.2, 8.18, 3.16) 6.8 Each 120 Volt AC Distribution panel DP1201, DP001, DP1202, DP1203, DP1204 and DP002 is energized from its associated inverter AND each inverter is connected to its respective D.C. Bus E1A11, E1D11, E1B11 and E1C11 (E2A11, E2D11, E2B11 and E2C11) as determined from Data Sheet 5, 6, 7, 8, and 9.
(Technical Specification 3.8.3.1d, e, f and g, 4.8.3.1).
6.9 Each 125 Volt DC bus E1A11, E1B11, E1C11 and E1D11 (E2A11, E2B11, E2C11 and E2D11) is energized from its associated battery bank E1A11, E1B11, E1C11 and E1D11 (E2A11, E2B11, E2C11 and E2D11) as determined from Data Sheet 5, 6, 7, 8, and 9.
(Technical Specification 3.8.3.1h, i, j and k, 4.8.3.1) 6.10 Channels I, II, III and IV 125V Battery Banks are each being supplied from ONE of their two associated chargers. (Technical Specification 3.8.2.1, 4.8.2.1.a) 6.11 Channels I, II, III and IV 125V total battery terminal voltage is greater than or equal to the minimum established float voltage determined from Data Sheet 9.
(Technical Specification 4.8.2.1.a) 6.12 The float current for each battery is d 2 amps when battery terminal voltage is greater than or equal to the minimum established float voltage as determined from Data Sheet 9.
[Battery Banks E1A11, E1B11, E1C11 and E1D11 (E2A11, E2B11, E2C11 and E2D11)].
(Technical Specification 4.8.2.3.a)
0PSP03-EA-0002 Rev. 41 Page 15 of 37 ESF Power Availability 7.0 Documentation 7.1 Data Package Cover Sheet 7.2 Data Sheet 1, 345 KV Switchyard Alignment 7.3 Data Sheet 2, Required ESF Power Train A 7.4 Data Sheet 3, Required ESF Power Train B 7.5 Data Sheet 4, Required ESF Power Train C 7.6 Data Sheet 5, Channel I, 120 VAC and 125 VDC Vital Bus Availability 7.7 Data Sheet 6, Channel II, 120 VAC and 125 VDC Vital Bus Availability 7.8 Data Sheet 7, Channel III, 120 VAC and 125 VDC Vital Bus Availability 7.9 Data Sheet 8, Channel IV, 120 VAC and 125 VDC Vital Bus Availability 7.10 Data Sheet 9, Bus and Charger Voltage Data
0PSP03-EA-0002 Rev. 41 Page 16 of 37 ESF Power Availability 8.0 References 8.1 Single Line Diagrams:
8.1.1 9-E-AAAA-01 #1(#2),
Main Generator Unit & Standby Xfmr Protection
& Metering 8.1.2 9-E-AAAB-01 #1(#2),
Class 1E 125V DC & 120V Vital AC, Non-Class 1E 48V, 125V, 250V DC &
120V Vital AC, Non-Class 1E Inverter Power for Computer 208/120V AC Regulated Power 8.1.3 9-E-DJAA-01 #1(#2),
125V DC Class 1E Distribution Swbd E1A11(E2A11) (Channel I) 8.1.4 9-E-DJAB-01 #1(#2),
125V DC Class 1E Distribution Swbd E1D11(E2D11) (Channel II) 8.1.5 9-E-DJAC-01 #1(#2),
125V DC Class 1E Distribution Swbd E1B11(E2B11) (Channel III) 8.1.6 9-E-DJAD-01 #1(#2),
125V DC Class 1E Distribution Swbd E1C11(E2C11) (Channel IV) 8.1.7 9-E-VAAA-01 #1(#2),
Vital 120V AC Distribution Panels DP001, DP1201 (Channel I) 8.1.8 9-E-VAAB-01 #1(#2),
Vital 120V AC Distribution Panels DP1202, DP1203 (Channel II & III) 8.1.9 9-E-VAAC-01 #1(#2),
Vital 120V AC Distribution Panels DP002, DP1204 (Channel IV) 8.2 Technical Specifications 3.8.1.1, 3.8.2.1, and 3.8.3.1 8.3 UFSAR Section 8.1, (Electric Power) Introduction 8.4 UFSAR Section 8.2, Offsite Power System 8.5 UFSAR Section 8.3, Onsite Power Systems 8.6 SPR 921204, Class 1E Electrical System Min/Max Voltages 8.7 SR 189442, Class 1E Electrical System Min/Max Voltages 8.8 0POP04-AE-0005, Offsite Power System Degraded Voltage 8.9 0PSP06-DJ-0001, 125 Volt Class 1E Battery 7 Day Surveillance Test 8.10 0PMP05-DJ-0010, 1E Battery Equalizing Charge 8.11 0PSP03-EA-0003, ESF Power Availability Shutdown, for Modes 5 and 6
0PSP03-EA-0002 Rev. 41 Page 17 of 37 ESF Power Availability 8.12 ST-AE-HL-94678, South Texas Project, Units 1 and 2 - Amendment NOS. 85 and 72 to Facility Operating License NOS. NPF-76 and NPF-80 (Extended AOTs for ECW, ECHW and SDGs) 8.13 CREE 96-9996, Capability of the Emergency Transformer 8.14 CREE 99-1981-1, HL&P Final Report on STP 345 KV Switchyard Transient Stability Impact on Existing CREE 97-4343-8 8.15 CREE 99-3416, Evaluate DC Voltage Used in 0PSP03-EA-0002 8.16 LER 99-003, Entry into Technical Specification 3.0.3 following a Partial LOOP 8.17 CREE 00-500-25, Possible Conditions on the ERCOT Grid that Influence Voltage or Grid Stability.
