LR-N10-0294, Hope Creek - Response to Request for Additional Information - License Amendment Request: Emergency Diesel Generators a and B Allowed Outage Time Extension: Difference between revisions

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{{Adams
#REDIRECT [[LR-N10-0294, Response to Request for Additional Information - License Amendment Request: Emergency Diesel Generators a and B Allowed Outage Time Extension]]
| number = ML102870101
| issue date = 09/30/2010
| title = Hope Creek - Response to Request for Additional Information - License Amendment Request: Emergency Diesel Generators a and B Allowed Outage Time Extension
| author name = Perry J F
| author affiliation = PSEG Nuclear, LLC
| addressee name =
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000354
| license number = NPF-057
| contact person =
| case reference number = LR-N10-0294
| document type = Letter type:LR, Request for Additional Information (RAI)
| page count = 161
| project =
| stage = Response to RAI
}}
 
=Text=
{{#Wiki_filter:PSEG Nuclear LLC P.O. Box 236, Hancocks Bridge, New Jersey 08038-0236 0 PSEG Nuclear LLC SEP 3 0 2010 LR-NI 0-0294 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Hope Creek Generating Station Facility Operating License No. NPF-57 NRC Docket No. 50-354 10 CFR 50.90
 
==Subject:==
 
==References:==
 
Response to Request for Additional Information  
-License Amendment Request: Emergency Diesel Generators (EDG) A and B Allowed Outage Time (AOT) Extension (1) Letter from PSEG to NRC, "License Amendment Request: Emergency Diesel Generators (EDG) A and B Allowed Outage Time (AOT) Extension," dated March 29, 2010 (2) Letter from NRC to PSEG, "Hope Creek Generating Station -Supplemental Information Needed for Acceptance of Requested Licensing Action Re: Amendment Request Regarding Emergency Diesel Generator Allowed Outage Time Extension (TAC No. ME3597)," dated May 4, 2010.(3) Letter from PSEG to NRC, "Supplemental Information
-License Amendment Request: Emergency Diesel Generators (EDG) A and B Allowed Outage Time (AOT) Extension," dated May 28, 2010 In Reference 1, PSEG Nuclear LLC (PSEG) submitted a license amendment request (H10-03)for the Hope Creek Generating Station (HCGS). The proposed change would modify TS 3/4.8.1,"AC Sources -Operating";
specifically ACTION b concerning one inoperable Emergency Diesel Generator (EDG). The proposed change would extend the Allowed Outage Time (AOT) for the'A' and 'B' EDGs from 72 hours to 14 days. The proposed extended AOT is based on application of the Hope Creek Generating Station (HCGS) Probabilistic Risk Assessment (PRA) in support of a risk-informed extension, and on additional considerations and compensatory actions.In Reference 2, the NRC requested supplemental information to complete the acceptance review of Reference
: 1. The PSEG response to the requested supplemental information was provided in Reference
: 3. Subsequently the NRC provided PSEG a Request for Additional Information (RAI)on the license amendment request. The responses to the non-PRA related RAI questions are provided in Attachment 1 of this letter (excluding the response to question 8.e; the response to this question will be provided in a subsequent submittal).
The responses to the PRA related RAI questions are provided in Attachment 2 of this letter. Attachment 3 provides additional supporting documentation, as discussed in Attachment
: 1. Attachment 4 provides revised regulatory commitments.
0 95-2168 REV. 7/99 Document Control Desk Page 2 LR-N10-0294 If you have any questions or require additional information, please do not hesitate to contact Mr.Jeff Keenan at (856) 339-5429.I declare under penalty of perjury that the foregoing is true and correct.Executed on \ L((Date)Sincerely, John S. Perry Site Vice President Hope Creek Generating Station Attachments (4)S. Collins, Regional Administrator
-NRC Region I R. Ennis, Project Manager -USNRC NRC Senior Resident Inspector
-Hope Creek P. Mulligan, Manager IV, NJBNE Commitment Coordinator
-Hope Creek PSEG Commitment Coordinator
-Corporate Attachment 1 LR-NIIO-0294 REQUEST FOR ADDITIONAL INFORMATION REGARDING PROPOSED LICENSE AMENDMENT EMERGENCY DIESEL GENERATORS A AND B ALLOWED OUTAGE TIME EXTENSION HOPE CREEK GENERATING STATION DOCKET NO. 50-354 By application dated March 29, 2010, as supplemented by letter dated May 28, 2010 (Agencywide Documents Access and Management System (ADAýMS) Accession Nos.ML1 00900458 and ML101590514, respectively), PSEG Nuclear ILC (the licensee) submitted a license amendment request for the Hope Creek Generating Station (HCGS). The proposed amendment would revise the Technical Specifications (TSs) to extend the allowed outage time (AOT) for the "A" and "B" emergency diesel generators (EDGs) from 72 hours to 14 days.The Nuclear Regulatory.Commission (NRC) staff has reviewed the information the licensee provided that supports the proposed amendment and would like to discuss the following issues to clarify the submittal.
: 1. In Attachment 5 of the application dated March 29, 2010, the licensee has identified six regulatory commitments associated with this license amendment request. The commitments relate to compensatory actions which would be applicable during the extended AO T for the. "A" and "B" EDGs. These compensatory actions would be incorporated into the TS Bases concurrent with implementation of the proposed amendment.
The NRC staff requests the following information:
: a. Commitment
#1 requires verification of availability and operability of systems, subsystems, trains, components, and devices required to mitigate the consequences of an accident prior to removing an EDG for extended preventive maintenance.
This is'to be done through TSs, pr'ocedures, or detailed analyses.1. What is the specific scope of plant equipment covered by this commitment?
RESPONSE TO 1.a.1 The scope of equipment covered by this commitment reflects what is credited in the A and B EDG AOT risk assessment (Attachment 4 of the March 29, 2010 LAR). This equipment is listed below.A EDG B EDG HPCI/RCIC HPCI/RCIC C EDG D EDG 1 of 16 Attachment I LR-NIO-0294 This commitment is effectively subsumed by original Commitments 3 and 4 (as revised);therefore PSEG proposes to delete this commitment.
Note that the HCGS Bases already had NRC-approved commitments/compensatory measures for the C and D EDG; PSEG aligned the proposed A and B EDG compensatory measures with the existing C and D measures, where appropriate.
This included utilizing similar terminology.
It was PSEG's intention to combine the compensatory measures for all 4 EDGs into a common list subsequent to the approval of the A and B amendment request (the A and B EDG AOT amendment request did not reflect this planned common list combination in order to facilitate the NRCs review of the A and B proposed change.).
However, following further consideration, PSEG has decided to revise the A and B commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
Deleting Commitment 1 is consistent with this approach.
A revised list of proposed commitments is provided in Attachment 4.Original Commitments 3 and 4 correspond to revised Commitments 1 and 2, respectively, in Attachment 4.2. Is this verification required only when it is planned to remove an EDG from service (as opposed to emergent failure of an EDG) for preventive maintenance, and is it only applicable when exceeding 72 hours? What about corrective maintenance or other inoperable causes?RESPONSE TO 1.a.2 This commitment is effectively subsumed by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
This verification, as implemented by Commitments 3 and 4, is required for planned inoperability or emergent failures of all of the EDGs. Since there will not be separate Technical Specifications for 72 hour and 14 day LCOs, these requirements will be met each time the EDG is removed from service..3. If components in scope are covered by an existing TS limiting condition for operation (LCO), is meeting the LCO and action requirements considered adequate to satisfy the commitment, or does the LCO need to be met without reliance upon the action requirements?
Why are these operability requirements not directly referenced in the TS action requirements for TS 3.8.1.1, rather than referring to the TS Bases and then to the LCOs?RESPONSE TO 1.a.3 This commitment is effectively subsumed by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
The components in scope of this commitment are covered by existing TS LCOs, and the LCO needs to be met without reliance upon the action requirements to satisfy the commitment.
These commitments
/ compensatory measures are appropriately included in the Bases for the following reasons:.10 CFR 50.36 establishes the TS LCO requirements:
2 of 16 Attachment 1 LR-N10-0294 Limiting conditions for operation are the lowest functional capability or performance levels of equipment required for safe operation of the facility.
When a limiting condition for operation of a nuclear reactor is not met, the licensee shall shut down the reactor or follow any remedial action permitted by the technical specifications until the condition can be met.The definition of remedial actions is described in the improved Standard Technical Specifications (NUREG-1433):
ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.The compensatory measures for the EDG AOT extension do not meet the requirements for inclusion in TS as ACTION statements.
These Tier 2 compensatory measures are in support of a PRA based analysis and they are pre-requisites prior to entering the extended AOT supplementing the PRA analysis.
They are not remedial actions to be taken if the LCO is not met, and they do not have specified completion times.Also note that the revised commitments use the TS definition term "OPERABLE", consequently when meeting this commitment the required components will be TS OPERABLE.Compensatory measures are appropriately included in the TS Bases. HCGS Amendment 75 (ADAMS ML01 1770266) dated August 1, 1995, granted the extension of the C and D EDG AOT to 14 days. Amendment 75 included compensatory measures that were part of the TS Bases. Establishing compensatory measures in the TS Bases is consistent with other recent EDG AOT extension amendments (see Section 5.3 of LAR H10-03, ADAMS ML100900458).
Consistent with industry and regulatory precedent, PSEG proposed compensatory measures to be included in the TS Bases. Further, since the HCGS Bases already had NRC-approved compensatory measures for the C and D EDG, PSEG aligned the proposed A and B compensatory measures with the existing C and D measures, where appropriate.
However, as discussed in the response to 1 .a.1, PSEG has decided to revise the A and B commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
If a required compensatory measure is already addressed by TS, then no commitment is needed. If the compensatory measure is not covered by TS, then a commitment is the appropriate method to capture the required measure.4. What components in the scope of this commitment (accident mitigation equipment) are not covered by the TSs and therefore may require procedural or detailed analyses to confirm availability?
RESPONSE TO 1.a.4 This commitment is effectively subsumed by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
As implemented by Commitments 3 and 4, the required systems are covered by TS to confirm operability.
3 of 16 Attachment I LR-NIO-0294
: 5. If a component in the scope of this commitment subsequently becomes unavailable or inoperable during the extended outage period, what TS action is required?RESPONSE To 1.a.5 This commitment is effectively subsumed by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
As implemented by Commitments 3 and 4, the TS action required is the action associated with that piece of equipment.
However, with an EDG also INOPERABLE, an additional assessment must be made ('cascading')
on the effect to the systems supplied by the out of service EDG.Cascading is addressed in PSEG Procedure OP-HC-1 08-115-1001, Exhibit 2: when a single EDG is declared INOPERABLE, evaluate whether other EDG supported equipment on the redundant electrical busses are capable of fulfilling their specified safety function(s) under design-basis accident conditions.
If the redundant components cannot be relied upon to fully satisfy their intended safety function then appropriate conservative action must be taken up to and including entry into T/S 3.0.3, as appropriate.(Reference Generic Letter 91-18)This issue is also discussed in NRC Inspection Manual Part 9900, Appendix C.9.6. Why is the term "available and operable" applied and how is this different than simply requiring a component to be "operable?" RESPONSE TO 1.a.6 This commitment is effectively subsumed by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
As implemented by Commitments 3 and 4, only the"operable" term will be retained.7. It is not clear how detailed analyses are intended to be used to determine the operability/availability of components to satisfy this commitment.
Describe under what conditions such analyses would be needed, and describe such analyses.RESPONSE TO 1.a.7 This commitment is effectively subsumed by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
As implemented by Commitments 3 and 4, TS requirements negate the need for any additional procedural or analysis controls.8. The commitment says Hope Creek "should" verify operability and availability; why isn't this more firmly worded since it is a commitment?
4 of 16 Attachment I LR-N 10-0294 RESPONSE To 1.a.8 This commitment is effectively subsumed by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
As implemented by Commitments 3 and 4, the required actions are more firmly worded.b. Commitment
#2 requires positive measures to preclude testing or maintenance activities on the components in the scope of commitment
#1 (this is assumed to be the meaning of "these systems, ...'). Why isn't the commitment worded more directly, such as "do not perform any voluntary testing or maintenance on otherwise operable components", rather than "positive measure should be provided to preclude ... ?" What constitutes a "positive measure?" Under what conditions could testing or maintenance activities be initiated but remain within the intent of this commitment?
RESPONSE TO 1.b This commitment is effectively replaced by Commitments 3 and 4 (as revised);
therefore PSEG proposes to delete this commitment.
As implemented by Commitments 3 and 4, the required actions are more firmly worded.c. Commitment
#3 requires the second EDG in the same mechanical division to be"capable, operable and available?" 1. How is "capable, operable and available" different than "operable?" RESPONSE to 1.c.1 This commitment will be re-worded as follows: When the A EDG is removed from service for an extended 14 day AOT, the C EDG shall be OPERABLE.
When the B EDG is removed from service for an extended 14 day AOT, the D EDG shall be OPERABLE.As discussed in the response to 1 .a.1, PSEG aligned the proposed A and B EDG AOT compensatory measures with the existing C and D measures, where appropriate.
This included utilizing similar terminology.
The terms "capable" and "available" are used in the existing equivalent compensatory measure for the C and D EDG AOT. The terms are effectively redundant to the term "operable";
therefore, the "capable" and "available" terms have been removed in the revised commitment wording (see revised List of Commitments, Attachment 4 of this submittal).
: 2. The existing TS 3.8.1.1 action e already provides a 2-hour completion time (CT)for the condition of two inoperable EDGs. It appears that this commitment would supercede this 2-hour CT and require an immediate shutdown.
Is this a correct interpretation of this commitment?
If not, please explain the intent of the commitment; if so, why is this not incorporated into required action e?5 of 16 Attachment I LR-N10-0294 RESPONSE To 1.c.2 The commitment, as revised, would require us to verify the second EDG in the same mechanical division to be OPERABLE prior to removing the EDG from service for the extended AOT. Once the EDG is removed from service, if the second EDG were to become INOPERABLE, TS 3.8.1.1 Action e would be invoked with the required 2 hour completion time as is currently required for the 72 hour AOT.d. Commitment
#4 requires minimizing removal of safety systems and important non-safety systems from service.1. What is the scope of systems included in this commitment?
RESPONSE TO 1.d.1 This commitment will be re-worded as follows: When either the A or B EDG is removed from service for an extended 14 day AOT, both HPCI and RCIC shall be OPERABLE.As discussed in the response to 1 .a.1, PSEG has decided to revise the A and B commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment, versus consistency/alignment with the C and D EDG AOT measures (see revised List of Commitments, Attachment 4 of this submittal).
: 2. Explain how this commitment differs from commitments
#1 and #2.RESPONSE To 1.d.2 This commitment will be re-worded as discussed in 1.d.1.3. Offsite power sources are identified in this commitment; doesn't the existing TS 3.8.1.1 actions c and g already address offsite power sources while an EDG is inoperable?
RESPONSE To 1.d.3 In the event one of the required circuits between the offsite transmission network and the onsite Class 1E distribution system became inoperable when one EDG was inoperable, TS 3.8.1.1 Action c would apply.Additionally, this commitment will be re-worded as discussed in 1.d.1.4. What constitute's "minimizing" with regards to this commitment?
Under what conditions, would these systems be permitted to be removed from service but remain within th Ie intent of this commitment?
6 of 16 Attachment I LR-N10-0294 RESPONSE To 1.d.4 This commitment will be re-worded as discussed in 1 .d.1.e. Commitment
#5 requires avoiding testing or maintenance which increases the likelihood of a plant transient.
What is the scope of this commitment and how is the determination made as to the likelihood of a plant transient?
Specifically describe how the decision to initiate testing or maintenance during the extended EDG outage is more restrictive compared to such decisions when the EDG is operable.RESPONSE TO 1.e This commitment will be re-worded as follows: Any component testing or maintenance that increases the likelihood of a plant transient shall be avoided during the extended 14 day AOT. This encompasses work activities categorized as Production Risk.The work week activities are given a production risk screening per PSEG Procedure WC-AA-104. If any activity screens 'in' for a production risk it would be excluded from performance during an extended A and B EDG outage (see revised List of Commitments, Attachment 4 of this submittal.
Original Commitment 5 corresponds to revised Commitment 3 in Attachment 4.).f. Commitment
#5 further states that plant operation should be stable. How is this defined?RESPONSE To M.f This commitment will be re-worded as discussed in 1 .e; the revised wording ensures no work activities will be performed that are a production risk.g. Commitment
#6 recommends not voluntarily entering an extended outage when adverse weather is expected.
What is the scope of "adverse weather?" What constitutes an "expectation" of severe weather (i.e., 10% probability at day 14 of a long range forecast)?
RESPONSE To 1._g PSEG has a previous commitment contained in PSEG Procedure HC.OP-AB.MISC-0001,"ACTS OF NATURE". This commitment requires PSEG to return EDGs to an operable status if Hurricane, Tropical Storm or Coastal flood WARNINGS are issued for the area. The procedure will be enhanced to include a requirement to review the 10 day forecast for Hurricane, Tropical Storm and Coastal flood WARNINGS.
If any of these WARNINGS are forecasted for the period, the EDG extended outage will be deferred.
Based on this information, the frequency of a Weather Related LOOP event during the 14-day EDG AOT would be much less than the nominal frequency used in the baseline Hope Creek PRA model.7 of 16 Attachment 1 LR-N10-0294 Because entry into the 14 day AOT may be due to unplanned EDG failure or could occur in a planned EDG outage when weather forecasts fail to identify severe weather, the conditional probability of 0.25 that severe weather could still occur is included in the risk assessment for the change in risk.Note that original Commitment 6 corresponds to Commitment 4 in Attachment 4.h. On page A-18 of Attachment 4 of the application dated March 29, 2010, four additional compensatory measures are identified related to fire risk results which do not appear in the commitment list. Are these intended to be implemented as commitments?
RESPONSE See Attachment 2 of this submittal 2. TS 3.8.1.1 action g requires restoration of all alternating current (A C) sources in 72 hours. Describe how this required action is applied consistent with a 14-day CT for the EDGs. For example, if an extended CT is entered on one EDG, and subsequently action g is entered due to emergent failures, does the 72 hour CT in action g now supercede the 14-day CT?RESPONSE To 2 The 72 hour CT in action g would supersede the 14 day completion time. For this condition to occur another EDG would become inoperable and one of the TS required off-site circuits would also be lost. Condition g would override the 14 day LCO and we would be required to restore all sources within 72 hours.3. The fire probabilistic risk assessment (PRA) portion of the risk analysis is based on the Individual Plant Examination of External Events (IPEEE) fire evaluation, which has been updated to reflect some new data and practices.
However, the models have not been assessed against the industry consensus standards, and no formal peer review has apparently been done.a. Have there been any external reviews of the fire PRA since the IPEEE? If so, describe the scope and findings of the reviews and the resolution of the identified issues for this application.
RESPONSE See Attachment 2 of this submittal b. What internal reviews have been done to the fire PRA since the IPEEE? Similarly describe the scope and findings of the reviews and the resolution of the identified issues for this application.
RESPONSE 8 of 16 Attachment 1 LR-N 10-0294 See Attachment 2 of this submittal 4. The fire risk evaluation of the configuration of one EDG out of service has not been described in sufficient details in the application.
: a. It is stated that only fires which cause a loss of offsite power are relevant to this application.
With one EDG out of service, increased risk would result from reliance upon the remaining operable safety train of equipment in the event that offsite power is lost to the electrical bus normally powered by the unavailable EDG (i.e., not necessarily a total loss of offsite power). This can occur from either a total loss of offsite power or a loss of offsite power to the one electrical bus. Are both of these scenarios captured in the fire PRA used for this application?
RESPONSE See Attachment 2 of this submittal b. As identified in Table 2-1 of Attachment 2 the supplemental dated May 28, 2010, fire scenarios may be screened below a threshold of I E-6 per year core damage frequency (CDF). For a specific application like the analysis of risk for an EDG outage, some screened scenarios may become more significant.
If screening of scenarios was performed for the baseline PRA, discuss the review of screened fire scenarios to assure that the configuration-specific risk is not underestimated.
RESPONSE See Attachment 2 of this submittal c. Multiple spurious operations have been found to be potentially significant to fire risk, yet these are dispositioned for HCGS only by acknowledging that the treatment of this failure mode in the IPEEE was "rudimentary," and then stating that hot shorts were considered for specific systems only. For this application, how has the licensee assured that a more comprehensive treatment of multiple spurious operations, given the current state of knowledge, would not significantly impact the risk results for fire?RESPONSE See Attachment 2 of this submittal d. The submittal dated May 28, 2010, states that no credit is taken for any suppression.
This seems to be unlikely, since it would mean that any fire precursor event would progress to a large engulfing fire. Clarify exactly how suppression is addressed in the fire PRA.RESPONSE See Attachment 2 of this submittal 9 of 16 Attachment 1 LR-N 10-0294 e. It is not clear if recovery of offsite power following loss due to fire effects is being credited in the analysis.
Clarify how the PRA addresses post-fire repairs and recovery of plant equipment and offsite power supplies.RESPONSE See Attachment 2 of this submittal f. One critical aspect of fire PRA development involves the physical location of cables.One approach when the locations are mostly unknown employs an "exclusion" assumption, that cables are assumed to be located anywhere except where they are known not to be present. Some cable routing information may not be readily available, and assumptions as to the location of such cables may be made to simplify the data collection to support the PRA development.
Are such assumptions employed in the HCGS PRA development?
If so, describe and justify these assumptions, and characterize their significance to this specific application.
RESPONSE See Attachment 2 of this submittal g. Describe any plant-specific features of the HCGS design related to detection, suppression, and mitigation of fires which are credited in the fire PRA. Examples of such items would be credit for water curtains, incipient detection, credit for prompt detection and/or suppression based on administrative controls, or other items that may be relevant to the risk analyses supporting this amendment request.RESPONSE See Attachment 2 of this submittal h. Describe how fire growth and propagation are treated in the HCGS fire PRA.Specifically identify andjustify any assumptions applied, and any fire modeling and codes used RESPONSE See Attachment 2 of this submittal L Fires occurring in the main control room, or other plant areas, which can lead to evacuation of the control room (including evacuation due to loss of functionality, not necessarily habitability, especially for ex-Control Room fires), have sometimes been conservatively modeled in fire PRAs. This can mask the risk importance of out-of-service equipment if such fires are conservatively assumed to be unmitigatable.
