ML20217B059
| ML20217B059 | |
| Person / Time | |
|---|---|
| Site: | Quad Cities  |
| Issue date: | 03/01/1991 |
| From: | Kovach T COMMONWEALTH EDISON CO. |
| To: | Lieberman J NRC OFFICE OF ENFORCEMENT (OE), NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM) |
| References | |
| NUDOCS 9103080280 | |
| Download: ML20217B059 (110) | |
Text
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) Common;ealth EdMn 6 1400 Opur Placa '
/. Downers Grove, Ulinois 60515 o
March 1, 1991 Mr. J.-Lieberman, Director Office of Enforcement U.S. Nuclear Regulatory Commission Nashir; ton, D.C.
20555 Attn: Document Control Desk
Subject:
Quad Cities Nuclear Power Station Unit 2 Notice of Violation and Proposea Imposition of Civil Penalty RRCAckeLEumoer_50:265
References:
(a) A.B. Davis to Cordell Reed letter dated January 30, 1991.
(b) H.J. Millei to Cordell Reed letter dated November 21, 1990.
(c) H.J. Miller to Cordell Reed letter dated December 18, 1990.
Mr-Lieberman:
This letter provides Commonwealth Edison Company's response to the Notice of Violation and Proposed Imposition of Civil Penalty, as transmitted in reference (a).
An Enforcement Conference was held on December 7, 1990 to discuss the results of the NRC's Inspection of the October 27, 1990 Intermediate Range Monitor (IRM) lligh Neutron Flux automatic unit shutdown which were transmitted in ref6rence (b).
Commonwealth Edison acknowledges the procedural violations as stated in the Notice of Violation contained in reference (a). Attachment A to this letter contains the corrective actions associated with the specific violations cited. Additional corrective actions in response to identified weakreesses were provided during the December 7, 1990 Enforcement Conference.
Attachment B contains the response to the issues discussed as potential violations in the NRC Inspection Report'(reference (b)), as requested in reference (a),
in addition, Attachment C provides information discussed during the Enforcement Conference regarding the number of hot standby operations occurrences that were.stmilar to that on October 26, 1990.
' Commonwealth Edison immediately recognized the significance of the October 27, 1990 automatic unit shutdown and quickly cm ducted both a station and corporate investigation to determine the causes of the event.
These investigations identified various weaknesses which included procedural adherence, operating shift communications, turnover of information between crew members, and management oversight and direction. Our corrective actions
-were focussed on the identified weaknesses of this event and we belleyed they were_ comprehensive in nature.
M
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i M. J. Lieberman March 1, 1991 1
l Since the Decemoer 7, 1990 Enforcement Conference, Commonwealth Edison has reviewed the October 27, 1990 automatic unit shutdown in conjunction with other Quad Cities events including a loss of reac+or coolant inventory event which occurred while Unit I was shutdown on January 24, 1991.
This retrospective review, which was prompted by the January 24, 1991 event, revealed the need to address broader root causes.
As a result, we have conducted a thorougt review of our management programs to identify if additional, more conprehensive corrective actions should be taken.
Commonwealth Edison presented the corrective actions to address these broader root causes during he February 21, 1991 Enforcement Conference.
That Enforcement Confere c e was in response to the Januar3 24, 1991 loss of reactor coolant inventory event. He believe that these corrective actions, in addition to those presented at the December 7, 1990 Conference, will enhance the overall operation of the plant as well as provide reasonable assurance that these types of events will not occur.
Quad Cities Station Management recognizes the need for effective management involvement in all aspects of plant operation.
As a result, aggressive and comprehensive actions are being implemented.
Quad Cities Station has recently implemented a " Heightened Level of Awareness (HLA)
Program" which utilizes the Braidwood Station HLA Program elements and alters the program to meet Quad Cities Station-specific needs. Various programs are also underway to effectively communicate expectations by Station management and to ensure those expectations are reinforced and effective in achievlag error-free operation throughout the plant organization.
In accordance with 10 CFR 2.205, enclosed is the payment of $50,000 in response to the imposed civil penalty.
If there are any questions or comments regarding this response, please contact Ms. R. Stols at (708) 515-7283.
Very truly yours, v
/
. I'
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T.J.bvach Neclear Licensing Manager cc:
A.B. Davis, Regional Administrator - RIII L.H. Olshan, Project Manager - NRR T.E. Taylor, Senior Resident inspector - Quad Cities RS/TK/Imw int.M 4 4 /19
1
' AUACHMEMLA RESPONM..TO NOTICE Of VI0l.ATION j
NRC INSPECTION REPORT' 50-265/90024 Etolaiton i
Quad Cities Nuclear Station Technical Specification.Section 6.2.A.1 requires in part, that detailed wr1+. ten procedures coverirg start-up, operation, and shutdown of the reactor, and other systems and components involving nuclear safety of the facility shall be prepared and adhered to.
1.
Temporary Procedure (TP) 6_303, " Shutdown from Power Operations to a
-Standby Not Pressurized Condition," stipulated the procedures for taking the _ uni.t from a power generation mode to a hot standby condition following a turbine torsional test.
~
Contrary to the above, on October-27, 1990, following an attempted turbine torsional test the Nuclear Station Operator-(NS0) failed to utilize th_e procedures specified in TP 6303 for taking the unit from a power generation mode to a-hot standby condition.
2.
Quad Cities Station Administrative Procedure (QAP), " Conduct of Shift Operations," QAP 300-2, Section C.13.j, requires that briefings be conducted by cognizant personnel for individuals involved in an evolution that is to be performed and Section C.28.c-of procedure-QAP 300-2 requires the Shift Control. Room Engineer-(SCRE) to be responsible for control room activities to assure safe plant operation.
Contrary to:the-above, on October 27, 1990, an inadequate shift briefing was conducted by the test director and shift engineer _for the third shift activities in that shift personnel were not briefed on the status of TP-.6303 and:the SCRE failed to supervise' control room activities by maintaining cognizant of the status of Unit 2 reactor operation in that he was unaware that the Nuclear Station Operator (NS0) had made the reactor.subcritical in the source range by control rod insertion.
3.
_QAP 300-1, " Operations Department Organization," Section C.10.q.5, requires in part that the NSO initlate " holds" during plant evolutions to ensure that an~ evolution does not threaten the stability of the Unit. QAP 300-1, Section C.10.p also requires-the NSO he alert and capable of performing his assigned duties in a professional manner at-all times.
Contrary =to the above, on October 27, 1990, the NSO failed to initiate a
'hol_d itquired to ensure Unit stability associated with the Electro-Hydraulic Control system restoration when reactor power was subtritical in the source range (100 cps).
A hold was required to facilitate a
_ controlled approach _to criticality. Additionally, the NSO failed to remain alert to control panel indications by failing to adequately monitor nuclear instrumentation during control rod withdrawal which resulted'in rapidly increasing power and a subsequent reactor scram.
ENLD7 44 /20
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4.
' Quad Cities Operatioas Procedure (QOP) 700-1, " Source Range Monitor Operation," Section F.2.a. requires that the source range monttor (SRM) detectors be-inserted as " range 4" is-approached on the Intermediate Range Monitors (IRM).
Contrary to the above, on October 27, 1990, the NSO failed in insert th~e SRMs as " range 4" was approached on the IRMs but waited until " range 1" of the IRMs was reached.
5.
00P 700-2, " Intermediate Range Monttor Operation," Section F.3.g, requires the NSO to decrease the IRM ranges as necessary to maintain between 20/125 and 50/125 of full scale.
Contrary to the above, on October 27, 1990, the NSO failed to decrease the IRM ranges as necessary to maintain 20/125 and 50/125 of full scale.
Response
Commonwealth Edison acknowledges the violation stated above.
The violation involved-the failure of the Operating crew to adhere to various administrative and operating procedures during the operation of the unit in hot standby which resulted in automatic unit shutdown.
Commonwealth Edison's review of the event determined that from the standpoint of the health and safety of the public, the event had minimal safety significance. Commonwealth Edison, however, views this event as significant due to the demonstrated performance. weaknesses by individuals and narrowly focussed management expectations.
-As indicated in the cover letter, Commonwealth Edison has conducted a retrospective review of recent events which have occurred at Quad Cities Station.
This review included both the October 27, 1990 automatic unit shddown and the January 24 -1991 loss of reactor coolant inventory events.
The review revealed the-need to address broader root causes.
The corrective actions which were developed following this comprehensive review are applicable to this specific violction, and are included in the discussion below. Corrective-actions which were developed following the December 7, 1990 Enforcement Confe;qnce are designated by an asterisk (*).
Corre.tthelttions_Iaken -
1.
An in-depth discussion was conducted with the members of the crew-involved in the event.
The discussion included members of upper Station Management, the Chief Nuclear Engineer and BHR Operations General Manager.
This was completed on October 28, 1990.
2, Prior-to assuming their shift duties, each operating crew was briefed on this event by upper station management.
During these briefings, the need for effective communications and the Shift Control Room Engineer (SCRE) oversight function _were stressed.
This item is cog iete.
Cotte ctlyelcitons_tolvpld_Eur_t h e r3J ola t ion 1.
The Quad :lties Operating Shif t Organization has been revised to add an SRO as an assistant to the SCRE during non-outage periods.
This augmentation of the shift organization will provide more effective oversight of unit operation by the SCRE. During outages, additonal augmentation of the control room organization is provided with an Outage Unit SRO.
The revised organization was implemented on February 1, 1991 (*).
SNLD744/21
i 2.
Shift briefings are conducted outside of the Control room and personnel are required to report to work one-half hour early for the briefing.
This action will ensure more effective shift briefings and discussion by crew members.
This action was implemented on February 20, 1991 (*).
3.
Quad Cities has developed a Heightened Level of Awareness (HLA) Program which identifies activities for which special briefings of all individuals prior to the start of the activity are required.
This program will provide for effective management oversight, implementation of the HLA Program was completed on February 22, 1991 (*).
4.
Operating Engineers Overview Guidelines for Control Room activities were implemented on February 15, 1991.
This program requires that Operating Engineers perform a structured overview of Control Room activities on at least a daily basis (*).
5.
The Nucleer Station Operator (NS0) who was involved in this event is currently off shift and has completed a remediation plan.
Management is assessing the NS0's performance during the course of the remediation plan in order to determine when he may be returned to NSO duties.
The primary focus of this remediation plan was a heightened awareness of attention to detail and understanding of reactor operations.
6.
The crew involved in this event received remedial training on operating the unit in hot standby.
The training consisted of classroom and simulator training.
Discussion topics included teamwork, communications and procedural compliance.
This was completed on October 31, 1990.
Augmented management overview was provided for the involved crew in the interim period prior to receiving training.
7.
A station committee (which incluocs a c.coss-sectior. of management and union employees) has been formed to ieview and evaiuate the issue of procedure usage. An action plan, based on this committee's results has been developed and implemented on February 28, 1991.
Part of this p'an will be a method to evaluate its effectiveness.
8.
An independent overview of the shift activities has been conducted by an experienced shift supervisor from LaSalle Statio1, The report of his observations has been reviewed by operations management. On February 14, 199! an action plan was implemented to enhance shift operations, 9.
A number of changes have been implemented to enhance the professional atmosphere in daily activities.
Quite time policy Reduction in nuisance calls to the SCRE and SE Ccmmunication control during surveillance tests Transfer of additional responsibilities to Shift Foreman from SE and SCRE This was completed on November 17, 1990.
l 10.
Standards for control room communications have been issued as an Operating Department policy document on January 30, 1991.
2HLDf41/h
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11.
Proceduralization of the turnover checklists for the NS0s and Shift Engineers (SE) has been accomplished to improve shift to shift communications.
Procedure revisions were approved on January 24, 1991.
12.
Procedure QTP 010-4, " Preparation, Performance and Revt?w of Special Operational Tests", has been revised to ensure the following are adequately addressed:
a.
identification of line of command and specific responsibilities if other than the normal shift operating organization is involved, b.
review of procedures to be used to enter and exit test conditions, c.
the need for special training or crew briefings, d.
special shift turnover requirements if the test will take more than one shift, and e.
requirements for procedure validation a: specified in QCAP 1100-4.
This was completed on January 24, 1991.
13.
A committee of operators and operating management will be formed to discuss enhanced expectations for plant operations.
This committee will be chaired by the Assistant Superintendent of Operating.
A report on recommendations will be issued by August 1, 1991 which will:
a.
clarify existing expectations for each operating position b.
further delineate command and control functions for the control room c.
evaluate log keeping requirements for enhancements / clarifications d.
evaluate shift briefing requirements for enhancements / clarifications As an interim measure, a letter was issued summarizing operating department management expectations for plant operations.
This was completed on December 12, 1990. Also, Itcensed operators reviewed the expectations for their positions as contained in administrative procedures.
This was completed on December 15, 1990.
EliLD744/D
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a ADACHMCKLB RESPONSE TO OTHER NRC ISSUES 1.
Cottentive Actions._By_the_Shtf.LL0perating_ Engineer Apparent _ Vin 11 tion The failure by the operating engineer (Test Director) to take adequate corrective action for the procedural deficiency identified concerning step 38b of temporary pmcedure 6303 during Shif t 1 1s. an apparent violation of 10 CFR Appendix B Criterion XVI, Corrective Action (265/90020-01)
Re.sponte Quad Cities. Station procedure QAP 300-2 Section C.13.bt5) provides the following guidance relative to performing procedures:
If the individual ac!Ually performing the activity cannot or believes he/she should not follow the procedure governing that activity as written, he/she shall place the system / component into a stable and safe condition and inform the responsible supervisor.
Situations such as this could occur if the procedure is found to be inadequate for the intended task, if unexpected results occur, or if two or more procedures governing the' activity confitet.
The supervisor shall resolve the discrepancy in the protec'ure by either:
.(a) determining the. methods by which the activity can be performed using the. procedure as writton and conveying this to the individual performing the activity, or (b) submitting a procedure change, either tempm ary or permanent,
' depending on the actual situation.
(No further procedural steps shall be accornplished until the procedure change-ts approved).
The addition of the note to Step 38b of the hot standby procedure TP 6303-was procedurally acceptable in that it was an attempt to explain completion of the step and not an attempt to change the intent of the step.
A review showed that our guidance on resolving procedural discrepancies-was not sufficiently comprehensive.
Clarification of an activity for personnel as allowed by (a) above did not recognize the potential need for
- that clarification to be documented for future use by other operators.
Notwithstanding-the-allowable actions taken by the Operating Engineer, Commonwealth Edison recognizes the need to minimize and control interpretations-of procedures without temporary or permanent procedure changes.
The policy on resolving procedural discrepancies'will be reviewed and appropriate changes made, including direction on the documentation of procedural step clarifications.
The review and procedure changes were completed on February 28. 1991.
ENLD744/24
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~ 2.
Adeguacy_oLHo.tltandby_frocedur.e.
AppatenLY1olation The inadequacy of the procedure in effect for the Hot Standby (HSB) evolution is an apparent violation of 10 CFR 50 Appendix B, Criterion V.
Response
Procedures r>present management's expectations and provide direction on how to perform activities.
Procedure QGP 2-4 " Shutdown From Power Operation To A Standby Hot Pressurized Condition" has been used successfully on several prior occasions and is not-considered inadequate.
However, our review-of_the procedure, in light of.this events, leads us to conclude that the procedure contains several ambiguous steps.
j Procedure QGP 2-4 will be revised to meet current station procedure upgrade program requirements by April 1, 1991.
In the interim, a temporary procedure _ change to QGP 2-4 has been issued to incorporate the
. lessons learned from this event.
The interim procedure revision was approved on January 31, 1991.
The Procedure Upgrade Program prioritization for Operating Procedures
_ has been reviewea to determine if-schedular modifications should be-implemented.- Operating procedures have been prioritized and the completion of operating procedure upgrades is anticipated by 1993.
1 i
s ZHLD144/25
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3.
Opettting_Inglater3 00_ Motif.lcation3 f__the_0n-Juty_Muclear_Eng!neer Anparentliolation 0AP 200-4 " Operating Engineer's" Secticn C.H,5 requires the operating engineer to notify the Nuclear Engineering group of all planned reactivity changes, such as startup, shutdown and major power changes to obtain i
recommendations for any special operating consideration.
The operating engineer as test director failed to identify to the on duty nuclear engineer that the reactor would be taken to a speciel hot standby condition with planned reactivity changes during which his recommendation and overview could be needed (265/90020-3a).
This is an apparent violation of Technical Specification, section 6.2.A.I for operation activities.
Bespons_e 1
Procedure QAP 200-4 Section C.6.h(5) requires that the Nuclear Engineering Group be nottfled of all planned reactivity changes, such as startup, shutdown, and major power changes.
The Nuclear Engineering Group was involved in test planning and therefore, was aware that several reactor status changes would occur.
The Lead Nuclear Engineer defined their involvement.
There was no requirement to again notify the on-duty nuclear engineer or have-him present during attempt to reach hot standby.
However, a nuclear engineer was on-shift for Intermediate Range / Average Power Range Monitor Overlap verification, and was aware of the planned 1
return to hot standby.
The OE complied with the procedural requirements.
An in-depth review of the procedure showed that the guidance provided was not sufficient in that, while the nuclear engineering group was l-notified of reactivity changes, nuclear engineer support was not required for some conditions, such as operating in a hot standby condition.
The requirement for qualified nuclear engineer (QNE) support in the control-room has been revised to require a QNE to be present whenever t-control rod manipulations are required with reactor power below 15%-
(except for control rod surveillances) and to support major rod manipulations above 15%.
A procedure change has been implemented on
~
January 31, 1991.
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ZtiLD744/26
.. - 4.
Logging _of_. Abnormal _Lvints Apparent _Y1alation QAP 300-10 Section C.4.g requires that abnormal conditions encountered shall be logged, including action, suspected cause, and any subsequent-troubleshooting results.
The hot notch condition occurring on the first i
shift for rod step 8-10 on rod G7, which required two-up-ranging on the-IRM, did not get logged.
The worth of the rod was unexpected.
The third
~ shift was not informed nor was the nuclear engineer informed of the hot notch occurrence (265/90020-030).
This is an apparent violation of-Technical Specification section 6.2.A.1 for operation activities.
Rtsponsa Hhile controlling reactor. power / pressure to allow Electro-Hydraulic j
Control (EHC) Pumps to be taken off, Control Rod G-7 was withdrawn from i
Position 08 to 10.
The Intermediate Range Monitors _ responded and required 1
ranging from about range 5 to range 7 over a time period of.a couple of minutes.
This notch worth was greater than average; however, it was not 1
unexpected because:
(1) Rod G-7 was near the core center, (2) notches 08 to 12 are always the highest worth, and (3) xenon conditions were rapidly changing.
Since this was not an abnormal condition, it was not logged by j
the crew.
This eve : was discussed during the shift relief since the next i
shift would be nottning out rods from this same rod pattern, in these conditions.
A review cf our guidance found that it was not sufficiently comprehensive.
Conditions encountered during the. shift, that in the judgement of the operator did not meet the threshold of " abnormal", were often verbally communicated to the next shift but not logged.
The rod worth encountered is an example. Given this, there was not assurance that this.information-would have-been passed on to subsequent shifts.
A committee of operators and operating management has been formed to discuss' enhanced expectations for plant operations.
An evaluation of log keeping requirements will be' addressed as part of that committee.
Committee recommendations are to be developed by August 1, 1991.
t 2NLD744/27
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ATTACHMENT C HISTORICAL OVERVIEH OF HOT STANDBY OPERATION At the December 7, 1990 Enforcement Conference, Commonwealth Edison stated that Quad Cities Station had operated in a similar plant condition (to that on October 27, 1990) on at least six separate occasions.
At the conference, the NRC staff requested that Commonwealth Edison provide the Staff with the procedures to demonstrate the operating condition.
Copies of procedure QGP 2-4 " Shutdown from Power Operation to a Standby Hot Pressurized Condition" were provided to the Senior Resident Inspector.
Subsequently, the NRC Staff issued a sumnary of the Enforcement Conference in reference (c).
In the reference (c) letter, the Staff stated, " Review of the information submitted identified that for the six HSB operations, three apparently did not involve operation with bypass valves closed.
the licensee's evaluation of the six previous entries into HSB operation was inaccurate." This issue was further discussed with the Senior Resident Inspector and additional information was provided to substantiate our position.
Attached is a summary of the hot standby occurrences and the supporting documentation which substantiates our position.
S 6
J SlM MRY OF HOT STAND 8Y OPERATIOM SIMILAR TO OCTOBER 27, 1990 s
January 3, 1988 1?GP:2-4 was initiated on Unit 1 to accommodate repairs of a Electro-hydraulic Control (EHC) oil lead on the turbine front -tandard. As indicated in the operating log, at 0430 all the turbine bypass valves were closed, reactor pressure was controlled through manipulation of control rods.
April 8, 1988 QGP 2-4 was initiated on Unit I to eccommodate the repair of an EHC oil
. leak on the #3 turbine control velve. As indicated in the operating logs, at
- 0455 the turbine bypass valves were closed and at 0530, the EHC pumps were secured.
_ At 1505,.the_reactorJstartup was terminated and QGP 2-4 was again initiated in-order to replace the #3 turbine control valve position. At 1950, the EHC pumps were secured and reactor-pressure was controlled through the manipulation of control rods.