8.18 CREE 03-16063-3, STP Position on GDC 17, Electric Power Systems, in regards to the Preferred Offsite Power System 8.19 0POP01-ZA-0021, AC Electrical Notes and Precautions 8.20 DCP 04-12263-31, Class 1E Battery Charger Setpoints 8.21 SPR 941413, M&TE Issue Sheets Not Completed 8.22 CAQ-D 11-1354-9, Include a Third Bullet that Allows Use of a Combination of Control Room Indication of Switchyard Breaker Status 8.23 South Texas Project Nuclear Plant Interface Coordination Agreement (January 1, 2017) 8.24 DCPs 05-10905-4 and -5, Replace Safety Related Inverters EIV001 & EIV002 8.25 CREE 11-10205-19, Gain Operating Margin on 480 VAC Buses 8.26 CREE 11-10205-19, UAT and ESF LTC Operations 8.27 10-5555, SOER 10-1, Large Power Transformer Reliability (Recommendation 6) 8.28 EC05000, Voltage Regulation Study 8.29 0POP02-AE-0002, Transformer Normal Breaker and Switch Lineup 8.30 CREE 13-1596-2, 345 KV Blessing Transmission Circuit (Blessing 44) Has Limited Capability To Provide the Required Voltage When Used As An Independent Source of Offsite Power 8.31 CREE 12-24599-1, Engineering Evaluation of Available Switchyard Indications When Comparing STP Switchyard Voltage to Pre-Defined Limits 8.32 CR 14-12078, Revise Procedures 0POP02-AE-0002 and 0POP04-AE-0005 to Remove References to Minimum Switchyard Voltages of 358 KV and 357 KV Because These Post Trip Voltage Support Limits Can No Longer be Satisfied by Normal Operation of the Transmission System.
8.33 DCP 17-402-1, 345 kV Transmission Line Name Change From Dow Velasco 18 to Jones Creek 18
0PSP03-EA-0002 Rev. 41 Page 18 of 37 ESF Power Availability 9.0 Support Documents 9.1 Addendum 1, 345 KV Switchyard Normal Operation 9.2 Addendum 2, Two Physically Independent Circuits 9.3 Data Package Cover Sheet 9.4 Data Sheet 1, 345 KV Switchyard Alignment 9.5 Data Sheet 2, Required ESF Power Train A 9.6 Data Sheet 3, Required ESF Power Train B 9.7 Data Sheet 4, Required ESF Power Train C 9.8 Data Sheet 5, Channel I, 120 VAC and 125 VDC Vital Bus Availability 9.9 Data Sheet 6, Channel II, 120 VAC and 125 VDC Vital Bus Availability 9.10 Data Sheet 7, Channel III, 120 VAC and 125 VDC Vital Bus Availability 9.11 Data Sheet 8, Channel IV, 120 VAC and 125 VDC Vital Bus Availability 9.12 Data Sheet 9, Bus and Charger Voltage Data
0PSP03-EA-0002 Rev. 41 Page 19 of 37 ESF Power Availability Addendum 1 345 KV Switchyard Normal Operation Page 1 of 1 345 KV NORTH BUS SOUTH BUS GEN 2 MT2 UAT 2 SBT 2 BLESSING 44 ANGSTR_STP1 /
ANGSTR_WHITE_1 HILLJE 64 W A PARISH 39 ELM CREEK 27 ELM CREEK 18 REFUGE 27 JONES CREEK CKT 18 GEN 1 UAT 1 SBT 1 MT 1 BKR CLOSED BKR OPEN 345 KV NC NC Y500 Y550 Y530 Y580 Y560 Y600 Y520 Y610 Y510 Y540 Y570 Y590 Y640 Y630 Y620 Y650 Y660 HILLJE 44
0PSP03-EA-0002 Rev. 41 Page 20 of 37 ESF Power Availability Addendum 2 Two Physically Independent Circuits Page 1 of 2
- 1) The following provides guidance regarding the requirement for two physically independent circuits between the offsite transmission network and the onsite Class 1E Distribution System:
a) In Modes 1, 2, 3 and 4, At least two physically independent circuits between the offsite transmission network and the onsite Class 1E Distribution System SHALL be OPERABLE.
(Technical Specification 3.8.1.1) b) The 400 ft. wide NW right-of-way common corridor out of STP property is considered as two independent rights-of-way; one with circuits to ANGSTR_STP1 / ANGSTR_WHITE_1 and Hillje 44, and the other with circuits to W.A. Parish 39, Hillje 64, Elm Creek 27 and Elm Creek 18. (Reference UFSAR 8.2.1.1) c) As delineated within UFSAR Section 8.2.1.1, The Hillje transmission lines cross under the Elm Creek transmission lines at the Hillje substation. Since the Hillje lines are below the Elm Creek line, the Hillje lines are not allowed to be credited with being an offsite source of power in accordance with GDC 17 (i.e., Hillje Ckt. 44 and Hillje Ckt. 64 SHALL NOT be utilized to satisfy Technical Specification requirements for an offsite transmission network).
d) As delineated within CREE 13-1596-2, the 345 KV Blessing transmission line (Blessing 44) has limited capability with respect to providing the required voltage when used as an independent source of offsite power. Due to this limited capability, the Blessing 44 line is not allowed to be credited with being an offsite source of power in accordance with GDC 17 (i.e., Blessing 44 SHALL NOT be utilized to satisfy Technical Specification requirements for an offsite transmission network). (Reference 8.30)
(continued on next page)
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 21 of 37 ESF Power Availability Addendum 2 Two Physically Independent Circuits Page 2 of 2 (continued)
(*) Blessing Ckt. 44, Hillje Ckt. 44 and Hillje Ckt. 64 are NOT qualified in accordance with GDC 17 AND SHALL NOT be utilized to satisfy Technical Specification requirements for an offsite transmission network.
