ML20032A021

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Forwards Review of Draft Evaluation of SEP Topic VI-7.B, ESF Switchover from Injection to Recirculation Mode. Agrees W/Nrc Conclusion That Plant Design Is Acceptable
ML20032A021
Person / Time
Site: Big Rock Point File:Consumers Energy icon.png
Issue date: 10/21/1981
From: Vincent R
CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.)
To: Crutchfield D
Office of Nuclear Reactor Regulation
References
TASK-06-07.B, TASK-6-7.B, TASK-RR NUDOCS 8110280159
Download: ML20032A021 (14)
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{{#Wiki_filter:-- e. CoRSum8l3 T'# ' %f'9-Power Company 6dgnd ui 9 OCT 2 7198I"$ k General Offices-212 West Michigan Avenue. Jackson MI 40201 * (517) 758-0660 I-October 21, 1981 g u.s. TMs's#0" Q2 e Director, Nuclear Reactor Regulation 9 / h ATT Mr Dennis M Crutchfield, Chief Q Operating Reactors Branch No 5 US Nuclear Regulatory Co= mission Washington, DC 20555 DOCKET 50-155 - LICENSE DPR-6 BIG ROCK POINT PLANT - SEP TOPIC VI-7.B. ESF SWITCHOVER FROM INJECTION TO RECIRCULATION MODE By letter dated June k,1981, the NRC transmitted for comment a dra.'t evaluation of SEP Topic VI-7.B for Big Rock Point. Consumers Power Company has t 'mpleted its review of this evaluation, and has documented that review in the atu 'te d report. Although the result of our review indice.ted agreement with the staff's conclus '.c.1 that plant design is acceptable, we have elected to submit the entire report i order to document more thoroughly the bases for that cenclusion. We trust that the staff vill find this information to be beneficial. I VsdG 'p R A Vincent Staff Licensing Engineer CC JGKeppler, USNRC NRC Resident Inspector jo?5 s j/ 8110280159 811021 PDR ADOCK 05000155 P PDR 1

Pge l of 5 ENCIDCURE REVIEW CF 3EP TOPIC VI-7.B "FFF GWITCHOVER" l BIG ROCK POINT PLANT A. Su -ary of NRC Evaluation Branch Technical Position ICSB 20 states that automatic transfer to the recirculation mode is preferable to manual transfer and should be provided for standard plant designs submitted for review on a generic basis. The Big Rock Point Plant does not have autematic transfer from the ECCS injec-tion mode to the recirculation mode nor is it a standard plant desi n. 6 Accordingly, the NRC evaluated the instrumentation and controls, that are used at the plant to terminate the ECCS injection phase to determine if auto-matic transfer is necessary to protect public health and safety. In performing its evaluation, the NRC utilized 1) Branch Technical Position ICSB 20, 2) IEEE Ftandard 279-1971 and 3) Regulatory Guide 1.62 as tL; most significant t.rrent licensing criteria. Based on its evaluation, the NRC determined that the primary instruments, which are used to determine when to make the manual switchover frem the control room, satisfy the single-failure criterien and are acceptable. B. Review of the NRC Evaluation According to the NRC evaluation, this tepic is applicable to the Big Rock Point Plant since ECCS vater is initially supplied by the fire protection system. Failure to terminate the introduction of fire water in a timely manner vill result in containment flooding. According to the evaluation, such flooding could cause the loss of safety instrumentation and, ultimately, containment itself. The evaluation cites ICSB 20 which states that "A design that provides manual initiation at the system level of the transfer to the recirculation mode, while not ideal, is sufficient and satisfies the intent of IEEE Standard 279 provided that adequate instrumentation and information display are available to the operator so that he can make the correct decisien at the correct time. Furthermore, it should be shown that, in case of operator error, there are sufficient time and information available so that the ocerator can correct the error, and the consequences of such an error are ac cept able. " The Big Rock Point cphere water levels at which ECCS.=v'tchover is to be initiated, and prior to chich an increasing water levet must be limited to protect the sphere itself, are given in the plant's Technical Specifications. As given in the baseo to Technical Specification ll. 3.1.h, the core spray recirculation system is " actuated manually when the water level in the containment rices to Elevation 587 feet". Technical Specification 3.5 " Post-Incident Spray Syatem", Item 3.5.2(b) states " Water addition to tha containment sphere must be manually stopped before the accumulated water level reaches an elevation of 596 feet." I