In addition, some plants only protect a single safety train of equipment for remote shutdown, so if a control room fire occurred during maintenance on that specific train of equipment, mitigation may not be available.
It is assumed that a control room fire could cause a loss of power to a bus during the diesel generator outage. Identify and 10 of 16 Attachment I LR-N 10-0294 describe the impact of such fires on the configuration-specific risk analyses for the diesel generator outage configurations, addressing any conservatisms in assumptions, and impacts due to plant design of remote shutdown capability.
RESPONSE See Attachment 2 of this submittal 5. The submittal identifies that based on a 14-day weather forecast; the frequency of loss of offsite power (LOOP) due to severe weather is reduced by 75%. Given the uncertainty of weather forecasting over extended periods, and since the licensee does not preclude the use of the 14-day extended CT for unplanned repairs, this reduction in frequency could be introducing a non-conservative bias in the risk results.a. Identify the nominal LOOP frequency applied in the baseline PRA, and the reduced frequency used for this application, and describe how each of these frequencies were calculated.
Justify the assumption of a 75% reduction in severe weather LOOP for a 14-day CT.RESPONSE See Attachment 2 of this submittal b. The offsite power recovery probability is directly dependent upon the cause of the loss of offsite power. Provide the baseline and analysis probabilities for offsite power recovery, and describe how the exclusion of 75% of the severe weather event frequency has been accounted for in the offsite power recovery probabilities.
RESPONSE See Attachment 2 of this submittal c. Provide a sensitivity analysis for the risk results if the nominal loss of offsite power frequency and recovery probabilities are retained for the configuration-specific risk evaluation.
RESPONSE See Attachment 2 of this submittal 6. Given a LOOP and failure of EDGs (station blackout), describe the assumptions for equipment credited in the PRA internal events model for continued core cooling. Include in your response any operator actions necessary, assumptions on environmental conditions given a station blackout, water inventories and makeup sources, and mission times. Does the PRA assume that core damage can be prevented even if AC power is not restored, or is offsite power recovery or diesel generator repair necessary?
RESPONSE 11 of 16 Attachment 1 LR-N10-0294 See Attachment 2 of this submittal 7. Considering that HCGS has four EDGs for a one unit plant, confirm the minimum number of EDGs that are required in each of following scenarios:
(1) loss of offsite power (LOOP) concurrent with a loss-of-coolant accident (LOCA); (2) LOOP while operating at full power; and (3) plant in extended hot or cold shutdown condition.
Provide details on the maximum loads that will be connected to each EDG in each of the above scenarios, assuming a single failure of an EDG.RESPONSE TO 7 Scenario (1) requires any three of the four EDGs, Scenario (2) requires any three of the four EDGs, and Scenario (3) requires two EDGs, one of which has to be the A or B EDG to support A or B RHR pump in shutdown cooling operation.
EDG loading detail is documented in Attachment 3 of this submittal:
PSEG calculation E-9(Q), Standby Class 1 E Diesel Generator Sizing, Revision 8. Calc E-9(Q), Attachment 8, Summary of SDG Loading, shows maximum loading for Scenario (1) and Scenario (2). Scenario (3) loading is bounded by Scenarios 1 and 2.8. Provide the following information relating to the Alternate AC source, proposed as an additional compensatory measure by the licensee in its letter dated May 28, 2010: a. A diagram which shows the connections between Salem Unit 3 Gas Turbine Generator (GTG) and the HCGS safety-related buses.RESPONSE TO 8.a The requested diagram is provided in Attachment 3: PSEG drawing 601701 S 1000- 33, Salem/ Hope Creek Generating Station 500, 13.8, 4 KV Elementary One Line.Additional information is also available on HCGS Single Line Diagram E-0001-0 (Q) and Salem No. 1 and No. 2 Units Generators
& Main Transformers One Line Control Diagram 203000 S 8789-53. (also included in Attachment 3)b. Confirm the estimated total time that will be required to enable the GTG to supply power to the HCGS safety-related buses from the onset of a LOOP condition, considering the various switching actions required.RESPONSE TO 8.b The total time required to enable the GTG to supply power to the HCGS vital buses is estimated to be three hours. This estimate was developed by interviewing operators from Salem and Hope Creek on the time required to execute the applicable portions of the existing approved station procedural guidance on response to a LOOP / SBO event.12 of 16 Attachment 1 LR-N10-0294
: c. Details on a previous occasion, if the GTG has been connected to supply HCGS safety-related buses.RESPONSE TO 8.c There are no previous occasions where the GTG was connected to the HCGS vital buses. The switchyard configuration required to directly connect the GTG (independent of offsite power) to the HCGS vital buses creates a complete loss of offsite power condition to HCGS and is not desirable in any normal plant operating condition.
: d. Details on reliability of the G TG and frequency of maintenance activities performed on the GTG to ensure high reliability.
RESPONSE TO 8.d The Salem Unit 3 GTG is started periodically under Salem Generating Station maintenance plan PM000905 per station procedure S3.OP-SO.JET-0001, Gas Turbine Operation.
This activity verifies Operations' ability to start and load the GTG on a monthly frequency.
From January 2009 to present the following issues were identified related to the operation (32 start / load demands) of the GTG:* Physical damage to connection cable (1 event)* Inadequate procedural guidance (3 events)* Turbine auto-synchronization (TAS) card (2 events) -Only prevented turbine from synchronizing to grid* Miscommunication within the digital control system (1 event)Out of the seven issues shown above, four were due to equipment issues and three were based upon procedural deficiencies.
Also, out of the four that could be classified as equipment issues, two of these events (the TAS card failures) only prevented the turbine jet from synchronizing to the grid. The jet would have been capable of energizing the bus on a "dead bus" event. The remaining two equipment failures that caused a failure to start / trip of the turbine have had corrective actions completed and the turbine has been operating satisfactorily without a reoccurrence of the issue.A comprehensive preventive maintenance plan, based on PCM Templates, is in place to ensure reliable GTG performance.
The preventive maintenance plan includes periodic instrumentation calibrations (8 year frequency), gas turbine relay and protective device calibration (3 year frequency), a GTG start under simulated dead bus conditions (1 year frequency) and an engine replacement
/ overhaul (10 year frequency).
: e. Considering the distance involved from Salem, confirm whether the GTG has been evaluated to ensure its capability to start and run large loads at the HCGS buses expected during a LOOP or station blackout (SBO). Discuss the capability of the GTG to cope with inrush currents associated with energization of large transformers during black start conditions.
RESPONSE TO 8.e 13 of 16 Attachment 1 LR-N10-0294 The response to this question will be provided in a subsequent submittal.
: f. Confirm that the GTG is not credited in Salem design basis events including SBO.RESPONSE TO 8.f The GTG (Salem Unit 3) is not credited in the Salem and Hope Creek Generating Station current design basis events including the SBO Event.9. An AOT extension for 14 days for EDGs "C"and "D" was approved by the NRC on August 1, 1995. In the current license amendment request, the compensatory measures for the proposed AOT extension for EDGs "A" and "B" and the previously approved AOT extension for EDGs "C" and "D" are separately listed in the TS Bases. These compensatory measures should be combined into a common list. Also, based on some of the previously approved extension of AOTs, explain the licensee's plans to implement the following additional compensatory measures: RESPONSE TO 9 As discussed in the response to 1 .a.1, PSEG initially aligned the proposed A and B compensatory measures with the existing C and D EDG AOT measures, where appropriate.
This included utilizing similar terminology.
It was PSEG's intention to combine the compensatory measures for all 4 EDGs into a common list subsequent to the approval of the A and B amendment request (the A and B EDG AOT amendment request did not reflect this planned common list combination in order to facilitate the NRCs review of the A and B proposed change.).
However, following further consideration, PSEG has decided to revise the A and B commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
: a. Maintenance will not be performed in the switchyard that would challenge offsite power availability during the 14-day EDG AOT.RESPONSE TO 9.a As discussed in the response to 1 .a.1, PSEG has decided to revise the A and B EDG AOT commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
The risk assessment for the A and B EDG AOT extension does not rely on, or credit, this compensatory measure. The addition of this commitment would further reduce the already very low risk contribution associated with the EDG AOT extension.
This commitment is effectively covered by the original Commitment 5 (as revised it is Commitment 3 in Attachment 4); i.e., maintenance work in the switchyard categorized as "Production Risk" would not be scheduled during the 14-day A and B EDG AOT.In the event one of the required circuits between the offsite transmission network and the onsite Class 1 E distribution system became inoperable when one EDG was inoperable, TS 3.8.1.1 Action c would apply.b. The system, dispatcher will be contacted once per day and informed of the EDG status along with the power needs of the facility during the 14 day EDG AOT.14 of 16 Attachment 1 LR-N10-0294 RESPONSE TO 9.b As discussed in the response to 1 .a.1, PSEG has decided to revise the A and B EDG AOT commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
The risk assessment does not rely on this measure; therefore it is not required for this AOT request.c, Maintenance will not be performed on the high-pressure core injection and the reactor core isolation cooling systems during the 14 day EDG AOT.RESPONSE TO 9.c This commitment is covered by the Commitment 2 (as revised in Attachment 4)d. Operating crews will be briefed on the EDG work plan and procedural actions regarding LOOP and SBO.RESPONSE TO 9.d As discussed in the response to 1 .a.1, PSEG has decided to revise the A and B commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
The risk assessment does not rely on this measure; therefore it is not required for this AOT request.e. Availability of the GTG will be checked before any EDG entering extended AOT (beyond 72 hours), and every 12 hours thereafter.
RESPONSE TO 9.e As discussed in the response to 1 .a.1, PSEG has decided to revise the A and B commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
The risk assessment does not rely on this measure (as discussed in the response to 8.f); therefore it is not germane to this AOT request. However, as an additional level of defense in depth, a commitment related to the availability of GTG will be included in the A and B EDG AOT request (see Commitment 5 in the revised List of Commitments, Attachment 4 of this submittal).
: 10. Explain the licensee's plan to amend TS 3.8.1.1 to require compensatory measures to be in place before entering 14 days AO T, and verified once per 12 hours, otherwise restore EDG to operable status within next 72 hours, not to exceed 14 days from discovery of failure to meet LCO.RESPONSE TO 10 No additional TS Action requirements are necessary, as discussed in the response to 1 .a.3.Establishing PRA based compensatory measures in the TS Bases is consistent with other recent EDG AOT extension amendments (see Section 5.3 of LAR H 10-03, ADAMS ML1 00900458).
Consistent with industry and regulatory precedent, PSEG proposed 15 of 16 Attachment I LR-NIO-0294 compensatory measures to be included in the TS Bases. Further, since The HCGS Bases already had NRC-approved compensatory measures for the C and D EDG, PSEG aligned the proposed A and B compensatory measures with the existing C and D measures, where appropriate.
However, as discussed in the response to 1 .a.1, PSEG has decided to revise the A and B commitments/compensatory measures to align precisely with the A and B EDG AOT risk assessment.
If a required compensatory measure is already addressed by TS, then no commitment is needed. If the compensatory measure is not covered by TS, then a commitment is the appropriate method to capture the required measure.PSEG's configuration risk management program requires configuration risk assessment of planned maintenance activities prior to initiating any maintenance activity in accordance with 10 CFR 50.65(a)(4).
PSEG procedures provide additional controls to protect the operability of redundant equipment and provide for the evaluations of emergent maintenance required by 10 CFR 50.65.The current Hope Creek TS and 10 CFR 50.65 require sufficient controls on concurrent maintenance and testing activities and require evaluation of the impact of emergent maintenance activities.
16 of 16 Attachment 2 LR-NI0-0294 PRA Related RAI Responses This attachment provides the responses to RAIs that primarily relate the methods and approaches used to assess the risk for the EDG AOT extension.
These responses are referenced in Attachment 1 of this package.
Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Attachment 2, LR-NJO-0294 Responses to PRA -Related RAIs Hope Creek EDG AOTLAR REQUEST FOR ADDITIONAL INFORMATION REGARDING PROPOSED LICENSE AMENDMENT EMERGENCY DIESEL GENERATORS A AND B ALLOWED OUTAGE TIME EXTENSION HOPE CREEK GENERATING STATION DOCKET NO. 50-354 This attachment provides the responses to RAIs that primarily relate the methods and approaches used to assess the risk for the EDG AOT extension.
These responses are referenced in Attachment 1 of this package.1 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR lh. On page A-18 of Attachment 4 of the application dated March 29, 2010, four additional compensatory measures are identified related to fire risk results which do not appear in the commitment list. Are these intended to be implemented as commitments?
RESPONSE TO 1.h The four additional compensatory measures on page A-18 of Attachment 4 are not intended to be implemented as additional commitments.
These compensatory measures have been identified to reduce the risk from fire events during performance of the extended AOT. The four compensatory measures are specifically addressed as follows:* Fire Compensatory Measure 1: Proper standby alignment of the opposite EDG train should be ensured prior to entry into the AOT as this would reduce the contribution from potential pre-initiator errors.Ensuring proper alignment of an operable EDG train is performed on a daily basis. Diesel building equipment operator rounds include verification of proper switch positions and indications, including annunciator status. EDG alarms are annunciated in the Main Control Room and alarm response procedures ensure proper response to unexpected alarms. Commitment
#1 in Attachment 4 of this submittal implements this compensatory measure." Fire Compensatory Measure 2: Besides the protected opposite EDG trains, elective maintenance should be avoided on all SACS and SSW trains that support the protected EDG trains.This compensatory measure is not credited in the risk assessment." Fire Compensatory Measure 3: Minimize general plant testing and electrical maintenance with the EDG out of service.Production risk screening per PSEG Procedure WC-AA-104 includes guidance to preclude voluntary testing and maintenance activities that significantly increase the probability of a plant transient during the extended EDG AOT maintenance window. Commitment
#3 in Attachment 4 of this submittal effectively implements this additional compensatory measure.* Fire Compensatory Measure 4: Increase fire protection measures (e.g., transient material surveillance) for protected EDG train rooms.PSEG Procedures FP-AA-008, "Hotwork" and FP-AA-002, "Impairments" Rev. 0] include controls for managing transient combustible loading and hot work. The Protected Equipment Program ensures that work activities are not normally allowed on the redundant EDG trains. Diesel building equipment operator rounds include verification of proper housekeeping conditions, and Fire Protection personnel inspect the EDG rooms approximately once per day. This compensatory measure is not credited in the EDG AOT risk evaluation.
2 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Attachment 2, LR-NJO-0294 Responses to PRA -Related RAIs Hope CreekEDGAOTLAR Fire Compensatory Measures 1 and 3 are adequately subsumed within the compensatory measures listed in Attachment 4 of this submittal.
Fire Compensatory Measures 2 and 4 are not credited in the EDG AOT risk evaluation.
The incremental risk (ACDF) associated with fire induced scenarios for the EDG A and B AOT extension is very small (<8% of the total calculated change). Therefore, additional compensatory measures directed solely at the fire sequences were not required in the final list of compensatory measures.3 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOT LAR 3. The fire probabilistic risk assessment (PRA) portion of the risk analysis is based on the Individual Plant Examination of External Events (IPEEE) fire evaluation, which has been updated to reflect some new data and practices.
However, the models have not been assessed against the industry consensus standards, and no formal peer review has apparently been done.4 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDGAOTLAR 3a. Have there been any external reviews of the fire PRA since the IPEEE? If so, describe the scope and findings of the reviews and the resolution of the identified issues for this application.
RESPONSE TO 3.a No external reviews of the fire analysis have been performed since the IPEEE. The IPEEE fire analysis was reviewed by a Team from SAIC and Sandia for the NRC. The results of that review are documented in Technical Evaluation Report Hope Creek Revision 1 May 18,1998 (USNRCJCN W6733).As part of the continuing safety enhancements at Hope Creek, a new fire PRA is currently being evaluated to assess its capabilities.
5 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Attachment 2, LR-NJO-0294 Responses to PRA -Related RAIs Hope Creek EDG AOTLAR 3b. What internal reviews have been done to the fire PRA since the IPEEE? Similarly describe the scope and findings of the reviews and the resolution of the identified issues for this application.
RESPONSE TO 3.b No internal reviews of the fire PRA analysis used in this submittal have been performed since the IPEEE. As part of the continuing safety enhancements at Hope Creek, a new fire PRA is currently being evaluated to assess its capabilities.
This effort includes assessing MSOs, cable routing, and other equipment credited in the fire PRA. No significant changes in the assessed fire risk related to these evaluations have been identified.
However, significant conservatisms associated with the fire PRA development project remain in both the fire PRA used for the EDG AOT risk evaluation and in the on-going fire PRA re-evaluation.
6 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Attachment 2, LR-N1O-0294 Responses to PRA -Related RAIs Hope Creek EDG AOTLAR 4. The fire risk evaluation of the configuration of one EDG out of service has not been described in sufficient details in the application.
7 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR 4a. It is stated that only fires which cause a loss of offsite power are relevant to this application.
With one EDG out of service, increased risk would result from reliance upon the remaining operable safety train of equipment in the event that offsite power is lost to the electrical bus normally powered by the unavailable EDG (i.e., not necessarily a total loss of offsite power). This can occur from either a total loss of offsite power or a loss of offsite power to the one electrical bus. Are both of these scenarios captured in the fire PRA used for this application?
RESPONSE TO 4.a Scenarios involving either a total loss of offsite power (LOOP) or a loss of offsite power to one electrical bus are included in the fire PRA used for this application.
A total loss of offsite power due to fire is possible for several compartments in the Turbine Building, Radwaste Area, and Control/Diesel Building and the yard because of the presence of offsite power bus bars or transformer protection relays.There are several fire scenarios that lead to an initiating event and loss of a single AC Bus. Examples of such scenarios include fire in the Class 1E switchgear rooms which are quantified in the fire PRA model. In addition, loss of an electrical Division is also postulated and quantified in the fire PRA model. This is exemplified by the loss of Division I due to a fire in the electrical access room coincident with a LOOP.In two of the diesel compartments (A and B), one of the two bus bar ducts is wrapped with a fire barrier for the postulated fire. Therefore, fires postulated in the A or B diesel compartment will not cause a loss of offsite power, but will cause loss of the diesel in the affected room, and the respective electrical bus.8 Attachment 2, LR-N] 0-0294 Responses to PRA-Related RAIs Hope Creek EDGAOTLAR 4b. As identified in Table 2-1 of Attachment 2 the supplemental dated May 28, 2010, fire scenarios may be screened below a threshold of IE-6 per year core damage frequency (CDF). For a specific application like the analysis of risk for an EDG outage, some screened scenarios may become more significant.
If screening of scenarios was performed for the baseline PRA, discuss the review of screened fire scenarios to assure that the configuration-specific risk is not underestimated.
RESPONSE TO 4.b Although a compartment was screened out if the screening core damage frequency (SCDF) for that compartment was less than 1E-06/yr, potentially risk significant compartments were identified for more detailed probabilistic safety assessment.
The 171 screened fire compartments were examined.
Only one used a LOOP initiating event which was the cable raceway room on the 102' elevation of the Control/Diesel Building.
This fire compartment had a screening core damage frequency (SCDF) of 7.90E-7/yr.
based upon use of conservative screening assumptions (such as failing all components and cables within the compartment).
All screened compartments contribute no more than 0.1% to total fire screened core damage frequency (SCDF) and do not contribute more than 0.1% to fire SCDF involving loss of offsite AC power. Given the implementation of more realistic boundary conditions on the sole fire compartment (cable raceway room on 102' elevation of the Control/Diesel Building), this SCDF is expected to decrease by an order of magnitude when realistic boundary conditions are applied. Therefore, the screened scenarios (only one of which is LOOP related) are found to be not significant for the EDG AOT risk assessment.
9 Attachment 2, LR-N1 0-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR 4c. Multiple spurious operations have been found to be potentially significant to fire risk, yet these are dispositioned for HCGS only by acknowledging that the treatment of this failure mode in the IPEEE was "rudimentary," and then stating that hot shorts were considered for specific systems only. For this application, how has the licensee assured that a more comprehensive treatment of multiple spurious operations, given the current state of knowledge, would not significantly impact the risk results for fire?RESPONSE TO 4.c The HCGS Fire PRA includes Multiple Spurious Operations (MSOs) for the following:
For a fire in a location that might cause spurious operation of one or more SRVs, the highest screening conditional core damage probability (SCCDP) was assigned to the compartment during screening (HCGS IPEEE p. 4-14).A review of other BWR fire PRA model MSO reviews and a review of the BWROG MSO items was performed for HCGS. Additional MSOs such as RHR LPCI flow diversion, MSIV fail to close, and HPCI/RCIC spurious start were evaluated by PSEG for HCGS and found to not significantly impact the results of the EDG AOT risk assessment.
In most cases, those rooms associated with fire induced LOOP events or loss of off-site power to one electrical bus did not also involve the MSOs applicable to HCGS The rooms associated with loss of off-site power events that did involve MSOs applicable to HCGS were evaluated and determined to have a negligible impact on the EDG AOT risk evaluation.
One notable example evaluated was the potential for a HPCI spurious start in three fire scenarios.
A sensitivity analysis was performed using the EDG AOT application specific model where a HPCI MSO basic event was added to the model and assumed to fail HPCI, RCIC, and FW due to a RPV overfill condition with a probability of 1.0. Including the MSO event for spurious HPCI initiation resulted in a negligible change in delta CDF, delta LERF, ICCDP, and ICLERP and therefore had no impact on the EDG AOT risk evaluation.
 