(**) AEP has connected a 345kV substation (Angstrom) between the STP Switchyard and the Whitepoint Substation. The transmission line is broken up into two parts known as ANGSTR_STP1 and ANGSTR_WHITE_1.
e) Examples of at least two physically independent circuits:
x ANGSTR_STP1 / ANGSTR_WHITE_1 and Elm Creek Ckt. 27 - The circuits are in different rights-of-way and the circuits do not share the same towers. The 400 ft. wide NW right-of-way common corridor out of STP property is considered as two independent rights-of-way.
x ANGSTR_STP1 / ANGSTR_WHITE_1 and Jones Creek Ckt. 18 - The circuits are in different rights-of-way and the circuits do not share the same towers.
BLESSING CKT. 44 (*)
SWITCH YARD
(**) ANGSTR_STP1 /
ANGSTR_WHITE_1 ELM CREEK CKT. 27 ELM CREEK CKT. 18 HILLJE CKT. 64 (*)
W.A.PARISH CKT.39 R
M P
F EMERG XFMR JONES CREEK CKT 18 138 KV BLESSING LINE REFUGE CKT. 27 EASTERN RIGHT OF WAY WESTERN RIGHT OF WAY NORTH WESTERN RIGHT OF WAY HILLJE CKT. 44 (*)
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 22 of 37 ESF Power Availability Data Package Data Package Cover Sheet Page 1 of 2 UNIT 1 (Circle Unit Performing Surveillance)
UNIT 2 NOTE x
IF this surveillance is being performed to satisfy Technical Specification Surveillance Requirement 4.8.1.1.1.a, THEN Data Sheet 1 through 9 SHALL be performed.
x IF this surveillance is being performed to satisfy the requirements of Technical Specification 3.8.1.1 ACTION Items a, b, c, or f, THEN ONLY Data Sheet 1, 2, 3, 4, and 9 are required to be performed.
x Permission to start test is required ONLY for manipulation of a system.
- 1. Data Takers and Procedure Performers:
- 2. Reason for Test:
(Modes 1, 2, 3 and 4) 4.8.1.1.1.a, 4.8.2.1.a and 4.8.3.1
________ Periodic Test
________ LCO 3.8.1.1.a, With one offsite circuit of the required A.C. electrical power sources inoperable.
________ LCO 3.8.1.1.b, With a standby diesel generator inoperable.
________ LCO 3.8.1.1.c, With one offsite circuit of the required A.C. electrical power sources and one standby diesel generator inoperable.
________ LCO 3.8.1.1.f, With two or three of the required standby diesel generators inoperable.
________ Other (explain) ________________________________________________________
- 3. IF M&TE was used, THEN ENSURE required information has been recorded on the M&TE Usage form (WOFWOME) in STP IMPACT for each piece of M&TE used.
(Reference 8.21)
Initials
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 23 of 37 ESF Power Availability Data Package Data Package Cover Sheet Page 2 of 2
- 4. Test Results:
________ Acceptable ________ Unacceptable IF unacceptable, THEN immediately INFORM the Shift Manager.
Test Performer Date Time
- 5. Test Results Second Review:
________ Acceptable ________ Unacceptable (complete section below)
Refer to Technical Specification __________ LCO Action Requirements Is this condition a potentially reportable occurrence?