Page 2 or 9 The above technical specifications are placed into effect in operating procedures COP 8 and E"P 3.3 Stcndard operatinc Procedure 00P 3 " lust-Incident System' requires that the operator " observe the sphere preacure and water level when the enclosure spray system is in operation. When sphere water level is Creater than 587 feet but less than 590 feet, ston addition of water." Emergency Operatin6 Procedures EMP 3 3 " Loss of Reactor Coolant" requires that during ECCS injection resulting from the automatic initiation of reactor core and sphere enclosure sprays, the operator isolate the enclosure sprays when the sphere level reaches 587 feet. In the same pro-cedural step that specifies termination of the enclosure sprays, the pro-cedure informs the operator that sphere water level must not exceed 590 feet elevation to protect the core spray sensors and control circuits. Upon initiating recirculation flow into the reactor ring spray header, the pro-cedure requires that the fire system supply to the sphere reactor core sprays be isolated (by closing Valves VFP P9 and VFP 30, see Attachment #1) to ensure that the 590 feet elevation cannot be attained by the sphere water 1evel. Upon completing this step, injection is terminated and an increase in sphere water level should cease. Drawing M-123 (Attachment' #1) shows two sphere level indication systems. The primary system involves level transmitter LT 3171 which supplies a signal representing sphere level to control room indicator LI 3h00. The secondary system involves four level switches LS 3562, 3563, 356h and 3565 Each switch supplies a level signal to energise its own control room light at its predetermined setpoint. As shown in the drawing, the switches energize their control room lights at sphere water levels of 574 feet, 579 feet, 587 feet and 595 feet. These two indication systems represent redundant and diverse means of ascertaining sphere water level. Drawings E-10h, Ellh Sh 1, WD Th0 Sh 11, WD Th0 Sh 12 and WD 740 Sh 13 (Attachments

  1. 2 through #6, respectively) reveal that each of these systems is supplied by the Clacs lE power system and can, therefore, be supplied by either on-site a-c power, off-site a-c power or on-site d-c power (station batteries).

Given thic ' redundancy and diversity in sphere level indication, as well as the fact that each indication system is Class lE supplied, it is highly improbable that a single-failure vould result in the loss of all Lphere level indication. Emergency Operating Procedure ENP 3.3 requires that either, or both, of these indication systems be utilized to determine when to begin evitchover.to the recirculation mode. It should be noted, however, that the raceway between the level sensors located in the sphere and the readout devices located in the control room is common to both indication systems at certain points along the cable routes. This condition results in the pousibility of certain single-failures such as high energy line breaks (HELB) or fires from affecting both indication systems. Although the probability of a fire occurring simultaneously with a design basis accident is not consistent with the single-failure criterion, it is conceivable (although very unlikely) that a HELB could affect both indication systems during the time at which they are required te provide necessary safety-related information. If an interaction between a HEL3 and the subject raceway is determined as actually possibic, it will be discussed in SEP Tople Ill-L A " Effects of Pipe Break On Structure, Systems and Components Inside Cont.ainment". i