==Reference:==
 
HCGS IPEEE: "Hope Creek Nuclear Station Individual Plant Examination for External Events," Public Service Electric and Gas Company, July 1997.BWROG MSO Items: "BWROG Generic MSO List" 10 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Attachment 2, LR-N]O-0294 Responses to PRA -Related RAIs Hope CreekEDGAOTLAR 4d. The submittal dated May 28, 2010, states that no credit is taken for any suppression.
This seems to be unlikely, since it would mean that any fire precursor event would progress to a large engulfing fire. Clarify exactly how suppression is addressed in the fire PRA.RESPONSE TO 4.d The submittal dated May 28, 2010 states in Table 2-1, under the line item "Fire Scenario Selection and Analysis" element, that fire suppression was assumed to fail, as well as manual fire suppression efforts and fire brigade response, with regard to fire damage evaluation for specific targets within a compartment.
An analysis for fire suppression was performed as part of the HCGS IPEEE and concluded that active fire suppression would not occur in a timely manner such as to preclude damage to targets within a compartment in which the fire has been postulated.
Therefore, since the fire suppression would not be effective in limiting the fire impacts to specific targets within a given compartment, no credit for active fire suppression is included in the HCGS EDG AOT fire risk analysis.With regard to fire precursor event progression to a large engulfing fire, the HCGS Fire PRA model used for the EDG AOT risk assessment utilized the Fire-induced Vulnerability Evaluation (FIVE) methodology (EPRI, 1993b) to define compartments suitable for an efficient and accurate fire assessment of HCGS, accounting for the potential spread of damage owing to fire among rooms. The methodology for defining fire compartments is based on information in the HCGS IPEEE and was not changed for the HCGS Fire PRA model used for the EDG AOT risk assessment.
A fire compartment interaction analysis (FCIA) was performed to establish the combinations of rooms that have boundaries which meet the FIVE criteria [EPRI, 1993b -Paragraph 5.3.6]. This reference lists six criteria suitable for defining a compartment boundary.
In the HCGS study, if all boundaries of a location, often comprised of more than one room, met at least one of the six criteria, then the location was considered a fire compartment for purposes of the HCGS fire PRA analysis.
One of the six FIVE criteria, which was applied in the HCGS FCIA, is "boundaries where automatic fire suppression is installed over combustibles in the exposing compartment on the basis that this will prevent fire spread to the adjacent compartment." Therefore, suppression was considered when establishing appropriate fire compartment boundaries for analysis.
However, this consideration is part of the FIVE methodology, which is an NRC-approved quantitative screening technique for fire analysis.A high hazard area analysis was performed as part of the IPEEE to consider the possibility of, and potential consequences of an extremely large fire, which by its intensity and duration might breach a fire barrier. The Diesel Generator rooms, among others, were considered high hazard areas due to a large quantity of combustibles normally contained within the rooms. A large fire scenario was postulated for each high hazard area to involve all of the fuel contained in the room and be uncontrolled by fire suppression or natural fire limiting phenomena (e.g., oxygen availability).
Determination of the frequency of such a large, uncontrolled fire used the FIVE d6tabase to estimate the fire frequency and by using conservative estimates of the complete failure of 11 Attachment 2, LR-N] 0-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR automatic fire suppression systems, manual fixed fire suppression systems, and fire brigade fire suppression efforts. The fundamental assumption in this analysis is that a large, uncontrolled fire, which can damage fire barriers and structures, can occur only if all fire suppression efforts fail. The possibility of a large fire initiated in the Diesel Generator rooms was included in the fire PRA analysis for this application.
 
==Reference:==
 
EPRI 1993b: Electric Power Research Institute, TR-100370, Revision 1, Fire Induced Vulnerability Evaluation (FIVE) Methodology, September 29, 1993.HCGS IPEEE: "Hope Creek Nuclear Station Individual Plant Examination for External Events," Public Service Electric and Gas Company, July 1997.12 Attachment 2,- LR-N] 0-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Attachment 2,~ LR-N] 0-0294 Responses to PRA -Related RAIs Hope Creek EDG AOTLAR 4e. It is not clear if recovery of offsite power following loss due to fire effects is being credited in the analysis.
Clarify how the PRA addresses post-fire repairs and recovery of plant equipment and offsite power supplies.RESPONSE TO 4.e The Hope Creek fire PRA does not credit any post-fire repair or recovery of plant equipment beyond that credited for the internal events PRA model.In addition, the Hope Creek fire PRA does not credit recovery of offsite power or alignment of the Gas Turbine Generator for mitigating loss of offsite power due to fire effects.13 Attachment 2, LR-N1 0-0294 Responses to PRA-Related RAIs Hope Creek EDGAOTLAR 4f. One critical aspect of fire PRA development involves the physical location of cables.One approach when the locations are mostly unknown employs an "exclusion" assumption, that cables are assumed to be located anywhere except where they are known not to be present. Some cable routing information may not be readily available, and assumptions as to the location of such cables may be made to simplify the data collection to support the PRA development.
Are such assumptions employed in the HCGS PRA development?
If so, describe and justify these assumptions, and characterize their significance to this specific application.
RESPONSE TO 4.f Some cable location data was unknown and "exclusion" assumptions were made for the EDG AOT risk assessment.
A fire compartment interaction analysis (FCIA) was performed for each fire compartment.
The FCIA included a summary of contents of the compartment along with sources of this information (HCGS IPEEE p. 4-7). Cable locations were determined through a combination of information found in plant data management systems and cable drawings, as supplemented through walkdowns (HCGS IPEEE p. 4-18).The lack of knowledge regarding BOP cable routing led to the assumption of a transient at least as severe as an MSIV closure for each compartment in the IPEEE. This assumption was made because of the lack of complete and precise knowledge of the cable inventory in each compartment.
This lack of knowledge uncertainty, therefore, led to this highly conservative assumption.
In general, cable inventories were known at the level of an electrical channel rather than component termination points.The 2003 PRA update reviewed fire initiating events and system impacts in an effort to remove the overly conservative initiating event assignments made in the IPEEE. For example, in the HCGS IPEEE, a fire in the CRD area was modeled as an MSIV Closure, which is overly conservative.
The 2003 PRA update modeled a fire in this area as a Turbine Trip. Use of this initiating event appropriately credits certain BOP equipment that was known to not be impacted by a fire in this area.
 