'May 30, 1988 QGP 2-4 (as modified by Temporary Procedure Change 5503) was initiated on Unit 1-to replace the. fast acting solenoid valve on the #4 turbine control valve, At 0930, the EHC pumps were secured and reactor pressure was
- maintained between 800-850 psig.
May 7, 1989
' QGPL2-4 was initiated on Unit I to replace the EGC electrical boards.
At 0732, the EHC pumps _were secured and reactor pressure was maintained at approximately 840 psig.
September 28, 1990 QGP 2-4 was initiated on Unit 2' to per form the turbine torsional test.
At 1025, the EHC pumps were-secured and reactor pressure was maintained between 850-900 psig.
tNLD744/29 e
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3anuary 1987 SHUTDCWN FDCH DCWER OPERATION TO A STANDBY HOT DRESSURIZE0 CON 0! TION a.
oudCSE The :ur:ose of tnis crocedure Is to outline the metnoe usec to snu Mown tne unit from a power-generation moce to a concitten of low cover.itn tne reactor pressure vessel pressurtzed anc the MSIV's eitner CLOSE0 or OPEN.
3, REFERENCES 1.
QOP 56701, EGC Settings.
2.
CCP 202-3, React 0r Recirculation System Flow Controller Coeration.
3.
QOP 600-B, Removing One of two Feedwater Regulator Valves frem Service.
4.
GOP 3200-5, Reactor Feed Putro Shutcown.
5.
QCP 700-2, Intermediate Range Monitoring Operation (IRM).
6.
QOS 700 Block.
7.
QOP 600-5, Removing tne Main Feedwater Regulator from Service.
8.
QOP 700-1, Source Range Monitoring Ooeration (SRM).
9.
GCP 5400-8, Starting Sparge Air to the Recombiner.
- 10. GCP 5400-5, Glycol System Shutdown.
11.
CCP 5400-9, Isolating Sparge Air to the Recomoiner.
- 12. 00P 5600-1, Gland Seal System, i3. QGP 4-1, Control Rod Movements and Control Rod Sequences.
14.
QCP 207-2, Declaring Rod Wortn Minimizor C:mouter Incoerable.
C.
DRERECUISITES 1.
Permission has eeen obtaineo from the Load Olscatcher to snutcoun the unit.
The Rod Worth Minimi.er is coerational/or a qualified person is 2.
?
dvallable to verify rod movements in accordance with the red sequence chosen prior to reactor power reaching 20'f.
The RWH may only be bypassed by using QOP 207-2.
A p p n y,. g 1/0023h
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OGP 2 4 Revision 13
- 3. -
If this procedure is terminated at any time during its execution.
insert a statement at the point of termination as to reason and the title of subsequent procedure.
Insert N/A in all remaining blanks, date, time and sign last page.
Retain terminated procedure in startup package.
4.
Perform MISV Closure Monthly Scram Sensor Functional Test, 005 250-1.
a.
If no work 15 to be performed in the MSIV room or drywell.
this prerequisite may be bypassed if a Operating Engineer. B w L h m. w)izej cy anI W s
00 Engr.
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Date D.
PROCEDURE Init+al 1.
If the reactor rectreulation flow controller is in EGC or MASTER-AUTO mode, place the controller in the MASTER-MANUAL. mode.
M 2.
Reduce power with tne master recirculation flow controller and oeserve the following:
NA h.
'a.
Power reduction rate shall be in accordance with the most recent operating recommendations under NORMAL and emergency coneltions.
b.
Continuously monitor-power decrease on APRM's, c.
Maintain Load Set 10% above generator load.
d.
On 901-5 (902-5), maintain the EGC settings in accordance with QOP 5670-1.
e.
Continue to reduce recirculation flow until the Master controller reacnes minimum scoed (a5%), then olace the recirculation flow controllers in the LOCAL-MANUAt. mode in accoroance with QOP 202-3.
f.
Con,tinue reducing recirculation flow to 38% oump speed.
Maintain the recirculation europs at equal. speeds.
3.
As condensate domineralizer differential pressure approaches =15 osid,-tsolate units one at a time to maintain greater than 150 gom flow through the domineralizers.
4 Commence. Inserting control rods in accordance with QGP 4-1 until the TURB PRESS GEN LOAD REJ STM VLV SYPASS alarm first annunciates (aseroximately 42% power),
Then reo' ace recirculation flow to minimum witn the potentiometer on tne Retirc' Pump Sceed Controllers.
Continue to insert control rods.
[Yes APPRU',c.C 1/0023h VAC191957 0 C. o. 5 A
OCP 8 4 Reetston 13 3.
If this procedure is terminated at any time during its execution.
insert a statement at the point of termination as to reason and the title of subsequent procedure.
Insert N/A in all remaining blanks,
-date, time and sign last page.
Retain terminated procedure in startup package.
i 4.
Perform MISV Closure Monthly Scram Sensor Functional Test, 005 250 a.
If no work is to be performed in the MSIV room or drywell.
thisprerequisitemaybebypassedifapQogizejbyan Operating Engineer.
B we L MM __,
/- 2 -W 09 Engr.
M'
\\
Oate D.
PROCEDURE Initial 1.
If the reactor recirculation flow controller is in EGC or MASTER-AUTO mode, place the controller in the MASTER-MANUAL mode.
OM 2.
Reduce power ~with the master recirculation flow controller and observe the following:
NA
.n.
a.
Power reduction rate snall be in accordance with the nest recent operating recommendations under NORMAL and emergency conditions, b,
Continuously monitor power decrease on APRM's.
c.
_ Maintain Load Set 10% above generator load, d.
On 901 5 (902-5), maintain the EGC settings in accordance wttn QOP 5670-1.
e.
Continue to reduce rectrculation flow until the Master controller reaches minimum speed (a5%), then place the recirculation flow controllers in the LOCAL-MANUAL mode in accordance with QOP 202-3.
f.
Continue reducing recirculation flow to 38% pump speed.
Maintain the racirculation pumps at equal speeds.
3.
As condensate domineraliter-differential pressure approaches 15 osid, isolate units one at a time to maintain greater than 150 gom flow through the domineralizers.
4 Commence inserting control rods in accordance with QGP 4-1 until the TUR8 PRESS GEN LOAD REJ STM VLV BYPASS alarm first annunciates (accroximately 42% power).
Then reduce recirculation flow to minimum with the potentiometer on the Rectre Pump Sosed controllers.
Continue to insert control rods.
h5 APPRU',c.C 1/0023h
-2
.g Q C.O 5 R
-~,cs-:.s v
a,3,3 p p
5; At 40% reactor power, CLOSE-the feedwater regulator'that A
His in MANUAL-in'accordance vith QOP 600-8.
fM NOTE
,z If feedwater Instabilities octur use the second feedwater regulator valve to return the feedwater system to a stable state, 6.
At approximately 4 x 106 lbs/hr feedwater flow and 150 L
amps on the condensate pumos, STOP a reactor feedwater f-pump in accordance with QOP 3200-5 and then STOP a condensate pump as follows:
/34d a..
Verify that reactor feed pump suction pressure is greater : nan
.350.psig.
b.
Place-the standby condensate pump selector switch 1
AC to 0FF.
c.
STOP a condensate pump 76 ba d.-
Select the tripped condensate pump'for STANOBY-
%g ',
' operation.
~
7.
'At approxtmately 30% reactor power,_ verify the Red Worth Minimizer (RHM) is operational.
The-READY and ON-l!NE light should boti :e Itt for one of the two (A or 8) RWM's.
I CAUTION ihe RHM may only be bypassed by using L
00P 207-2.
l 8.-
At.A convenient--time, below'200 MWe remove feedwater heaters e
1 l-from service.
IM 6
At approximately 2
.10 Ibm /hr feedwater' flow.
9.
L
~
- Observe that the recirculation-loop A and 8 flow limit gb:.7 a.
alarms annunciates.
v
-i b.-
. Verify 1the RNM screen disolays "8ELOW 20% POWER" and "8 LOCKS' ENABLED"( Any unacknowledged _ alarms-t should be acknowledged. Verify that the control i --
tod positions are_in accordance with the sequence-displayed and that there are-no insert A
1
.M or-wlthdrawal errors.
c.
IF the RHM is-inoperable' an independent verif ter _is' required for rod. movements.
Enter the verifier's name.
- MA -
Vwrifter APPROVED 1/0023h-
_3 YAR ! 91987
.Q.c.o.s a
b QGP 2 4 aevision13 Insart'the IRM detectors in accordance wtth 00P 700-2.
10.
Tech Spec Tables 4.1.2 and 4.2.1 require the following Tests te performed during' controlled shutdowns unless performed within the
.1 1.
preceding 7 days.
Operating Otoartment shall Derform:
/j/
a.,
(1)
High Flux APRM (heat talance) (QoS 700-6).
W
~[-
(2)
IRM Hign Flux (QOS 700-5).
Instrument Maintenance Department shall perform:
b.
-Prior to Startuo-Shutcown Instrument
'd v (1)
Surveillance (S.T. #41).
START-tne turbine bearing Itft Dumps run for 10 minutes NN__
12, to check proper operation then STOP them.
CAUTION
.i Do not start the turning gear motor during the performance of the next step.
Otspatch en ooerator to the tureine oil reservoir and check tne l3.
auto start of:
FW Emergency Bearing Oil Pumo (EBOP).
[O a.
Motor Suction Pump (MSP).
hM b.
Turning Gear 011 Pump (TGOP).
c.
to TR 12-(22) as Transfer auxillary' power from TR.11-(21) 8A> S _
14.
foilows:
CAUTION Do not allow tuses to oe in parallel
--any longer than necessary, to n-Turn the synchroscope switen ON for TR 12-(22)
%51 a.
Bus 11 (21) creaker.-
_ Check that TR 11 and 12 (21 and 22) are synchronizedM 0_.
and the voltages are equal.
CAUTION Failure to trio the creaker immediately may result in a tr'; of cets creakers from nigh-circulating :ar ent.
APPROVED MAR 101987 4-1/0023h Q. C O. S. R
-_1.______,
QGP 2 1 RevMien 13 Insert the IRM detectors in accordance with QOP 700-2.
10.
TechSpecTables4.1.2.and4.2.1requirethefollowin
!)..
preceding 7 days,
/
Operating Department shall perform:
l a.
W (00$ 700-6).
-())
.High Flux APRN (heat balance)
([
!RM H1gh Flux (QOS 700-5).
(2)
Instrument Maintenance Department shall perform:
8' b.
Prior to Startuo-Shutdown Instrument
,3d (1)
Surveillance (S.T. #41).
START the. turbine bearing Ilft pumps, run for 10 minutes$d to check proper operation then STOP them.
12.
CAUTION Do not start tre turning gear motor j
during tne performance of the rient step.
j
- 13. Dispatch an operator to the turbine oil reservoir and check the auto start of:
Emergency Bearing 0t1 Pump (EBOP).
RL a.
Motor Suction Pump (MSP).
h/k b.
Turning Gear Oil Pump (TGOP).
c.
to TR 12 (22) as 005 Transfer auxiliary power' from TR 11 (21) 14.
follows:
CAUTION Do not allow buses to te in parallel any-longer than necessary, n-for TR 12 (22) to 25
. Turn the synchroscoot swtten ON-a, Bus 11 (21) creaker.
-Check, that:TR 11 and 12 (21 and 22) are synchronizedAA.
c.
and tne voltages-are equal.
CAUTION Failure to trio the creaker immediately may result in a tr'; cf Octn creakers from nign circulating current.
APPROVED MAR 101987 4-I/0023h-QCOSA
- ca c.4 aevisten 13 i
j c.
CLOSE TR 12 (22) to But 11 (21) breaker.
/hc (1)
Check for breaker closed Indication.
(2)
Check for parallel feed alarm.
c.
OPEN TR 11 (21) to Bus 11 (21) creaker.
(1) Check for breaker open indication.
(2)
Reset parallel feed alarm.
e.
Turn the synchroscope switch 0FF for TR 12 (22) to Bus 11 (21).
/MS f.
Turn the synchroscoce switch ON for TR 12 (22) to
()
Bus 14 (24).
f -R S g.
Check that TR 11 and 12 (21 and 22) are synchronized n
and the voltages are equal.
C/45 CAUTION Failure to trip the breaker levnedtately may result in a trip of both breakers from hign circulation current.
h.
CLOSE TR 12 (22) to Bus 14 (24) breaker.
Mws (1)
Check for creaker closed indication.
(2)
Check for parallel feed alarm.
1.
OPEN TR 11 (21) to Sus la (24) breaker.
5 (1)
Check for breaker open indication.
(2)
Reset parallel feed alarm.
j.
Turn the synchroscope switch 0FF for TR 12 (22) to Bus 14 (24).
[293 IS, Continue Inserting control rods in the selected rod sequence.
- 16. When the feedwater master level controller output approaches a 2ero signal transfer level control to
,r L4 r
the low flow control valve in accordance wtth QOP 600-5.
17.
Request permission from the load dispatcher to g
separate the gencrator, i
A[T 18.
STOP inserting control rods when generator output is at 50 MWe.
APPROVED 1/0023h '
Q.C.O.S.R.
OGP 2 a Revision 13 Place the turbine supervisory instruments on H1 speed
-l and turbine rpa (T 146/T-246) on trend if desired.
19.
Verify that the Bypass Valve Opening jack green CLOSED light is on at panel 901-7 (902-7), and the Indicator
-p fk a.
reads zero, CAUTION Ouring the performance of the nextif the OCB's do not trip steps after reaching zero output, 30 seconds The manually TRIP the generator.
also trips
_ generator trip-button RESET the stator cooling water pumps.
to 86 relay in the aux. control room start the stator cooling pump.
[djt With the Load Set reduce generator output to i
20.
10 MWe and establish VAR's at zero.
TRIP the turbine with the Remote Trip Button and verify the h(
21.
__ hk following:
- a. All stop and control valves close.
R2 All intercept valves close, b.
The extraction check valves close and the A0 extrac c
r c.
bypass valves open, g
Generator OCB's auto trip after 30 seconds d.
time delay.
CAUTION Opening the vacuum breaker at high roms imposes excessive loads on the (1200)
Do not turbine last stage buckets.
open the vacuum breaker unless it is necessary to quickly reduce turbine rpm and then do not lower vacuum below 25 inches of Hg (no greater tnan 5 inches of Hg back pressure).
bN Perform' turbine overspeed if required.
22.
Notify the 1.oad Olspatcher that the turbine is tripped and receive. orders to OPEN the Unit 23 disconnects and reclose the 3a5 KV ring bus.
g4 Notify the Eculoment Operator eefore closing the 3a5 KV OCB's.
APPRC i; 'L.R ' c '33 7 1/0023h OC^5*
~ ~ - ~ _ _ _ _ _
QGP 2 a Revision 13 i
/
g l
Place the turbine supervisory instruments on Hi speed and turbine rps (T 146/T-246) on trend if desired.
19.
Verify that the 8ypass Valve Opening jack green CLOSED 901-7 (902-7), and the indicator p
A light is on at panel a.
reads zero.
CAUTION Ouring the performance of the nextif the OCB's do not trip within steps after reaching zero output, 30 seconds the generator.
The manually TRIP also trips generator trip button RESET the stator cooling water pumps.
to 86 relay in the aur control room start the stator cooling pump.
With the Load Set reduce generator output to
[k, J
10 MHe and establish VAR's at zero.
20.
TRIP the turbine with the Remote Trip Button and verify the h(
21.
following:
hk
- a. All stop and control valves close.
kO All intercept valves close.
b.
The extraction check valves close and the A0 extraction _
f-.
V_
c.
bypass valves open.
~ 4 Generator CCB's auto trip aftor 30 seconds
]k d.
time delay.
CAUTION Opening the vacuum breaker at high roms imposes excessive loads on the (1200)
Do not turbine last stage buckets.
open the vacuum creaker unless it is necessary to quickly reduce turbine rpm and then do not lower vacuum below 25 inches of Hg (no greater than 5 inches of Hg back pressure).
Perform' turbine overspeed if required.
22 Notify the Load Dispatcher that the turbine is tripped and receive orders to OPEN the unit 23 disconnects and reclose the 345 KV ring bus.Notifv the E the 345 KV OCB's.
' MR'c T 1/0023h W
'-"--------.m_,_
W 2-6 Revisten 13 I
24, Monitor turbine vibration and if vibration is excessive through the critical soeed range (1200 rpm) open the vacuum 10[.
hreaker, then CLOSE it onen the turoine is cast the critical r
h speeo.
2 5." Verify the Motor Suction Pumo (HSP) and the Turning Gear 011 Pumo (TOOP) automatically start as turbine tube oil cressure decr6ases to 20 psig.
(IJd.
20.
START the turbine bearing lift Dumos before the turbine comes to rest, but not cefore turbine speed is less than
[W7-800 rom.
[>Y
- 27. Verify the turning gear motor starts and the turning gear engages as the turbine comes to rest.
/
v
- 28. Set the turbine oil cooler outlet temperature at 90'F.
h[.
29.
Press the vent pushbutton at the hydrogen panel to place the hydrogen system in a vent status.
Set the rotometer flow g.{
at I scfh.
Fv
- 30. OPEN the above seat and below seat drains.
kd
- 31. Verify that alarm H-9, GEN EXCITER FIELO BRKR OPEN, on N
panel 901-8(902-8) is energized.
32.
Insert control rods in the selected sequence.
33.
When reactor power is between 5% to lot trans'er g
the reactor mode switch to STARTUP as follows:
vv a.
Verify that the APRM's indicate between at to 15% on coth 901-5 (902-5) and 901-37 (902-37).
b.
Verify that the IRM's are on scale in accordance with
/?
QOP 700-2.
'D<D c.
Transfer the mode switch to STARTUP.
d.
Switch the IRM's to record.
chemistry 7'
Notify Rad-Protection to begin 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> reactor,k3E a 34.
surveillance.
Name of person notified.
fa
,p 35.
Insert control rods and maintain desired reactor pressure with the pressure setpoint adjust
.b b controlling the turbine bypass valve position.
a.
If steam line pressure decreases to less than 900 psig -perform the folicwing:
APPROVED MAR 191987 1/0023h Q.C.O.S.R
'X,7 2 a Revtsten 13 (1)
-Bypass the charcoal adsorner bed by placing
)
O _ 8 the charcoal adsorber modt switch in SYPASS.
x N
Verify A0 5418 opens and A0 5414 closes.
'I N
<2)
Start sparge air eer QOP 5400-8.
NOTE For the B train of Unit One, skle steps 0.35.a.(3) and 0.35.a.<4).
/N/2 (3)
OPEN the recomoiner bypass valve 5499-718.
(4)
CLOSE the recomeiner train inlet VA1.VE ho f
5499-75/76.
NOTE Reactor pressure can now be controlled as long as tne ineoard and outboard MSIV's remain open using the turbine pressure setDoint adjust to control the bypass valve (s) position.
Condenser vacuum must be maintained and the turbine EHC system must remain operating.
In this procedure, the term "under control" means that reactor pressure is stable or decreasing.
If maintenance is to be performed to equipment that requires that the turbine EHC system be off, reactor pressure must be maintained without the turbine bypass valves.
This can be accomplished by using the steam from decay heat to maintain turbine seals and condenser vacuum.
The point of adcing heat to the reactor is on IRH range 7 and above.
Below range 7, only residual and decay heat will affect reactor temperature /cressure.
APPROVED MAR 1919o7 1/0023h
-8 O.:3SR
QGP 2 4 Reetston 13
- (1)
Bypass the charcoal adsorber bed by placing 8-the charcoal adsorber mode switch in BYPASS.
'4, y 8
Verify A0 5418 opens and A0 5414 closes.
/v3 (4
<2)
Start sparge air per QOP 5400-8.
NOTE For the B train of Unit One, skip steps 0.35.4 (3) and 0.35.a.(4).
NA (3).
OPEN the recombiner bypass valve 5499-718.
(4)
CLOSE the recombiner train inlet VALVE h4
.o 5499-75/76.
NOTE Reactor pressure can now be controlled as long as the inboard and outboard MSIV's remain open using the turbine pressure setootnt adjust to control the bypass valve (s) position.
Condenser vacuum must be maintained and the turbine EHC system must remain operat\\ng.
In this procedure, the term "under control" means that reactor pressure is stable or decreasing.
If maintenance is to be performed to equipment that requires that the turbine EHC system be off_, reactor pressure must be maintained without the turbine bypass valves.
This can be accomplished by using the steam from 4
cecay heat to maintain turbine seals and condenser vacuum.
The point of adding heat to the reactor is on.IRM range 7 and above.
Selow range 7, only residual and decay heat will affect reactor temperature / pressure.
I l
APPROVED MAR 1b 1987 i/0023h 0.: o s 9
QGP 2 4 teetston 13 i
If there is negligible decay heat, the a
reject / low from the clean-ust system to the condenser may be sufficient to control reactor pressure.
Be careful to riot excessively load down the RBCCW system and cause an increase in drywell cooler temperature resulting in high crywell pressure.
Additional control rods may have to be inserted to maintain a subcritical reactor as reactor coolant temperature decreases.