_____ Yes
_____ No Should an LCO Action Statement be entered?
_____ Yes
_____ No Remarks__________________________________________________________________________
Shift Manager Date Time
- 6. Data Review:
Surveillance Coordinator Date Time
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 24 of 37 ESF Power Availability Data Sheet 1 345 KV Switchyard Alignment Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet) UNIT 2 345 KV N BUS (CP010 OR SCADA 345A) 345 KV S BUS (CP010 OR SCADA 345B)
NORTH AND SOUTH BUS IN SERVICE WITH VOLTAGE t 339 KV (REFERENCE AC STEPS 6.1, 6.2 AND 6.4)
YES NO APPROVED 345 KV OFFSITE CIRCUITS (GDC 17)
NW RIGHT OF WAY 1 ANGSTR_STP1 /
ANGSTR_WHITE_1 YES NO NW RIGHT OF WAY 2 ELM CREEK 27 YES NO OR W A PARISH 39 YES NO OR ELM CREEK 18 YES NO EASTERN RIGHT OF WAY REFUGE 27 YES NO OR JONES CREEK 18 YES NO AT LEAST 2 RIGHTS OF WAY AVAILABLE YES NO GEN 2 MT2 UAT 2 SBT 2 BLESSING 44 ANGSTR_STP1 /
ANGSTR_WHITE_1 HILLJE 64 W A PARISH 39 ELM CREEK 27 ELM CREEK 18 REFUGE 27 JONES CREEK 18 GEN 1 UAT 1 SBT 1 MT 1 345 KV SOUTH BUS NC NC Y500 Y550 Y530 Y580 Y560 Y600 Y520 Y610 Y510 Y540 Y570 Y590 Y640 Y630 Y620 Y650 Y660 HILLJE 44 W Right of Way NW Right of Way 2 Eastern Right of Way 2
NW Right of Way 1 RECORD VOLTAGE RECORD VOLTAGE 345 KV NORTH BUS S014 S024 G029 G019 9446 9396 8446 8646 9276 8396 9186 8276 8186
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 25 of 37 ESF Power Availability Data Sheet 2 Required ESF Power Train A Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 DESIGNATE (99)
Class 1E 4160 VAC Bus Power Source (note 2)
(1)
(2)
(3)
(4)
(5)
UNIT AUX XFMR UNIT 1 STBY XFMR UNIT 1 STBY XFMR UNIT 2 STBY XFMR UNIT 2 STBY XFMR UAT TO AUX BUS 1F(2F)
SUPLY CLOSED CLOSED OPEN CLOSED OPEN STBY XFMR 1 TO STBY BUS 1F(2F) SUPLY OPEN CLOSED CLOSED OPEN OPEN STBY XFMR 2 TO STBY BUS 1F(2F) SUPLY OPEN OPEN OPEN CLOSED CLOSED AUX TO STBY BUS 1F(2F) TIE CLOSED OPEN N/A OPEN N/A BREAKER/DISC POSITION REQD UNSAT EMER XFMR TO BUS 1K/1L (2K/2L) SPLY N/A N/A STBY BUS 1F(2F) TO XFMR E1A(E2A) BKR SW-NORM CLOSED OPEN STBY BUS 1F(2F) TO XFMR E1A(E2A) DISC SW-NORM CLOSED OPEN EMER BUS 1L/2L TO XFMR E1A(E2A) BKR SW-EMER N/A N/A EMER BUS 1L/2L TO XFMR E1A(E2A) DISC SW-EMER N/A N/A SPLY BKR E1A(E2A)/1 CLOSED OPEN DG OUTP BKR E1A(E2A)/14 N/A N/A SPLY BKR E1A(E2A)/12 CLOSED OPEN SPLY BKR E1A(E2A)/13 CLOSED OPEN OUTP BKR E1A(E2A)/2E CLOSED OPEN OUTP BKR E1A(E2A)/2A CLOSED OPEN CROSS TIE E1A(E2A)/2C OPEN CLOSED 13.8 KV EMERG 1L(2L)
UNIT 1 STBY XFMR UNIT 2 STBY XFMR UNIT AUX XFMR EMER XFMR 480VAC E1A1(E2A1)/E1A2(E2A2) 4.16 KV BUS E1A(E2A) 11(21) DG Note 1, Indicates Technical Specification related electrical lineup.
Note 2, Required per Technical Specifications, EITHER UNIT AUX XFMR OR UNIT 1 STBY XFMR OR UNIT 2 STBY XFMR SHALL be the power source for 4.16 KV Bus E1A(E2A).
PERFORMED BY DATE TIME AUX 1F(2F)
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 26 of 37 ESF Power Availability Data Sheet 3 Required ESF Power Train B Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 PERFORMED BY DATE TIME DESIGNATE (9)
Class 1E 4160 VAC Bus Power Source (note 2)
(1)
(2)
(3)
(4)
(5)
UNIT AUX XFMR UNIT 1 STBY XFMR UNIT 1 STBY XFMR UNIT 2 STBY XFMR UNIT 2 STBY XFMR UAT TO AUX BUS 1G(2G) SPLY CLOSED CLOSED OPEN CLOSED OPEN STBY XFMR 1 TO STBY BUS 1G(2G) SPLY OPEN CLOSED CLOSED OPEN OPEN STBY XFMR 2 TO STBY BUS 1G(2G) SPLY OPEN OPEN OPEN CLOSED CLOSED AUX TO STBY BUS 1G(2G) TIE CLOSED OPEN N/A OPEN N/A BREAKER/DISC POSITION REQD UNSAT STBY BUS 1G(2G) TO XFMR E1B(E2B) BKR SW-NORM CLOSED OPEN STBY BUS 1G(2G) TO XFMR E1B(E2B) DISC SW-NORM CLOSED OPEN EMER BUS 1L(2L) TO XFMR E1B(E2B) BKR SW-EMER N/A N/A EMER BUS 1L(2L) TO XFMR E1B(E2B) BKR DISC SW-EMER N/A N/A SPLY BKR E1B(E2B)/1 CLOSED OPEN DG OUTP BKR E1B(E2B)/14 N/A N/A SPLY BKR E1B(E2B)/12 CLOSED OPEN SPLY BKR E1B(E2B)/13 CLOSED OPEN OUTP BKR E1B(E2B)/2F CLOSED OPEN OUTP BKR E1B(E2B)/2A CLOSED OPEN CROSS TIE E1B(E2B)/2C OPEN CLOSED UNIT 1 STBY XFMR UNIT 2 STBY XFMR UNIT AUX XFMR EMER XFMR 4.16 KV BUS E1B(E2B) 12(22) DG Note 1, Indicates Technical Specification related electrical lineup.
Note 2, Required per Technical Specifications, EITHER UNIT AUX XFMR OR UNIT 1 STBY XFMR OR UNIT 2 STBY XFMR SHALL be the power source for 4.16 KV Bus E1B(E2B).