==Reference:==
 
HCGS IPEEE: "Hope Creek Nuclear Station Individual Plant Examination for External Events," Public Service Electric and Gas Company, July 1997.14 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDGAOTLAR Attachment 2, LR-NJO-0294 Responses to PRA -Related RAIs Hope Creek EDG AOTLAR 4g. Describe any plant-specific features of the HCGS design related to detection, suppression, and mitigation of fires which are credited in the fire PRA. Examples of such items would be credit for water curtains, incipient detection, credit for prompt detection and/or suppression based on administrative controls, or other items that may be relevant to the risk analyses supporting this amendment request.RESPONSE TO 4.cl Although the design and operation of HCGS includes fire detection and suppression equipment and procedures/programs, such as incipient detection and administrative controls for prompt detection and/or suppression, these were not credited in the HCGS fire PRA.For initial screening of fire compartments, the probability of not extinguishing a fire from a source before damage to a component was set to 1.0.The following describes the disposition of detection and fire suppression treatment for the EDG AOT fire risk assessment:
* There are no active fire doors at HCGS. All doors are normally closed unless a fire watch is posted." Automatic fire suppression systems, including C02, were not credited in the HCGS IPEEE fire analysis.* Manual fire suppression (i.e., fire brigade) was not credited in the HCGS IPEEE fire analysis.* No credit was taken for suppression of transient combustible fires.15 Attachment 2, LR-N] 0-0294 Responses to PRA-RelatedRAIs Hope Creek EDGAOTLAR Attachment 2, LR-N1O-0294 Responses to PRA -Related RAIs Hope Creek EDGAOTLAR 4h. Describe how fire growth and propagation are treated in the HCGS fire PRA.Specifically identify and justify any assumptions applied, and any fire modeling and codes used.RESPONSE TO 4.h Introduction A fire growth and propagation analysis was performed as part of the HCGS IPEEE to determine the probability of damaging a target without consideration of suppression and the probability of not extinguishing a fire before damage to a target.The analyses for determining the probability of not extinguishing a fire before damage to a target concluded that active and manual fire suppression would not occur in time to prevent damage to a target. Therefore, active and manual fire suppression was not credited in the fire PRA. See the response to Item 4(g) for additional details.The other assumptions and modeling approaches used are discussed below. This primarily relates to the determination of the probability of damaging a target.Discussion Four types of fire damage mechanisms are modeled: plume effects, ceiling jet effects, hot gas layer effects, and thermal radiation effects. Fire damage calculations are performed using a modified version of the formulation found in the Fire Screening Methodology User Guide, EPRI, 1993 -Attachment 10.4 (HCGS IPEEE p. 4-29). The FIVE fire damage formulation makes the following conservative assumptions and approximations which are also adopted in the HCGS fire analysis:* Exposure fires instantly attain their peak intensities and remain there for the duration of the fire.* Heat release rates (BTU/sec-ft
: 2) are associated with fully involved conditions.
* Targets respond with no delay to temperature changes in the surrounding environment.
* Heat loss to boundaries is 70% of the heat of the fire.* Heat loss by convection in ventilated room fires is neglected.
* Plume and hot gas layer temperature effects are superimposed to determine if targets have been damaged.With the exception of the diesel-generator rooms, liquid pool fires are modeled as unconfined because this maximizes the total heat release (BTU/sec) for a given heat generation flux (BTU/sec per ft 2 of pool surface).
Spacing and drainage in the diesel generator room limits a liquid pool to approximately 100 ft 2.16 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope CreekEDG AOTLAR The IPEEE fire walkdown did not find stored transient combustibles in excess of three gallons per container.
Quantities of five gallons through 20 gallons are investigated in the IPEEE study depending on the compartment.
Because the diesel-generators are sources for larger leaks, a variety of diesel fuel oil liquid pools up to 20 gallons is investigated for the diesel-generator rooms.Cabinet fires are simulated by a fire located at the top of the cabinet with a heat release rate of 1233 BTU/sec which corresponds to a peak heat release rate for control cabinet fires. The analyzed trash can fire is 32 gallons using the maximum heat release rate found in FIVE. Pump fires are treated as unconfined liquid pool fires located at the elevation of the pump using a quantity of fuel that conservatively bounds the amount of lube oil in the pump (usually one or two gallons).Two types of computations are modeled: steady state and pseudo-time dependent.
The former assumes that the fire burns at the peak heat release rate of a material for infinite time (i.e., with no fuel consumption).
The latter is an attempt, using a steady state formulation, to estimate the time to damage target materials versus the time that fire detection and suppression would occur. Fuel consumption is also included in that the fire is assumed to burn at the peak heat release rate until the fuel is completely consumed.Steady state plume effects and ceiling jet effects are modeled using the equations and formulation of FIVE. Both of these conservatively add the heat available in the hot gas layer to either the plume or ceiling jet in order to determine if the target damage criterion has been exceeded.
Steady state thermal radiation effects are modeled using FIVE also.The pseudo-time dependent computations, which calculated the competition between fire damage time and fire suppression time are modeled consistent with FIVE. However, because of the limitations of the FIVE formulation, the following modifications are made to the FIVE Fire Screening Methodology in an attempt to insert slightly more realism into the model." The FIVE model resulted in unrealistically high plume and ceiling jet temperatures, far higher than the flame temperature of the source.Therefore, temperature of the ceiling jet and plume regions is limited to the typical hydrocarbon adiabatic limiting flame temperature which is approximately 2600'F [NFPA, 1995a -Page 1-86]." When calculating the time to damage a target, the FIVE model does not include an estimate of the time that the fuel would be consumed by its own combustion.
In the IPEEE report, this time is estimated from the total quantity of energy in the fuel (BTU) divided by the heat release rate of the fuel (BTU/sec)." The FIVE model does not conserve energy and therefore overestimates the total energy released.
In this work, total energy contained in the fuel, Qtotal (in BTU), is calculated from the specific heat release quantity of the fuel (BTU/Ibm) and the postulated amount of fuel (e.g., five gallons).Physical constants of the fuel are either taken from the FIVE document, Marks Standard Handbook for Mechanical Engineers, or the Handbook of 17 Attachment 2, LR-N] 0-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Chemistry and Physics. Qtotal is conserved by adjusting the energy of the hot gas layer to equal Qtotal minus the energy in the plume minus the energy in the ceiling jet minus the energy in thermal radiation.
FIVE uses the horizontal distance to the target to estimate thermal radiation effects. The actual line of sight distance is used in this model.The modified formulation also led to a difference between how FIVE and the HCGS IPEEE fire analysis methodology use the input quantities.
The HCGS IPEEE fire analysis methodology use of the quantities is described below:* The fuel heat release rate, in BTU/sec per ft 2 of area, is used only in the calculation for total heat release rate (BTU/sec) by multiplying it by the area of the fire. The results are somewhat sensitive to the assumed BTU/sec per ft 2.An extensive set of sensitivity studies helped establish a reasonable heat release rate, which is 120 BTU/sec per ft 2.* A fuel density was used to convert the volume of fuel (given in gallons) to the mass of fuel. The mass of fuel was used only to obtain Qtotal as described above." The specific area (ft 2/gal) of unconfined liquid pools is used to define the total heat release rate (BTU/sec) for unconfined fires. The specific area and the input volume of fuel defines the spill radius which, in turn, defines the extent of effect of the plume. The radius of influence of the plume is assumed to be proportional to the radius of the liquid pool. The specific area also influences the time for fuel consumption (called the burn out time) via the calculation of total heat release rate. An extensive set of sensitivity studies helped establish a reasonable specific area, which is 120 ft 2/gal.Assumptions and Approximations In addition to the assumptions contained within the FIVE methodology, the following additional assumptions are used in carrying out the calculations of fire damage in the HCGS IPEEE fire analysis: " No credit was taken for cabling protected by conduit or enclosed cable trays." When determining damage to target cables from a specific source (in the absence of suppression), if any elevation of cable is calculated to be damaged, all of the cables are assumed to be damaged.These additional assumptions are conservative.
Summary The HCGS IPEEE fire modeling is a modified version of the FIVE methodology with additional conservative assumptions to determine the probability of damage to targets.In addition, the HCGS fire analysis uses the FIVE methods with slightly more realistic 18 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAls Hope Creek EDG AOTLAR modifications to some of the calculational schemes as described above. These modifications are justified in the IPEEE submittal.
Active and manual fire suppression methods are not credited.
See the response to Item 4(g) for additional discussion.
 
==References:==
 
HCGS IPEEE: "Hope Creek Nuclear Station Individual Plant Examination for External Events," Public Service Electric and Gas Company, July 1997.FIVE: EPRI, "Fire-Induced Vulnerability Evaluation (FIVE), "EPRI TR-100370, April 1992.NFPA: National Fire Protection Association, "The SFPE Handbook of Fire Protection Engineering, Second Edition," June 1995.19 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Attachment 2, LR-NJO-0294 Responses to PRA -Related RAIs Hope Creek EDG AOTLAR 4i. (a) Fires occurring in the main control room, or other plant areas, which can lead to evacuation of the control room (including evacuation due to loss of functionality, not necessarily habitability, especially for ex-Control Room fires), have sometimes been conservatively modeled in fire PRAs. This can mask the risk importance of out-of-service equipment if such fires are conservatively assumed to be unmitigatable.(b) In addition, some plants only protect a single safety train of equipment for remote shutdown, so if a control room fire occurred during maintenance on that specific train of equipment, mitigation may not be available.
It is assumed that a control room fire could cause a loss of power to a bus during the diesel generator outage.Identify and describe the impact of such fires on the configuration-specific risk analyses for the diesel generator outage configurations, addressing any conservatisms in assumptions, and impacts due to plant design of remote shutdown capability.
RESPONSE TO 4.i (a) For fire scenarios that lead to evacuation of the control room, the Hope Creek PRA credits accident mitigation from the Remote Shutdown Panel (RSP). Operation from the RSP is directed by procedure HC.OP-IO.ZZ-0008(Q), "SHUTDOWN FROM OUTSIDE CONTROL ROOM". Failure of the operators to mitigate accidents from the RSP is modeled with a human error probability (HEP) of 6E-2 based on information from the Hope Creek IPEEE.The fire analysis considers both full control room evacuation scenarios and smaller higher frequency fires that could impact single cabinets and therefore single trains of equipment.(b) The RSP at Hope Creek includes instrumentation and controls for RCIC, RHR B (Suppression Pool Cooling (SPC) and Shutdown Cooling (SDC) modes), division B and D SRVs, and the associated loop B support systems (e.g., Safety Auxiliaries Cooling System loop B and Station Service Water loop B). If loop B equipment is unavailable from the RSP (e.g., EDG B failed or in maintenance), procedure HC.OP-IO.ZZ-0008(Q) provides direction for local operation of RHR A (SPC and SDC modes) for containment heat removal or RHR C and D (Low Pressure Coolant Injection (LPCI) mode) for low pressure inventory makeup. The Hope Creek PRA also credits a procedure for local manual containment venting.Although only loop B equipment is available from the RSP, the available procedural direction and operator training allow credit for local operation of loop A mitigation systems. Therefore, both loop A and B equipment may be available for fire scenarios that lead to evacuation of the control room, and the modeling of operation from outside the control room (i.e., the RSP or local controls) does not adversely mask the importance of the diesel generator outage configurations.
20 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOT LAR 5. The submittal identifies that based on a 14-day weather forecast; the frequency of loss of offsite power (LOOP) due to severe weather is reduced by 75%. Given the uncertainty of weather forecasting over extended periods, and since the licensee does not preclude the use of the 14-day extended CT for unplanned repairs, this reduction in frequency could be introducing a non-conservative bias in the risk results.21 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR 5a. Identify the nominal LOOP frequency applied in the baseline PRA, and the reduced frequency used for this application, and describe how each of these frequencies were calculated.
Justify the assumption of a 75% reduction in severe weather LOOP for a 14-day CT.RESPONSE TO 5.a The nominal total LOOP initiating event frequency in the baseline Hope Creek PRA model is 2.37E-2/yr.
The LOOP initiating event frequency is based on using the industry data in NUREG/CR-6890 and performing a Bayesian update with plant specific operating experience.
The conditional probabilities and their corresponding individual causal LOOP frequencies are determined based on the NUREG/CR-6890 data and methods. The baseline LOOP frequency of 2.37E-2/yr is comprised of the four types of LOOP contributors as follows: LOOP Causal Factors: Frequency (Per/yr)Plant Centered 2.24E-3/yr Switchyard Centered 9.55E-3/yr Grid Related 6.94E-3/yr Weather Related 4.98E-3/yr Total Nominal LOOP Frequency 2.37E-2/yr For the 14-day EDG CT calculation, the Weather Related LOOP contribution is reduced by 75% as part of Compensatory Measure 4 (of Attachment 4 of this submittal) based on engineering judgment.
The revised LOOP frequency used as part of Compensatory Measure 4 is 2.0E-2/yr and is comprised as follows: LOOP Causal Factors: Frequency (Per/yr)Plant Centered 2.24E-3/yr Switchyard Centered 9.55E-3/yr Grid Related 6.94E-3/yr Weather Related 4.98E-3/yr
* 0.25 = 1.25E-3/yr Total Compensatory Measure LOOP 2.OE-2/yr Frequency 22 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Hope Creek procedures provide direction in the event of severe weather. Based on the extended weather forecasts, a 14-day EDG AOT would not be initiated during warnings related to severe weather conditions.
Based on this information, the frequency of a Weather Related LOOP event during the 14-day EDG AOT would be much less than the nominal frequency used in the baseline Hope Creek PRA model.Because entry into the 14 day AOT may be due to unplanned EDG failure or could occur in a planned EDG outage when weather forecasts fail to identify severe weather, the conditional probability of 0.25 that severe weather could still occur is included in the risk assessment for the change in risk.This is judged to be an appropriate estimate.Two sensitivity cases are performed with the severe weather to demonstrate the impact of this assumption:
* Probability of 1.0 that severe weather could still occur during the 14 day outage (i.e., 100% of nominal severe weather LOOP frequency from baseline Hope Creek PRA model)." A conservative estimate that the probability of severe weather occurrence during the 14 day outage is 50% of that with no compensatory measure to plan the outage when severe weather is not expected and to verify that severe weather warnings are not present at the start of the AOT.(For the results of the sensitivity cases see the response to RAI 5c.)23 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG A OT LAR Atahet2 RNO09 epne oPR-eatdRA oeCekEGATA 5b. The offsite power recovery probability is directly dependent upon the cause of the loss of offsite power. Provide the baseline and analysis probabilities for offsite power recovery, and describe how the exclusion of 75% of the severe weather event frequency has been accounted for in the offsite power recovery probabilities.
RESPONSE TO 5.b The individual offsite power recovery events credited in the Hope Creek PRA model are provided in Table RAI-5b-1.
The Hope Creek PRA model credits offsite power recovery based on the specific cause of the loss of offsite power (e.g., Plant Centered, Switchyard Centered, Grid Related, Weather Related).
Consistent with the development of the LOOP initiating event frequency, the offsite power recovery probabilities are based on the industry data in NUREG/CR-6890.
The offsite AC power recoveries are developed and used in the HCGS PRA model specifically tied to the LOOP causal event.The frequency of loss of offsite AC power due to severe weather is reduced by 75% from 4.98E-3/yr to 1.25E-3/yr. (See the response to RAI 5a.) The conditional AC non-recovery probability for severe weather LOOP initiators is unchanged.
The offsite power recovery probabilities are specific to the type of LOOP initiating event (i.e., the offsite power recovery events are not a weighted average);
therefore, the weather related recovery probabilities are not revised based on the exclusion of 75% of the weather related frequency as part of Compensatory Measure 4 (of Attachment 4 of this submittal).
The 75% reduction in the initiating event frequency for the severe weather initiating event reduces the severe weather frequency but the causal specific conditional probability for offsite AC recovery does not change.24 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Table RAI-5b-1 OFFSITE AC POWER NON-RECOVERY PROBABILITIES CREDITED IN HOPE CREEK PRA MODEL Basic Event ID Basic Event Description I Non-Recovery Probability OSPR30MIN-PC FAILURE TO RECOVER OSP WITHIN 30 MIN. (PLANT CENTERED LOOP EVENT) 4.79E-01 FAILURE TO RECOVER OSP WITHIN 30 MIN. (SWITCHYARD CENTERED LOOP OSPR30MIN-SWYD EVENT) 5.95E-01 OSPR30MIN-GR FAILURE TO RECOVER OSP WITHIN 30 MIN. (GRID RELATED LOOP EVENT) 8.25E-01 OSPR30MIN-SW FAILURE TO RECOVER OSP WITHIN 30 MIN (WEATHER RELATED LOOP EVENT) 7.73E-01 OSPR4HR-PC FAILURE TO RECOVER OSP WITHIN 4.5 HRS (PLANT CENTERED LOOP EVENT) 4.03E-02 FAILURE TO RECOVER OSP WITHIN 4.5 HRS (SWITCHYARD CENTERED LOOP OSPR4HR-SWYD EVENT) 6.72 E-02 OSPR4HR-GR FAILURE TO RECOVER OSP WITHIN 4.5 HRS (GRID RELATED LOOP EVENT) 1.32E-01 OSPR4HR-SW FAILURE TO RECOVER OSP WITHIN 4.5 HRS (WEATHER RELATED EVENT) 3.61 E-01 OSPR6HR-PC FAILURE TO RECOVER OSP WITHIN 5.8 HOURS (PLANT CENTERED LOOP EVENT) 2.55E-02 FAILURE TO RECOVER OSP WITHIN 5.8 HOURS (SWITCHYARD CENTERED LOOP OSPR6HR-SWYD EVENT) 4.40E-02 OSPR6HR-GR FAILURE TO RECOVER OSP WITHIN 5.8 HOURS (GRID RELATED LOOP EVENT) 8.62E-02 FAILURE TO RECOVER OSP WITHIN 5.8 HOURS (WEATHER RELATED LOOP OSPR6HR-SW EVENT) 3.14E-01 OSPR7HR-PC FAILURE TO RECOVER OSP WITHIN 7 HRS (PLANT CENTERED LOOP EVENT) 1.78E-02 FAILURE TO RECOVER OSP WITHIN 7 HRS (SWITCHYARD CENTERED LOOP OSPR7HR-SWYD EVENT) 3.14E-02 OSPR7HR-GR FAILURE TO RECOVER OSP WITHIN 7 HRS (GRID RELATED LOOP EVENT) 6.10E-02 OSPR7HR-SW FAILURE TO RECOVER OSP WITHIN 7 HRS (WEATHER RELATED LOOP EVENT) 2.80E-01 OSPR2OHR-PC FAILURE TO RECOVER OSP WITHIN 20 HRS (PLANT CENTERED LOOP EVENT) 1.76E-03 FAILURE TO RECOVER OSP WITHIN 20 HRS (SWITCHYARD CENTERED LOOP OSPR2OHR-SWYD EVENT) 3.51 E-03 OSPR20HR-GR FAILURE TO RECOVER OSP WITHIN 20 HRS (GRID RELATED LOOP EVENT) 5.66E-03 OSPR2OHR-SW FAILURE TO RECOVER OSP WITHIN 20 HRS (WEATHER RELATED LOOP EVENT) 1.33E-01 25 Attachment 2, LR-N] 0-0294 Responses to PRA-Related RAIs Hope Creek EDG AOT LAR 5c. Provide a sensitivity analysis for the risk results if the nominal loss of offsite power frequency and recovery probabilities are retained for the configuration-specific risk evaluation.
RESPONSE TO 5.c Two sensitivity cases have been performed to retain the nominal loss of offsite power frequency and recovery probabilities (i.e., do not credit Compensatory Measure 4 (of Attachment 4 of this submittal)).
Note that as part of the RAI response, original Compensatory Measures 1 and 2 were subsumed by original Compensatory Measures 3 and 4. Therefore, original Compensatory Measures 3, 4, 5, and 6 have been renumbered (and revised) as Compensatory Measures 1, 2, 3, and 4, respectively, for the RAI response per Attachment 4 of this submittal.
The results for the sensitivity case to credit only Compensatory Measures 1 through 3 (of Attachment 4 of this submittal) are added to a reproduction of Table 3.4-5 of Attachment 4 to the March 29, 2010 LAR submittal (with the associated changes to reflect the revised compensatory measures). (See Table RAI-5c-1.)
One of the two additional sensitivity cases shows that using the nominal loss of offsite power frequency (i.e., no credit for Compensatory Measure 4 (from Attachment
: 4) does not change the conclusions of the 14-day EDG AOT calculations.
The second sensitivity case shows the results if 50% probability of severe weather reduction is achieved by the Compensatory Measure 4 (from Attachment 4).Figure RAI-5c-1 shows the change in risk metric ICCDP as a function of the degree of credit assigned to Compensatory Measure 4 (from Attachment 4), i.e., adequate planning of EDG AOT to avoid severe weather. As can be seen, the ICCDP is below the acceptance guideline without the Compensatory Measure 4 (0% credit). The Compensatory Measure 4 is considered a prudent action by PSEG and it will be implemented to minimize the probability of severe weather during the extended EDG AOT.The changes in risk for both of the additional sensitivity cases related to credit for the reduction in the severe weather LOOP initiator remain within the risk acceptance guidelines in RG 1.174 and RG 1.177.26 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG AOTLAR Table RAI-5c-1 QUANTITATIVE RESULTS OF THE RISK METRICS FOR EDG A&B OOS WITH CONSIDERATION OF COMPENSATORY MEASURES (PRA INCLUDES BOTH INTERNAL AND EXTERNAL EVENTS)ICCDP ICLERP Case Description ACDF ALERF EDG A EDG B EDG A EDG B (per yr) (per yr) OOS OOS OOS OOS Base Case 3.86E-07 2.95E-08 2.38E-07 5.02E-07 1.35E-09 5.53E-08 (Gas Turbine removed from service)Compensatory Measure 1 (of Attachment
: 4) 3.44E-07 2.36E-08 2.34E-07 4.26E-07 1.27E-09 4.41 E-08 Prevent Coincident Planned EDG Maintenance (A&C or B&D)Compensatory Measure 2 (of Attachment
: 4) 3.54E-07 2.47E-08 2.26E-07 4.53E-07 6.54E-1 0 4.68E-08 Prevent Coincident HPCI and RCIC Maintenance with EDG A or B OOS Compensatory Measure 3 (of Attachment
: 4) 3.80E-07 2.89E-08 2.34E-07 4.95E-07 1.04E-09 5.44E-08 Minimize Testing of Sensitive Equipment with EDG A or B OOS Compensatory Measure 4 (of Attachment
: 4) 2.66E-07 2.91 E-08 1.15E-07 3.95E-07 9.61E-10 5.48E-08 Preclude entry into extended EDG AOT during Anticipated Severe Weather Compensatory Measures 1-4 (of Attachment
: 4) 1.94E-07 1.81 E-08 9.96E-08 2.72E-07 <1.OOE-10 3.49E-08 Compensatory Measures 1-3 (of Attachment
: 4) 3.07E-07 1.84E-08 2.19E-07 3.71E-07 2.47E-10 3.51E-08 Compensatory Measures 1-4 (of Attachment
: 4) 2.31E-07 1.82E-08 1.38E-07 3.04E-07 <1.OOE-10 3.49E-08 (50% credit for not entering 14 day AOT if severe weather)27 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope CreekEDG AOTLAR Attachment 2, LR-NJO-0294 Responses to PRA -Related RAIs Hope CreekEDGAOTLAR 6E-07 5E-07 0.5 4E-07 0.4 ICCD.P Acceptance Guideline--L ----------------- ----------------------------------------------------------------
(3.71 E-07)......
(2.... ..72E_07)3E-07 0.3 -4 2E-07 0.2 1E-07 0.1 0%50%75%100%Fraction of Severe Weather Eliminated by Compensatory Measure Figure RAI-5c-1:
ICCDP as Function of Fraction of Severe Weather Eliminated by Compensatory Measure 4 (of Attachment 4 of this submittal) 28 Attachment 2, LR-NIO-0294 Responses to PRA-Related RAIs Hope Creek EDG A OT LAR Attachment 2, LR-NJO-0294 Responses to PRA-Rela ted RAIs Hope Creek EDG AOTLAR 6. Given a LOOP and failure of EDGs (station blackout), describe the assumptions for equipment credited in the PRA internal events model for continued core cooling. Include in your response any operator actions necessary, assumptions on environmental conditions given a station blackout, water inventories and makeup sources, and mission times. Does the PRA assume that core damage can be prevented even if AC power is not restored, or is offsite power recovery or diesel generator repair necessary?
RESPONSE TO 6 Given a LOOP and failure of EDGs (station blackout), the Hope Creek PRA model assumes that offsite power recovery or alignment of the Salem Gas Turbine Generator is necessary to prevent core damage for the 24 hour PRA mission time. This assumption may be conservative because Hope Creek has equipment and procedures for the following:
* Operator alignment of the portable power supply for long term HPCI, RCIC, and SRV control,* Operator alignment of the diesel fire pump for late low pressure injection, and* Local manual opening of containment vent valves.These mitigation actions support long term core cooling and containment heat removal without the availability of offsite AC power.There are mitigation measures that can be taken to extend the time before offsite AC power recovery must be achieved.
These include the following considerations: " Operator Actions* Assumptions on environmental conditions
* Water inventories
* Makeup sources" Mission times Attachment 6-1 (provided below, as part of the Response to this Question 6) provides information from the Hope Creek PRA Event Tree Notebook to discuss the above considerations for coping during long term station blackout scenarios.
Note that the above operator actions and mitigation strategies are only applicable to the internal events PRA for crediting offsite AC power recovery.29 Attachment 6-1 EXCERPT FROM HOPE CREEK LOSS OF OFFSITE POWER AND STATION BLACKOUT EVENT TREE NOTEBOOK Attachment 6-1 Loss of Offsite Power and Station Blackout ATTACHMENT 6-1 LOSS OF OFFSITE POWER AND STATION BLACKOUT EVENT TREE NOTEBOOK PLANT CONDITION IMPACTS Time Line For SBO sequences, there is a strong potential for complex, time varying system dependencies following a loss of offsite power and unavailability of emergency AC power. Therefore, time dependent AC power recoveries are used to evaluate the availability of key functional capabilities (i.e., coolant injection and containment heat removal) during the progression of events through the initial 24 hours following the LOOP initiating event. Figure 5-1 is a simplified time line describing the time phases used in constructing the LOOP event tree. Figure 5-1A supplements Figure 5-1 by providing additional detail on the limiting conditions.
Figures 5-1 and 5-1A also list some of the considerations or attributes associated with the time phases. While the list is not complete, it provides a simple way of looking at some of the key aspects of the time phases.Figure 5-1A summarizes the duration of time that specific parameters or systems can be considered adequate to support a safe stable state. This figure shows that there are a myriad of issues that limit plant response to an SBO to less than 24 hours. The most limiting of the parameters or systems are as follows: " DC power from 125V DC batteries with no load shed" Proximity to pressure suppression pressure (PSP)" Drywell temperature proximity to limit" RCIC back pressure trip* Torus temperature (HCTL)The failure to run failure mode is calculated as a 24 hour mission time for all components with the following exceptions:
* The diesel generator has a 24 hour mission time but uses a surrogate 6 hour mission time to represent the impact of a 24 hour run time (see Component Attachment 6.1-1 Attachment 6-1 Loss of Offsite Power and Station Blackout Data Notebook (Appendix G) for the correspondence of this time with the convolution of run time and offsite AC power recovery assumed times)." The battery life is estimated at 4 hours without chargers available, i.e., for SBO conditions.
If the portable power supply to the chargers can be aligned, battery life itself is not limiting.
However, containment conditions are calculated to eventually become unacceptable for continued operation of HPCI and RCIC in accordance with the EOPs within 8 hours based on MAAP calculations.
Therefore, HPCI and RCIC are limited to operation at less than 8 hours for multiple phenomenological effects (See Section 5.2).* HPCI and RCIC under SBO conditions are assessed for an 8 hour mission time despite the fact that certain SBO sequences credit times shorter than 8 hours for HPCI or RCIC successful operation.
The use of 24 hour run time for other components is consistent with the required mission time from the HCGS Success Criteria Notebook and the ASME PRA Standard and does not result in a substantial increase in the failure probability and therefore it is considered acceptable to incorporate this potentially slightly conservative assumption.
Attachment 6.1-2 Attachment 6-1 Loss of Offsite Power and Station Blackout DC BATTERY LIFE -Boildown Phase w/o Initial Injection 30 min.3.5 4 V 5.2 6 6.4 h rs. hrs. hrs. hrs. hrs.9 Hirs.11 Hrs.Phase I Phase II Phase III I Phase IV HPCI/RCIC Operation Phase DFP Post Injection Phase Phase 11 III Description 0 -30 min: Initial time phase that addresses possible boildown of RPV coolant inventory if no make-up is available and allowable time for AC power recovery prior to core damage.30 min. -4 hours: Effects of the SBO investigated for adverse impacts on success during this period where there is dependence on HPCI/RCIC operation:
* High Drywell Temperature
* RCIC backpressure trip* Torus Temperature (above HCTL)
* High containment pressure (PSP)* CST Inventory Battery Capacity* High torus suction temperature 4 hrs. -6 hrs: There is a period of accident mitigation for the SBO that is dependent upon the ability to maintain HPCI and RCIC operability following the battery depletion.
This time period beyond 4 hours (battery depletion) is dependent upon successful use of the portable power source for the battery chargers.
If this is successful, HPCI or RCIC continued injection is possible if not otherwise limited by:* Size of Recirc seal LOCA
* PSP* High DW temperature
* Room cooling> 6 hours: The primary reason for this time phase limitation is exceeding HCTL or PSP and the requirement for emergency blowdown at approximately
 