If the main steam lines must be depressurized, decay heat must be removed and reactor pressure controlled using a comolnation of RCIC and/or HPCI.
It is important to understand that each subsequent reactor pressure control mode is increasingly more difficult to initially stabilize. 00 @I proceed to the next mode or take equipment out-of-service until there is assurance that reactor pressure can be controlled with the systems that remain in service.
36.
If reactor pressure is to be maintained with bypass valves, mark all sub' sequent steps with N/A and sign off procedure.
_ /lh, 37.
%utting down to a subcritical Hot Standby condition, a.
Start rejecting water from the cleanup system to the condenser or radwaste in preparation for bypass valve closure, b.
Insert control rods until reactor pressure (D}fy equals 920 psig and the reactor is subtritical-by at least,three rods.
38.
If the main steam lines can remain pressurized (MSIV's open) and reactor pressure can be controlled with the turbine bypass valves closed, mark all subsequent steps N/A and sign off this procedure.
In this stable condition, the turbine EHC system may be taken out-of-service.
N APPROVED MAR 191987 1/0023h Q.C.O.S.R.
I 1
aevu ton 13 39.
If the outboaro MSIV's must be closed Out the steam l' et can remain pressurized, perform the following:
a.
START torus cooling in preparation of running 4
b' OPEN or verify GPEN main steam line
- in v a l ve s MO-220-1, MO-220-2, MO-220-3, - id g)y 90 220-90A, B, C, D.
c.
CLOSE three outboard MSIV's and verify that reactor pressure is under contre'
_hM d.
In the following steps if reactor cressure increases. ::ntrol pressure first with RCIC and if necessary HPCI.
e.
CLOSE fourth outeoard MS!v and monitor reactor pA pressure.
~
f.
If reactor pressure is under control, the outeoard MSIV's may rcmain closed.
Mark all subsequent steps N/A and sign off this procedure.
M 40.
If tne main steam lines must ce depressurized, perform the following:
HO.].E.
Turbine stdam seals and condenser vacuum will be lost as a result of these steps.
Permit adequate time elapses Detween each step to assure reactor pressure is under control.
If during the performante of the following steps, reactor pressure can not be controlle1 with the use of RCIC and HPCI, reverse the
- steps, repressurize the main steam lines, recover turbine seals and condenser vacuum.
Do not allow the high pressure systems to depressurize the reactor to the point of isolating themselves.
Maintain reactor pressure eetween 600 to 900 PSIG.
APPROVED 1/0023h
'0-
"R ! 3 I3SI OC0S4
Ocp g.a
' Revision 13 39.
If the outboard MSIV's must be closed, but the steam lines can remain pressurized, perform-the following:
4.
START torus cooling in preparation of running
M 4 b.
OPEN or verify OPEN main steam line drain valves HO-220-1 MO-220-?, MO-220-3, and d
MO-220-90A. B, C, D.
c.
CLOSE three outboard MSIV's and verify that i
reactor pressure is under control.
hN d.
In the following steps if reactor pressure lnereases, centrol pressure first with RCIC and if necessary HPCI.
e.
CLOSE fourth outboard MS!V and monitor reactor g
pressure.
f.
If reactor pressure is under control, the j
outboard MSIV's may remain closed.
Mark all
)
subsequent steps N/A and sign off this procedure.
M 1
40.
If the main steam lines must be depressurtzed, perform the following; j
NOTE Turbine steam seals and condenser vacuum will be lost as a result of these steps.
Permit adequate time elapses between each step to assure reactor pressure is under contro.
If during the performance of the following steps, reactor pressure can not be controlled with the use of RCIC and HPCI, reverse the steps, repressurize the main steam lines, recover turbine seals and condenser vacuum.
-- D) not allow the high pressure systems to copressurize the-reactor.to the point of isolating themselves.
Maintain reactor pressure petween 600 to 900 PSIG.
APFRC',10
-I(0023n 10-qq l g jgg7 GCCsa
M84 Reetsien 13 4.
fndividually CLOSE the main steam liae drain orifice bypass valves, MO-220-90A. B C, D.
AJk Verify reactor pressure remains under control.
D.
Slowly throttle CLO![0 the cutside drain valve HO-220-3.
Verify reactor pressure remains under Nb control.
c.
CLOSE the outboard main steam line drain valve M0-220-2. Verify reactor pressure remains under control.
Mk d.
fhit places the reactor in the hot standbv condition with the reactor 1501'1t.6 Do not take any 40011 1 steps to turn eautement over to maintenance untti reac.
gressure control is assured.
41.
Isolate the off-gas system as follows:
a.
CLOSE the primary jet motive steam supply valves 3099 93A/B and 3099-94A/B.
dd b.
CLOSE the secondary jet.gugtton valvn 5499-276A/B u
Mb and 5499-277A/B.
c.
CLOSE the secondary jet notive steam supply valves 3099-91A/B and 3099-92A/B.
A)h d.
Place the off-gas suction valves bypass switch on Mg panel 901-7(902-7) in the BYPA$$ position.
e.
OPEN filter butiding bypass valve 5499 71A.
f.
If an extended system shutdown is planned, secure the glycol cooling system per QOP 5400-5.
I g.
After the recombiner vessel has aooled below 350'F, Isolate sparge air per QOP 5400-9.
M 42.
If this condition is held for an extended period of time the pressure may decay more than desired.
To restore pressure perform the following:
'W Carefully bring the reactor critical, NF s
(% b7
-1 Come up to tne heating range and establish a slow heeting rate.
APPROVED MAR 191987 1/0023h
-11 Q.C.O.S.R.
'I 007 2 4 a
ae<tsten 13 c.
4tch rods as necessary to maintain the i
desired temperature and pressure.
The reactor should reach an ecullibrium condition i
enere no further rod movements are necessary.
'UT 43.
If a'crywell entry is to De made (when primary containment is required) the crywell airlock must ce leak rate tested within 3 days of the entry, If frecuent entries-ar> made, the airlocA must be leak rate tested at intervals not to excesc 3 days.
Unit
- l. -
Date/ Time
/ [k
/)d50 gy,
m G(}/h4 1
4 Como etto (Operator'y-
/h<MY Reviewed (Shift pfgineer)
Seviewed h
/ (Coerating Engineer)
APPRUvCD l
(final)-
YAR 191987 l
-1/0023h 12-l' Q.C.O.S.R.
L
!e _.... - _,.
CGo 2 4
%tsieni3 c.
Notch rods as necessary to maintain the desired temperature and pressure.
The reactor should reach an equilibrium condition
-E',
{
where no further rod movements are necessary.
'dT 43.
If a*dryveil entry is to be made (when primary containment is recutred) the drywell airlock must be leak rate tested vtthin 3 days.of the entry.
If frecuent entries are made the airlock must be leak i
rate tested at Intervals not to exceed 3 days.
1 1
l Unit Date/ Time _ /-3-[k O 50 d
Comoleted Oc/ MAN g(Operator)-
A/<awW nevsewed (Shift Vgineer)
@m3-neviewed
/ (Operating Engineer)
+
APPRUvED (final)
VAR 191987 1/0023h
.12 Q.C.O.S.R.
ll,lyy I'ItsS'w 7ly
\\
E.; h 'f[\\,,,a c' e. o
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Date d. 9-TT ' ~ '
F~
January 1987
$HUTDOWN FRCM PChER OPER,Ai!0N to A SiaN0BY MOf 89E55URIZED COND!!!ON A.
DuYCSE ine :urcose of tnis procedure is to outline the tetned used to snutso n the snit from a oCuer. generation MCe to a condition of low oCuer ei!9 tne reactor pressure vessel pressurtzed and the 451V's either CLOSED or CPEN.
8.
REFERENCES 1.
QOP $670-1, EGC Settings.
2.
QCP 202-3, Reactor Rectreulation System Flow Controller Coeration.
3.
OCP 600-8, Removing One of two feedwater Regulator Valves frem
- Service, a.
QOP 3200-5. Reactor Feed Pumo Snutdown.
5.
00P 700-2, Intermediate Range Monitoring Operation (!PM).
6.
005 700 Block, r
7.
QCP 600-5, Removing the Main Feedwater Regulator from Service.
8.
QOP 700-1, source Range Monitoring Operation (SRM).
9.
QOP 5a00-8, Starting Sparge Air to the Recomeiner.
- 10. 00P 5a00-5, Glycol System Shutdown.
- 11. QCP 5a00-9, Isolating Soarge Air to the Recombiner.
- 12. QCP 5600-1, Gland Seal System.
- 13. OcP a-1, Control Rod Movements and Control Rod Sequereti.
- 14. QOP 207-2, Declaring Rod Worth Minimizer Comouter Inoperable.
I
- 15. 005 250-1, MS!V Closure Montnly Scram Sensor Functional fest.
C.
PREREQUISITES 1.
Permission has been obtained from the Lead 015Datener to snutdown the unit.
l 2.
The Rod Worth Minimizer is operational /or a Qualtfled person is available to verify rod movements in accordance with the rod sequence chosen prior to reactor power reaching 20%. The RHH may only be bypassed by using 00P 207-2*
APFnu,:.C 1/0023h g 1 ) 1937 Q.C 0 $ 4 l
m.,,
QCP 2 4 aseiston la i
s/
If this procedure is terminated at any tih.e during its esecution.
insert a statement at the point of termination 45 to reason and the title of subsequent procedure, Insert N/A in all remaining blanAs.
date, time and sign last page.
Retain terminated procedure in start.up package.
4.
Perform MISV Closurt Monthly Scram Sensor Functional Test. 005 250-1.
4.
If no work is to be performed in the MS!V room or drywell, this prerecuisite may be bype,$ sed if authorized by an Operating Engineer.
& de h I t __
Op Engr.
("J 0~a t e D.
PROCEDURE Init'at 1.
If the reactor recirculation flow controller it in EGC or MASTER AUTO mode, place the controller h
in the MASTER-MANUAL mode, 2.
Reduce power with the master rectreulation flow controller and observe the following:
a.
Power reduction rate shall be in accordance with the most recent operating recommendations under NORMAL and emergency condtttons.
b.
-Continuously monitor _ power decrease on APRM's.
c.-
Maintain Load Set 10% above generator load.
d.
On 901-5 (902-5), maintain the ECC settings in accordance vitn 00P 5670-1.
e.
Continue to reduce rectrculation flow until the Master controller reaches minimum speef (45%), then place the rectreulation flow controllers In the LOCAL MANUAL mode in accordante with QOP 202-3.
f.
Continue reducing rectreulation flow to 38% pump speed.
Maintain the recirculation pumps at equal speeds.
3.
As condensate domineralizer differenttal-pressure approaches 15 estd. Isolate units one at a time to maintain greater than 1500 g g ff flow through the domineralizers.
4.
Commence inserting control rods in accordance with QGP a-1 until the PA 6 PRESS GEN LOAD REJ STM VLV BYPASS &larm first annunciates (approntmately 42% power).
Then reduce l
rectreulation flow to minimum with the potentiometer on KI the Recirc Pump Sou s Controllers.
Continue to insert control rods.
APPhu',c.0 1/0023h g
.) g QC054
QGP 2 4 Revision 13 3.
If this procetture is terminated at any time during its esecution, insert & statement at the point of termination as to reason and the title of subst1uent procedure.
Insert N/A in all remaining blanks, date, time and sign list page.
Retain terminated procedure in start.up package.
a.
Perform MISV Closure Monthly Scram $sator Functional rest, QOS 250-1.
a.
If no wrk. is to et performed in the M51V room or drywell, this OrtreQuisite may be byp4ssed if Authorized by anI/ht Operat'ng Engineer.
N dh
,y 09 Engr.
G 0~a t e D.
PROCEDURE Intt'al 1.
If the reactor recirculation flow controller is in EGC or MASTER AUTO mode, place the controller
/)g in the MASTER-MANUAL mode.
D7 P@J 2.
Reduce power with the master recirculation flow controller
/j and observe the following:
4.
Power reduction rate shall be in accordance with the most recent operating recommendations under NORMAL and emergency conditions.
b.
Continuously monitor power decrease on APRM's.
c.
Maintain Load Set 10% above genert. tor load.
d.
On 901-5 (902-5), maintain the EGC settings in accordance with QOP 5670-1.
e.
Continue to reduce recirculation flow until the Mastcr controller reacnes minimum speed (45%), then place the recirculation flow controllers in the LOCAL-MANUAL mode in accordance with QOP 202-3.
f.
Continue reducing recirculation flow to 38% pump speed.
Maintain the recirculation pumps at equal speeds.
3.
As condensate demineralizer differential pressure approaches 15 05td. isolate units one at a time to maintain greater than 1500 p E flow through the domineralizers.
'f F a.
Commence inserting control rods in accordance with QGP a-1 until the TURB PRESS GEN LOAD REJ STM VLV BYPASS alarm first annunciates (approximately 42% power).
Then reduce recirculation flow to minimum witn the potentiometer en the Rectre Pump Speed Controllers.
Continue to insert 44' control rods, f/ /
APPRU,c.0 1/0023h
^D ' a s
,.g. v.
e 5.
At act reactor power, CLOSE the feedwater regulator that c> 4-is in MANUAL. in accordance with 00P 600-8.
/
NOTE If feedwater instabilities occur use the second feedwater regulator valve to return the feedwater system to a stable state.
6.
At approximately 4 106 les/hr feedvater flow and 150 amps on the concensate pumps STOP 4 reactor fetcwater pump in accordance with QOP 3200-5 and then STCP a 3
condensate pump as follows:
/'d 4.
Verify that reactor feed Dump suction pressure is greater t$an 350 psig.
b.
Place the standby condensate pump selector switch pJ to 0FF.
63 c.
STOP a condensate pump.
d.
Select the tripped condensate pump for STANOBY hi 4
operation.
7.
At approximately 30% reactor power, verify the Rod Horth Minimt:er (RHM) is operational.
The READY and ON-LINE light should be:n :e i
lit for one of the two (A or B) RHN's.
{
CAUTION The RHM may only be bypassed by using QOP 207-2.
B.
At a convenient time, below 200 MHe remove feedwater heaters W,
from service.
9.
At approximately 2 x 106 lbm/hr feedwater flow, a.
Observe that the rectreulation loop A and B flow limit Y7) alarms annunciates.
D.
Verify the RHH screen displays "BELOH 20% PohER" and " BLOCKS ENABLE 0" Any unacknowledged alarms should be acknowledged. Verify that the control rod positions are in accordance with the sequence displayed and that there are no insert N,
l or withdrawal errors.
i If the RWH is inoperacle, ah independent verifter is required c.
for rod movements, Enter the vertfler's name.
A.WA-Vertfler APPRUVED 1/0023h MAR 191937 Q.C.0 S R
008 2 4 Revisien 13 l
10.
Insert the IRH cetectors in accordance vtth 00P 700-2.
/dl 11.
Tech Spec Tables 4.1.2 and 4.2.1 reautre the following tests be performed during controlled shutdowns unless performed within the preceding 7 days, a.
Operating Department shall perform:
(1)
High Flux APRM (heat balance) (QOS 700-6).
W___
(2)
IRH High Flux (QOS 700-5).
b.
Instrument Maintenance Decartment shall cerform:
(1)
Drior to Startup-Shutcown Instrument g'"7 7g Surveillance (S.T. 841).
/J/A 12.
W RT the turoine bearing lift cumps, run for 10 minutes to check croper oceration then STOP them.
Y CAUTION Do not start the turning gear motor during the performance of the next step.
13.
Olscatch an operator to the turbine oil reservoir and check the auto start of:
a.
Emergency Bearing 011 Pump (EBOP).
W b.
Motor Suction Pump (HSP).
d c.
Turntng Gear Oil Pump (TGOP).
d 14.
Transfer auxiliary power from TR 11 (21) to TR 12 (22) as
/> 4
~
7 foilows:
CAUT10N Do not allow buses to te in parallel any longer than necessary.
4.
Turn the synchroscoce switcn DN for TR 12 (22) to pa Bus 11 (21) creater.
I/ T b.
Check that TR 11 and 12 (21 and 22) are synchronized and the voltages are equal.
MI CAUTION Fatture to trio the creaker immeciately may result in a tri: of oth treakers frSm high circulating.,arrent.
APPROVED 1/0023h a-MAR 101987 QC05R
l OCP 2-4 Revision 13 10.
Insert the IRH detectors In accordance with 00P 700-2.
- -Mi 11.
Tech Spec Tables 4.1.2 and 4.2.1 recuire the following Testt be performed during controlled shutdowns unless performed within the preceding 7 days.
l a.
Operating Department shall perform:
(1)
Hi Flux APRM (heat balance) (QOS 700-6). 6 1
(2)
!RM High Flux (QoS 700-5).
]
b.
Instrument Maintenance Department shall perform:
( l ',
Prior to Startup-Shutdown Instrument
<f Surveillance (S.T. sal).
/J/A g"O' 7 "
i 12.
START the turbine bearing lift pumps, run for 10 minutes to check proper operation then STOP them.
Y CAUT!CN 00 not start the turning gear motor during the performance of the nest step.
13.
Olspatch an operator to th6 turbine oil reservoir and check the auto start of:
a.
Emergancy Bearing Oil Pump (EBOP).
"75 b.
Motor Suction Pump (HSP).
d, c.
Turning Gear Oil Pump (TGOP).
Jd 14, Transfer auntliary power from TR 11 (21) to TR 12 (22) as follows:
N CAUi!CN Do not allow buses to be in parallel any longer than necessary, a.
Turn the synchroscope switch CN for IR 12 (22) to IO Bus 11 (21) creaker.
c.
_ Chock that TR 11 and 12 (21 and 22) are synchronized and the voltages are equal.
N C&UTION Failure to trip the preaker imrreciately may result in a tri: of coin treakers from nigh circulatteg current.
APPROVED 1/0023h a-MAR 10 G87 QC05R
- Cp :.s OtvisiCn 13 c.
CLOSE TR 12 (22) to Sus 11 (21) breaker, 39' (1)
Check for breaker closed indication.
(2)
Check for parallel feed alarm, d.
OP(N TR 11 (21) to Bus 11 (21) Dreaker.
/W (1) Check for breaker open Indication.
(2)
Roset parallel feed alarm.
e.
Turn the synchroscope switch 0FF for TR 12 (22) to Bus 11 (21).
SY f.
Turn the synchroscoce switch CN for TR 12 (22) to Bus 14 (24).
N g.
Check that TR 11 and 12 (21 and 22) are synchronized 1
and the voltages are equal.
D CAUTION Failure to trip the breaker immediately may result in a trip of both breakers from high circulation current.
n.
CLOSE TR 12 (22) to Bus 14 (24) breaker.
N (1)
Check for breaker closed Indication.
(2)
Check for parallel feed alarm.
1.
OPEN TR 11 (21) to Bus la (24) breaker.
)I (1)
Check for breaker open indication.
I L
(2)
Reset parallel feed alarm.
j.
Turn the synchroscope switch 0FF for TR 12 (22) to Bus 14 (24).
[
- 15. Continue inserting control rods in the-selected rod sequence.
- 16. When the feedwater master level controller output approaches a Zero signal transfer level control to the low flow control valve in accordance with 00P 600-5.
W 17.
Request permission from the load dispatcher to separate the generator.
W
- 18. STOP inserting control rods when generator Tu]'j output is at 50 MWe.
-rd ft, vg APPROVED 1/0023h q4p 7 g jgg7 Q.C.O.S.R.
QCp 3.a Reei%1Cn 13
~
1 19.
Place the turbine supervisory instruments on H1 spaed and turbine rps (T-146/T-246) on trend if desired, cyf l
Verify that the Sypass Valve Opening jack green CLOSED a.
light is on at panel 901-7 (902-7), and the indicator N
' reads zero.
CAUTION During the performance of the next steps if the OCB's do not trip within 30 seconds after reaching zero output, manually TRIP the generator.
The generator trip button also trips stator cooling water pumps.
RESET the 86 relay in the aux. control room to start the stator cooling pump.
20.
With the 1.oad set reduce generator output to M
10 MWe and establish VAR's at zero.
21.
TRIP the turbine with the Remote Trio Button and verify the Wf following:
- a. All stop and control valves close.
'f#
b.
All intercept valves close.
d 8
O c.
The extraction check valves close and the A0 extraction Y. " " #"d 8
bypass vaives open.
cr4 Whs i.J,, r d.
Generator OCB's auto trip after 30 seconds
.1 p m time de1ay.
<rt3 4.J.f,,
v' i m.c,) s e CAUTION u 3.), f,,
" "t < /s Opening the vacuum breaker at high rpms (1200) imposes excessive loads on the turbine last stage buckets.
Do not open the vacuum breaker unless it is necessary to quickly reduce turbine rpm and then do not lower vacuum below 25 inches of Hg (no greater than 5 inenos of Hg back pressure).
'b 22.
Perform' turbine overspeed if required.
23.
Notify the Load Dispatcher that the turbine is tr'oped and roceive orders to OPEN the unit disconnects at.d reclose the 345 KV ring bus.
Notify the Eautement Operator before closing 7d the 3a5 KV OCB's.
1/0023h 6
'M R ', ' T l
QCP 2 4 Revision i) 19.