AUX 1G(2G)
STBY 1G(2G)
E1B(E2B)/12 E1B(E2B)/13 E1B1(E2B1)
XFMR E1B2(E2B2)
XFMR 480VAC E1B1(E2B1)/E1B2(E2B2)
E1B1(E2B1)
E1B2(E2B2)
E1B(E2B)/2A E1B(E2B)/2F E1B(E2B)/14 E1B(E2B)/1 E1B(E2B)/2C
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 27 of 37 ESF Power Availability Data Sheet 4 Required ESF Power Train C Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 DESIGNATE (99)
Class 1E 4160 VAC Bus Power Source (note 2)
(1)
(2)
(3)
(4)
(5)
UNIT AUX XFMR UNIT 1 STBY XFMR UNIT 1 STBY XFMR UNIT 2 STBY XFMR UNIT 2 STBY XFMR UAT TO AUX BUS 1H(2H) SPLY CLOSED CLOSED OPEN CLOSED OPEN STBY XFMR 1 TO STBY BUS 1H(2H) SPLY OPEN CLOSED CLOSED OPEN OPEN STBY XFMR 2 TO STBY BUS 1H(2H) SPLY OPEN OPEN OPEN CLOSED CLOSED AUX TO STBY BUS 1H(2H) TIE CLOSED OPEN N/A OPEN N/A BREAKER/DISC POSITION REQD UNSAT STBY BUS 1H(2H) TO XFMR E1C(E2C) BKR SW-NORM CLOSED OPEN STBY BUS 1H(2H) TO XFMR E1C(E2C) DISC SW-NORM CLOSED OPEN EMER BUS 1L(2L) TO XFMR E1C(E2C) BKR SW-EMER N/A N/A EMER BUS 1L(2L) TO XFMR E1C(E2C) BKR DISC SW-EMER N/A N/A SPLY BKR E1C(E2C)/1 CLOSED OPEN DG OUTP BKR E1C(E2C)/14 N/A N/A SPLY BKR E1C(E2C)/12 CLOSED OPEN SPLY BKR E1C(E2C)/13 CLOSED OPEN OUTP BKR E1C(E2C)/2E CLOSED OPEN OUTP BKR E1C(E2C)/2A CLOSED OPEN CROSS TIE E1C(E2C)/2C OPEN CLOSED UNIT 1 STBY XFMR UNIT 2 STBY XFMR UNIT AUX XFMR EMER XFMR 4.16 KV BUS E1C(E2C) 13(23) DG Note 1, Indicates Technical Specification related electrical lineup.
Note 2, Required per Technical Specifications, EITHER UNIT AUX XFMR OR UNIT 1 STBY XFMR OR UNIT 2 STBY XFMR SHALL be the power source for 4.16 KV Bus E1C(E2C).
AUX 1H(2H)
STBY 1H(2H)
E1C(E2C)/12 E1C(E2C)/13 E1C1(E2C1)
XFMR E1C2(E2C2)
XFMR 480VAC E1C1(E2C1)/E1C2(E2C2)
E1C1(E2C1 E1C2(E2C2)
E1C(E2C)/2A E1C(E2C)/2E E1C(E2C)/14 E1C(E2C)/1 E1C(E2C)/2C PERFORMED BY DATE TIME
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 28 of 37 ESF Power Availability Data Sheet 5 Channel I, 120 VAC and 125 VDC Vital Bus Availability Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 R3R ALT XFMR 1(2)ERV001A ALT XFMR 1(2)ERV002A 480V MCC E1A1(E2A1)
INVERTER RECTIFIER 1(2)EIV1201 480V MCC E1A2(E2A2)
BATT CHGR E1A11(E2A11)-1 BATT CHGR E1A11(E2A11)-2 125VDC BATTERY E1A11(E2A11)
BREAKER POSITION NORMAL ABNORMAL E1A2(E2A2) /A2L ON OFF E1A2(E2A2) /A5L ON OFF E1A1(E2A1) / R2L ON OFF E1A1(E2A1) / R3L ON OFF E1A1(E2A1) / Q1R ON OFF E1A1(E2A1) / R3R ON OFF E1A11(E2A11)-2 CB-1 E1A11(E2A11)-2 CB-2 E1A11(E2A11) /2A E1A11(E2A11)-1 CB-1 E1A11(E2A11)-1 CB-2 E1A11(E2A11) /3A E1A11(E2A11) /1B CLOSED OPEN E1A11(E2A11) /5D ON OFF E1A11(E2A11) /5E ON OFF 1(2)EIV1201 1 - RECTIFIER AC INPUT ON OFF 2 - BATTERY INPUT ON OFF 3 - INVERTER OUTPUT ON OFF 4 - BYPASS SOURCE AC INPUT ON OFF INVERTER SUPPLYING LOAD LIGHT ON OFF AC INPUT ON OFF AC INPUT ON OFF 1(2)EIV001 1 - AC INPUT ON OFF 2 - BATTERY INPUT ON OFF 3 - INVERTER OUTPUT ON OFF 4 - BYPASS SOURCE AC INPUT ON OFF INVERTER SUPPLYING LOAD LIGHT ON OFF DP1201 NORMAL SOURCE ON OFF DP001 NORMAL SOURCE ON OFF 125VDC SWBD E1A11(E2A11)
4 2
1 STATIC XFR SW MAN BYPASS SW 3
4 2
1 INVERTER RECTIFIER 1(2)EIV001 NORMAL SOURCE NORMAL SOURCE 120VAC DP001 120VAC DP1201
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 29 of 37 ESF Power Availability Data Sheet 6 Channel II, 120 VAC and 125 VDC Vital Bus Availability Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 STATIC XFR SW MAN BYPASS SW 3