===6.4 hours===
leading to blowdown in the 6.4 hour time frame and possible core damage by 7.0 hours. Once the batteries deplete, continued adequate core cooling requires that the portable power supply for charging the batteries and the DFP are available and effective in providing a depressurized RPV and adequate RPV makeup.Figure 5-1 Time Phases for SBO Event Sequences IV Attachment 6.1-3 Attachment 6-1 Loss of Offsite Power and Station Blackout Figure 5-1A Restrictions on HPCI/RCIC Success with No Other Mitigating Actions Included Parameter Time Line or Condition (Time to Reach a "Limit")System Batteries DC 0 4.0 Hrs.pSp(2)DW/T(2)Portable Power Supply with No Leak (HC07004C)(1)w/12.5 gpm Leak(3)w1120 gpm Leak (HC07008CX) with No Leak (HC07004A)(1)w11 2.5 gpm Leak (HC07007)(3)w/120 gpm Leak (HC07008CX)
No Torus Cooling HC07007x (initial T=85&deg;F)with No Leak (HCO7004A) w/12.5 gpm Leak (HC07007)w/120 gpm Leak (HC07007C) 5.2 Hrs.(4)20 Hrs.-13 Hrs.I-I--24 Hrs.-24 Hrs.I 11.6 Hrs.Torus Temp.(HCTL)I-I 4 Hrs.-160&deg;F 6.4 Hrs.T/T >HCTL RCIC Back Pressure (44 psig in DW)F 1-24 Hrs.Not Limiting Not Limiting (1) 24 hour operation requires torus cooling.(2) Requires emergency depressurization based on proximity to PSP or DW/T limit curves (-340oF).(3) 24 hour operation with a small recirc seal leak requires SPC and DW sprays.(4) With RCIC operation, the time to reaching the PSP limit curve is extended slightly to 5.6 hrs.Attachment 6.1-4 Attachment 6-1 Loss of Offsite Power and Station Blackout Potential plant conditions that may limit system operability during an extended SBO event need to be addressed to determine what AC power recovery time is reasonable to include in the probabilistic assessment.
The possible limitations and impacts include the following:
Possible Limitation SBO Impact Drywell Temperature exceeds design Limit 340OF Torus temperature exceeds HCTL (-185 0 F at 1000 psig)Torus temperature exceeds acceptable values for HPCI/RCIC operation with suction from the torus Containment pressure exceeds PSP RCIC high turbine exhaust pressure trip Battery life is exceeded CST Volume is exhausted (CST volume is nominally 300,000 gal.)RPV emergency depressurization required; this causes low steam pressure to HPCI/RCIC.
RPV emergency depressurization required; this causes low steam pressure to HPCI/RCIC.
If CST source is unavailable, the torus source may be relied upon. This is a higher temperature (less limiting) than the HCTL effect discussed above.PSP requires emergency depressurization at approximately 28 psig in the drywell; this causes low steam pressure to HPCI/RCIC.
RCIC will trip on high exhaust pressure trip (setpoint 50 psig or approximately 44 psig in the DW)(1)Control of HPCI, RCIC, and SRVs is unavailable from the control room unless portable power supply is aligned for charging support.HPCI/RCIC must be operated with suction from the torus. This may cause failure due to high suction temperature.
(1)One of the physical restrictions on RCIC operation is the high turbine exhaust pressure trip. This trip setting at HCGS was 25 psig for the pre-EPU plant. This translatds into a containment pressure of approximately 19 to 20 psig. Under certain degraded accident conditions whereIRCIC operation can be beneficial this trip setpoint could be exceeded.
As part of the EPU implementation, PSEG has increased the RCIC trip set point to 50 psig in the fall of 2007. This translates into a containment pressure of approximately 44 psig. This is well above the Pressure Suppression Pressure (PSP) at which emergency depressurization is directed.
Therefore, there are no longer any identified accident sequences in the HCGS PRA for which the RCIC high turbine exhaust pressure trip is limiting.Attachment 6.1-5 Attachment 6-1 Loss of Offsite Power and Station Blackout Possible Limitation HPCI/RCIC room temperatures Control Room Temperature RPV Water Level Compressed Gas Operation Diesel Fire Pump Recirculation Pump Seal LOCA SBO Impact Potential premature isolation or failure of the HPCI/RCIC equipment.
Lack of AC power causes the loss of active room cooling. HPCI and RCIC operation could be compromised under certain conditions. (Not limiting for SBO unless there is gland seal failure)Adverse equipment or personnel habitability effects could result inside the Control Room.The RPV fuel zone water level instruments are powered by essential buses. Under SBO conditions, RPV level indication is available.
The 14 Target Rock SRVs have accumulators that would be relied upon for SBO sequences.
DFP effectiveness considered limited in current model.Seal LOCA reduces time available for crew response.
This is explicitly treated probabilistically in the CAFTA model and the effects are reflected in the deterministic MAAP calculations.
HCGS has performed a number of deterministic analyses in support of the Station Blackout Coping Assessment as part of the response to the NRC SBO Rule. The following discussion summarizes some of the technical analyses used by PSEG in the SBO Coping Analysis and analyses developed here using MAAP to support analysis beyond the 4 hour coping period in these assessments.
PSEG has developed an extensive library of deterministic calculations using MAAP 4.0.4 and MAAP 4.0.6. These calculation sets are both performed at the EPU power level of 120% of OLTP. The Level 1 analyses has shown that either set of calculations provide accurate information regarding primary system and containment response.Attachment 6.1-6 Attachment 6-1 Loss of Offsite Power and Station Blackout Therefore, the following discussions will use both sets of MAAP calculations interchangeably to describe the limitations on plant response to LOOP and SBO conditions.
DW Temperature and Torus Temperature As noted in Section 2 and in the Success Criteria Notebook, there are a number of heat removal systems available for HCGS. These include the following: " Torus Heat Removal-RHR in suppression pool cooling-RHR in drywell spray mode" Shutdown Cooling-RHR heat removal from the RPV directly* Containment Vent-Both heat removal and containment pressure control.* Drywell Coolers-DW coolers are used principally for DW temperature control. Their capacity is too small to act as the sole containment heat removal method to prevent overpressurization.
High drywell temperature may arise in the primary containment equipment areas (drywell, wetwell) as a result of the loss of drywell coolers due to the loss of offsite power. The heat transfer from process steam lines and the reactor vessels contribute heat to the containment drywell and have been analyzed for the thermal transient resulting from a station blackout.Temperatures are acceptable, i.e., well below the 340&deg;F DW temperature "limit". (MAAP Case IB-LI-5, HC07006A, HC07007C, HC07007D, HC07007E, HC07007F, and HC07008C)The drywell temperature is acceptable for the following conditions:
* 24 hours of HPCI or RCIC operation with SPC operating and no significant recirc seal leak* Greater than the time available for the SBO conditions even with a small or large recirc seal leaks Attachment 6.1-7 Attachment 6-1 Loss of Offsite Power and Station Blackout Additionally, it is expected that containment torus conditions would not approach the HCTL within the limiting time frame which would require the operating crew to reduce the potential challenge to containment integrity by depressurizing the RPV. However, should the operating crew decide to perform an emergency depressurization of the RPV without regard for the operating ECCS, the turbine driven systems could be rendered inoperable, potentially causing core damage if the operators were subsequently unable to restore coolant inventory using the DFP or RCIC with the low pressure trip bypassed.Plant specific MAAP analyses indicate the following:
* Drywell Temperature remains below 340&deg;F for an extended time even including (1) the RPV remaining at pressure, (2) an SRV discharging to the torus, and (3) 120 gpm leakage from the RPV to the drywell.* The suppression pool temperature remains below the HCTL if the RPV is slowly depressurized during the initial 4 hours.See MAAP Cases IB-LI-5, HC07006A, HC07007C, HC07007D, HC07007E, HC07007F, and HC07008C.Containment Pressure Limiting Conditions for SBO High containment pressure may arise from LOCA, recirculation pump seal LOCA, or loss of DHR. There could be adverse impacts on HPCI and RCIC due to high containment pressure and required RPV depressurization on PSP.The EOP for containment control specifies that emergency RPV depressurization is required if the containment pressure exceeds the Pressure Suppression Pressure (PSP). The PSP curve for HCGS has a safe region below approximately 28 psig. Pressures above 28 psig in containment could occur under certain conditions of recirculation pump seal LOCAs.The containment pressure is calculated using MAAP to exceed the PSP at approximately 8 hours into the event if a large recirculation pump seal LOCA occurs. This means that this parameter could be limiting in the assessment of the possible core damage sequences without any AC power. (MAAP Case HC07008CX using MAAP 4.0.6 [IB-LI-5]
resulting in approximately Attachment 6.1-8 Attachment 6-1 Loss of Offsite Power and Station Blackout 5.8 hours.) This limitation is further discussed under HPCI/RCIC operability in the individual nodal event tree discussions.
5.2.3.2 Non-Limiting Conditions for SBO High containment pressure may also lead to automatic RCIC turbine trip due to high turbine exhaust pressure and Target Rock SRV reclosure (not an issue within 8 hours).* The revised RCIC high back pressure turbine trip as a result of an EPU modification (50 psig) is no longer limiting for the SBO for sequences.
* Target Rock SRV reclosure occurs at differential pressure of approximately 20 psig. (N 2 gas pressure -containment pressure).
The pneumatic supply pressure = 90 psig." The required differential pressure to keep SRVs open = 20 psid per system engineer input from Target Rock. This is utilized in MAAP for relief valve logic. When SRVs are manually open and RPV pressure drops to within 20 psi of containment pressure, the SRVs are modeled to close. This value is modeled in MAAP and will cause manually open relief valves to close and prevent reopening even manually above this containment pressure.Battery Life DC availability to support RPV inventory makeup can be provided by batteries or a portable power supply to the chargers.PSEG has developed a procedure and the associated hardware to allow a portable power supply to be used to provide power to the 125V DC and 250V DC chargers.
This procedure and hardware allow for extending the availability of DC power beyond 4 hours despite an SBO.Without the use of the portable power supply to the chargers, battery depletion would result in inadequate instrumentation and control power for turbine driven systems. The model accounts for initial battery failure and battery depletion at 4 hours if no chargers (AC power) are available.
The minimum battery life for the four 125 VDC divisions is derived from PSEG design estimates.
This may be slightly conservative and increase the importance of the crew action to align the portable power supply for the chargers.Attachment 6.1-9 Attachment 6-1 Loss of Offsite Power and Station Blackout DC Load Shed There are DC load shed actions specified in the HCGS procedures, however, the actions are taken ostensibly to reduce heat loads in various compartments and not to preserve DC power.The HCGS coping time of 4 hours is met without the need for the DC load shed actions.It is also noted that no analyses are available from HCGS to support extending the DC battery life of any of the critical batteries beyond 4 hours, except for the use of the portable power supply and alignment of chargers.CST Volume The nominal CST volume is adequate (-300,000 gal.) to support RCIC or HPCI injection for 24 hours approximately 130,000 gal. are required for the 4 hour SBO required mission time to meet the SBO rule. Therefore, there is more than adequate water supply for the 4 hour coping time for the SBO event.HPCI/RCIC Room Temperature High room temperatures in the Reactor Building can cause the trip of turbine driven systems (i.e., steam line break logic) or extreme environmental stress on critical components under SBO conditions.
The steam tunnel equipment area contains steam process lines which contribute heat and therefore has been analyzed for the thermal transient resulting from a station blackout.
High steam tunnel temperature occurs in the SBO and causes MSIV closure. HPCI/RCIC operation is not adversely impacted because no HPCI or RCIC temperature indicators are located in the steam tunnel.Nevertheless, the HPCI and RCIC systems isolation within the rooms and pipe chase due to steam line break logic may be challenged under SBO conditions and therefore these temperature isolations should be bypassed if the isolation temperature is reached within a time phase.Attachment 6.1-10 Attachment 6-1 Loss of Offsite Power and Station Blackout The HPCI equipment area (HPCI room) contains steam driven and DC energized equipment and therefore has been analyzed for the thermal transient resulting from a station blackout.HPCI operability over the 24 hour mission time does not require room cooling (which is dependent on AC power), except if a gland seal system failure has occurred. (See Dependency Notebook and HPCI System Notebook.)
Under SBO conditions and no gland seal failure, the SBO evaluation by PSEG supports operability of HPCI for 4 hours without AC power. This operability does require bypassing the high room temperature trip setpoint at 160 0 F. Therefore, a crew action is required for success of the HPCI system without room cooling and without a gland seal failure. This is extrapolated to 8 hours using survivability envelopes from NUMARC 87-00. Therefore, the SBO sequences are quantified using the HPCI fault tree representative of an 8 hour operation and mission time. HPCI operation does not include dependence on the fan or room cooler for operation during SBO/LOOP sequences for 8 hours without AC power when there is no gland seal failure.The RCIC equipment area (RCIC room) contains steam driven and DC energized equipment and therefore has been analyzed for the thermal transient resulting from a station blackout.RCIC room cooling is required for the 24 hour mission time only if a coincident gland seal failure occurs. (See Dependency Notebook and RCIC System Notebook.)
Bypass of the temperature trips is directed by Hope Creek procedures.
Under SBO conditions, there are design calculations (GR-0022) that support the operability of the HPCI and RCIC equipment over a 4 hour coping time. These calculations can be summarized as follows: The steam line piping is routed through a number of rooms. These rooms are oriented 180 degrees away from the steam tunnel. The calculations for rooms 4110 (RCIC) and 4111 (HPCI) in GR-0022 include any steam piping and turbine exhaust piping routed within the room.The calculated temperature rise over 4 hours using a conservative number of cycles and temperatures is found in Calc GR-022. The results are as follows: Attachment 6.1-11 Attachment 6-1 Loss of Offsite Power and Station Blackout CONSERVATIVE SBO TEMPERATURES FOR RX BUILDING (CALC NO. GR-0022)iF System Room Temp -F 1RCIC 14110 1147 HPCI 4111 174 (1) NUMARC 87-00.SBO mitigation is described in HC.OP-AB.ZZ-0135 and listed in UFSAR Table 13.5.2.HPCI/RCIC are designed to isolate in the event of a high-energy line break (HELB) in the respective compartments.
An isolation trip setpoint of 160&deg;F ambient room temperature for rooms 4110 and 4111 is used at HCGS. SBO temperatures may exceed the trip setpoint and inadvertently isolate the system during SBO. Per HC.OP-AB.ZZ-0135, operators take steps to bypass the HPCI/RCIC high ambient temperature isolation logic before room temperatures exceed the isolation setpoints (Step 4.5.10). Thus, the resulting SBO temperatures will not have an adverse impact on the way in which HPCI/RCIC design functions are performed or controlled if the steam line temperature isolation is bypassed.Room Cooling Gland Seal Mission Time Required Adequate System Leakage (Hrs) (Alternatively SPC) w/No Room Cooling HPCI Yes 24 Failed No Yes 8 Failed No Yes 4 Failed No HPCI No 24 No Yes No 8 No Yes No 4 No Yes RCIC Yes 24 Failed No Yes 8 Failed No Yes 4 Failed No RCIC No 24 No Yes No 8 No Yes No 4 No Yes Attachment 6.1-12 Attachment 6-1 Loss of Offsite Power and Station Blackout The EPU implementation included a series of GE Task Reports. The one evaluating SBO (GE-NE-0000-0005-6467-01 Task 903) concluded that loss of ventilation during the SBO coping period of 4 hours does not prevent functioning of coping equipment.
Compressed Gas Operation Certain equipment items required for safe shutdown are operated by compressed air/nitrogen.
Hope Creek does not have DC energized compressors to supply this equipment.
Therefore, system accumulators are a source of stored compressed air/nitrogen of sufficient capacity to operate the compressed air/nitrogen operated equipment necessary to bring and maintain the plant in safe shutdown for a station blackout event. Accumulator dependent equipment identified by procedures or operational requirements shall be activated by the accumulators and operate within their design limits.The RCIC system does not require any air operated equipment.
All air operated valves fail in the required position for continued RCIC system operation.
The HPCI system does not require any air operated equipment.
The SRVs have a high success probability over the initial 24 hours because the SRV accumulators are sufficient to support SRV operation over this timeframe.
The 14 Target Rock SRVs each have an accumulator.
The total number of actuations available is approximately 42 to 70. The basis for this is documented in the SRV system notebook.Control Room Effects During a station blackout event, heat will be added to the control room as a result of operating personnel activities and equipment powered from uninterruptible AC sources and DC sources.It is conservatively assumed that all energy expended within the control room is converted to heat and contributes to the heat rise. Complete loss of cooling to these areas under SBO conditions can be addressed by opening doors and removing ceiling tiles according to procedure HC.OP-AB.ZZ-135.
This is proceduralized.
If at least one diesel-generator of Division 1 or 2 starts, in response to a loss of offsite power, it is possible to power a train of Attachment 6.1-13 Attachment 6-1 Loss of Offsite Power and Station Blackout control room ventilation.
The design calculation for the SBO coping time of 4 hours shows adequate control room temperatures.
If no EDGs start and room heat up locks are shed or dealt with, then the event tree path followed provides success if AC power is recovered within 20 hr (given success of the portable power source for a battery charger).The EPU implementation included a series of GE Task Reports. The one evaluating SBO (GE-NE-0000-0005-6467-01 Task 903) concluded that loss of ventilation during the SBO coping period of 4 hours does not prevent functioning of coping equipment.
Therefore control room heat-up is not considered limiting in the SBO or LOOP assessment.
High Temperature in Switchgear Room The essential switchgear equipment area contains DC energized equipment which' contributes heat and has been analyzed for the thermal transient resulting from a station blackout.Essential AC equipment (switchgear, battery chargers, motor control centers, transformers, etc.)required for recovery will operate at temperatures exceeding 115OF (ref. NUREG/CR-4942, NUMARC 87-00 App. F). Automatic fire suppression systems are not utilized in the essential switchgear areas. The switchgear rooms are adequate for more than 4 hours without any cooling or crew actions. Procedures direct additional mitigation action if necessary.
This includes opening doors and use of portable fans if feasible.
Under SBO conditions, these rooms will have little or no heat load.The EPU implementation included a series of GE Task Reports. The one evaluating SBO (GE-NE-0000-0005-6467-01 Task 903) concluded that loss of ventilation during the SBO coping period of 4 hours does not prevent functioning of coping equipment.
Diesel Fire Pump The diesel-powered fire pump (DFP) injection source could be viable as long as the RPV can remain completely depressurized.
However, several conditions can compromise this makeup source: Attachment 6.1-14 Attachment 6-1 Loss of Offsite Power and Station Blackout* SRVs can only depressurize the RPV to 50 to 90 psig which restricts the maximum DFP flow to the RPV* Battery depletion* Containment pressurization
* Elevation head required to reach the RPV may be large enough to reduce flow to less than adequate* Alignment would be required under adverse conditions When the batteries deplete, the SRVs can no longer remain open and the RPV will repressurize.
Inventory will be discharged via the SRVs at high RPV pressure as a result of decay heat.However, with the portable power supply for AC power to the chargers, DC power remains available indefinitely and the DFP remains a viable method of RPV injection until the SRVs reclose due to high containment pressure unless containment venting can be implemented.
MAAP HC07007F demonstrates the adequacy of the DFP flow to the RPV after approximately 4 hours.The time before SRVs reclose is approximately 20 hours [HC07005, HC07018].
Therefore, there is at least 20 hours available for AC power recovery when the following are available and effective:
* Portable power supply for battery charging* DFP for RPV injection Recirculation Pump Seal LOCA A failure of the recirculation pump seals induced in both pumps due to a loss of RACS and break down of the seals could result in adverse DW environment (pressure and temperature) that could limit HPCI and RCIC viability.
The recirculation pump seal leak has two critical parameters that can influence the accident sequence:* The time at which a seal leak develops* The magnitude of the seal leak Attachment 6.1-15 Attachment 6-1 Loss of Offsite Power and Station Blackout In general, analyses have imposed the conservative assessment that the seal leak is initiated at the time of the SBO. (This is judged to be conservative and realistically could be delayed by several hours.)The magnitude of the seal leak is judged to generally be quite small for the latest design recirculation pump seals. However, there remains a probability of a large seal leak and this is probabilistically included in the model. (See Appendix G of the Component Data Notebook.)
Attachment 6.1-16 Attachment 3 LR-N10-0294 Supplemental Information (as discussed in Attachment 1)* PSEG Calculation E-9, Standby Class 1 E Diesel Generator Sizing, Revision 8" PSEG drawing 601701 S 1000 -33, Salem / Hope Creek Generating Station 500, 13.8, 4 KV Elementary One Line." Salem No. 1 and No. 2 Units Generators
& Main Transformers One Line Control Diagram 203000 S 8789-53* HCGS Single Line Diagram E-0001-0 (Q)
FORM I Page 3 of 3 (Page I and 2 contain the instructions)
NC.DE-AP.ZZ-0002(Q CALCULATION COVER SHEET Page 1 of 8 CALCULATION NUMBER.: E-9(Q) REVISION:
8 TITLE: Standby Class 1E Diesel Generator Sizing#SHTS (CALC): 8 #ATTI#SHTS:
9/WI A~,#IDV/50.59 SHTS: 313 #TOTA L S HTS: .. W 71kq CHECK ONE: '/F 110-1[9 FINAL 0 INTERIM (Proposed Plant Change) [] VOID D] FINAL (Future Confirmation Req'd, enter tracking Notification number)SALEM OR HOPE CREEK: nj Q -LIST X] IMPORTANT TO SAFETY D] NON-SAFETY RELATED HOPE CREEK ONLY: []Q [-]Qs -Qsh I-F rJR El ARE STATION PROCEDURES IMPACTED?
YES [] NO Z IF "YES", INTERFACE WITH THE SYSTEM ENGINEER & PROCEDURE SPONSOR. ALL IMPACTED PROCEDURES SHOULD BE IDENTIFIED IN A SECTION IN THE CALCULATION BODY [CRCA 70038194-0280].
INCLUDE AN SAP OPERATION FOR UPDATE AND LIST THE SAP ORDERS HERE AND WITHIN THE BODY OF THIS CALCULATION.
El CP and ADs/CDs INCORPORATED (IF ANY): See Page 2 of this Calculation DESCRIPTION OF CALCULATION REVISION (If applicable.):
See page 2 of this Calculation PURPOSE: See page 3 of this Calculation CONCLUSIONS:
See Page 7 of this Calculation z" 0 LLJ 0 U-LLJ 00 Printed Name/ Signature Date ORIGINATORICOMPANY NAME: Saeed Savar/Seconded F ck,=, REVIEWER/COMPANY NAME: /011 VERIFIERICOMPANY NAME: CONTRACTOR SUPERVISOR (If applicable)
PSEG SUPERVISOR APPROVAL: (Always required)
-- 2 4 Nuclear Common Page 13 of 15 Revision 10 Calculation E-9(Q) Rev.8 Standby Class IE Diesel Generator Sizing Revision History Rev. No. 8 Summary of changes: 1. Incorporated the following outstanding CDs: ECA H CD # Discipline Rev. #80003623 E502 Electrical 0 80003631 E502 Electrical 0 2. The reference page, revision history page and the page containing note #4 were partially re-typed.3. General changes were incorporated to improve the format and consistency with the current calculation procedure.
Revision No. 7: Summary of Changes: I. Following CD's: 4H-0377/E507/0 and 4H-0330/E509.
These changes only affect Table 7, MOV Load on SDG's 2. Comments from 10CFR50.54 review, breaker rating was used for several Heat Tracing Panels (note 26)3. Uses actual conversion formula from HP to KW rather than a 0.8 factor.4. The entire calculation was reformatted in Excel. Rev. 6 was a hand calculation.
7 z< 5. Incorporated Engineering Evaluation H- I1-KJ-EEE-1270, Rev. 0 U 6. Added MDE-01-016 Maximum Motor Loading For LOCA and LOP for CS, RHR SACS, SSWS Pumps 7. Added SDG loading summary table 8.z 7-)0 hi F-U3)z" 0 U-)w L0 02 Cn 71 0 0-Li-C)LLA Peo D 0C, Cf)U0 Calculation E-9(Q)Standby Class 1E Diesel Generator Sizing Rev.8 Section 1.0 Objective 2.0 Plant Layout 3.0 Design Basis 4.0 Summary Of Loading 5.0 Notes 6.0 Conclusions
 