Place the turbine supervisory instruments on Hi speed l
and turbine rps (T-146/1-246) on trend if desired.
cr27 l
Vertfy that the Bypass Valve Opening jack green CLOSED a.
light is on at panel 901-7 (902-7), and the indicator N
' readt zero.
CAU T(0,,,N During the performance of the next steps if the OCB's do not trip within 30 seconds after reaching zero output, manually TRIP the generator.
The generator trip button also trips stator cooling water pumps.
RESET the 86 relay in the aus, control room to start the stator cooling pumps 20.
With the Load Set reduce generator output to M
10 MWe and establish VAR's at zero.
S 21.
TRIP the turbine with the Remote Trip Button and verify the d
following:
- 4. All stop and control valves close.
'f#
b.
All intercept valves close.
f8 8' ' E &
The extraction check valves close and the A0 extraction W.
b ro,%,,
c.
cy3 bypass valves open.
ae t.)
. e d.
Generator OCB's auto trip after 30 seconds W
crf5 4Jer
'6
time delay.
n r. c,) s e CAut!ON g, y,,,,
L' " /s Opening the vacuum breaker at high roms (1200) imposes excessive loads on the turbine last stage buckets. Do not open the vacuum breaker unless it is necessary to quickly reduce turbine rpm and then do not lower vacuum below 25 inches of Hg (no greater than 5 inches of Hg back pressure).
~
'b 22.
Perform turbine overspeed if required.
23.
Notify the 1.oad Dispatcher that the turbine is tripped and receive orders to OPEN the unit disconnects and reclose the 34$ XV ring bus.
Notify the Ecuipment Operator tefore closing 7d_
the 345 KV OCB's.
1/0023h W.R';Q[
CC;';
"G P 2, - a aviuen ')
24.
Monitor turbine vibration and if vibration is escessive through the critical speed range (1200 rpm) open the vacuum creaker, then CLOSE It unen the tureine is past the v itical
"/A speed.
25/ Verify the Motor Suction Pump (HSP) and the furning Gear Oil Pumo (TGOP) automatically start as turcine lube oil pretsure decreases to 20 ostg.
-rrf 26, START the turbine bearing lift pumps cefore the turbine comes to rest, but not cefore tureine speed is less than 800 rpm.
Yd Tce6 [,d y[,
f7 27.
Verify the turning gear mter starts and the turning gear engages es the tureine comes to rest.
28.
Set the tureine oil cooler outlet temperature at 90'F.
M r,, jh 29.
Press the vent pushbutton at the hydrogen panel to place the hydrogen system in a vent status.
Set the fotometer flow at I scfh.
'fd 30.
OPEN the above seat and below seat drains.
-(8 31.
Verify that alarm H-9, GEN EXCITER FIELO BRKR OPEN, on panel 901-8(902-8) is nergized.
YT]
32.
Insert control rods in the selected sequence.
W3 33.
When reactor power is between 5% to 10% transfer the reactor mode switch to STARTUP as follows:
r"W a.
Verify tnat the APRH's indicate between at to 15% on both 901-5 (902-5) and 901-37 (902-37).
b.
Verify that the !RM's are on scale in accordance with QOP 700-2.
-rd c.
Transfer the mode switch to STARTUP.
W d.
Switch the IR"'s to record.
"Td i
34.
Notify Rad-Protection to eegin 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> reactor chemistry l
surveillance.
Name of person notified, d L A.,a J YN 35.
Insert control rods and maintain desired reactor pressure with tne pressure setpoint adjust l
controlling the turbine bypass valve position.
crid' i
4.
If steam line pressure cecreases to less than 900 psig, perform the following:
APPROVED MAR 191987 1/0023h Q.C.0SR l
l l
1 QCP-3 a aseisten 13 (1)
Bypass the chartoal adsorber bed by placing the charcoal edsorber mode switch in BYPASS.
Verify A0 5418 opens and A0 5414 closes.
-Td
.(2)
Start sparrte air ter QOP 5400-8.
N*C NOTE For the B train of Unit One, skip steps 0.35.4.(3) and 0.35.a.(4).
(3)
OPEN the recombiner Dypass valve 5499 718.
We
< /. x)
(4)
CLOSE the recombiner train inlet VALVE g_ c, g e.7,,, v., l., a 5499-75/76.
w
- v NOTE Reactor crosstre can now be cor. trolled as long as the inboard and outboard MSIV's remain open using the turbine pressure $ttpoint adjust to control the bypass valve (s) position.
Condenser vacuum must be maintained and the turbine EHC system must remain operating.
In this procedure. the term "under control" means that reactor pressure 15 stable or decreasing.
If maintenance is to be performed to equipment that requires that the turbine EHC system be off, reactor pressure must be maintained without the turbine bypass valves.
This can be accomplished by using the steam from decay heat to maintain turbine seals and condenser vacuum.
The point of adding heat to the reactor t
is on IRM range 7 and above.
Below range 7 only residual and decay heat will affect reactor temperature / pressure.
APPROVED MAR ! b 13o7 l/0023h 8
O.C 3 5 R
ocp g.a Revision 13 (1)
Bypass the charcoal adsorber bed by placing the charcoal adsorber mode switch in 8YPASS.
Verify A0 5418 opens and A0 5414 closes.
-id
.(2)
Start sparge air per QOP $400-8.
N*O WTE For the 8 train of Un't One, skip steps 0.35.a.(3) and 0.35.4.(4).
4(/.r$
~
(3)
OPEN the recombiner bypass valve 5499-718.
- N:
< / w/
(4)
CLOSE the recombiner train inlet VALVE 46 %
5499-75/76.
e.y, win u
.. V.,
- v NOTE Reactor pressure can now be controlled as long as the inboard and outboard MS!V's remain open using the turbine pressure setpoint adjust to control the bypass valve (s) position.
Condenser vacuum must be mathtnined and the turbine EHC system must remain operating.
In this procedure, the term "under control" means that reactor pressure is stabl; or decreasing.
If maintenance is to be performed to equipment that requires that the turbine EHC system be off, reactor pressure must be maintained without the turbine bypass valves.
This can be accomplished by using the steam from decay heat to maintain turbine seals and condenser vacuum, The point of adding heat to the reactor is on IRM range 7 and above.
Below range 7 only residual and decay heat will affect reactor temperature / pressure.
APPROVED M AR ! S 1981 1/0023h 0.0 3 S R
QGP 2 4 Reitston 13 w so e If there is negligible decay heat, the reject flow from the clean-upt system to the condenser may be sufficient to control reactor pressure.
De careful to not excessively load down the RSCCW system and cause an increase in drywell cooler temperature resulting in high drywell pressure.
Additional control rods may have to be Inserted to maintain a subcritical reactor 45 reactor coolant temperature decreases.
If the main steam lines must be depressurized. decay heat must be removed and reactor pressure controlled using a combination of RCIC and/or HPCI.
It is important to understand that each subsequent reactor pressure control mode is increasingly more difficult to initially stabilize. OQ NOT proceed to the next mode or take equTpInent out-of-service until there is assurance that reactor pressure can be controlled with the systems that remain in
- service, 36.
If reactor pr6ssure is to be maintained with bypass valves, mark all subsequent steps with N/A and sign off procedure.
- /t 37.
Shutting down to a $Ubcritical Hot Stand y condition, a.
Start rejecting water from the cleanup system to the condenser or radwaste in preparation for bypass valve closure.
8 b.
Insert control rods until reactor pressure equals 9?.0 psig and the reactor is subcritical by at least three rods.
VI 38.
If the main steam Innes can remain pressurtzed (MSIV's open) and reactor pressure can be controlled with the turbine bypass valves closed, mark all subsequent steps N/A and sign off this procedure.
In this stable condition, the turbine EHC system l-may be-taken out-of-service.
- /#
APPROVED i
l MAR 191987 i/coz3h Q.C.O.S.R.
~.
-~
Ocp 2 a Reetston 13
,,g, 39.
If the outboard MSIV's must ce closed, but the steam itnes can 1
remain pressurized, serform the followthg:
a.
START torus cooling in p?eparation of runnthg HPCI or RCIC.
g+
b.
OPEN or verify OPEN main steam line drain valves 4-220-1. MO-220-2, MO-220-3, and MO-220-90A, B, C, D.
c.
CLOSE three outboard MSIV's and verify that reactor pressure is under control.
_ N/+
i d.
In the following steos if reactor cressure increases, control pressure first with RCIC and if necessary HPCI.
]
e.
CLOSE fourth outboard MSIV and monitor reactor pressure.
N/+
j i
f, if reactor pressure is uncer centrol, the i
outboard MS!V's may remain closed.
Mark all subsecuent steps N/A and sign off this procedure.
MN 40.
If the main steam lines mest be depressurtred; perform the
_following:
NOTE Turbine steam seals and c'.idenser vacuum will be lost as a result of these steps, permit adeouate time elapses between each step to assure reactor pressure it under control, If during the performance of tne-following steps, reactor pressurs can not be controlled with tne use of RCIC and HPCI, reverse the
- steps, repressurtre the main steam lines,
. recover turbine seals and condenser vacuum.
Do not allow the nigh pressure systems to depressuri2e the reactor to the point of isolating themselves.
Maintain reactor pressure eetween-600 to 900 PSIG.
l L
APFff0VED 1/OO23h 10-qq t g gg7 L
0.C 0 s a
QGP 2 4 Revision 13 39.
If the outboard MSIV's must be closed, but the steam )tnes can remain pressurized, perform the following:
a.
START torus cooling in prepar4 tion of running HPCI or RCIC.
+
b.
OPEN or verify OPEN main steam line drain vatves MO-220-1. HO-220-2, HO-220-3, and MO-220-90A, B. C, D.
c.
CLOSE three outboard MSIV's and verify that reactor pressure is under control.
- /+
d.
In the following steos if reactor pressure increases, control pressure first with RCIC and if necessary MPCI.
e.
CLOSE fourth outboard MSIV anc monitor reactor pressure.
- NA f.
If reactor pressure is under control, the outboard MSIV's may remain closed.
Mark all subtedudnt steet N/A and sign off this procedure.
N 40.
If the main steam 11.'.vs must be depressurized, perform the following:
NOTE Turbint steam seals and condenser vacuum will be lost as a result of these steps.
Sermit adeduate time elapset between eacn step to assure reactor pressure is under centrol.
If during the performance of tne following steps, reactor pressure can not be centrolled with the use of RCIC and HPCI, reverse the
- steDs, repressurize the main steam lines, recovir turbine seals and condenser vacuum.
Do not allow tne nign pressure systems to 3epressurize tne reactor to the point of Isolating themselves.
Maintain reactor pressure between 600 to 900 PSIG.
APPRoyED I
1/0023n 10-qq 3 g ;gg7 O.C 0 s R
MP 2 4 Reetston 13 4.
Individually CLOSE the main steam line draln orifice bypass valves. HO-220-90A, B, C, D.
Verify reactor pressure remains under control.
NL
~
0.
Slowly throttle CLOSCO the outside drain vaire HO-220-3.
Verify reactor pressure remains under Control.
/4 c.
CLOSE the outboard main steam line drain valve HO-220-2. tarify reactor pressure remains under control.
g/r d.
This places the reactor in the hot standby condition with the reactor isolated.
Do not take any additional steps to turn equipment over to maintenance until reactor pressure control is assured.
41.
Isolate the off-gas system as follows:
a.
CLOSE the primary jet motive steam supply valves 3099-93A/B and 3099-94A/B.
b.
CLOSE the secondary jet suction valves 5499-276A/B and 5499-277A/B.
d c.
CLOSE the secondary jet motive steam supply valves 3099-91A/B and 3099-92A/8.
,J/A-d.
Place the off-gas suction valves bypass switch on panel 901-7(902-7) in the BYPASS position, e.
OPEN filter building bypass valve 5499.71A.
o/+
f.
If an extended system shutdown is planned, secure the glycol cooling system per QOP 5400-5.
N/A g.
After the recombiner vessel has cooled below 350'F,
_fj isolate sparge air per QOP 5400-9.
/V/A 42.
If this condition is held for an extended period of time the pressure may decay nore than desired.
To restore pressure perform the following:
a.
Carefully bring the reactor critical.
b.
Come up to the heating range and establish vj4
/
a slow heating rate.
APPROVED MAR 191987 1/0023h Q.C.O.S R
QGP 2 4 Revision 13 c.
Notch rods as necessary to maintain the oestred temperature and pressure.
The reactor should reach an equilibrium condition g/, _
.here no further rod movements are necessary, W
43.
If a drywell entry is to t,e made (when primary containment i.. required) the crywell airlock must be leak rate tested within 3 days of the entry.
If frequent entries are made, the airlock must be leak rate tested at intervals not to exceed 3 days.
Unit Date/ Time 4/??
e c,#
Compteted 7 /$,4e da (Operator)
Reviewed wh ---
/' '(Shif t Enginder)
Reviewed h hv. [~
' (Coerating Engineer)
APPRUvED (final)
YAR 191987 1/0023h
.:2-Q.C.C.S.R.
QGP 2 4 Revision 43 c.
4tch rods as necessary to maintain the desired temperature and pressure.
The re&ctor should reach an ecullibrius condition where no further rod movements are necessary.
gU 43.
If a drywell entry is to be made (when primary containment is required) the drywell airlock must ce leak rate tested within 3 days of the entry.
If frequent entries are made, the t.1rlock must be leak rate tested at Intervals not to escled 3 days. -
Unit Date/ Time M9/7v o( #
Completed Fd.4e d<<
(Operator)
Reviewed e_
/~ '(SM f t Enginder)
Reviewed N b [-
i (Operating Engineer)
APPRUVED (final)
VAR 191987 1/0023h 12-Q.C.O.S.R.
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8 GCP 2-a Sni f t Engr. 7//MA/ )
Revisten 13 Date u - F-W
/
January 1987 SHUTOOWN FROM POWER OPERATION TO A STATC6Y HOT PRESSURIZED CONDITION A.
DURPCSE The ourpose of this procedure Is to outline the metnod used to shutdown 1
the unit from a cover-generation mode to a conaltion of low oower with the reactor pressure vessel pressurized and the MSIV's either CLOSED or OPEN.
S.
REFERENCES 1.
QOP 5670-1 EGC Settings.
2.
QOP 202-3, Reactor Recirculation System Flow Controller Operation.
3.
00P 600-8, Removing One of Two Feedwater Regulator Valves from Service.
4 QOP 3200-5, Reactor Feed Pumo Shutdown.
5.
QOP-700-2, Intermediate Range Monitoring Operation (IRM).
6.
005 700 Block.
7.
00P 600-5, Removing tne Main Feedwater Regulator from Service.
8.
- QOP 700-1 Source Range Monttoring Operation (SRM).
9.
- QOP 5400-8, Starting Sparge Air to the-Recomeiner.
- 10. QOP 5400-5, Glycol System Shutcown.
- 11. 00P $400-9, Isolating Sparge Air to the Recombiner.
- 12. 00P-5600-1, Gland Seal System.
13.- QGP 4-1, Control Rod Movements and Control Rod Sequences.
14 CCP 207-2, Declaring Red Worth Minimizer Computer Incoerable.
C.
PREREQUISITES 1.
Permission has oeen obtainea from the t. cad Dispatcher to shutdown-the unit.
2.
The Rod Worth Minimizer is operational /or a cualified person is
-available to verify rod movements;_in-accordance.with the rod secuence chosen orter to reactor power reacning 207.. The RWM may only be bypassed by using QOP 207-2.
APFnuvdD 1/0023h
-1 g 1.,jg g Q.C.3 S n
i OGP 3 4 Reeiston 13 3.
If this procedure is terminated at any time during its execution.
insert a statement at the point of termination as to reason and the title of subsequent procedure.
Insert N/A in all remaining blants.
date, time and sign last page.
Retain terminatad procedure in startuo package.
a.
Perform MISV Closure Monthly Scram Sensor Functional Test, QOS 250-1.
a.
If no work is to be performed in the MS!V room or drywell, this orerecuisite may be e pas ed if authorized by an Operating Engineer.
G w
4177
/ 00 Engr.
Date D.
PROCEDURE Init'al 1.
If the reactor recirculation flow controller is in EGC or MASTER-AUTO mode, place the controller in the MASTER-MANUAL mode.
NA 2.
Reduce power with the master rectreulation flow controller and coserve tne following:
ut a.
Power reduction rate shall be in accordance with the most recent operating recommendations under NORMAL and emergency conditions.
b.
Continuously monitor power decrease on APRM's, c.
Maintain Load Set 10% above generator load, d.
On 901-5 (902-5), maintain the EGC settings in accordance wtth
-QOP 5670-1.
e.
Continue to reduce recirculation flow until me Mascer controller reacne's minimum speed (45%). then place the recirculation flow controllers in the t.0 CAL-MANUAL moce in accordance with QOP 202-3.
f.
Continue reducing recirculation flow to 38% oumo toeed.
Maintain the recirculation cumes at equal seteds.
3.
As condensate demineralizer differential cressure acoroacnes 'S ostd, isolate units one at a time to maintain greater than 1500 gem flow through the domineralizers, nA a.
Comence inserting control rods in accordance with QGP 4-1 until the TURB PRESS GEN LOA 0 REJ STM VLV BYPASS alarm first annunciates (accroximately 42% cower).
Then reduce recirculation-flow te e imum =lth the potentiometer on n
tne Rectre Pumo Speed Co. trollers.
Continue to insert control rods.
4A A P P n U ' c. C
~
YAR 131957 Q C.C.5 R
OGP 2.a Reetston 13 3.
If thl$ procedure l$ terminated at any time during its eseCution.
insert & r,tatement at the point of termination 45 to reason and the title of subleQuent procedure.
Insert N/A in all remaining blanks, date, time and sign last page.
Retain terminated procedure in startup package.
4 Perform M!$V Closure Monthly Scram Sensor Functional Test. 005 250-1.
a.
If no work is to be performed in the MS!V room or drywell, this prereduisite may be b pasled if authorized by an Operating Engineer.
O, y..
4.f.77_
/00 Engr.
Date 0.
PROCEDURE init+a1 1.
If the reactor recirculation flow controller is in EGC or MASTER-AUTO moce, place the controller in the MASTER-MANUAL mode.
NA 2.
Reduce power with the master recirculation flow controller and observe the following uk l
a.
Power reduction rate shall be in accordance with the most recent operating recommendations under NORMAL and emergency conditions, b.
Continuously monitor power decrease on APRM's, c.
Maintain load Set 10% above generator load.
d.
On 901-5 (902-5), maintain the EGC settings in accordance with QOP 5670-1.
e.
Continue to reduce recirculation flow until the Master controller reaches minimum speed (45%), then olace the recirculation flow controllers in tne LOCAL-MANUAL mode in accordance with 00P 20243, f.
Continue reducing recirculation flow-to 38% oump speed.
Maintain the recirculation pumps at equal speeds.
3.
As condensate demineralizer differential pressure approaches : S psid, Isolate units one at a time to maintain greater than 1500 gem flow through the demineralizers.
wA 4
Commence inserting. control rods in accordance with OGP a-1 until the TURB PRESS GEN LOAD REJ STM VLV BYPASS Alarm first annunciates (accroximately 42% power).
Then reduce recirculation flow to minimum witn the Dotentiometer on the ReCire Pump $ceed Controllers.
Continue to insert control rods, e
APFnu.c.C m 023n
+
ygg l j jgg7 0 C.C 5 A
Revisten 13 5.
At act reactor power, CLOSE the feedwater regulator that is in MANUAL in accordance with QOP 600-8.
.uA NOTE If feedwater instabilities occur use the second feedwater regulator valve to return the feedwater syst6m to a stable state.
- 6..
At.Approximately 4 x 106 lbs/hr feedwater flow and 150 amps on the condensate pumps. STOP & reactor feedwater pump in accordance with QOP 3200-5 and then STOP a condensate pump as follows:
us 4.
Verify that reactor feed pump suction pressure is greater than 350 0519 b.
Place the standby condensate pump telector switch to 0FF.
wA c.
STOP a condensate pump.
us d.
Select the tripped condensate pump for STANOBY operation.
9N 7.
At approximately 30% reactor power, verify the Rod Horth Minimizer (RHM) is cperational.
TM READY and ON-LINE light should botn de lit for one of the two (s or B) RHM's.
CAUTION The RHM may only be bypassed by using 00P 207-2.
8.
At a convenient time, below 200 MWe remove feedwater neaters from service, u
9.
At approximately 2 x 106 lbm/hr feedwater flow.
4.
Observe that the recirculation loop A and 8 flow limit alarms annunciates, m
b.
Vertfy the RHM screen displays " BELCH 20% P0HER" and " BLOCKS ENABLED" Any unacknowledged alarms should be acknowledged.. Verify that the control l
rod positions are in-accordance with the j-sequence displayed and that there are no insert i
l-or withdrawal errors, e
l' c.
IF the RHM is inoperable, an independent verifier is required for rod movements.
Enter the vertfler's name.
Vertfter APPROVED 1/0023h g g )gg7 Q.c. 0. S R
QCP 2 4 Revision 13 10.
Insert the IRM detectors in accordance with QOP 700-2.
no 11.