4 480V MCC E1A4(E2A4) 480V MCC E1A1(E2A1)
BATT CHGR E1D11(E2D11)-1 BATT CHGR E1D11(E2D11)-2 125VDC BATTERY E1D11(E2D11) 125VDC SWBD E1D11(E2D11)
ALT XFMR 1(2)ERV001D INVERTER RECTIFIER 1(2)EIV1202 2
1 BREAKER POSITION NORMAL ABNORMAL E1A1(E2A1) /T3R ON OFF E1A4(E2A4)/ F3R ON OFF E1A4(E2A4) / C1L ON OFF E1A4(E2A4) / F3L ON OFF E1D11(E2D11)-2 CB-1 E1D11(E2D11)-2 CB-2 E1D11(E2D11) /3A E1D11(E2D11)-1 CB-1 E1D11(E2D11)-1 CB-2 E1D11(E2D11) /2A E1D11(E2D11) /1B CLOSED OPEN E1D11(E2D11) /3B ON OFF AC INPUT ON OFF 1(2)EIV1202 1 - RECTIFIER AC INPUT ON OFF 2 - BATTERY INPUT ON OFF 3 - INVERTER OUTPUT ON OFF 4 - BYPASS SOURCE AC INPUT ON OFF INVERTER SUPPLYING LOAD LIGHT ON OFF DP1202 NORMAL SOURCE ON OFF
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 30 of 37 ESF Power Availability Data Sheet 7 Channel III, 120 VAC and 125 VDC Vital Bus Availability Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 STATIC XFR SW MAN BYPASS SW 480V MCC E1B1(E2B1) 480V MCC E1B2(E2B2)
BATT CHGR E1B11(E2B11)-1 BATT CHGR E1B11(E2B11)-2 125VDC BATTERY E1B11(E2B11) 125VDC SWBD E1B11(E2B11)
ALT XFMR 1(2)ERV001B INVERTER RECTIFIER 1(2)EIV1203 BREAKER POSITION NORMAL ABNORMAL E1B2(E2B2) /A6R ON OFF E1B1(E2B1)/ Q2L ON OFF E1B1(E2B1) / Q1R ON OFF E1B1(E2B1) / Q2R ON OFF E1B11(E2B11)-2 CB-1 E1B11(E2B11)-2 CB-2 E1B11(E2B11) /3A E1B11(E2B11)-1 CB-1 E1B11(E2B11)-1 CB-2 E1B11(E2B11) /2A E1B11(E2B11) /1B CLOSED OPEN E1B11(E2B11) /5D ON OFF AC INPUT ON OFF 1(2)EIV1203 1 - RECTIFIER AC INPUT ON OFF 2 - BATTERY INPUT ON OFF 3 - INVERTER OUTPUT ON OFF 4 - BYPASS SOURCE AC INPUT ON OFF INVERTER SUPPLYING LOAD LIGHT ON OFF DP1203 NORMAL SOURCE ON OFF
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 31 of 37 ESF Power Availability Data Sheet 8 Channel IV, 120 VAC and 125 VDC Vital Bus Availability Page 1 of 1 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 STATIC XFR SW MAN BYPASS SW 3
4 BREAKER POSITION NORMAL ABNORMAL E1C4(E2C4) /D1R ON OFF E1C2(E2C2) /H2L ON OFF E1C2(E2C2) /H4R ON OFF E1C2(E2C2) /A4R ON OFF E1C2(E2C2) /H4L ON OFF E1C1(E2C1) /Q2R ON OFF E1C11(E2C11)-2 CB-1 E1C11(E2C11)-2 CB-2 E1C11(E2C11) /3A E1C11(E2C11)-1 CB-1 E1C11(E2C11)-1 CB-2 E1C11(E2C11) /2A E1C11(E2C11) /1B CLOSED OPEN E1C11(E2C11) /5D ON OFF E1C11(E2C11) /5E ON OFF 1(2)EIV1204 1 - RECTIFIER AC INPUT ON OFF 2 - BATTERY INPUT ON OFF 3 - INVERTER OUTPUT ON OFF 4 - BYPASS SOURCE AC INPUT ON OFF INVERTER SUPPLYING LOAD LIGHT ON OFF AC INPUT ON OFF AC INPUT ON OFF 1(2)EIV002 1 - AC INPUT ON OFF 2 - BATTERY INPUT ON OFF 3 - INVERTER OUTPUT ON OFF 4 - BYPASS SOURCE AC INPUT ON OFF INVERTER SUPPLYING LOAD LIGHT ON OFF DP1204 NORMAL SOURCE ON OFF DP002 NORMAL SOURCE ON OFF 480V MCC E1C2(E2C2) 480V MCC E1C4(E2C4) 480V MCC E1C1(E2C1)
BATT CHGR E1C11(E2C11)-1 BATT CHGR E1C11(E2C11)-2 125VDC BATTERY E1C11(E2C11) 125VDC SWBD E1C11(E2C11)
INVERTER RECTIFIER 1(2)EIV1204 ALT XFMR 1(2)ERV001C ALT XFMR 1(2)ERV002C INVERTER RECTIFIER 1(2)EIV002 STATIC XFR SW MAN BYPASS SW 3
4 2
1 NORMAL SOURCE NORMAL SOURCE 120VAC DP002 120VAC DP1204
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 32 of 37 ESF Power Availability Data Sheet 9 Bus and Charger Voltage Data Page 1 of 6 UNIT 1 (Circle Unit Performing Data Sheet)
UNIT 2 REMARKS DEVICE NUMBER DESCRIPTION REMARKS M&TE Used:
Description Range M&TE No.