==7.0 References==
Attachments Attachment I -Table -SDG Load Assignments Attachment 2 -Table -All SDGs In Service Attachment 3 -Table -SDG 'A' Off Line Attachment 4 -Table -SDG 'B' Off Line Attachment 5 -Table -SDG 'C' Off Line Attachment 6 -Table -SDG 'D' Off Line Attachment 7 -Table -MOV Loads On SDG 'A'Attachment 8 -Table -Summary of SDG Loading Attachment 9 -MDE-0 1-016 Maximum Motor Loading For LOCA and LOP for CS, RHR SACS, SSWS Pumps.......................................................
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7 pages Page 3 of 8 Calculation E-9(Q) Rev.8 Standby Class 1E Diesel Generator Sizing 1.0 PURPOSE: The purpose of this calculation is to demonstrate that during and following a Design Basis Accident (DBA) the steady state and maximum loading of each Standby Diesel Generator (SDG) at any time does not exceed its continuous rating.2.0 PLANT LAYOUT: 2.1 The Hope Creek plant has four 4.16KV engineering safeguard system (Class I E) buses 2.2 Each SDG is connected thru breakers to the 4.16KV bus of each class lE channel.2.3 Each Class 1 E bus also has two separate offsite power sources connected to it by breakers.
The normal configuration is shown on Fig. 1.STATION SERVICE XFMRS 18X501 IAX501)NC 5NO N)) No T)NO T NC )NO T )NC N )) N )tC , ) ) N-4.16KV 4.16KV r4.16K .1K 10IA404 I0A402 ISA403 10A401 7NO) NO) NO) NO)0G400 16400 ( > 1CG400 .AG400 ZD- DIESEL DIESEL< " EN EN .- DIEEL--' ' DIESEL-"T CHD CH.B N. CH. C EN. CH. A EN<CH....CH.
_-.K D/3 ..EJ J.. ..Cn~z-0 C")w CD LiJ 0 C.)7 0>-Elf Page 4of 8 i, Ln D Calculation E-9(Q) Rev.8 Standby Class 1E Diesel Generator Sizing 3.0 DESIGN BASIS 3.1 The SDG must be capable of automatic starting, reaching full speed, rated voltage and frequency within 10 seconds after receipt of start signal.3.2 The SDG must be able to shutdown the plant under the following conditions:
3.2.1 Loss of offsite power (LOP) with three of the four SDGs available.
 