Tech Spec Tables 4.1.2 ano 4.2.1 reautre the following Tests be performed during controlled shutdowns unless performec within the preceding 7 days, a.
Operating Department shall perform:
(1)
High Flux APRM (heat calance) (QOS 700-6).
oA (2)
IRM High Flux (005 700-5).
b.
Instrument Maintenance Decartment shall perform:
4"141 (1)
Prior to Startuo-Shutcown Instrument Surveillance (S.T. #41),
h Q[g l
12.
START the turbine bearing lift pumos, run for 10 minutes to check crocer operation then STOP them.
u n.
CAUTION Do not start the turning gear motor during the performance of the next step.
- 13. Otspatch an operator to the tureine oil reservoir and check the auto start of:
a.
Emergency Bearing Oil Pump (EBOP).
tA b.
Motor Suction Pump (MSP),
9A c.
Turning Gear Oil Pump (TGOP).
ta 14 Transfer auxiliary power from TR 11 (21) to TR 12 (22) as follows:
wA CAUTION Do not allow buses to te in carallel any longer than necessary, a.
Turn the synchroscoce swit:n ON for TR 12 (22) to Bus 11 (21) breaker, u it D.
Che:K that TR 11 and 12 (21 and 22) are synchroni:ed and the voltages are equil.
n CAUTION Failure to triD the 0'eaker i meciately may resuit in a t*': cf :::n :rea(ers from nign :tr:ulatt g :arrent.
APPROVED 1/0023h YAR 101957 QC05o
QGP 2-6 Revision 13 10.
Insert the IkN detectors In'accordance with QOP 700-2.
_ v-o 11.
Tech Spec Tables 4.1.2 and 4.2.1 require the following Tests be performed during controlled shutcowns unless performed within the preceding 7 deys.
4.
Operatin; Department shall perform:
(1) high Flux APRM (hvat balance) (QOS 700-6).
uA (2)
IRM High Flux (QOS 700-5).
)
i b.
Instrument Maintenance Department shall perform N 141 (1)
Prior to Startup. Shutdown Instrument 4
d Qg Surveillance (S.T. #41).
/
11, START the turbine bearing lift pumos, run for 10 minutes to check proper operation then STOP them, u n, CAUTION Oo not start the turning gear motor during the performance of the next step.
13.
Olspatch an operator to the turbine oil reservoir and check the auto start of:
a.
Emergr,< Bearing Oil Pump (EBOP).
m b.
Motor S
- on Pump (MSP).
9A c.
Turning
.n.
Oil Pump (TGOP).
p 14 Transfer auxillary power from TR 11-(21) to % 12 (22) as follows:
uA CAUTION Co not allow buses to be in parallel any longer tilan necessary.
a.
Turn tne synchroscope switen ON for Til 12 (22) to Bus 11 (21)-creaker, wA b.
Check that TR 11 and 12 (21 and 22) are synenronized and the voltages are eaual.
w t-CAUT!ON Failure to trio -ne reaker immediately may result in a : ': Of :::n treakers from nign :treula:t g :urrent.
APPROVED 1/0023h MAR 1019e7 JC05R
GGP 2 4-Reelston 13
-.x c.
CLO$t TR 12 (22) to 8us 11 (21) breaker, o
1 (1)
Check for breaker closed' Indication.
'(2)
Check for parallel feed alarm, d.
OPEN TR 11-(21) to Bus 11_ (21) breaker.
ss (1) Check for breaker open Indicatico
'l (2)
Reset parallel fecd alarm.
e.
Turn the synchroscope: switch 0FF for TR 12 (?2) to Sus:11 (21),
_ww f.
. Turn the-synchroscoce' switch ON for TR 12 (22) to Sus-14 (24).
ex
'., g.
Check _that TR il and 12 (21 and 22) are synchronized
~ and..the voltages are equal, uA CAUTION Failure to trip the breaker immedtately may result, in a trip of both breakers from high circLlation current.
h.-
.CLOSE TR 12 (22) to Bus 14 (24)-breaker.-
wA (1)
Check for breaker closed indication.
(2)
. Check for parallel feed alarm.
t..
-OPENTRll~E2i) to Bus 14-(24) breaker.
9A
^
-(l)- ' Check for breaker open indication,
( 2 5.
Reset parallel feed alarm.
j.
Inrn the synchroscope switch'0FF for:TR 12 (22) to Busi14 (24).
~
15..- Continue _-inserting control-rods n the selected rod sequence.
- 16. When-the feedwater master level ~ controller output approaches a zero signal transfer level control to
,the low flow control valve in accordance~with QOP 600-5.
wA
.o
' Request-permt $sion from the load dispatcher to 17.
separate the generator.
w 18.
STOP inserting control rods wr.en generator output is at SC HWe, 9A APPROVED 1/0023h MAR 191987 Q.c.o.s.a.
-Revision 13 19.- Place _the turbine supervisory instruments on Hi speed l
and turbine rps (T-146/T-246)'on trend if desired.
oA a.
Verify that the_ Bypass Valve Opening jack green CLOSED light is.on at panel 901-7 (902-7), and the indicator reads zero, uk CAUTION During the performance of the next steps 1f the OCB's do not trip _wlthin 30 seconds after reaching zero output, manually TRIP-the generator, The generator trip button also trips stator cooling water pumps.
RESET tne 86 relay in the aux, control room to start the stator cooling pump.
20.
With the Lo40 Set reduce generator output to 10 MWe and establish VAR's at zero.
9A 21.
TRIP the turbine with the Remote Trip Button and verify t.ie following:
96
- a. All stop and control valves close.
p o, b.
All intercept valves close, nA c.-
The extraction check valves close and the A0 extraction bypass _ valves open.
w a, d.
Generator OCB's auto trip after 30 seconds titre delay.
ON CAUTION Opening the vacuum breaker at high rpms (1200) imposes excessive loads on the turbine-last stage buckets.
Do not open the vacuum breaker unless it is necessary to quickly reduce turbine rpm and then do not' lower vacuum below 25 inches of Hg (no greater tnan 5 inches of Hg back pressure).
I 2 2.-
Perform turbine overspeed If reautred, n n. _
23.
Notify the Load 01spatcher'that the-turbine is l
tripped and receive orders to OPEN the unit Olsconnects and reclose-the 345 KV ring bus.
L Notify the Eauipment Operator before closing l
the 345 KV OCB's.
us APFAC,iC 1/0023h 'it.R ' ; Q2 1C:5-
%%F 4*o Revision 13 19.
Place the turbine supervisory instruments on H1 speed l
and turbine rpm (T-146/T-246) on trend if desired, uA a.
Verify that the Bypass Valve Opening jack green CLOSED light is on at panel 901-7 (902-7), and the indicator reads zero.
uk CAUTION During the performance of the next steps if the OCB's do not trip within 30 seconds after reaching zero output, manually TRIP the generator.
The generator trip button also trips stator cooling water pumps.
RESET the 86 relay in the aux, control room to start the stator cooling pump, 20.
With the Load Set reduce generator output to 10 MWe ar.d establish VAR's at zero, ys 21.
TRIP the turbine with the Remote Trip Button and verify the following:
w6
- a. All stop and control valves close.
96 b.
All intercept valves close, wA c.
The exttaction check valves close and the A0 ex+raction bypass valves open.
wA d.
Generator OCB's atto trip after 30 seconds time delay.
9A CAUTION Opening the vacuum breaker at high rpms (1200) imposes excessive loads on the turbine last stage buckets.
Do not open the vacuum breaker unless it is necessary to Quickly reduce turbine rpm and then do not lower vacuum below 25 inches of Hg (no greater tnan 5 inches of Hg back pressure).
22.
Perform turbine overspeed if required.
N6 23.
Notify the Load Dispatcher that the turbine is tripped and receive orders to OPEN the unit disconnects and reclose the 345 KV ring bus.
Notify the Eauipment Operator eefore closing tne 345 KV OCB's, us APFsC. :
1/0023h VOR ' c :^^'
OC:5-
OGP 2 4 Revision 13
- 24. Monitor turbine vibration and if vibration is excessive i
through the critical speed range (1200 rpm) open the vacuum breaker, then CLOSE It wnen the turbine is past the critical speed.
_99
- 25. Verify the Motor Suction Pump (MSP) and the Turning Gear Oil Pump (TGOP) automatically start as turbine lube oil pressure decreases to 20 psig.
uk 26.
START the turbine bearing lift pumps before the turbine comes to rest, but not before turbine speed is less than 800 rpm.
u~
- 27. Verify the turning gear motor starts and the turning gear engages as the turbine comes to rest, a
28.
Set the turbine oil cooler outlet temperature at 90'F.
m 29.
Press the vent pushbutton at the hydrogen panel to place the hydrogen system in a vent status.
Set the retometer flow at I scfh.
uA
- 30. OPEN the above seat and below seat drains, os
- 31. Verify that alarm H-9, GEN EXCITER FIELO BRXR OPEN, on panel 901-8(902-8) is energized, u p.
p N
32.
Insert control rods in the selected sequence.
_\\"
here.gd5 33, When reactor power is between 5% to 10% transfer the reactor mode switch to STARTUP as follows:
a.
Verify that the APRM's indicate between 4% to 15% on cotn L
901-5 (902-5) and 901-37 (902-37).
l l
b, Verify that the.IRH's.are on scale-in accordance with 00P 700-2.
vo c.
Transfer the mode switch to STARTUP.-
Yo d.
Switch the IRM's to record.
Vo 34.
Notify Rad-Protection to begin 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> reactor chemistry surveillance.
Name of person notified.
C>' he W
35.
Insert control rods and maintain desired reactor pressure with the pressure setpoint adjust controlling the turbine bypass valve position, vo a.
If steam line pressure' decreases to less than 900 l
psig, perform the following:
APPHOVED l
MAR 191987 1/0023h Q.C.O S R I
r
. =..
-QGP 2 4 Revision 13.
- (1)
Bypass the charcoal adsorber bed by placing the charcoal adsorber mode switch in 8YPASS.
Verify A0 5418 opens 4.it A0_5414: closes.
Yx)
(2)
Start sparge-air. Der QOP 5400-8.
98 Note For the 8 train of Unit One, skip steps 0.35.a.(3) and 0.35.a.(4).
(3)
OPEN the recombiner bypass valve 5499-718.
u-t e s nan to (4)
CLOSE the recombiner train inlet VALVE 5499-75/76.
NOTE Reactor pressure can now be controlled
-as long as_-the inDoard and outboard MSIV's remain open using the turbine pressure setpoint adjust to control the bypass valve (s) position.
Condenser vacuum must be maintained and tne turbine EHC system must remain operating.
In this procedure, the term "under control" means that reactor pressure is stable or decreasing.
If maintenance is to'be performed to equipment that requires that the turbine _EHC system be off, reactor
-pressure must be maintained witnout the turbine bypass valves.
This can ce accomplished by using the= steam from
-decay heat to maintain-turbine seals and~ condensar vacuum.
The point of adding heat to the reactor is on IRH range 7 and above. 1Below range 7 only residual and decay heat _
will affect reactor temperature / pressure.
l' hoPROVED MAR 151957 1/0023h C.C 3 S R l
1
OGP 2 a Revision 13 (1)
Bypass the charcoal adsorber bed by placing the charcoal adsorber mode switch in BYPASS.
Verify A0 5418 opens and A0 5414 closes.
to (2)
Start sparge air per QOP 5400-8.
98 NOTE For the B train of Unit One, skip steps 0.35.a.(3) and 0.35.a.(4).
(3)
OPEN the recomoiner bypass valve 5499-718.
u-s etr-a La (4)
CLOSE the recombiner train inlet VALVE I
5499-75/76.
NOTE Reactor pressure can now be controlled as long as the inboard and outboard MSIV's remain open using the turbine pressure setcoint adjust to control the bypass valve (s) position.
Condenser vacuum must be maintained and the turbine EHC system must remain operating.
this procedure, the term "under
'a
,ntrol" means that reactor pressure is stable or decreasing.
If maintenance is to be performed to equipment that requires that the turbine EHC system be off, reactor pressure must be maintained without the turbine bypass valves.
This can be accomolished by using the steam from decay heat to maintain tureine seals and condenser vacuum.
The point of adding heat to the reactor is on IRM range 7 ano above.
Below range 7 only residual and decay heat will affect reactor temperature /cressure.
APPROVED YAR 1 b 1987 1/0023h 8-0.0 0 $ R
QGP 2-4 Reviston 13 If there is negligible decay heat, the reject flow from the clean-uk system to the condenser may be sufficient to control reactor pressure, 86 careful to not excessively load down the RBCCW system and cause an increase in drywell cooler temperature resulting in high drywell pressure.
~
Additional control rods may have to be inserted to maintain a subcritical reactor as reactor cool. ant temperature decreases.
If the malo steam lines must be depressurized, decay heat must be removed and reactor pressure controlled using a comelnation of RCIC and/or hPCI.
It is important to understand that each subsequent reactor pressure control node is increasingly more difficult to initially stabilize. 00 NOI proceed to the next mode or take equipment out-of-service until there is assurance that reactor pressure can be controlled with ':he systems that remain in service.
36.
If reactor pressure is to be maintained with bypass valves, mark all subsequent steps with N/A and sign off procedure, uA
- 37. Shutting down to a subcritical Hot Standby condition, a.
Start rejecting water from the cleanup system to the condenser or radwaste in preparation for bypass valve closure.
%o b.
Insert control rods until reactor pressure equals 920 psig and the reactor is subcritical by at least three rods.
w 38.
If the main 5tdam lines can remain pressurized (MSIV's open) and reactor pressure can be controlled with the turbine bypass v51ves closed, mark all subsequent stifos N/A and sign off this procedure.
In this stablo condition, the turbine EHC system may be taken out-of-service.
APPROVED MAR 191987 1/0023h Q.C.O.S.R.
l
QGP 2 4 Revision 13 39.
If the outboard MSIV's must be closed, but the steam lines can remain pressurized, perform the following:
a.
START torus cooling in preparation of running HPCI or RCIC.
NA b.
OPEN or verify OPEN main steam line drain valves HO-220-1, MO-220-2, HO-220-3, and HO-220-90A, B, C, 0, wA c.-
CLOSE three outboard MSIV's and verify that reactor pressure is under control.
ux d.
In the following steps if reactor oressure increases, control pressure first with RCIC and if necessary HPCI.
e.
CLOSE fourth outeoard MSIV and monitor reactor pressure.
MA f.
If reactor pressure is under control, the outboard MS!V's may remain closed.
Mark all subsequent steps N/A anro sign off this procedure.
NA 40.
If the main steam lines must ce depressurized, perform the following:
NOTE Turbine steam seals and concenser vacuum will be lost as a result of these steps.
Permit adequate time elapses between each step to assure reactor pressure is under control.
If during the performance of the following steps, reactor pressure can not be controlled with the use of RCIC and HPCI, reverse the
- steps, repressurize the main steam lines, recover turbine seals and condenser vacuum.
Do not allow the high pressure systems to depressurite the reactor to the point of isolating themselves.
Maintain reactor pressure between 600 to 900 PSIG.
APFRovEO 1/0023h
-10 ggg 3 g gg7 OCC59
QGP 8 4 Revision 13 39.
If.the outboard MS!V's must be closed, but the steam lines can remain pressurized, perform the following:
a, START torus cooling in preparation of running HPCI or RCIC.
NA b.
OPEN or verify CPEN main steam line drain valves MO-220-1. MO-220-2, MO-220-3. and MO-220-90A. B. C. O,
.wA c.
CLOSE three outboard MSIV's and verify that reactor pressure is under control, uA 4
d.
In the following steps if reactor pressure increases, control pressure first with RCIC and if necessary HPCI, e,
CLOSE fourth outboard MSIV and monitor reactor pressure.
MA f.
If reactor pressure is under control, the outboard MSIV's may remain closed.
Mark all subsequent steps N/A and sign off this procedure.
HA 40.
If the main steam lines must be depressurized, perform the following:
NOTE Turbine steam seals and cemdenser vacuum will be lost as a result of these steps.
Permit adequate time elapses between each step to assure reactor pressure is under control'.
If during the performance of the following steps, reactor pressure can not be controlled with the use of RCIC and HPCI, reverse the ' steps, repressurize the main steart, lines, recover turbine seals and condenser vacuum.
Do not allow the high pressure systems to depressurize the reactor to the point of isolating themselves.
Maintain reactor pressure between 600 to 900 PSIG.
APFROVED 1/0023h-10-tyg 3 g lgg7 OCCSR
QGP 2 a
+
Revtston 13 4.
Individually CLOSE the main steam line drain orifice bypass valves MO-220-90A, B, C, D.
Verify reactor pressure remains under control, w
b.
Slowly throttle CLOSE0 the outside drain valve MO-220-3.-
Verify reactor pressure remains under control.
u h.
c.
CLOSE the outboard main steam line drain valve MO-220-2.
Verify reactor pressure remains under control.
9A d.
This places the reactor in the hot tandby condition with the rwactor isolated.
Do not take any additional steps to turn equipment over to maintenance until reactor pressure control is assured, al.
Isolate the off-gas system as follows:
a.
CLOSE the primary jet native steam supply valves 3099-93A/B and 3099-94A/8.
uA b.
CLOSE the secondary jet suction valves 5499-276A/B and 5499-277A/S.
9n c.
CLOSE the secondary jet motive steam supply valves 3099-91A/8 and 3099-92A/8.
9A
-d.
Place the off-gas suction valves bypass switch on panel 901-7(902-7) in the BYPASS position, ws e.
OPEN filter building bypass valve 5499-71A.
as f.
If~an extended system shutdown is planned, secure the glycol cooling system per QOP 5400-5.
m g.
Af ter the recomptner vessel has cooled below 350'F,
.lsolate sparge ir per QOP 5400-9.
9A t
42.
If this condition is held _for an extended period of time the pressure may decay more than desired.
To restore pressure perform the following:
a.
Carefully bring the ' reactor critical.
M b.
.Come up to the heating range and-establish a slow heating rate.
uh l
APPROVED l
1/0023h Q.C.O.S.R.
OGP 2 4 Revision 13 c.
Notch rods as necessary to maintain the desired temperature and pressure.
The reactor should reach an equilibrium condition wnere no further rod movements are necessary.
.uA 43.
If a drywell entry is to be made (when primary containment is required) the drywell airlock must be leak rate tested within 3 days of the entry.
If frequent sotries are made, the airlock must be leak rate tested at intervals not to exceed 3 days.
=~
Unit i
Date/ Time
%l tin h%
Completed K bN (Operator)
Reviewed
~ (Shift Engineer)
Reviewed A
w
/ (Operating Engineer)
APPRUVED (final, YAR 191987 1/0023h 12-Q.C.C.S.R.
QGP 2 4 Revision 13 c.
Notch rods as necessary to maintain the desired temperature and pressure.
The reactor should reach an equilibrium condition where no further rod movements are necessary.
4 E
43.
If a drywell entry is to be made (when primary containment is required) the drywell airlock must be leak rate tested within 3 days of the entry.
If frequent entries are made, the airlock must be le&K rate tested at intervals not to exceed 3 days.
Unit i
]
Date/ Time
%lt\\n
\\t % #>
Comoleted K db (Operator)
Reviewed
~ (Shift Engineer)
Reviewed hb
/ (Operating Engineer)
APPRUVED (final)
'A AR 1919871919871/0023h 12-Q. C. C S. R
Commonwealth Edison Company STATION No. 4 Q.U AD-C ITIES
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QAP 1100-T6 Revision 9 l
?EMPORARY CHANGE TO PERMANENT PROCEDURE March 1988 I-REQUEST / TEMPORARY PROCEDURE REQUEST shu TD.au h.
P. m a TITLE %*reo/4,,H.rPong<iecdac../,7JJMPORARY CHANGE NUMBER 80.3 PROCEDURE / BLOCK AFFECTED: Q GP 2 - /
T. C. SUPERSEDED S'9/A Request terminates 30 days from approval date.
dM preco a 'K. v ocy eT:9.s r'.
A u cc e 7 2.s m m CHANGE REQUESTED:
fA a ro < r }> n e.r3c0 n..S tk < r-vy n - de oc a n <.*t'e < Uy Auru.sr)
REASON FOR CHANGE:
NEW
[SUPPt.EMENT REPLACEMENT ALTERNATIVE TX. c ~. h s witch e wk Ts clo n t a G ey 1 w < Kr vr w is h p otky F c om Ruw 2~e ~ s m ['- e n m. cle.
RE00ESTOR,_ 6-L 72 DATE REQUESTED 6'/1/r T Authorized copies held by:
Permanent Procedure Change Noeded? @
Original-Tech Staff Supv.
1.
Cccu. Ctr.T.C. Log 5.
9.
2.
v,' N r o 6.
10.
~
3.
v,z gs o 7.
11.
4.
cA, F e-d,.. % u 8.
12.
Obtatn the appropriate approvals below in accordance with QAP 1100-7.
Refer to OAP 1100-T1 for the accrocriate sionatures for this reauest.
Temporary Procedure or Temporary Change that changes "intfr8Klghl100-Il3 required)
Review and Approval:
TWfspg g
'ROCEDURE EY.A CS 5503 fyg Office Supervisor Tech Staff Supervisor 5503
_ Asst. Supt. Operating Authorization:
Operating Engineer Station Manager Asst. Supt. Maintenance Rad-Chem Supervisor Date Approved Security Admin.