Cal. Due Date
- 1. Personnel Participating in Performance of Data Sheet 9.
Personnel Date Time
- 2. Data Sheet 9, Bus and Charger Voltage Data Completed By:
Operator Date Time
- 3. Data Sheet 9, Bus and Charger Voltage Data, Bus and Charger Voltage Data Reviewed By:
Unit Supervisor Date Time
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 33 of 37 ESF Power Availability Data Sheet 9 Bus and Charger Voltage Data Page 2 of 6
- 1. IF this surveillance is being performed to satisfy the requirements of Technical Specification 3.8.1.1 ACTION Items a, b, c, or f, THEN ONLY those readings indicated with an asterisk (*) are required to be completed. Tables 2 thru 5 need NOT be retained when performing this surveillance to satisfy the requirements of Technical Specification 3.8.1.1 ACTION Items a, b, c, or f. (Reference 8.2)
- 2. IF any voltage readings are NOT within Satisfactory Range, THEN immediately NOTIFY the Unit Supervisor or Shift Manager. (References 8.6 and 8.7)
- 3. Determines the availability of the 138 KV Emergency Transformer for possible use during a Loss of Offsite Power. (3) This meets commitments made for the SDG, ECW and Essential Chilled Water Technical Specification Change. (Reference 8.12).
- 4. WHEN recording Auxiliary and Standby Bus voltages, THEN voltage indication on CP010 is preferred.
- 5. Voltages on all three phases of each bus SHOULD be verified. Voltage disparity between all three phases can indicate a degraded transducer, meter, selector switch, or an actual power distribution fault.
Table 1. 13.8 KV Bus Voltage Data BUS/CHARGER (LOCATION)
RECORDED TEST VALUE SATISFACTORY RANGE INITIAL
- Aux Bus 1F(2F)
(4) (5) (CP010 or Local Voltmeter)
________ KV 12.8 - 14.5 KV
- Stby Bus 1F(2F)
(4) (5) (CP010 or Local Voltmeter)
________ KV 12.8 - 14.5 KV
- Aux Bus 1G(2G)
(4) (5) (CP010 or Local Voltmeter)
________ KV 12.8 - 14.5 KV
- Stby Bus 1G(2G)
(4) (5) (CP010 or Local Voltmeter)
________ KV 12.8 - 14.5 KV
- Aux Bus 1H(2H)
(4) (5) (CP010 or Local Voltmeter)
________ KV 12.8 - 14.5 KV
- Stby Bus 1H(2H)
(4) (5) (CP010 or Local Voltmeter)
________ KV 12.8 - 14.5 KV (3) (5) Emer Bus 1L(2L)
(CP010)
________ KV 12.8 - 14.5 KV (5)
- 4.16 KV Bus E1A(E2A) (CP003)
________ KV 3.92 - 4.4 KV (5)
- 4.16 KV Bus E1B(E2B) (CP003)
________ KV 3.92 - 4.4 KV (5)
- 4.16 KV Bus E1C(E2C) (CP003)
________ KV 3.92 - 4.4 KV
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 34 of 37 ESF Power Availability Data Sheet 9 Bus and Charger Voltage Data Page 3 of 6
- 1. Electricians assist by measuring the battery charge current at the battery field cable and total battery terminal voltage.
- 2. IF Battery Chargers are on equalize charge per 0PMP05-DJ-0010, THEN Electricians or MOST PLACE battery chargers on FLOAT charge prior to readings and log time off of equalize charge in 0PMP05-DJ-0010. WHEN readings are complete, THEN return Battery Chargers to equalize and log time on in 0PMP05-DJ-0010.
- 3. IF any voltage readings are NOT within Satisfactory Range, THEN immediately NOTIFY the Unit Supervisor or Shift Manager. (References 8.6 and 8.7)
Table 2. Channel I Bus and Charger Voltage Data BUS/CHARGER (LOCATION)
RECORDED TEST VALUE SATISFACTORY RANGE INITIAL 480 V LC E1A1(E2A1)
(EAB 10' Swgr Rm)
________VAC 443 - 507 VAC 480 V LC E1A2(E2A2)
(EAB 10' Swgr Rm)
________VAC 443 - 507 VAC Charger E1A11-1(E2A11-1)
(EAB 10', Rm 007)
________VDC 128.5 - 131.6 VDC Charger E1A11-2(E2A11-2)
(EAB 10', Rm 007)
________VDC 128.5 - 131.6 VDC DC SWITCHBOARD E1A11(E2A11)
(EAB 10', Rm 007)
________ VDC 128.5 - 131.6 VDC Battery E1A11(E2A11)
Charge Current at the Battery Field Cable (EAB 10', Rm 008)
________ AMPS (1)
< 2 AMPS Battery E1A11(E2A11)
Total Battery Terminal Voltage (EAB 10', Rm 008)
________ VDC (1)
> 128.03 VDC Vital AC Panel DP001 (EAB 10', Rm 007)
________ VAC 117 - 122 VAC Vital AC Panel DP1201 (EAB 10', Rm 007)
________ VAC 115 - 125 VAC
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 35 of 37 ESF Power Availability Data Sheet 9 Bus and Charger Voltage Data Page 4 of 6
- 1. Electricians assist by measuring the battery charge current at the battery field cable and total battery terminal voltage.