====3.2.2 Design====
Basis Accident (DBA) with three of the four SDGs available.
DBA is defined as loss of offsite power concurrent with a loss of coolant accident (LOCA).3.3 Equipment required to shutdown the plant under the conditions stated in paragraph 3.2 is allocated between the four SDGs such that a safe shutdown is assured with any three of the four SDGs in operation.
The load allocation is shown in Attachment 1.4.0
 
==SUMMARY==
OF LOADING 4.1 Demands in KW on each SDG are tabulated in Attachments 2 through 6.4.2 The following conditions are considered in calculating load demands of the SDGs: 4.2.1 Attachment 2 shows loading conditions of the four SDGs for the situation in which all four SDGs are in service.4.2.2 Attachment 3 shows loading when SDG "A" is not available, and SDGs "B", "C" and "D" ,., are available.
 
====4.2.3 Attachment====
 
4 shows loading when SDG "B" is not available, and SDGs "A", "C" and "D" are available.
 
====4.2.4 Attachment====
 
5 shows loading when SDG "C" is not available, and SDGs "A", "B" and "D" z are available.
< 4.2.5 Attachment 6 shows loading when SDG "D" is not available, and SDGs "A", "B" and "C" 0are available.
 
====4.2.6 Attachment====
 
7 shows the MOV loading 4.2.7 Attachment 8 is a summary of Attachments 2 through 8 0 e 5.0 NOTES 5.1 An inspection of Attachment 1 Table shows that LOP loading of SDGs is bounded by the DBA loading, Therefore only DBA loading calculations are shown in Tables in Attachments 2 through-u 6.ry LIA> 5.2 All loads in the 0-10 minute period are automatically applied. Additional loads are energized 02 manually after 10 minutes in accordance with Attachment I Table requirements.
en 2)~-7 0 a-J 0~en w Page 5 of 8 O2 EI, D3 Calculation E-9(Q) Rev.8 Standby Class 1E Diesel Generator Sizing 5.3 Non-Class 1E loads are tripped by the LOCA signal and may be manually applied after 0-10 minute period as permitted by the available capacity of the SDG and in accordance with Attachment 1 Table requirements.
 
===5.4 Class===
lE loads may also be tripped manually, if their continued operation is not necessary.
5.5 The kilo-watt (KW) values shown in Attachment 1 Table have been derived using the accepted electrical conversion formula using horsepower (HP) and efficiency (EFF), KW = HP x 0.746/EFF.
5.6 The power factor (PF) values shown in Attachments 2 -6 Tables, for motors rated greater than 250 HP, was input from calculation F- 1.1(Q), sheet 12, (Ref. 7.4).5.7 The power factor (PF) values shown in Attachments 2 -6 Tables, for motors rated 250HP or less, was input from calculation E-1.1 (Q), sheet 5, assumption 12 , (Reference 7.4).5.8 Power factor used for the battery chargers are assumed to be typical based on the similarity of the equipment.
The typical power factor was calculated by the following for battery charger 1A-D413: a Rated output 200A at 132 V DC* Rated input 56A at 480 V, 3PH, AC N Charger efficiency at 100% load = 0.875 WATTSOut = (200)*(132)=
26400 W WATTS In= 26400/0.875=
301 7 1 W U VA In = (5 6)*(4 8 0)*(3)"' = 46558 VA z PF = 30171/46558=0.648
<0 (a 5.9 Power factor used for MOVs is assumed at 0.4 based on a review of MOV operating F--characteristic curves.(in Z 5.10 Power factor of essential lighting, is assumed at 0.9. The lighting installed included 0_0 incandescent, fluorescent, high pressure sodium and mercury vapor. The lowest power factor per manufacturer cut sheets of the types installed is 0.9.&#xa9;a 5.11 Essential lighting loads are taken at 100% of the MCC breaker rating feeding the panel.i, Lw 5.12 Hydrogen recombiners PF is assumed to be 0.85 instead of 1.0 because of combination of the> induction motor blower and the resistive heating elements, 0 5.13 The kilo-var (KVAR) values shown in Tables 2 -6 were derived from the formula;ZKVAR --TAN (COS- (PF)} KW 0 0-ry Page 6 of 8 Li wO Calculation E-9(Q) Rev.8 Standby Class lE Diesel Generator Sizing 5.14 The SDG KVA is derived from the formula;KVA = (KW' + KVAR )5.15 The SDG power factor (PF) is derived by the formula;PF = KW/KVA 5.16 The load for various heat tracing panels was considered as the VA rating of the transformer feeding the heat tracing.
 
==6.0 CONCLUSION==
 
Calculations reveal that the maximum loading of each of the four SDGs at any time for conditions stated in paragraph 3.2.2 is within the SDG rating as follows: RATING KW KVAR PF KVA Continuous 4430 -3323 T 0.8 5538 2000 hr 4737 3553 0.8 5921 2 hr 4873 3655 0.8 6091 30 minute 5316 3987 0.8 6645 A summary of results is presented in Table in Attachment 8.0)Margin z o Hope Creek UFSAR Section 8.3.1.1.3 states that each SDG is rated at 4430 kw for continuous operation Q and at 4873 kw for 2 hours of short time operation in any 24 hours. Regulatory Guide 1,9 provides guidance on selection of SDG during the plant construction and states that it should have a continuous 0 load rating equal to conservatively estimated loads plus a 10 to 15 percent margin. IEEE-387 identifies this margin value at 10 percent. Attachment 8 of this calculation provides a summary of each standby Vdiesel generator loading. It demonstrates that the maximum loading of the diesels remains within the 10 percent above each SDG continuous rating.a> The changes incorporated Revision 8 are only to include the maximum stroke time (84 seconds) of A ar_ MOVs associated with the SACS crosstie valves for inlet and outlet to Spent Fuel Pool System heat o exchangers.
The stroke time for these valves is changed from 62 seconds to 84 seconds as the result of replacement valves being of a different design. The specialty review performed as part of the Design Change Package concluded that the change does not affect the previously analyzed loading and the w> established margin with respect to the standby diesel generators sizing.0 LU C/0~Page?7 of'8 Lu Calculation E-9(Q) Rev.8 Standby Class 1E Diesel Generator Sizing Impact on Procedure and Calculations The change in the valve stroke time was evaluated for impact on the Inservice Testing and Valve Program governing procedures as part of the specialty review during the DCPs 80003631 and 80003623 review and approval.Calculations (E-1.1, E-4.1, E-5.1, and E-6.l) identified in the reference section of this calculation are s input to this calculation and were reviewed for impact due to the changes incorporated by this revision.The review concluded that there are no impacts. Mechanical calculation JE-0015, diesel fuel oil storage tank is an output calculation.
The changes implemented by this revision will not impact calculation JE-0015.
 
==7.0 REFERENCES==
 
7.1 IEEE std. 308-1978.
Criteria for class IE power systems for nuclear power generating stations.7.2 NRC regulatory guide 1.9, Rev. 2, 1979. Selection, design and qualification of diesel -generator units used as standby (onsite) electric power systems at nuclear power plants.7.3 ANSI/IEEE std. 387-1977.
Criteria for diesel -generator units applied as standby power supplies for nuclear power generating stations.7.4 Calculation E-1. 1(Q), Short Circuit Studies of 13.8KV, 7.2KV and 4.16KV systems 7.5 HCVD PMOI8Q-0499 Vol. 1, Rev. 19, Operation and Maintenance Manual for Emergency Diesel Generator.
 