Asst. Supt. Technical Services Tempor yChangethatdoesnotchange"jntent"( neludes unchanged renewals).
=- -
MO J SRO
_ Security Administrator Haster Mechanic Mech. Maint. Foreman f~//o/PP
[0fficeSupervisor
,,_ Rad-Chem Supervisor Master Inst. Mechanic Instrument foreman
/
DATE APPROVED
_ Haster Electrician
_ Elect. Maint. Foreman
,_, Tech S taf f Supv.
Asst. Supt. Tech. Serv.
ON-SITE REVIEW (14 OAYS)
~
Asst. Supt. Operating Tech Staff Supv.
Station Manager
_ Operating Engineer Asst. Supt. Maintenance Rad-Chem Supervisor Security Administrator (QSP)
DATE
[ Asst. Supt.TechnicalServices APPROVED Office Supervisor 176039a (final)
APR 071988
Jn!0 0 M_C "Shif2 Engr, __ LibA
- GP 2 4
,z Cate 5.19-M 4evi s ten 13 lanuary 1987 SHUTOOWN FROM PCNER OPERATION TO A 5 TAM 08Y HOT PRESSURIZE 0 COM0! TION A.
PURPCSE The ourpose of this procedure is to outline the method used to shutdown the unit from a power-generation mode to a condition of low power with the reactor pressure vessel pressurized and the MSIV's either CLOSED or
- OPEN, 6.
REFERENCES 1.
2.
QOP 202-3, Reactor Recirculation System Flow Controller Operation.
3.
QOP 600-8. Removing One of Two Feedwater Regulator Valves from Service.
4 QOP 3200-5, Reactor Feed Pumo Shutdown.
5.
QOP 700-2, Intermediate Range Monitoring Operation (IRM).
6.
QOS 700 Block.
7.
QOP 600-5, Removing the Main Feedwater Regulator from Service.
8.
QOP 700-1, Source Range Monitoring Operaticn (SRM).
9.
QOP $400-8, Starting Sparge Air to the Reccabiner.
10.
QOP 5400-5, Glycol System Shutdown.
11.
QOP 5400-9, Isolating Sparge Air to the Recemeiner.
- 12. 00P 5600-1, Gland Seal System.
13.
QGP 4-1, Control Rod Movements and Control Rod Sequences.
14.
QOP 207-2, Oeclaring Rod worth Minimizer comouter Inoperable.
15.
QOS 250-1, MSIV Closure Monthly Scram Sensor functional Test.
I.
C.
PRCRECUISITES 1
r 1.
Deritssicn has ceen obtaineo from the Lead Olsoatener to snutcown
- ne unit.
l 2.
The Rod Worth Minimtzer is coerational/or a qualifled oerson i5 available to verify rod movements in accordance with the rod secuence chosen orlor to reactor cower reacning 207.. The RW111ay only be bypassed Dy using QCP 207-2.
Appnt, g i /0023h TEMPORARY
- @*[h, ~
PRES
ocEcuRE EXPlRES MAR '. s 1957 s503 3503 E Hy.
0.C'O 5 M n n o ye.
e dev's 'on 13 3.
If this crocacure is terminated at any time during its execution, insert a statement at tne seint of termination as to reason and the title of subsequent orocedure.
Insert N/A in all restining clanks, date, time and sign last page.
Retain terminated procedure in startuo package.
4.
Perform MISV Closure Monthly Scrr S?Mor Functional Test, QOS 250-1.
If no work is to be performed in the MSIV ecos or drywell, a.
this preregulsite may be oyp4ssed if authorized oy an Operating Engineer, h Lldn b cM4 00 Engr.
Oate D.
.P,R,0CEDUR E Initial 1.
If the reactor recirculation flow controller is in EGC or MASTER-AUTO mode, place the controller
\\m in the MASTER-MANUAL mee.
,4 y
2.
Reduce power with the master recirculation flow controller and oeserve the following:
a.
Power reduction rate shall be in accordance with the most recent operating recomendations under NORMAL and emergency conditions, b.
Continuously monitor power decrease on APRM'1.
c.
Maintain Load Set 10% above generator load, d.
On-901-5 (902-5), maintain the EGC settingt in accordance with QOP 5670-1.
e.
Continue to reduce recirculation flow until the Master i
controller reacnes minimum speed (45%), then place the recirculaticn flow controllers in the LOCAL-MANUAL mode In accordance with QOP 202-3.
l '
f.
Continue reducing recirculation flow to 38% oumo speed l
l Maintain the recirculation pumps at equal spetos.
I i
3.
As condensate domineralizer differential pressure aoorcacnes 15 l
ostd, Isolate units one at a time to maintain greater tnan 1500 gorp[
flow through the domineralizers.
N 4
Comrnence inserting control rods in accordance with QGP 4-1 untti tne TUR8 3RESS GEN LCAO REJ STM VLV SYPASS alarm first annunciates (acoroximately.12% cower).
Then reduce l
recirculation flow to minimum with the cotentiometer on the Recirc Pumo Sceed Controllers. Continue to insert ej/
Wr TEMPORARY miPORAFTf
'ROCFOURE EXFIRES ROCEDUE NN APPAO',c.0 I/0023h MAR 131987
- 8. o o m Q. C. O. 5. A
1 Revision 'l S.
At 401. reactor oower, cLOSE the feedwater regulator that
/ d is in MANUAL, inr accordance with QOP 600-8.
_M NSI.E If feedwater Instabilities occur use the second feedwater regulator valve to return the feedwater-system to a stable state.
6.
At apprortsately 4 x 106 lbs/hr feedwater flow and 150 amos on the condensate pumps, STOP a reactor feedwater pump in iccordance with (OP 3200-5 and then STOP a
[/
condensate-pump as follows:
/
Verify that reactor feed pump suction pressure is greater than-a.
350 psig.
b.
Place the stanoby condensate pump selector switch V'#
to 0FF, c.
STOP a condensate pump.
I d.
Select the tripped condensate pump for STAN06Y operation.
./>
/
7.
At approximately 30T. reactor power, verify the Rod Worth H!nimizer (RW) is operational.
The READY and ON-LINE light should both be lit for one of' the two (A or 8) RW's.
CAUTION The RHM may only be bypassed by using 009 207-2.
8.
At a convenient time, below 200 MWe remove feedwater heaters from service.
%c 9.
At approximately 2 x 106 l
lbs/hr feedwater flow.
Observe that the recirculation loop A and 8 flow limit-4.
alarms annunciates.
40 b.
Verify the RW screen displays "8ELOW 207, POWER" i
and "8 LOCKS EMABt.E0*. Any unacknowledged alarms l
should be acknowledged.
Verify that the control
^i l
rod positions are in accordance with the sequence displayed and that there are no insert l'
or vithdrawal errors.
ha
.I (F the RMM 15 inoperacle, an independent verifier is requireo c.
for rod movements.
Enter the verifier's name.
Ver)fIer
{gCRARY rgypangny APPRUViD 1/0023h QFIREs
-3 NN 5503 MAR 191937 6 09y 5
I N%
Q.C.O S R
~
asett'en 13 l
10.
Insert the IRM detectors in accordance ettn CCP 700-2.
.%o 11.
Tech Spec Tables 4.1.2 and 4.2.1 require the following fests be performed during controlled shutdowns unless performed vithin the preceding 7 days, a,
Operating Department shall perform:
(1)
High Flux APRM (heat calance) (OCS 700-6).
(2)
IRM High Flux (QOS 700-5),
b.
Instrument Maintenance Department shall perform:
(1)
Prior to Startuo-Shutdown Instrument Survetilance (S.T. sal).
12.
START the turoine bearing lif t cumos, run for 10 minutes to check proper operation then STOP them.
CAUTION Do not start the turning gear motor during the performance of the next step.
13.
Olspatch an operator to the turbine oil reservoir and cneck the auto start of:
a, (mergency Bearing 011 Pumo (EBOP).
Jo b.
Motor Suction Pump (MSP).
c.
Turning Gear Oil Pumo (TG09).
W 14.
Transfer auxillary power frora TR 11 (21) to TR.12 (221 as follows:
kt[-
CAUTION Oo not allow buses to be in parallel any longer than necessary.
a.
turn the synchroscoce swt ten CN for TR 12 (22) to Sus 11 (21) creaner.
c.
Check tnat TR 11 and 12 (21 and 22) are synchron' zed and tne voltages are equal.
fdb CAUTICH Failure to trio the creaker invnedtately may result in a trio of both breakers from nigh circulating current.
Tc4 APPROVED PRO fC TEMrr,Ny j
a-
" GOC i EX?!9ES %R 191S87 1/0023h ETpfg 75 7 30b Q.C O.S R R 09 9 y
4
- C?
- 4 aseis'en 13 1
c.
CLOSE TR 12 (22) to Sus 11 (21) breaker.
_kd (I)
Check for breaker closed Indication, (2)
Check for parallel feed alars, c.
OPEN TR 11 (21) to Bus 11 (21) breaker.
M (1) Check for breaker open Indicatloo.
(2)
Reset parallel feed alars.
Turn the synchroscoot switch 0FF for TR 12 (22) to e.
But 11 (21).
(g
,_ F CA:-
f.
Turn the synchroscope switch ON for TF. 12 (22) to Bus 14 (24).
~
g.
Check that TR 11 and 12 (21 and 22) are synchronized and the voltages are equal.
Fed C.AUTION Failure to trip the breaker levnediately may result in a trip of both breakers from high circulation current.
h.
Ct.0SE TR 12 (22) to Bus 14 (24.) breaker, b
(1)
Check for breaker closed Indication.
(2)
Check for parallel feed alarm.
r'. n 1.
OPEN TR 11 (21) to Bus la (24) breaker.
(1)
Check for breater open Indication.
(2)
Roset parallel feed alarm.
j.
Turn the synchroscope switch 0FF for TR 12 (22) to Bus 14 (24).
g[c
- 15. Continue Inserting control rods in the selected red sequence.
16.
dhen the feedwater taster level controller outQut accroaches a zero signal transfer level control to tne low flow control valve in accordance with 00P 600-5.
Ym 17.
Request permission frem the load dispatcher to separate the generator.
W 18.
STOP laserting control rods when generator ou tpu t i s a t 50 MWo.
W APPA0vED Ilo023h "EMPORARY C'
'S MCEDURE EXPlREE -
p l g {ggy 5503
- 5D
- w 6.09 13
_AcA_ss
,e Revision 13
~
19.
Place the turbine supervisory instruments on H1 speed and turbine rpa (T-146/T-246) on trend if desired.
[UO l
a.
Verify that the Bypass Valve Opening jack green CLOSED light is on at panel 901-7 (902-7), and the indicator bC/b reads zero, CAUTION Ouring the performance of the next steps if the OC3's do not trip within 30 seconds af ter reaching zero output, manually TRIP the generator.
The generator trip button also trips stator cooling water pumps.
RESET the 86 relay In the aus, control room to start the stator cooling pump.
20.
With the Load Set reduce generator output to 10 % and establish VAR's at zero.
W 21.
TRIP the turbine with the Remote Trip Button,and veriff the following:
- 4. All stop and control valves close, v.o b.
All intercept valves clost.
V-o c.
The extraction check valves close and the A0 extraction bypass valves open.
ko n
.i d.
Generator OCB's auto trip after 30 seconds time delay.
V.o CAUTION Opening the vacuum breaker at high rpms (1200) imposes excessive loads-on the turbine last stage buckets.
Do not open the vacuum breaker unless It is necessary to quickly reduce turbine rpm and then do not lower vacuum below 25 inches of Hg (no greater than 5 inches of Hg back pressure).
22.
Perform turbine overspeed if required.
23.
Notify the Load Olspatcher that the turbine is trloped and receive orders to OPEN the unit disconnects and reclose the 345 KV ring bus.
Notify the Eculement Operator before clostng the 345 KV OCB's.
b TEMPORAFT/
AEFRCVEC 1/0023h
. CUR-WIRES PRocEc ;:-
m !P s 9503 M I. ' U C I
- 6. 0 9 73 280) dos n Q.C 0 5 i
- GP 2 4 Revision 43 24.
Monitor turcine vibration and if vibration is excessive througn the critical speed range (1200 rpm) open the vacuum breater, then CLOSE It when ene turefne is past the critical soeed.
_M A 25.
Verify the notor Suction Pumo (NSP) and the Turning Gear
'~
011 Pumo (TGOP) autca4t1cally start as turbine luce etI u
pressure decreases to 20 pstg.
START the tureine bearing lift pumos before the turbine 26.
comes to rest. but not before turbine speed is less than 800 rpm.
W 27.
Verify the turning gear motor starts and the turning gear j
'(),
',,1 engages u ine cureine co.es to rest.
m 28.
Set the turbine oil cooler outlet temperature at 90'F.
bc 29.
Press the vent pushbu*. ton at the hydrogen panel to place the hydregen system in a vent status.
Set the rotometer flow at I scfh.
P*
e@ p.
Verify that alarm H-9, GEN EXCITER FIELO 6AXA OPEN on 30.
OPEN the above seat and below seat drains.
ffd a
y panel 901-8(902-8) is energized.
w W
3 32.
Insert control rodr a the selected sequence.
b
<ek g
- h ~f AuTio A.L l
r+ may he n
ue.ses.sny
+e ennektly mout A Mede swI A L
[
+
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(* ls y.s s ee ease,t ned. 7X.'s mv.s r be ce9 e+aj Latere i
/
resshe pressere n<cl.as - r.re peig,
33.
when reactor power is eetween 5% to 10% transfer the reactor mode switch to STARTUP as follows:
W
-o$
a.
e$h Verify that the APRM's indicate between at to 15% on both 901-5 (902-5) and 901-37 (902-37).
J Q
fn b.
Verify that the IRM's are on scale in accordance with QCP 700-2.
W c.
.T ansfer the. mode swlten to STARTUP.
W d.
Switch the IRM's to record.
h Mer:{y tel<p feo - 1/14:4 C ed h are ewett eed W
t-e, i
e 34.
Stify Rad-Protection to begin 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> reactor enemistry surveillance.
Name of person notifled.
ftuu W
35.
Insert control rods and maintain desired reactor pressure with the pressure setpoint adjust controlling the turDine bypass valve position.
7Y--
i 4.
If steam line pressure decreases to less than 900 m,,.,,oa wr m" *"
~
.9 l-e 4evisien 13 l
(1)
Sycass the. charcoal adsoreer bed by placing the charcoal adsorcer mode swttch in BYPASS.
Verify A0 5418 opens and A0 5414 closes, (2)
Start soarge air oar QOP 5400-8.
7E-NOTE For the 8 train of Unit One, skip steps 0.35.a.(3) and 0.35.a.(4).
(3)
OPEN the recomeiner bypass valve 5499-718.
_//4 (4)
CLOSE the recomeiner train inlet VALVE 5499-75/76.
s/
NOTE Reactor pressure can now be controlled as long as the incoard and outboard MSIV's remain open using the turbine pressure setpoint adjust to control the bypass valve (s) position. Condenser vacuum must be maintained and the turbine EHC system must remain operating.
In this procedure, the term "under control" means that reactor pressure is stable or decreasing.
If maintenance is to be performed to equipment that requires that the turbine D:C system be off, reactor
~
pressure must be maintained without the turbine bypass valves.
7his can be accomptished by using the steam from decay haat to maintain tureine seals and condenser vacuum.
7he point of adding heat to the reactor is on IRM range 7 and above.
Below range 7, only residual and decay heat will affect reactor temperature / pressure.
CEDURE p9955
~
~
3 APPROVED g09 %
1 093 yg3 MAR !91987 1/0023h
-B-0.0 0 S R
.v Revision 13 If there is negligible decay heat, the reject fluw from the clean-up system to the condenser may be sufficient to control reactor pressure.
Se careful to not excessively load down the R8CCW system and cause an increase in drywell cooler temperature resulting in high drywell pressure.
Additional control rods may have to be inserted to maintain a subcritical reactor as reactor coo knt temperature decreases.
If the main steam lines must be depressurized, decay heat must be removed and reactor prassure controlled using a comelnatten of RCIC and/or HPCI.
It is _lmportant to understand that each subsequent reactor pressure control mode is increasingly more difficult to initially stabilize. 00 N0I proceed to the next mode or take equ _ipment out-of-service until there is assurance that reactor pressure can be controlled with the systems that remain in service.
36.
If reactor pressure is to be maintained with bypass valves, mark all subsequent steps with N/A and $19n off procedure.
4/A 1
f 37.
Shutting down to a subcritical Hot Standby condition.
Start rejecting water from the cleanup system a.
to the condenser or radwaste in preparation for bypass valve closure.
&M b.
Insert control rods until reactor pressure 1
1 equals 920 psig and the reactor is subcritical by at least three rods, j
i 38.
If the main steam lines can remain pressurtzed (MSIV's open) and reactor pressure can te controlled with the turbine bypass valves closed, mark all subsequent steDs N/A and sign off this procedure.
In this stable Condition, the turbine EHC system may be taken out-of-service.
d reupon 79f03my APPROVED
- 1/0023h respo% anM MAR 191987 0 9 9q sgoc"r %" M k
Expragg Q g 9 g p.
5503 60 %
asettion '3
'39.
If the outboard MS!V's must be closed, but thz steam lines can remain pressurtzed, perform the following:
a.
START torus cooling in preparation of running HPCI or RCIC.
b.
OPEN or verify OPEN main steam line drain -
valves MO-220-1. MO-220-2, MO-220-3, and MO-2 20- 90A, 5, C. O.
c.-
CLOSE three outboard MSIV's and verify that reactor pressure is under control.
Y d.
In the following steps if reactor pressure increases, control pressu're first witit RCIC and if necessary HPCI.
e.
CLOSE fourth outboard MS!V and monttor reactor pressure.
Md 1
f.
If reactor pressure 15 under control, the outboard MS!V's may remain closed.
Mark all subsequent steps N/A and $1gn off this procedure, s f 40.
If the main steam Ilnes must be depressurtzed, perform the following:
NOTE Turbine steam seals and condenser vacuum will be lost as a result of these steps.
Permit adequate time elapses between each step to assure reactor pressure is under control.
If during the performance of the following steps, reactor pressure can not be controlled with the use of RCIC and HPCI, reverse the
- steps, repressurize the main steam lines, recover turbine sealsJ nd condenser vacuus.
Do not allow the high pressure systems to capressurize the reactor to the point of isolating themselves.
Maintain reactor pressure between 600 to 900 PSIG.
rgAPORARY EXPfRES SSoy BCLDUh M9 5503 9 APPROVED S Os4 1/0023h ag4g!glgg7
- 0. C. 0 s. R
v hY Ob Revision 13 Individually CLOSE the main steam line drain a.
orifice bypass valves. MD-220 90A, 8, C, D.
Verify reactor pressure remains under control.
_d i
b.
Slowly throttle CLOSED the cutside drain velve T'
MO-220-3.
Verify reactor pressure remains under control.
CLOSE the outboard main steam line drain c.
valve MO-220-2.
Verify reactor pressure remains under control.
g d.
This places the reactor in the hot standby condition with the reactor isolated.
Do not take any additional steps to turn equipment over to maintenance until reactor pressure control 11 assured.
41.
Isolate the off-gas system as follows:
CLOSE the primary jet motive steam supply valves a.
i 3099-93A/B and 3099-94A/8.
r[A b.
CLOSE the secondary jet suction valves 5499-276A/8 and 5499-277A/S.
CLOSE-the secondary jet motive steam supply valves c.
3099-91A/B and 3099-92A/8.
d.
Place the off-gas suction valves bypass switch on panel 901-7(902-7) in the SYPASS position, i
OPEN filter building bypass valve 5499-71A.
e.
f.
If an extended system shutdown is planned, secure the glycol cooling system per QOP 5400-5.
g.
After the recomeiner vessel has cooled below 350*F, h
isolate sparge air psr QOP 5400-9.
42.
If this condition is held for an extended period of time the i
pressure may decay more than desired.
To restore pressure perform the following:
i a.
Carefully bring the reactor critical.
/[A b.
Come up to the heating range and establish I
a slow heating rate.
V
"*Ocg' URg TEMFORARY CXPlRES e goCL'. Uh 5503 APPROVED 4" 0 )
40 %
i l
1/0023h 6 09g MAR 19 $87 l
Q.C.O.S.R.
.a.
4evision 13 c.
% ten rods as necessary to maintain the costred temperature and pressure.
The reactor thould reach an ecullibrium condition enere no further rod movements are necessary.
//_
43.
If a drywell entry is to ce made (when primary I
containment is required) the drywell airlock must be leak rate tested within 3 days of the entry.
If frequent entries are made, the airlock must be leak rate tested at intervals not to exceed 3 days.
Unit I
I Date/ Time 6-M87 / O/30
(
Completed f[u (Operator)
Reviewed
/
/
(Shif t Engtr)(er)'
deviewed M u-
/OperatingEngineer) r-c SSO3 igMFORART EgiRES paoctoum.
%M g,h g
APPROVED (final)
MAR 191987 1/0023h Q.C.O.S.R.