- 2. IF Battery Chargers are on equalize charge per 0PMP05-DJ-0010, THEN Electricians or MOST PLACE battery chargers on FLOAT charge prior to readings and log time off of equalize charge in 0PMP05-DJ-0010. WHEN readings are complete, THEN return Battery Chargers to equalize and log time on in 0PMP05-DJ-0010.
- 3. IF any voltage readings are NOT within Satisfactory Range, THEN immediately NOTIFY the Unit Supervisor or Shift Manager. (References 8.6 and 8.7)
Table 3. Channel II Bus and Charger Voltage Data BUS/CHARGER (LOCATION)
RECORDED TEST VALUE SATISFACTORY RANGE INITIAL Charger E1D11-1(E2D11-1)
(EAB 10', Rm 009)
________ VDC 128.5 - 131.6 VDC Charger E1D11-2(E2D11-2)
(EAB 10', Rm 009)
________ VDC 128.5 - 131.6 VDC DC SWITCHBOARD E1D11(E2D11)
(EAB 10', Rm 009)
________ VDC 128.5 - 131.6 VDC Battery E1D11(E2D11)
Charge Current at the Battery Field Cable (EAB 10', Rm 006)
________ AMPS (1)
< 2 AMPS Battery E1D11(E2D11)
Total Battery Terminal Voltage (EAB 10', Rm 006)
________ VDC (1)
> 128.03 VDC Vital AC Panel DP1202 (EAB 10', Rm 009)
________ VAC 115 - 125 VAC
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 36 of 37 ESF Power Availability Data Sheet 9 Bus and Charger Voltage Data Page 5 of 6
- 1. Electricians assist by measuring the battery charge current at the battery field cable and total battery terminal voltage.
- 2. IF Battery Chargers are on equalize charge per 0PMP05-DJ-0010, THEN Electricians or MOST PLACE battery chargers on FLOAT charge prior to readings and log time off of equalize charge in 0PMP05-DJ-0010. WHEN readings are complete, THEN return Battery Chargers to equalize and log time on in 0PMP05-DJ-0010.
- 3. IF any voltage readings are NOT within Satisfactory Range, THEN immediately NOTIFY the Unit Supervisor or Shift Manager. (References 8.6 and 8.7)
Table 4. Channel III Bus and Charger Voltage Data BUS/CHARGER (LOCATION)
RECORDED TEST VALUE SATISFACTORY RANGE INITIAL 480 V LC E1B1(E2B1)
(EAB 35', Swgr Rm)
________ VAC 443 - 507 VAC 480 V LC E1B2(E2B2)
(EAB 35', Swgr Rm)
________ VAC 443 - 507 VAC Charger E1B11-1(E2B11-1)
(EAB 35', Rm 213)
________ VDC 128.5 - 131.6 VDC Charger E1B11-2(E2B11-2)
(EAB 35', Rm 213)
________ VDC 128.5 - 131.6 VDC DC SWITCHBOARD E1B11(E2B11)
(EAB 35', Rm 213)
________ VDC 128.5 - 131.6 VDC Battery E1B11(E2B11)
Charge Current at the Battery Field Cable (EAB 35', Rm 214)
________ AMPS (1)
< 2 AMPS Battery E1B11(E2B11)
Total Battery Terminal Voltage (EAB 35', Rm 214)
________ VDC (1)
> 128.03 VDC Vital AC Panel DP1203 (EAB 35', Rm 213)
________ VAC 115 - 125 VAC
This procedure, when complete, SHALL be retained for five years.
0PSP03-EA-0002 Rev. 41 Page 37 of 37 ESF Power Availability Data Sheet 9 Bus and Charger Voltage Data Page 6 of 6
- 1. Electricians assist by measuring the battery charge current at the battery field cable and total battery terminal voltage.
- 2. IF Battery Chargers are on equalize charge per 0PMP05-DJ-0010, THEN Electricians or MOST PLACE battery chargers on FLOAT charge prior to readings and log time off of equalize charge in 0PMP05-DJ-0010. WHEN readings are complete, THEN return Battery Chargers to equalize and log time on in 0PMP05-DJ-0010.
- 3. IF any voltage readings are NOT within Satisfactory Range, THEN immediately NOTIFY the Unit Supervisor or Shift Manager. (References 8.6 and 8.7)
Table 5. Channel IV Bus and Charger Voltage Data BUS/CHARGER (LOCATION)
RECORDED TEST VALUE SATISFACTORY RANGE INITIAL 480 V LC E1C1(E2C1)
(EAB 60' Swgr Rm)
________ VAC 443 - 507 VAC 480 V LC E1C2(E2C2)
(EAB 60' Swgr Rm)
________ VAC 443 - 507 VAC Charger E1C11-1(E2C11-1)
(EAB 60', Rm 319)
________ VDC 128.5 - 131.6 VDC Charger E1C11-2(E2C11-2)
(EAB 60', Rm 319)
________ VDC 128.5 - 131.6 VDC DC SWITCHBOARD E1C11(E2C11)
(EAB 60', Rm 319)
________ VDC 128.5 - 131.6 VDC Battery E1C11(E2C11)
Charge Current at the Battery Field Cable (EAB 60', Rm 321)
________ AMPS (1)
< 2 AMPS Battery E1C11(E2C11)
Total Battery Terminal Voltage (EAB 60', Rm 321)
________ VDC (1)
> 128.03 VDC Vital AC Panel DP002 (EAB 60', Rm 319)
________ VAC 117 - 122 VAC Vital AC Panel DP1204 (EAB 60', Rm 319)
________ VAC 115 - 125 VAC
__________