Page 3 of 5 i ? D. As noted in Section A of this review, ICSB 20 states that manual initiation at the system level of the transfer to the recirculation mode is acceptable provided that adequate instrumentation and information display are available to the operator so that he can make the correct decision at the correct time. The Big Rock Point Plant provides the operator with adequate in-strumentation and information such that the ope *ator can initiate recircu-lation at the correct time. As previously mentioned, both the Standard and Emergency Operating Procedures clearly indicate that operator action is required at, or shortly after, the water level reaches Elevation 587 feet. In addition, both procedures indicate that the water level must not exceed Elevation 590 feet. In addition, the operator has at his disposal two redundant systems of level indication to determine when Elevation 587 feet is attained. 3 ~ ICSB 20 also states that in case of operator error, there must be sufficient time and information available so that the operator can correct the error, and the consequences of such an error are acceptable. A complete failure to terminate ECCS injection would conceivably be the worst-case error resulting in damage to the sphere itself. As shown in Attachment #7, the operator has at the minimum approximately one and one-half hours after the time at which the sphere level reaches 587 feet until a level of 590 feet is attained. ( As described in Attachment #7, this duration of one and one-half hours is considered conservatively low due to such high injection flow rates assumed in the calculation.) This one and one-half hour duratien should provide smple time for the operator to discover that he has failed to stop the sphere water level from increasing and take the required remedial action to effect proper ECCS recirculation. Failing to terminate ECCS injection and limit the increasing sphere water level is highly unlikely in the first place since procedural requirements so clearly indicate that operator Getion is required at, or shortly after, the sphere level reaches Elevation 587 By the time the level has reached Ele-vation 587 feet, the operating crev vill have opened the appropriate emer-gency procedure and will have been utilizing the procedure for a number of hours. Nevertheless, no matter how unlikely, should the operator fail to terminate ECCS injection and stop the level rise in accordance with emergency procedures prior to Elevation 590 feet, the sphere integrity vill scill not have been jeopardi:cd. Certain core spray instrumentation still in use at this time such as FT 2162 (which provides indication of core recirculation flow) and level switches LS 3563, LS 356h and LS 3565, however, vill become submerged. Submerging this equipment, however, will not result in a sirnificant impact on the plant since PT 186.which senses pressure between core spray valves MO 7051 and MO 7061.could be used to determine core spray flow. FT 186 is not subject to submergence. In additien, a loarth level switch LS 3562, installed at Elevatien 595 feet, vill still be available for service. ~ Sphere integrity will not be jeopardized until the upper Technical Specifi-cation limit of 596 feet is reached. It is expected that the operator vill have an additional duration in excess of one ana one-half hours by which to terminate injection before Elevation So6 feet is attained. Prior to Ele-vation 596 feet, however, the rising sphere water level vill cause the fourth level switch LS 3562 to provide a control room indication at an Ele-vation of 595 feet. Terminating the ECCS injection flow at this point in time vill be acceptable from a safety standpoint since the integrity of the sphere vill have been maintained.

Pa63 h of 5 i Regarding manual switchover at the system level it should be noted that Regulatory Guide 1.62 states the following:

1) Item C1: "Means should be provided for manual initiation of each protective action (eg, reactor trip, containment isolation) at the system level, regardless of whether means are also pro-vided to initiate the protective action at the component or channel level (eg, individual control rod, individual iso-lation valve)."
2) Item C3: "The switches for manual initiation of protective actions
  • at the system level should be located in the control room and be easily accessible to the operator so that action can be taken in an expeditious manner."
3) Item C5: " Manual initiation of protective actions should depend on the operation of a minimum of equipment consistent with Ite=s 1, 2, 3 and h above."

In addition to the above Regulatory Guide 1.62 items, Paragr aph #1 of the subject NRC evaluation for SEP Topic VI-7.B. states that the safety objective of the NRC requiring certain plants to add some automatic features to assist in the realignment of the ECCS from the injection to the recircu-lation mode is to reduce the number of necessary operator actions. Although the manual method of ECCS switchover from injection to recircu-lation at the Big Rock Point Plar.t is not in strict conformance with Item Cl of Regulatory Guide 1.62, the Consumers Power Company believes that it does meet the intent of Item C5 and of Paragraph #1 of the subject NRC cvaluation of SEP Topic VI-T.B. As described in Emergency Operatius Procedure EMP 3 3, the switchover requires that the following steps be carried out (refer to Attachment #1):

1) Close enclosure spray valves MO 706h and M0 7068,
2) open MO 7066 to admit fire water to the core spray heat exchanger,
3) check M0 7062 closed, b) start ve core spray pump, and
5) close the 6" and h" fire water supply valves in the machine shop VFP 29 and VFP 30.