STATION No.4 0.U AD-CITIES r
M UNIT I g,. 2,,
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Unit dA(
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QCP 2 4 Shift Engr.
/Ws 4L, g~ __ _-
Revision 15 Date_ r-7 W r
Octetsr 1988 SHUTfCHN FRON POWER OPERAf!ON TO A W DBY & MES %RIZED CC40!i:CN A.
PURPOSE
~
The purpose of this procedure is to outline the method used to shutdown the unit from a power-generation mode to a condition of low power wtth the reactor pressure vessel pressurized ano the MSIV's either CLOSED or OPEN.
B.
REFtRENCES 1.
00P 5670-1. EGC Settings.
i QOP202-3,ReactorRecirculationSystemflowControllerOperation.
2.
3.
00P 600-8. Removing One of two feedwater Regulator Valves from service.
4 QOP 3200-5, Reactor Fe&d Pump Shutdown.
I 5.
00P 700-2, Intermediate Range Monitoring Operation (IRM).
6.
005 700 Block.
7.
00P 600-5, Removing the Main reeawater Regulator from Service.
8.
QOP 700-1. Source Range Moaltoring Operation (SRM).
9.
QOP 5400-8, Starting Sparge Air to the Recombiner.
- 10. 00P 5400-5, Glycol' System Shutdown.
[
- 11. QOP 5400-9, Isolating Sparge Air to the Recombiner.
- 12. 00P C600-1, Gland Seal System.
- 13. QGP 4-1, Control Rod Hovements and Control Rod Sequences.
14._ Q09 207-2 Rod idorth Minimizer Bypass Control.
C.
PRERE0VISITES i
1.
Permission has been obtained from the load Dispatcher to shutdown the unit.
2.
The Roc Nortt. Minimizer is operational /or a quallfled person _is available_to verify rod movements lo accordance with the rod i
sequence chosen prior to reactor power reaciting 207.. The RWM may only be bypassed by using QOP 207-E.
.,,:pp,g.,u 1/0023h y a j gg
(
GuBAB '
OGP 2 a Revision 15 3.
If this procedure is terminated at any time during its execution, insert a statement at the point of termination as
') reason and the title of subsequent prc,cedure.
Insert N/A in all remaining blants, date, time and sign last page.
Retain ter + a'ad proceoure in startup package.
4.
Perform MISV Closure Monthly Scram Sensor Fune.tional Test, Q05 250-1.
a.
If no work is to be performed in the MSIV room or drywell, this prerequisite may be bypassed if apthorized by an Operating Er.gineer.
A > / a Op Engr.
(
Date D.
PROClDURE Initial 1.
If the reactor recirculation flow controller is in EGC or MASTER-AUTO mode, place the controller G
in the MASTER-MANUAL mode.
CD 2.
Reduce power with the master recirculation flow controller r ?g' and observe the following:
Ju a.
Power reduction rate shall be in accordance with the most recent operating recommendations under NORMAL and emergency conditions, b.
Continuously monitor power decrease on APRM's.
e -e Maintain-Load-Set 107abovegenerator load.
d.
On 901-5 (90:.-5), mairitain the EGC settings in accordance with 00P 5670-1.
e.
Continue to reduce recirculation flow until the Master controller reaches minimum speed (45%), then place the rectrculation flow cor. trollers in the LOCAL-HANUAL node in accorcance with QOP 202-3.
f.
Continue redecing rectreulation flow until total core flow is approximately a5 M1b/hr. Maintain the recirculation pumps at approximately equal speeds.
(SIL 380, rev. 1) 3.
As condensate demineralizer differential pressure approaches
/",,
15 psid, isolate demins one at a time to maintain greater than 1500 gpm flow through each demineralizer.
4.
Verify that the RWH is operable and blocks are enabled to Q~
1001 power.
oo
/\\P PROVED OCT '41999 1/0023h Q.C.O.S.R.
1 I
=-
OGP 2-4 Revision 15 5.
Commence Inserting control rods in accordance with QGP 4-1 until the TURB PRESS GEN LOAD REJ STM VLV BYPASS alarm i
first annunciat.t (approximately 42% power).
Then reduce recirculation flow to minimum with the pctentiometer <a
.f 1
the Recirc Pump Speed Controllers. Continue to insert i
R i
6.
At 40% reactor power, CLOSE the feedwater regulator that k
is in MANUAL in accordance with QOP 600-8.
av NOTE If feedwater instabilities occur use the second feedwater regulator valve to return the feeowater system to a stable state.
6 7
At approximately 4 x 10 lbs/hr feedwater flow and 150 amps on the condensate pump:, STOP a reactor
,/ f feedwater pump in accordance with QOP 3200-5 and then STOP a condensate pump as follows:
a.
Verify that reactor feed pump suction pressure is greater than 350 psig.
b.
Place the standby condensate pump selector switch
[/
to 0FF.
ud c.
STOP a condensate pump.
T>
s.
. r.
d.
Select the tripped condensate pump for STANDBY
(,
operation.-
U 8.-
At approximately 30% reactor power verify the Rod North Minimizer (RWM) is operational.
The READY and ON-LINE light should both be lit for one of the two (A or B) RHM's.
CAUTION i
The RWH may only be bypassed by using QOP 207-2.
9.
At-a convenient time, below 200 MWe remove feedwater heaters [
from service, f2
- 10. At approximately 2 x 106 lbm/hr feedwater flow, a.
Observe that the recirculation loop A and B flow limit alarms annunciates.
APPROVID OCT 'i 938 M.0.M.
1/0023h __
OGP 2-4 Revision 15 b.
Verify the RWH screen displays "BELOW 201. POWER" and " BLOCKS ENABLE 0" Any unacknowledged alarms should be acknowledged. Verify that the control rod positions are M accorcance with the sequence displayed and that there are no insert
/'I or withdrawal errors.
c.
IF the RWH is inoperable, an independent verifter is required for rod novements.
Enter the verifier's U/A name.
Verit t er 11.
Insert the IRH detectors in accordance with OOP 700-2.
12.
Tech Spec Tables 4.1.2 and 4.2.1 reautre the following Tests be performed during controlled shutdowns unless performed within the preceding 7 days, a.
Operating Department shall perform:
(1) 1RH High Flux (005 700-5).
b.
Instrument Maintenance Department shall perform:
(1)
Prior to Startup-Shutdown Instrument sf/
Surveillance (5,T. #41).
N T-13.
START the turbine bearing lift pumps, run for 10 minutes g
to check proper operation then STOP them.
N/
Do not start the turning gear notor during the performance of the next step.
14.
Dispatch an operator to the turbine oil reservoir and check the auto start of:
a.
Emergency Bearing Oil Pump (EBCP).
/
b.
Hotor Suction Pump (HSP).
<O,9
/.-
c.
Turning Gear Oil Pump (TGOP).
'7/r,
APPROV~3 i
OCT '4 E8 1/0023h O. C. O. S. R.
OGP 2 4 Revision 15 15.
Transfer aux 111ary power from TR 11 (21) to TR 12 (22) as y
follows:
C VTION l
Do not allow buses to be in parallel any longer than necessary.
a.
Turn the synchro', cope switch ON for TR 12 (22) to Bus 11 (21) breaker, b
b.
Check that TR 11 and 12 (21 and 22) are synchronized g
and the voltages are equal.
~
CAUTION Failure to trip the breaker immediately may result in a trip of both breskers from high circulating current.
c.
CLOSE TR 12 (22) to,B,us
'.1 (21) breaker.
(1)
Check for breaker closed indication.
(2)
Check for parallel feed alarm.
d.
OPEN TR 11 (21) to Bus 11 (21) breaker.
(1) Check for breaker open indication, e
(2)
Reset parallel feed alarm.
e.
Turn the synchroscope switch Off for TR 12 (22) to Bus 11 (21).
g f.
Turn the synchroscope switch ON for TR 12 (22) to Bus 14 (24).
N g.
Check that TR 11 and 12 (21 and 22) are synchronized and the voltages are equal.
CAUTION failure to trip the breaker immediately may result in a trip of both breakers from high circulation current.
h.
CLOSE TR 12 (22) to Bus 14 (24) breaker.
N (1)
Check for breaker closed indication.
(2)
Check for parallel feed alarm.
AFPROVIJ OCT 4 U38 l
u002n Q.c.o.s.R.
i
- ,4; i
- [WPCRARf
- A NG[ * * !{:WANEN* JCCCElLO(
- gj ;.;-
f
=
4 E lUE S I < 'EMP';4 A R f 3CCCIN RE JElLEST aggggt
- 44 5Jes a Fmn %c Qvca hen To 4
% { h. f b L Jf % L E n 1> hcr; "IEN'i' IMI D6h 8MI l
!* *: '^
i
/
3RCCEDURE BL:Ct m !C*E) MP D-4
?
- . 5 PERSE:ED Request termtaates 30 says from soorova
- 4 e CWANCE 4E!LE!*!)
Cla in e 6 /.' A O. 19 av k<nfor 6. h tf' h,1 ha, A.,1qq r
4 1
4 i
th C'h Alas in
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~
RE ASCN 8'CR lWaNCE NEd
_ SUPPLEMENT REPLACEMENT L atfERNAf;vE j% h,kim enca r & a + hpe hrd Ent-Ghc. w t k 40 J
QAP 1100 T14 femocrary Change Notice Sheets. 94ve eeen precared for esisting procecures and will be 31stributed to the scoroortate manual hoicers.
(NRC Inscectten Report 254/88015 and 255/88015)
CRIGINATOR W-,
DATE RE')UESTEO. I~ w M Autnortzec ceptes nela ey:
Permanent Procedure Change Neeces) j~~
Original-Tech Staff Suov.
1 Com. Ctr. f.C. Log 5.
9.
2.
%J t tru mne _
6.
10.
3.
mRF %
1.
11.
4 LC/ NMD 8.
12.
Obtain the appropriate acDrovals below in accordance with QAP 1100-7 Defer to CAP 1100 71 for tme leerecriate tianatures for thit recuest.
Temporary Procedure or Temocrary Change that changes " intent (QAP 1100-T13 recut es)
Review and aDoreval:
EXPTRES
_ Office Supervisor fecn Staff Superviter g$g g gg %
ass t. Suot. Operat t'ig Authorization:
~
0perating Engineer Station Manager
,_,,,,a s s t. S uo t. Ma i n t e na n c e APPROVED Rad-Chem Supervisor 04te Accroveo
~
,_,5ecurity Admin.
Asst. Suot. Technical Services W 31 M d
EXPIRES
~ EOP Coordinator (For QGAs)
- 0. C. O. S. R.
5758 fts $6189 famoorary Change that coes not enange " intent" (incluces unchangea renewals).
/7/W NWh*
SRO 1 5RO
__,, Security Administrator
_,,,,_,Ma s t e r Me c h a n i c
_ Mech. Maint, foreman Master Inst. Mechanic Instrument Foreman r" 9
'V'7
[0fficeSupervisor
[ Rad-ChemSupervisor DATE APPROVED Haster Electrician Elect. Maint. Foreman fech Staff Supv.
,,_,,,A s s t. S up t. Te c h. Serv.
GSEP Coordinator CN-SITE REVIEW (14 OAYS)
_,,_,,,EOP Coordinator (For CCAs)
~
f>$Wh Asst. Supt. Operating tech Staff Supv.
Station Manager
~@FOPllfdkTl NdnjlRTE M
V & t-4 4*Wo*J 5 - +
1.
CP(N TR 11 (21) to Sus 14 (24) breaker.
/
/'ji/ /J1
/
\\
(1)
Chec( for breater open Indication.
(2)
Roset parallel feed alors.
j.
Turn the synchroscope switch 0FF for TR 12 (22) to Sus 14 (24).
df/[d?,,
f
- 16. Continue inserting control rods in the selected rod sequence.
17.
When the feedwater master level controllar output approaches a zero signal transfer level control to the low flow control valve in acc>rdance with 00P 600-5.
II//h le.
Request permission fros the Load Dispatcher to separate the generator, sdt
/
19.
STOP inserting control rods when generator output is betweet 50 MWe and 300 MWe as determined by the Shif t Engineer or Operating Engineer, r/&_
20.
Place the turbine supervisory Instruments on Hi speed and turbine rpe (T-146/T-246) on trend if desired.
55//h
/
4.
Verify that the 6ypass Valve Opening jack green CLOSED light is on at panel 901-7 (902-7), and the Indicator reads zero.
TEMpogAny f/d PROCEDURE EXplkgS CAUf!0N 5758 06 $9 Ouring the performance of the next steps if the OC8's do not trip within 30 seconds after reaching zero output, manually TRIP the generator.
The generator trip button also trips EXP@gg stator cooling water puers.
RESET t HE g 4% N 86 relay in the aus. Control room to l
start the stator cooling pump.
gy$$
21.
With the Load Set reduce generator output to 10 MWe and establish VAR's at zero.
2/AL
/
22.
TRIP the turbine with the Remote Trip Button and verify the following
&/A i
a.
All stop and control valves close.
c/A!
/
b.
All intercept valves close.
SS/d
/
c.
The extraction check valves close and the A0 extraction bypass valves open, ff/dC
/
i.w <...,
1/0023h p,y 3
)
-. -. ~. -.
J QGP 2 4 Revision 15 I
d.
Generator OCB's auto trip after 30 seconds.
time delay.
- _ge, i
CAVi!ON i
Opening the vacuum breaker at high rpms (1200) imposes excessive loads on the i
turbine last stage buckets.
Do not open the vacuum breaker unless it is necassary to quickly reduce turbine rpm i
i and-then do not lower vacuum below 25 Inches of_Hg (no greater than 5 inches l
of Hg back pressure).
23.
Perform turbine overspeed if required.
d)
-24.
Notify the Load Dispatcher that the turbine is tripped and receive orders to OPEN the unit disconnects and reclose the 345 KV ring bus.
Notify the Eculpment Operator before closing the 345 KV OCB's.
,/
- 25. Monitor turbine vibration end if vibration is excessive through the critical speed range (1200 rpm) open the vacuum
~
breakor, then CLOSE it when the turbine is past the critical y
speed.
- 26. Verify the Motor Suction Pump (MSP) and the Turning Lear
//
011 Pump (TGOP). automatically start as turbine lube oil
(..[%
L,
~ v -.. $
pren fre.cetreaser to* 20 psig,. -
M 4-27.
START the turbine bearing fif t pumps before the turbine g'
comes to rest, but not before turbin'e speed is less than 800 rpm.
28.
Verify the turning gear motor starts and the turning gear 7[ f engages as the turbine comes to rest.
- k. c73Yt(
4 29.
Set the turbine oil cooler outlet temperature at 90'F.
30.
Press the vent pushbutton at the hydrogen panel to place the hydrogen system in a veat status.
Set the rotometer flow at 1-scfh.
31._ OPEN the ebove seat.and below seat drains.
-32.
Verify that alarm H-9. GEN EXCITER FIELD BRKR OPEN, on Y
panel 901-8(902-8) is energized.
uO I
APPROVED OCT ' i 1998.
1/0023h Q.C.O.S.R.
. :.=--.
e QGP 2-4 Revision 15 33.
Insert control rods in the selected sequence.
CAllTION It may be necessary to carefully move tha mode switch to the one o' clock position to assure the scram bypass relays are energized.
This HUST be completed before reactor pressure reaches 850 psig.
- 34. When reactor power is between 5% to 10% transfer g/
the ree.ctor mode switch to STARTUP as follows:
67 a.
Verify that the APRH's indicate between 4% and 12% on both 901-5 (902-5) and 901-37 (902-37).
b.
Verify that the IRM's are on scale in accordance with
(
QOP 700-2.
c.
Transfer the riode switch to STARTUP.
M d.
Switch the IRM's to record.
e.
Verify relays 590-II2A, B, C, and 0 are energized, f?' _._
35.
Notify Rad-Protection to begin 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> reactor chemistry surveillance.
Name of person notified. 6T&F b##NMAd
/' d A. ; a
..
- d6,a leertacentrolvads andmatatain desired r.eactor -.yf
/8 pressure with the pressure setpoint adjust
/'
(
controlling the turbine bypass valve position.
a.
If steam line pressure decreases to less than 900 psig, perform the following:
(1)
Bypass the charcoal adsorber bed by placing
,4 the charcoal adsorber mode switch in BYPASS.
Verify A0 541B opens and A0 5414 closes.
(2)
Start sparge air per QOP 5400-8.
N NOTE For the B train of Unit One, skip steps 0.36.a.(3) and 0.36.a.(4).
(3)
OPEN the recombiner bypass valve 5499-718.
M APPROVD OCT 4 D3B 1/0023h
-B-O C. O. S. R.
QGP 2-4 Revision 15 (4)
CLOSE the recombiner train inlet VALVE
/
5499-75/76.
b)/4
/
NOTE Reactor pressure can now be controlled as long as the inboard and outboard MS!V's remain open using the turbine pressure setpoint adjust to control the bypass valve (s) position. Condenser vacuum must be maintained and the turbine EHC system must remain operating.
In this procedure, the term "under control" means that reactor pressure is stable or decreasing.
Ifmaintenanceisto.peperformedto equipment that requires that-the turbine EHC system be off, reactor pressure must be maintained without the turbine bypass valves.
This can be accomplished by using the steam from decay heat to maintain turbine seals and condenser vacuum.
The point of. adding heat to the reactor is on IRM range 7 and above. Below r.
. m 9.y;..on h retidualaand Necay heat e 4
o.
~
will affect reactor temperature / pressure.
If there is negligible decay heat, the reject flow from-the clean-up system to.
the condenser may be sufficient to control reactor pressure.
Be careful to not excessively load down the RBCCH system and cause an increase in drywell cooler temperature resulting in high drywell pressure.
Additional control rods may have to be inserted to maintain a subtritical reactor as reactor coolant temperature decreases.
APPROVED 4
OCT 3 1988 1/0023h Q.C.O.S.R.
a
l QGP 2-4 l
Revision 15 If the main steam Ilnes must be.
depressurized, decay heat must be renoved and reactor pressure controlled using a co.i.bir.ation of RCIC and/or HPCI.
It is important to understand that each subsequent reactor pressure control mode is increasingly more difficult to initially stabilize. DO NOT proceed to the next mode or take equipment out-of-service until there is assurance that reactor pressure can be controlled with the systems that remain in service.
37.
If reactor pressure is to be maintained with bypass valves, mark all subsequent steps with N/A and sign off procedure.
A/k 38.
Shutting down to a subcritical hot Standt,y condition, a.
Start rejecting water from the cleanup system to the condenser or radwaste in preparation for
/
/ju bypass valve closure.
- M'6 t/ rest. 5j b.
Insert control rods until reactor pressure equals 920 psig and the reactor is subtritical
- $ #,"' ' M' by at least three rods.
M r* -- ~~ - 49. rif *6e min deem Hmes ran remain pressurized.
o (MSIV's open) and reactor pressure can be controlled with the turbine bypass valves closed, mark all subsequent steps N/A and sign off this procedure.
In this stable condition, the turbine EHC system may be taken out-of-service.
s 40.
If the outboard MSIV's must be closed, but the steam lines can remain pressurized, perform the following:
a.
START torus cooling in preparation of running HPCI or RCIC.
/VM _
b.
OPEN or verify OPEN main steam line drain valves HO.220-1, HO-220-2, H0-220-3, and HO-220-90A, B, C, D.
M c.
CLOSE three outboard HSIV's and verify that AM
/
reactor pressure is under control.
d.
In the following steps if reactor pressure increases, control pressure first with RCIC and if necessary HPCI.
e.
CLOSE fourth outboard MSIV and monitor reactor M
pressure.
APPROVED l/0023h ___
_ _ _ _ _ ___ __ ________0m CmOmS1 R._
QGP 2-4 Revision 15 f.
If reactor pressure is under control, the
~
outboard MSIV's may remain closed.
Mark all subsequent steps N/A and sign off this procedure.
N,,,
41.
If the main steam lines must be depressurized, perform the following:
1 NOTE Turbine steam seals and condenser vacuum will be lost as a result of these steps.
Permit adequate time elapses between each step to assure i
reactor pressure is under control.
If during the performance of the 4
following steps, reactor pressure can not be controlled with the use of RCIC and HPCI, reverse the. Steps, repressurize the main steam lines, recover turbine seals and condenser vacuum.
Do not allow the high pressure systems to depressurize the reactor to the point of isolating themselvt:5.
Maintain reactor pressure t4 tween 600 to 900 PSIG.
- a r.< IMWitlually.CLOLthe.maltwsteam I tne Jrain orifice bypass valves, H0-220-90A, B, C, D.
Verify reactor pressure remains under control.
Af b.
Slowly throttle CLOSED the outside drain valve HO-220-3. Verify reactor pressure remains under control.
c.
CLOSE the outboard main steam line drain valve MO-220-2.. Verify reactor pressure remains under control.
A/A-d.
This places the reactor in the hot standby condition with the reactor isolated. Do not take any additional steps to turn equipment over to maintenance until reactor pressure control is assured.
42.
Isolate the off-gas system as follows:
a.
CLOSE the primary jet motive steam supply valves 3099-93A/B and 3099-94A/B.
b.
CLOSE the secondary jet suction Lalves 5499-276A/B and 5499-277H B.
A/N' APPROVED u0023h ggg Q.C.O.S.R.
QGP 2-4 Revision IE i
c.
CLOSE the secondary jet motive steam supply valves 4
3099-91A/B and 3099-92A/B.
_A d.
P1;;e tre off-qn "t'.len va'w es t apan 5 di tch on panel 901-7(902-7) in the BYPASS position.
_d e.
OPEN filter building bypass valve 5499-71A.
/./4 f.
If an extended system shutdown is planned, securs the glycol cooling ;ystem per 00P 5400-5.
AY g.
After the recombiner vessel has cooled belon 350*F, Isolate sparge air per 00P 5400-9.
43 If this condition is held for an extended per!od of time the pressure may decay more than desired.
To restore pressure perform the following:
a.
Carefully bring the reactor critical.
M b.
Come up to the heating range and establish a slow heating rate.
/Yd c.
Notch rods as necessary to maintain the desired temperature ind pressure.
The reactor should reach an equilibrium condition A__
where no further rod movements are necessary.
_MT 44.
If a drywell entry is to be mado (when primary
&..~.
,., rcate vomant wis-renaired).the.dcywal k airlock aust.
be leak rate tested within 3 days of the entry.
If frequent entries are made, the airlock must be leak rate tested at intervals not to exceed 3 days.
[
Unit Date/ Time 9#ea
- 7. /4f9 08CO
/
dMedmrN' compieted (Opgrator)
Reviewed eh
/ ' dhTft Engineer)
APPROVED Reviewed OCT n 4 1938 (Operating Engineer)
(final)
Q.C.O.S.R.
1/0023h,
- r Commonwoolth Edison Company 1
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STATION No. 4 0.U AD-C ITIES 66..
I UNIT ll
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QGP 2-4 Shif t Engr._9 M-9 e Date
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Revision 15 October 1988 SHUTDOWN FROM POWER OPERATION TO A STANDBY HOT PRESSURIZED CONDI110N A.
PURPOSE i
The purpose of this procedure is to outline the method used to shutdown the unit from a power-generation mode to a condition of low power with the reactor pressure vessel prwssurized ano the HS!V's either CLOSED or OPEN.
B.
REFERENCES 1.
QOP 5670-1, EGC Settings.
2.
QOP 202-3, Reactor Rectreulation System flow Controller Operation.
3.
QOP 600-8, Removing One of Two feedwater Regulator Valves from Service.
4.
QOP 3200-5, Reactor feed Pump Shutdown.
5.
QOP 700-2, Intermediate Range Monitoring Operation (IRM).
6.
005 700 Block.
7.
QOP 600-5, Removing the Main feedwater Regulator from Service.
~ 4.8.- d)0P.700-1t-Gouree Range Wonitoring 4peratton~tSRM).
c.
9.
00P 5400-8 Starting Sparge Air to the Recombiner.
- 10. QOP 5400-5, Glycol System Shutdowr.
- 11. QOP 5400-9, Isolating Sparge Air to the Recombiner.
- 12. QOP 5600-1, Gland Seal System.
- 13. QGP 4-1, Control Rod Movements and Control Roo Sequences.
- 14. QOP 207-2, Rod North Minimizer Bypass Control.
C.
PRERE0VISITES 1.
Permission has been obtained from the Load Olspatcher to shutdown the unit.
2.
The Rod North Minimizer is operational /or a qualified person is available to verify rod movements in accordance wl.th the rod sequence chosen prior to reactor power reaching 20%. The RWM may only be bypassed by using QOP 207-2.
APPROVED 1/0023h g.g jogg Q.C.O.S.R.
OGP 2 4 Revision 15 3.
If this procedure is terminated at any time during its executiv.,
insert a statement at the point of termination as to reason and the title of subsequent procedure.
Insert N/A in all remaining blanks, date. time and sign last page.
Retain terminated procedure in startup package.
4.
Perform HISV Closure Monthly Scram Sensor functional Test.
l 005 250-1.
a.
If no work is to be performed in the M51V room or drywell, this prereaulsite may b b, ssed if authorized by an 1
Operating Engineer.
Ei
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,,,,, (,Date D.
PROCEDURE Initial 1..
If the reactor recirculation flow controller is in EGC or MASTER AUTO mode, place the Controller in the MASTER-MANUAL mode.
__ /D 2.
Reduce power with the master recirculation flow controller and observe the following:
/b a.
Power reduction rate shall be in accordance with the most recent operating recommendations under NORMAL and emergency conditions, b.
_ Continuously monitor power decrease on APRM's.
e.s Mairrtain-Load-Se t 107.c tbove Hjenerator ' load.
i-s-
d.
On 901-5 (902-5), maintain the EGC settings in accordance with 00P 5670-1.
e.
Continue to reduce recirculation flow untti the Master controller reaches minimum speed (45%), then place the recirculation flow controllers in the LOCAL-MANUAL mode in accordance with 00P 202-3.
f.
Continue reducing recirculation flow until total core flow is approximately 45 Mlb/hr. Maintain the recirculation pumps at.
approximately ecual speeds.
(SIL 380, rev. 1) 3.
As condensate domineralizer differential-pressure approaches 15 psid, isolate demins one at a time to maintain greater than D
1500 gpm flow through each demineralizer.
/0 4.
Verify that the RHM is operable and blocks are enabled to 100% power.
M APPROVED-OCT '41988 1/0023h Q.C.O.SR.
___.._.._..,.~__._._..:
OGP i'-6 i-Revision 15 j
5.-
Commence inserting control rods in accorcance with QGP 4-1 until the TURB PRESS GEN LOAD REJ STM VLV BYPASS alarm first annunciates (approximately 421 power).
Then reduce
- recirculation flow to minimum with the potentiometer on the Rectre Pump Speed Controllers. Contir e to insert control rods.
M_,
6.
At 407, reactor power, CLOSE the feedwater regulator that is in MANL'AL in accordance with QOP 600-8.
// d 4
NOTE If feedwater instabilities occur use the second feedwater regulator valve to return the feedwater system to a stable state.
7.
At apprortmately 4 x 106 lbs/hr feedwater flow and j
150 amps on the condensate pumps, STOP a reactor feedwater pump in accordance with QOP 3200-5 and then STOP a condensate pump as follows:
kN a.
Verify that reactor feed pump suction pressure is greater than 350 psig.
b.
Place the standby condensate pump selector switch to 0FF.
/dM c.
STOP 3 condensate pump, kW) d.
Select the' tripped condensate pump for STANDBY operation.
__hh i
1 8.
At approximately 30% reactor power, verify the Rod North Minimizer
.I (RWM) is operational.
The READY and ON-LINE Ilght should both be lit for one of the two (A or B) RHH's.
CAUTION B
The RWH may only be bypassed by using 00P 207-2.
4 9.
At a convenient time, below 200 MWe remove feedwater heaters
/*s%
from service.
- 10. -At approximately 2 x 106 lbm/hr feedwater-flow, a.
Observe that the recirculation loop A and B flow limit alarms annunciates.
[M r
APPROVED OCT'41Hs Q.C.O.S.R.
l~
1/0023h -.-
. _.__ _. _ _.. _ _ _. _ _.. _ _. ~._
QGP 2-a Revision 15 b.
Verify the RWM screen displays "BELOW 20% POWER" 4
and " BLOCKS ENABLE 0", Any unacknowledged alarms should be acknowledged. Verify that the control rod positions are in accordance with the sequence displayed and that there are no insert Eh or withdrawal errors.
c.
If the RHH is inoperable, an independent verifter is required for rod movements.
Enter the verifter's dlA _
name.
Verifier I
11.
Insert the IRH detectors in accordance with QOP 700-2.
hko 12,. Tech Spec Tables 4.1.2 and 4.2.1 require-the following Tests be performed during controlled snutdowns unless performed within the i
preceding 7 days.
a.
Operating Department shall perform:
(1)
IRH High Flux (QOS 700-5).
M i
b.
Instrument Halntenance Department shall perform:
(1)
Prior to Startuo-Shutdown Instrument Survell!ance (S.T.-#41).
M
- 13. START the turbine bearing lift pumps, run for 10 minutes to check proper operation then STOP them.
8 10 CAUTION 00 not start the turning gear. motor during the performance of the next step.
14.- Olspatch an operator to the turbine oil reservoir and check the auto start of:~
a.
Emergency Bearing 011 Pump (EBOP).
d'/60
/WM 'I b.
Motor Suction Pump (MSP),
/10 c.
Turning Gear 011 Pump (TGOP).
AW 1
/W PROVD OCT '4 E8 1/0023h- 0. C.0 S. R.
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, - - - - - - -, -.. - - - -. - - - - - ~. - - ~ - - -., - - - -. - - -
QGP 2-4 Revision 15 15.
Transfer auxillary power from TR 11 (21) to TR 12 (22) as follows:
_ [iM CAUTlCN Do not allow buses to be in parallel any longer than necessary, a.
Turn the synchroscope switch ON for TR 12 (22) to b,~^
Bus 11 (21) breaker, b.
Check that TR 11 and 12 (21 and 22) are synchronized and the voltages are equal, bW C A'JT ION Failure to tri'p the breaker imediately may result in a trip of both breakers from high circulating current, c.
CLOSE TR 12 (22) to Bus 11 (21) breaker.
he (1)
Check foi breaker closed indication.
(2)
Check for parallel feto alarm, d.
OPEN TR 11 (21) to Bus 11 (21) breaker.
[V (1) Check for breaker open indication.
s (2)
Reset parallel feed alarm, e.
Turn the synchroscope switch 0FF for TR 12 (22) to bO~N Bus 11 (21).
f.
Turn the synchroscope switch ON for TR 12 (22) to Bus 14 (24).
be g.
Check that TR 11 and 12 (21 and 22) are synchronized p
and the voltages are equal.
CAUTION Failure to trip the breaker intnediately may result in a trip of both breakers from high circulation current, b
h.
CLOSE' TR 12 (22) to Bus 14 (24) breaker.
(1)
Check for breaker closed indication.
(2)
Check for parallel feed alarm.
/,i' P P M D OCT 4 538
,3,
- 0. c. o. s. R.
QGP 2 4 Revisten 15 4
1.
OPEN.TR 11 (21) to Bus 14 (24) breaker, bl (1)
Check for breaker open Indication.
(2)
Reset parallel feed alarm.
j.
Turn the synchroscope switch 0FF for TR 12 (22) to Bus 14 (2a).
/n~4
- 16. Continue inserting control rods in the selected rod sequence.
- 17. When the feedwater master level controller output approaches a zero signal transfer level control to i
the low flow control valve in accordance with 00P 600-5.
4-
- 18. -Regnst permission from the Load Dispatcher to dM separate the generator.
- 19. STOP inserting control rods when generator output is-between 50 MWe and 150 MWe as determined by the Shift Engineer or Operating Engineer.
M
-j 20.. Place the turbine supervisory instruments on HI speed
'l and-turbine rpm (T-146/T-246) on trend if desired.
A S~^_
i i
Verify that the Bypass Valve Opening jack green CLOSED a.
light is on at panel 901-7 (902-7), and the indicator,/ M reads zero.
CAUTION.,
4 " -.
During the performance of the next steps if the OCB's do.not trip within 30 seconds after reaching zero output.
. manually TRIP the generator.
The-i:
generator trip button-also trips stator cooling' water pumps - RESET the 86 relay in the aux. control room to start the stator cooling pump.
r
- 21. With the Load Set reduce generator output to l>
10 MWe and estabitsh VAR's at zero.
i 22.. TRIP the turbine'with the Remote Trip' Button and verify the b following:-
a.
All stop and control val'ves close.
/nw b.
All intercept valves close.
/A^
i c.
The extraction check valves close and the A0 extraction bypass valves open.
/WPROVD j
- 1/0023h OCT ^ i 1288 o
Q.c.o.s. R.
L
OCP 2 4 Revision 15 d.
Generator OCB's auto trip after 30 seconds time delay.
./JQul, C_A,UTION Opening the vacuum breaker at high rpms (1200) imposes excessive loads on the turbine last stage buckets.
Do not open the vacuum breaker unless It is necessary to quickly reduce turbine rpm and then do not lower vacuum below 25 inches of Hg (no greater than 5 inches of Hg back pressure).
J \\ *\\
- 23. Perform turbine overspeed if required.
24.
Notify the Load Dispatcher that the turbine is tripped and receive orders to OPEN the unit disconnects and reclose the 345 KV ring bus.
Notify the Ecuipment Operator before closing
,AbA the 345 KV OCB's.
- 25. Monitor turbine vibration and if vibration is excessive through the critical speed range (1200 rpm) open the vacuum breaktt, then CLOSE it when the turbine is past '.ae critical
.M speed.
- 26. Verify the Motor Suction Pump (MSP) and the Turning Gear Oil Pump (TGOP) automatically start as turbine lube oil
.b prenmeterf enses *to 20 psig,
"- in
- -. s
- 27. START the turbine bearing lift pumps before the turbine cones to rest, but not before turbine speed is less than M
800 rpm.
- 28. Verify the turning gear rotor starts and the turning gear
[nv\\
engages as the turbine comes to rest.
- 29. Set the turbine oil cooler outlet temperature at 90'F.
Sk 30.
Press the vent pushbutton at the hydrogen panel to place the hydrogen system in a vent status. Set the rotometer flow b^
at I scfh.
- 31. OPEN the above seat and below sent drains.
41-1
APPROVD OCT ' ! D38 Q.C.O.SR.
l 1/0023h
-7
m OGP 2-4 Revision 15
-j
\\
33.
Insert control rods in the selected sequence.
__M CAUTION It may be necessary to carefully move the mode switch to the one o' clock position to assure the scram bypass relays are energized.
This MUST be completed before reactor pressure reaches 850 psig.
)
34.
When reactor power is between 5% to 10% transfer the reactor mode switch to STAPTUP as follows:
[tbA a.
Veelfy that the APRH's indicate between 4% and 12% on i
both 901-5 (902-5) and 901-37 (902-37).
b.
Verify that the IRM's are on scale in accordance with 00P 700-2.
COM c.
Transfer the mode sultch to STARTUP.
rd A d.
Switch the IRM's to record.
/e#
e.
Verify relays 590-Il2A, B, C, and 0 are energized.
/A M 35.
Notify Rad-Protection to begin 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> reactor chemistry surveillance. Name of person notifled. // MfdMsd_
ML\\
aa.
s t, d6.9 1msertacmtroit.rnds irideaintatn desired reactor --
....i pressure with the pressure setpoint adjust I
d controlling the turbine bypass valve position, 1
If steam line pressure decreases to less than a.
900 psig, perform the following:
(1)~
Bypass the charcoal adsorber bed by placing the charcoal adsorber mode switch in BYPASS.
Verify A0 5418 opens and A0 5414 closes.
Mi g
.2)
Start sparge air per QOP 5400-8. O 'i.c b MMW
,,go c g pa g t n
NOTE S o 70 csto slo. J S/M LQ 6 P 2
- I Hbd d Wh~ ~
For the B train of Unit One, skip steps 0.36.a.(3) and D.36.a.(4).
(3)
OPEN the recombiner bypass valve 5499-718.
MA j
/iP P R O V D OCT ^ i 3 38 i/0023h o.c.o s.R.
QCP 2-a i
Revision 15 (4)
CLOSE the recombiner train inlet VAL'5E
/JA 5499-75/76.
NOTE Reactor pressure can now be controlled as long as the inboard and outboard M51V's remain open using the turbine presswre setpoint adjust to control the bypass valve (s) position. Condenser vacuum must be maintained and the turbine EHC system must remain operating.
In this procedure, the term "under control" means that reactor pressure is stable or decreasing.
If maintenance is to be performed to equipment that requires that the turbine EHC system be off, reactor pressure must be maintained without the turbine bypass valves. -This can be accomplished by using the steam from decay heat to maintain turbine seals and condenser vacuum.
The point of adding heat to the reactor is on-IRH range 7 and above. Below Tan 9e 7;*-ely residual and decay-heat -
will affect reactor
-temperature / pressure.
If there is negligible decay heat, the-reject flow from the clean-up system to the condenser may be sufficient to control reactor pressure.
Se careful
.to not excessively load down the RBCCW system and cause an increase in drywell cooler-temperature resulting_in high
'drywell pressure.
4 Additional control rods may have to be inserted to maintain a subtritical reactor as reactor coolant temperature decreases.
AFPROVD l
OCT 61998 1/0023h Q.C.O.S.R.
i
4 6-QGP 2-4 Revision 15 If the main steam lines must be depressurized, decay heat must be removed and reactor pressure controlled using a combination of RCIC and/or i
HPCI.
It is important to understand that each subsequent reactor pressure control mode is. increasingly more difficult to initially stabilize. 00 NOT proceed to the next mode or take equipment out-of-service untti there is assurance that reactor pressure can be controlled with the systems that remain in
- service, j
37.
If reactor pressure is to be maintained with bypass valves, mark j
all subsequent steps with N/A and sign off procedure.
AJ A
- 38. Shutting down'to a subcritical Hot Standby condition.
a.
Start rejecting water from the cleanup system to the condenser or radwaste in preparation for bypass valve closure.
AJA b.
Insert control rods until reactor pressure squals 920 psig.and the reactor is subcritical by at least three rods.
MA Q*
r* ~ "* - -39.. If 4he win st+am Haes can remainr pressurized (MSIV's open) and reactor pressure can be controlled with the turbine bypass valves closed, mark all subsequent steps N/A and sign off this procedure.
t In this stable condition, the turbine EHC system may be taken out-of-service, dA 4
- 40. If the outboard MSIV's must be closed, but the steam lines can remain pressurized, perform the following:
i a.
START torus cooling in preparation of running HPCI or RCIC,
/d A -
b.
OPEN or verify OPEN main steam line drain valves 6 220-1 HO-220-2, MO-220-3, and MO-220-90A, B, C D.
N A.
c.
CLOSE three outboard MS!V's and verify that reactor pressure is under control.
N 4-d.
In the following steps if reactor pressure increates, control pressure first with RCIC and if necessary HPCI.
e.
CLOSE fourth outboard MSIV and monitor reactor MA pressure.
)
1/0023h OCT 941938 Q.c.o.S.R.
OGP 2 4 Revision 15 f.
If reactor pressure 15 under control, the outboard MS!V's may remain closed.
Mark all
' subsequent stept N/A and sign off this procedure.
_ rJ A 41.
If the main steam lines must be depressurized, perform the following:
NOTE Turbine steam seals and condenser vacuum will be lost as a result of these steps.
Permit adequate time elapses between each step to assure reactor pressJre is under control.
If during the performance of the following ste'os, reactor pressure can not be controlled with the use of RCIC and HPCI, reverse the steps, repressurize the main steam lines, recover turbine seals and condenser vacuum.
Do not allow the high pressure systems to depressurize the reactor to the point of isolating themselves, Maintain reactor pressure between 600 to 900 PSIG.
- a..', indtvitlually { LOSE,the. main sttam line. drain a
orifice bypass valves. HO-220-90A, B, C. O.
MA Verify reartor pressure remains under control.
b.
Slowly throttle CLOSED the outside drain valve MO-220-3. Verify reactor pressure remains under control.
)J A _
c.
CLOSE the outboard main steam line drain valve HO-220-2. Vertfy reactor pressure
. }A A
remains under control.
d.
This places the reactor in the hot standby condition with the reactor isolated. Do not take any additional steps to turn equipment over to maintenance until reactor pressure control is assured.
42.
Isolate the off-gas system as follows:
a.
CLOSE the primary jet motive steam supply valves 3099-93A/B and 3099-94A/B.
IJ 6 _
b.
CLOSE the secondary jet suction vaives 5499-276Alb and 5499-277A/B.
/J A APPROViD I/0023h 4 OCTP 1938 Q.C.O.S.R.
l SGP 2 4 Revision 15 CLOSE the secondary jet notive ~ steam supply valves
/dA c.
3099-91A/B and 3099-92A/B.
Place the off-gas suction valves bypass switcn or.
AJA__
d, panel 901 7(902-7) in the BYPASS position.
OPEN filter building bypass valve 5499-71A.
DM_
e.
If an extended system shutdown is planned, secure M
f.
the glycol cooling system per QOP 5400-5.
After the recombiner vessel has cooled below 350'F, N A_
g.
isolate sparge air per QOP 5400-9.
if this condition is held for an extended period of time theTo restore pressure perfo 43, pressure may decay more than desired.
the following:
/d b Carefully bring the reactor critical.
a.
Come up to the heating range and establish d/t _
b.
a slow heating rate.
Notch rods as necessary to maintain the c.
The desired temperature and pressure.
reactor should reach an equilibrium condition M
where no further rod movements are necessary.
If a drywell entry is to be made (when primary 44.
the.drywell airlock aust.
teateinmenta s renuired)
If be leak rate tested within 3 days of the entry.
frecuent entries are made, the airlock must be leak rate tested at intervals not to exceed 3 days.
[td O Unit Date/ Time 9.E2 90 ND f
Compieted v 3Lau (Operatori Reviewed t-v ~
(Shlftb ng1neer) i 8
le OCT a s t338 Reviewed (Operating Engineer) 0.C.O.S.R.
j (final)
' 1/0023h
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