In accordance with Regulatory Guide 1.62, Item C3, Steps 1 through h above are all acecmplished in the control rocm. Item 5, however, is accomplished locally in the mschine shop to ensure that core recirculation spray can be maintained and the. a<s: injection flow can be terminated outside of the sphere to reduce the pos.;bility of sphere flooding due to a broken spray header inside the sphere. In accordance with Regulatory Guide 1.62, Icem C5, the required operator actions to effect the ECCS switchover are at a minimum. e.*e 1

Pace 5 of 5 C. Conclucien: At the Big Rock Point Plant, the switchover from ECCS injection to recircu-lation is accomplished manually by performing a minimum of operator actions. The primary instruments used to determine when to make the ECCS switchover are diversified, redundant and are supplied by the Clasa 1E power system. Furthermore, these instruments are specifically called out in the plant's operating procedures. In addition, in the case of operttor error and/er equipment malfunction, adequate procedural riotification, instrumentation infor=ation and time existe to allow an operator to make the switchover and limit the increase of sphere water level to an elevation less than 590 feet. Additional time and information also exist prior to the ve.ter level reaching Elevation 596 feet and jeopardizing the sphere itself. As a result of the above, it can be said that the method of ECCS switchover at the Big Rock Point Plant meets the intent of the current licensing criteria as itemized in Gection A of this reviev and is acceptable. Automatic actions are, therefore, not required or necessary to protect the health and safety of the public. / \\ 4

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~. BIG ROCgOJNJ PLANT Ba w < ms-oT 7 2' " CONSUMERS POWER CO. ,. Y F,.[ w. 7Jt -'ai ELECTRIC ENGINEERNG DEPARTMENT ~ APP T l p p',]r .r4 y z g. ;N C A E VO A 4'.' NC JAcnsces. uor.moAse app .g d ['. 6 pe/-- / ~ 4 - 74 cc,==Ectro To f3 -73 .M ~o W D 740 mcEr i 3 APP l

ATTACHMENT T Cen;um ro Powcr Ccmpany Subj:ct Time to Increase BRP Pcg3 1 Nuclear Activities Dept. Sphere Level From 587' to 590' of a Engineering Calculation By ::AT g, Sate 10/2/ BChkd//gBDate n/r/w np PURPOSE: Determine the amount of time it takes during the post-incident ECCS injection phase to increace the Big Rock Point aphere water level from an elevation of 587' to an elevation of 590'. l Assumptions and

References:

1) Amount of sphere free volume available to be filled is 10h,217 gal as determined by JLKuemin,10/6/80, and reviewed by KAToner 10/2/31.
f. abject calculations (3PGs) entitled: " Big Rock Point Containment Volume to 590' elevation".

'2) Case #7 of Consumers Power Company response to LER 80-023 ( AIR

  1. A-NA-80-73) gives a conservatively high estimate of post-incident injection flow rate of 1128 gal / min. Although this case was computed assuming a sphere internal pressure of 10 psig and a reactor pressure of 38 psig, it is considered conservative as 2t assumes that both enclosure sprays are operating, the core ring spray is operating and a break in the core no::le spray piping has occurred slightly upstrean of the reactor allowing all vould-be no::le flow to drop directly into the sphere. Furthermore, it st said be noted that only 23" of the total injection flow is directed toward the preseurized reactor. The flow breakdoin 10 given belev:

574 gym Flov out of no::le break = Steam Drum Flow (cavity) 55 gpm = Flow into core ring sprays 321 gpm = Flov through pri encl cpray 59 gpm = Flow through sec encl spray 119 gpm = 1128 gpm TOTAL INJECTION FLOW = r 10/2/81

Censumers Power Company Subjact Time to Increace one Pago2 Nuclear Activities Dept.

.:ph re Level From 587' to 590' Of 2

Engineering Calculation B y KA,',, mDatelo/2/; Chkdg3g3 ato e./f/pf D AP Time To Increrice fiphere Ievel From 587' to 590': Time = 92.4 min or 1 Hr & 32 Min = g .}}

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