===7.6 Calculation===
: 4. 1(Q), Class lE 125V DC Station Battery and Charger Sizing.7.7 Calculation JE-00 15, Diesel Generator Fuel Oil Tank Sizing 7.8 Calc E-5.I(Q), Class 1E 250 VDC Station Battery and Charger Sizing.Io3,., 7.9 Calc E-6.1, Non Class lE 250/125 VDC System Station Battery and Charger Sizing z 7.10 E-0001-0 (Q) Rev. 17 HCGS Single Line Diagram (station)Cn zo3 0<Lii C1.-9 4 H--012 w-i, I 0 Cn I,[ry Page 8 of 8 rr, iC 01Pg 8o CJ USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 1 SDG Load Assignment Calculation E-9 Rev. 8 Page 1 of 8 i ComponeW Data CHNNL A" CHNlI 'C'" COIN]". P" CBIHNL] D" DBA (Note 13) LOP (Note 13)" -E " -L; ..: "" .: ". .F U I U L.*I'tem .... .. ! : : " " ..: ..1 * .'o : .2 .- -. I I- ."' .... 'No1ECITO gieeto i 0 ." z z- o'. :'.me E Tim.'re CLASS IE LOAI)S ... ___ ____ ___'__ I, I, 1 IRE.ACTOR CORE SPRAY PUMPS (Note 8) IA,B,C,D-P206
',655 10.930! 525.41, 1 j 525.41: 11 525.411 1 ;525.41; 1 i 525,41' 3 :19s (6)2 IHRp13TYAU5 CLoteS)S PU!('t8 I,,DP1 [ 250 1!0.90 002.69! 1- 1002.69. 1 :1002.69 1 J002.69! 1 '1002.69; 3 13s (6) 1 llmin 3 AEYU.CGSS1UI'(oe)
IABC-20 530 10.940, 420.62. 1 i420.62! 1 '420.62 1 420.62i I 420.62', 3 458 2 .45s 4 !CORE SPRAY PNP. RMv.CLRLUNIT I1AT1H.U1H-VH21II 15 0.9201 12.16 2. 24.33i 2 24.33 2 24.33 2 : 24.33i 3 ,40s '5 !MOTOR OPERATED VALVES" SEENOTE4 SET ]14.811 1 !14.81I I [14.81I I 14.81 1 1 [4.81' sets 13s 5sts1387 6SG MUITL.AS1A,BC,D-VH401i.
25 .0.920' 20.271 1I 20,27' 1i 20.27 11 2 0 2 7 jT 207311s ''5'7 ITAE SIRUcTURE SUFPLYFANS
!1A,B3,C,D-V503
! 40 '0.920. 32.431 1 !32,43, 1' 32.43 1i 32.431 1 ; 2.43j 2 138 (29) !2 (29)INTAKCE STRU JRThAVELING SCREENS 2 '- 2 165 I 9 'RJ-IR PUMP RM UNIT COOLER FANS __ATU_-__I,__"__020___6___2.
_3243 _____.4 __2-_2.4__2__3243_3__
0 I 1 11lmin-10 COOLERS JIA,BI-VH208 I 5 10.9201 4.05, .2. 8.111 i 1 ,65s 1 i65s 11 1.A, B-VH1209 ' 15 .0.920. 12.16! 2 24.33, .I 1 65s I  12 1I25-VDCBATTERYCHARGERS T;A, B..C, I4I3 : 37.95. 2 75.90, 3 113.85'2 75.90" 3 "113.85' 8 '13s 8 1l3s JsEENoTh17
,1!A.,BC.D14 i'I -'---" I* SEE NOTE 22 FOR I4INIMUM REQ'D I [CD, DD-44.4 I I *I I ...DISLAREA BATrlIRY ROOM FEXHAUST i I , , i 1 ...ii [ 3 1 13 FANS !IA, B,C,D-V406 1 10.9201 0.81!1 ': 0.811 1: 0.811 1 0.81! 1 :0,811 3 3s 3 113s 14 iDISEL FUEL OIL TR.ANSFER PUMPS [1AT1RU1H-P40t 5 ' 0.920i 4.05: 2 ', 8.111 2 8.11' 2' 8.11' 2 8.11 3 ,>60mm, 3 ,6omit 15 STATION SERV1ICEWATERPU/v1IS(N'ote8)
IlA, B, DC-P502 " 800 .0.9411 634.22: 1 634,221 1I 634.22 1 634.22 1 1 634.22j 3 755s J 3558 16 RBFRVSREC!RCULAT1ONSYSTEvIEANS
*IA'I1RU1F-V2l3
[150 .0.920' 121.63: 2 I 243.26 1 I 121.631 " 1i6I7 om0RSPLFS AB-43 ]40 092 3,31 .01 32.3- i 243.260.0 1 1 32,463 4 .3 198,30s (7- -1 3 i208Y/! 20-V AC XFMRS TO POWEiR DIST ,:, I '18 :PANELS 10X.201, 202, 203, 204' see nte 25 I 37.50 4 .37.50[ 4 37.50:4 37.50' 4 37.501 12 113.s 12  10lX411, 412,413,414
[. I ' I.!102X421, 422, 423, 424 ; .-, i !S'10X501, 502, 503, 504 .; i ,________________
19 -RESERVED FOR FUTURE USE ______________
________ ___ ________ __20 ]INTAXESTRUcTOJREEXHAUSTFANS
'LA, B,C,D-V504 40 32.43: I 32.43'"1 34 I: 32.43 1 32.43! 2 i138(29) -13s(29)jCONTROL ROOM CHILLED WATER i .21 IC[R.CULATINGP1MPS IlA, IB-P40O 60 :10.920: 48.65. : I .48.65 .1 :48.65 1 165s I 1 1658 22 iCNTRLRMSUPPLYUNITHTGCOIILS lIA, IB-VHg403 90.00. 1 90.00 ! i1 90,00: 1 i60s 1 60s 23 .CONTROLROOMWATERCHILLERS(Notel10)
:IA, IB-K400 '' I 80 0'.925 506.00-, ' Ii 506.001 ": I 506.00 1 0 '110s(28)24 iDIF.SELGENRMRECIRCSYSTEMSFANS
'IATOI, AR11-V412
: 125';09201 101.36! 2 "202.721 2 :.20.72i 2 :,202.72:, 2 .20.2..72; 3 130s(9)
* 3 30sC0NTIYr {14 ISTRUMN GAS ' .., i I [ '25 COMPRESSORS
]IA, 1B-K.202 , 15 .0.9201 12.16, i 1, 12.16. 1 12.1 6 I 1 !30rain 1 i30 min 26 BATT'IERY CHARGERS, 250-VDCx 110D423 10D433 I NOTE18 , ! 1.00. 1I 19.00 I 0.001 1 i19.00. 0.001 2' 13s 2 [138 II'n iCONTROL ARE'ABATERYr ROOM EXHAUST I '.2o 4oI I,.5 I i I 4 605 1 6 0s 27 FANS 1IA, IB-V4t0 1 5 1090 t0 0 I .i 1 405$28 ]RBFRVSRECIRCUrNITI-IEATINGCOL, S IIATI-RUIF-VH213 2 , 200.00; 1 ,100.00 2' 200.00 1 10000O 4. '(7) ' -, TRAVELING SCREEN SPRAY WATER I i z , : 55 29 BOOSTERPUMPS CA B, C,D-P507 , 20 0.920 16.22 1 516.21 55 16.2 i 1: 16.22 1 16225 , 3 1ss 30 RB FRVSVENTUNITIEATINGCOLS IA,'IB'-VH206
;2 , : 32.006 1 32.001 00007 1 32-.00, 000. 13s () 1 -3 jAFEY AX&deg; L G&deg;&deg; SYS.PU~ts (No~mte 8) 1 A,, D-2 3 : 0.40 42.2 1, 42&#xfd;2 2 &#xfd;1406 ' 1 42&#xfd;2 3 4s] 5 31 SFANS IA, t I-V415 1 30 1 0.9201 24.33. 2 1 24.3.3 , 1 24T331 -3,0 i S3s 32 CONTROL ROOMEMERGENCY FILTERANS IA, IB-VH400 1 25 0.9201 20.27. 1 , 1 I 20.271 1 202 1 I 207 30 6 30s USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 1 SDG Load Assignment Calculation E-9 Rev. 8 Page 2 of 8 Cmponent Data CNN "A' CHNL C CENLB CHNL"D (N D A 13)1 LOP (Note1)]3: .......: 'fT~:*'" .- ::,, .: .' Q. I._-, ..IA. IiPi '00, : i : .o -.SAFETY AUX COOLING SYSTEM UNIT, 6* : 0 II 33 COOLERS 'lA. ,CD-VH214 7.50 0.920: , '2 12.16 6! 216' 2 45s 2 145s 34 FUEL POOL COOLING PUMPS 1A, IB-P21I 75 :0.9201 60.82 1 1 60.821 0.00: I 60.82. 0.00! 1 &#xfd;61minm 1 161rmin CONTROL ROOM EMERGENCY FILTER UNIT I i I I 35 IELECTRICHEATINGCOILS IA, 1B-V400 13.00 1 13.00' 1 13_00 1 130s ' I,30s 36 CONTROL EQUIPMENT ROOM AIR SUPPLY 25 9 0 1 2 I 7 1 36FANS 1IA, 1B-VH407 250 '0.9201 202.7P- 11'202.72 1 202.72;1 I 70s 1 1705 37 iRB FRVS VENT SYS FANS IA, 1B-V206 i 25 0.920 20.27, I20.27' 0,00; 1, 2027. 0.00 ' 11ys CONTAINMENT HYDROGEN RECOM , iNER '38 !SYSTEM IA. 113-S205 140.00, I 140.00 0.00 1 140.001 1 24h I -h&#xfd;CONTROL EQIP ROOM SUPPLY UNIT HEATING -'39 iCOILS IIA, IB-VH407 100.00 0.00' 1 100.00 1 [00.00 1 :,70s 1 :70s I ..40 SERVICE WATERSELF-CLEANING STRAINERS IA, B,C, D-F509 1 0.920. 0.81 1 0.81, 1 0.81 1' 0.&1 1 081: 55s 55S 41 STANDBYLIQUffDCONTROLPUMPS ,IA, IB-P208 40 :0.920' 32.43 1 .32.43 1 32.43: 2 2 '13Ss(O15) 42 IRESERVE FOR FUTURE USE , : __, + ___ _ , ! , ,_44 RESERVED FOR FUTURE USE ! ,. -_ ...___ _' ! _ I I T 45 RESERVED FOR FUTURE USE --.... ' T-,480 V POWER SUPPLY TO CLASS IE CHILLER IA, IB-C488, I I I .' 1 46 PANELS IA, IB-C491 4.00. 1 4.00 1 4.00 1 4.00 1 , 4.00. 21 I 13s 47 TRAVELINOSCREENS I1A, 111, IC, ID-S501 5 .0.920 4.05 1 1 4.05 1 ' 4.051 1 4.05' 1 4.05. 3 55s 3 155s 48 ,ECCS JOCKEY PUMPS 1IA, 1B, IC. ID-P228 10 0.920 SI. I 8.11 1 I 8.111 1 I 811 1 I 8.11 3 1s 1 3 '13s MOTOR DRIVEN DIESEL GENERATOR FUEL LI 'I 10 9201i 49 OIL STANDBY PUMPS IA, IB, IC, 1D-P402, 2 0.9201 1.62! 1 1.62 1 1.621 1 1.621 1 ' 1.621 3 13s 3 13s STANDBY LIQUID CONTROL PUMP ROOM I " 4500 _ _ 'UC .HEATERS JA, IB-VE261 ' 45.00: 1 45.00, 0.00' i 45.00: 1 15 m i 1 15min 1480 V POWER SUPPLY TO HYDROGEN AND 51 OXYGEN ANALYZER PANELS IA-C',00 lB-C200 .100; 1 1.00: 0001 1.00; 0.00! 1 13s 1 13s 52 ,250VDCBATTERYROOMDUCT HEATERS II0-VE418 10.00 1 10.00 0.001 000 1 ,13s 1 13s'125 V DC DIESEL AREA BATTERY ROOM 53 DUCTHEATERS IA, 1B, IC. 1D-VE420 21.001 1 21.00: i 21.00 1 21.00, 1 21.00t 3 1s I13s 54 iHPCI PUMP ROOM DUCT HEATER 1I0-VE260 7 .0.00 .1I 55 IRCIC PUMP ROOM DUCTHEATER I10-VE259
: 7. .00i ,00, 0.00! 1 7.001 000 1 Is ! 1:s 56 .250VDCBATTERYROOMDUCTHEATER 1l0-VE417
' 8.00: 0.00', 0.001 1 8.00; 0.00! 1 135 I 13s 57 !CLASSIEPANELROOMWATERCHILLERS 11A, IB-K403(16) , 430(16) '0.9251 198.00 1 1 198.00, 0.00, 1 , 198.00. i 0.00. 1 125s(28) 1 .125s(28)ICLASS IE PANEL ROOM CHILLED WATER , ' ' I i , i 58 1P S IA, 113-P414 40 0.920 32.43 1 32.43 0.00. 1 32.43, 0.00 1 175s 1 75s ICLASS IE PANEL ROOM SUPPLY & REUR 1ABV408 0.920! 60.82 59 CASR FANS MLRIB-VHMS UPLY1RN' 75 I 60.82! 0.001 1 60.82! i 0.00! 1 180s I S8s 60 ICLASS 1EPANELROOMELECTRIC HEATERS 1A, lB-VH408 _10.00 1 I 100.00 1 0.00! 100.00 __0.00i l _-Ss _ !61 BATTERYYROOMEXHAUSTFANS i1A, B-V416 002 0.8] 1 ' 081 0.001 0.81 0.00. 1 160s I .60s 62 IBATTERY ROOM DUCT HEATERS 1A. IB-VE423 14.001 0.001 1 ' 14.00 j 14.001 2 ,13s
* 2 135 63 !H/0, ANALYZER HEiAT TRACING PANELS -F RCC200, DC200 15,00: 0.00i 1 ' 15.001 1 1 15.001 1 13s I J 13s 64 iRESERVED FOR FUTURE USE .j 65 IRESERVED FOR FUTURE USE-66 !RESERVED FOR FUTURE USE I .. .i USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 1 SDG Load Assignment Calculation E-9 Rev. 8 Page 3 of 8[_ _ComponentData CHNL"A" CHNL"C" CHNL "B" CHNL"D" DBA(Note 13) LOP(Note 13)i ~~p 0 l;i., j Z.IteM.--~.No.~~~~~~~Tm -i :.Time~ qnpet~. H, l ~~67 RESERVED FOR FUTURE USE _ ____ I i .: _68 RESERVED FOR FUTURE USEI ___69 RESERVED FOR FUTURE USE I__ -70 RESERVED FOR FUTURE USE 4 0 2 1 ' 0.00! 1 t NON-O.AS1/
LOADS ii ]i ''SeeNote I- I I___ _ s____ ___ ___ ___ ___ ___ ___ ___ __'___ I _ !jTURBINE GENERATOR TURNING GEAR OILa 71 pUMP 10-Pill "I 40 10-920i 32.001 1: 32.001 0.00_ 1 10min 1 !10min'STANDBY LIQUID CONTROL SOLUTION I 72 ;OPERATINGHEATER 410"276 i 10.00 1 10.00 0.00 0.00 0.00' 1 10min i 1 10rmin IAI-THRU IHI-V212 IA2- THRU 73 &#xfd;DRYWELL COOLNG UNIT FANS Ii112-V212
: 20 0.920 16.22i 8 129.74 , 0.00 8 I2974 0.001 -8 :13s 74 IRADWASTE EXHAUST FANS OA(B,C)-V305 100 0.920 81.09 1 81.09 1 81.09 1 81.09. 0.00! -i 3 4min i00L31 1. 10L1U, ;Notes 21& ,-:I 75 ESSENTIALPLANTLIGHTING 10L211. 10L411 23 52.40. I 5240 1 93.50. I 37401 1 I 93.50 2 0min ' 2 -13 s 76 CRD WATER PUMPS 1 IA, IB-P207 250 i0920' 202.721 0.00i 1 .202.72' 0.001 1 202.72 1 1l1min cI; 1 6min T'LURBINE BUILDING BA13=ERY ROOM', I I 77 iEXHAUSTFANS IA, 113-V138 3 10.920!, 2.431 1 2.43; I 0.00, 1 2.43' I 0.001 ,0 1b .min I113s TURBINE GENERATOR AUX BEARING LIFT I " " 00I 1 78 IPUMPS 9-SBP EACH AND !]A THRU IJ-P1 10 45 .0.9201 36.49; , 0.00 0.00 105.4'0C 1 340 min 14mi TURNING GEAR.- 60 HP ilOG-110 60 0.9201 48.65 0.00 0.001 0.001 0.00' _____, I I-KOO] iI' i I!2ri n 79 EMERGENCY INSTRUMENT AIR COMPRESSOR i I 150 0.920- 121.631 121.63 0.00 0.00. 0.001 --L 20 i.80 IRADWASTE SUPPLY FANS OA-V316. OB-V316 100 0.920 81.09 o 0.00 1 1 81.09- 0.00. 1 , 81.09i --1I14min IREACTOR BUILDING SUPPLY AIR HANDLING I i , 81 UNITS &#xfd;IA,1B, IC-VH300 150 0.920; 121.63. 1 121.63 1 121.63. 0.001 1 I 121.63;' 119s 82 REACTOR BUILD1NG EXHAUST FANS I1A, IB, 1C-V301 200 10.920 162.17: 1 T 162.17' 0.00o I 162-! 1 162.171I 2 il9s 83 RADWASTE TANK VENT FILTER FANS IOA-V306.0B-V306
'7.50 :0920, 608:1 6.08 0.00. 6.08 o.00; 1 61, mi 1 TURBINE BUILDING BATI'ERY ROOM SUPPLY , ' ' : i I 84 !FANS :]A, IB-V137 5 0.9201 4.05; 1 .4.05; 0.00; 1 4.05 0.00oo 10 min 1 113s 1 RADWASTE TANK VENT FILTER HEATING 85 COILS 0A L3-VI06 3.601 1 3.60, 0.00 1t 3.60. 0.00; 61 miinI 1 14 min 86 CHEMICAL LAB EXHAUST FANS IA, 0B-V307 20 .10.920 16.22: 1 16.221 0.00. 1' 16.12 0.00! 1 1120rmin j I ilImin IDESEL GENERATOR STARTING AIR' I i 87 iCOMPRESSORS IA-THRU1D-K402
.15 0.920 12.16, 1 12.16 1I 12.16t 1 12.161 1 12.16! 3 .lmin T3 11min 88 REACTOR AUX COOLING SYSTEM PUMPS IA, IR-P209 : 150 10.9201 121.631 1 121.63: 0.001 1 121.63 0.00: --'185s 89 125-V DC BATTERY CHARGERS IAI(2), IBI(2).D473
-Notes 19 '0.8001 57.001 2 : 114.00-, 0.00' 2 1 114.00! I 0.001 1 10lmin 2 ;13 90 125-VDCBATTERYCHARGERS IAI(2) IBI(2)-D474 Notes 17 '0.8001 38.00! 1 38.00: 1 I 38.00 1 38.00 1 .38.00' 4 10m 4 113s 91 250-VDCBATTERYCHARGERS 110D143 Notes20* 0.800j 57.00 i --0 0.0 0,00, 1 57.00 0.0 I 10min 113 s STANDBY LIQUID CONTROL SOL MIXING .1 , 7 I It [92 HEATER 10-E277 ..40.001 0.00' 0.00 0.00, 1 i 40.00- 1 10rmin 110 mini 93 RFPTAUXLUBEOILPPUMPQ(NOTEI2)&
ilA.IB,1C-1(2)P]24 25 -0.920 20.27i1 1 2027:1 I 20.27 1 20.271 0.00: 3 115m .3 15rmin TURNING GEAR MOTORS IlA, IB, IC-SI00 1.50 i 0.920, 12 1 .22i1 1.22 1 1.22 0.0011 3 115min 3 15mm 94 "RESERVED FOR FUTURE USE W- .0.00; 0.0& 0.00 0.00'95 1208V/120VACXFMRSTODISTPANELS 1005,20627.208.0 2 60.00: 60.00 1 30.00 30.00 3 m .3 13s USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment I SDG Load Assignment Calculation E-9 Rev. 8 Page 4 of 8____________________
_______ Cmpnel~ts CINL "A- C{NL"-C' CHNL "B" CUNIAD" DBA (Note 13) LOP (Note 13)REACTOR BUILDING FLOOR DRAIN SUIP I01 34.05 :_ I I '13 DESC00R0 ooT ION, , o o 2 96 jPUMPS .A1B, IC, ID -P265 5 10920 4.05 0.00~ 2 s.11l C.000 2 till1 2 110mn 213 97 DRYWELLEQ-UIPDRAINSUMPUMPS 1A, 1B-P267 1 5 0920 4.05 1 4.051 0.00! 1 4.05' I o.001 -1 2 13 s 9a 'DRYWELL FLOOR DRAIN SUMNPUMPS 1C, IP267 5 0.9201 4.05' 1 4.051 0-00 1 4.05, 0.001 -; 1 13s 99 *1A5929 SUPL FO UNI VENT RAITO j LMONITrORINGSYSTEMS
: VENTA LBS2 O 3.50, 1 3.500 3.50 1 3 150 3.501 0.! 1 110mi 1 s ,POWER SUPPLY FOR DLD RADIATION
* I j I 100 MON1TOR4NGSYSTEMS 110s935 ' 3.50' 0.00' 1 3.50 0.00 0.001 1 ,10min 1 13s 101 !TURBINE GENERATOR MAIN SEAL OIL PUMP I10-P173 T 20 0.920 '16." 0.0 0.00 1 16.22; 0.00 1 55mi" TURBINE GENERATOR RECIRC SEAL OIL .2, 102 PUMP ;10-P171 7.50 (0.920! 6.08 0.00j 0.00 1 6.08: 0.00' I 155 min , 1 :55 min ITURBINE GENERATOR SEAL OIL VACUUM 103 ;PUmp ]OP 172 3 :0j.920! 2.43] 0.0o 000, 1 2.43: 0.00 1 55 min 1 !55 mn RAWASTE + 24V DC BATTERY ROOM DUCT 104 ;HEATER 1O0-VE313
.5.00. 1 5.00; 0.00:0.00
-I 14mi CONDENSATE STORAGE TANK HEAT&deg;2 I .I .I 105 CTRACING (SEE NOTE26) 1C8i 12.00; 0.00 1 12.00" .0.00, 0.00. 1 '10min 1 113 s 106 ITSCSUPPLYSYSTEM FAN 0V11314 ., i 20.O1 000 1 i 2000. 000 , 0.00 1 15mi L 1 15m 107 )TSC SUPPLY SYSTEM HEATING COIL 0VH34. 0o 0.00! i 108 TSC EMERGENCY FILTER FAN iOOV 314 1 20.00 0.00; 1. 20.00 0.001 0.00 1 15 min i I 1l5min 109 TSC EMERGENCYFILTER HTG COIL IOVH 313 r 13.00 i 000! 1 13.001, 0.00 [ 0.00 15 min 1 ,15 min l10 STEAM TUNNEL UNIT COOLERS 1A, IB-V216 i 16.001 1 0.00: 0_001 1 16.00. 1 16.001 --1 mifn TURBINE BUILDING BATrERY ROOM SUPPLY T -111 FAN&HTGCOIL IjOVE132 50.00' 1 50.00; _ 0.00. 0.00! 0.001 I 10min 1 3s'TURBINE BUILDING COMPARTMENT I , I I 112 ,EXHAUSTFANS 10V106,1I0V19 0.000: 1 0.001 0.00. 0.00 --, 1 &#xfd;>10min CONTROL AREA 125 V DC BAT1"ERY ROOM I.- ' I 113 'DUCTHEATER
'10-VE419 16.00 1 16.00' 0.00 0.00. 0.00i 1 10 1 13S REMOTE SHUTDOWN PANEL ROOM SUPPLY I : 00 114 FAN 4.001 4.00! 0.00: 0.00 I 1 10 min[REMOTE SHUTDOWN PANEL ROOM BEATING: I i 000i , I Ii 115 COIL oVH316 10. 1 10.00 0001 .0.00 0.00 .-PLANT LEAK DETECT1ION SYSTEM HEAT q .I 116 TRACING PANEL (SEE NOTE 26) 10C282 12.00, ().001 1 0.00 0.00, 1 ' 12.00 1 10min 110min 117 1UNITVENTRMSIHEATTRACINGPANEL i10C 355 [ 15.001 15.001 i 0.00 i 0.00': 0.00j 1lm 110mmin]POST ACCIDENT SAMPLING SYS HEAT ; w ' I I I 11i ITRACING-PANEL IOC203 i 15.00' 0.0: 1 15.001 0.001 0.00' 1 10min 1 10min 119 jELECTRIC.UNITrBEATERS OT. 0BVEO389 !24.00 0.0 0, 1 24.97 0.o.00 0.00&sect;1 31t0min 3 10min 0CVE390 _ ,ffi __ _ ,II 120 TSC ELECTRIC-PANSHUMIDIFIERNOE26) iAVH314 i 16 0.920j 12.971 0.00' 13.97!' 0.00 0 0.00 1 '10 mi 1 10m 121 IWING AREA EXHAUST FANS IAV414, BV414 16.00 1 16.00 0.00' 0.00' 1 16.00, I "10amn 122 WING AREA SUPPLY FANS IAVH3O4, tBV11304 , ___ .40.00 1 40.00 0.00 0.01 40.00: 1'1mi 123 SPDSUPS .30N401 .60.00, 1 60.00: 1 60.00. ..0.00 0.00, 1 1 20min_ _ _ _ _ -- ------- L. --.
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby I E Diesel Generator Sizing Attachment 1 SDG Load Assignment Calculation E-9 Rev. 8 Page 5 of 8 NOTES 1 EACH STANDBY DIESEL GENERATOR IS RATED AS FOLLOWS: 4430 KW -CONTINUOUS WITH 10% OVERLAOD CAPACITY FOR 2 HRS IN EVERY 24 HOURS 4737 KW -2000 HOURS 4873 KW -2 HOURS 5316 KW -30 MINUTES 2 LOADING SEQUENCE IS BASED ON AVAILABILITY OF THREE SDGs AND THEIR ASSOCIATED ELECTRIC POWER DISTRIBUTION SYSTEMS DBA = DESIGN BASIS ACCIDENT DBA = LOCA + LOP LOCA = LOSS-OF-COOLANT ACCIDENT LOP = LOSS OF OFFSITE POWER 4 MOV'S MAXIMUM STROKING TIME WILL VARY FROM 20 TO 70 SECONDS EXCEPT FOR THE MAIN STEAM STOP VALVES, WITH STROKING TIME OF 120 SECONDS, THE SACS DISCHARGE TO TOWER VALVES, WITH STROKE TIME OF 90 SEC, AND SACS CROSSTIE VALVES TO INLET & OUTLET OF SPENT FUEL POOL COOLING HEAT EXCHANGERS WITH STROKING TIME OF 84 SECS. ALTHOUGH MOV LOADS ARE OF SMALL MAGNITUDE AND SHORT PERIOD OF APPLICATION, MOV LOADS OF 14.81 KW FROM TABLE 7 ARE USED FOR CONSERVATISM-5 "OPERATING KW" IS OBTAINED USING THE STANDARD HP TO KW TRANSFORMATION FORMULA FOR ALL LOADS.6 DURING A DBA, ANY TWO CORE SPRAY PUMPS AND THREE RHR PUMPS CAN BE MANUALLY TRIPPED AFTER 10 MINUTES FROM THE OCCURENCE OF LOCA, DEPENDING ON THE LOAD ON EACH STANDBY DIESELGENERATOR EITHER THE A OR THE B RHIR PUMP MUST BE RETAINED IN SERVICE AFTER 10 MIN. FROM THE OCCURENCE OF LOCA USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment I SDG Load Assignment Calculation E-9 Rev. 8 Page 6 of 8 7 BUSES A AND B EACH HAVE TWO FRVS RECIRCULATING FANS AND TWO UNIT HEATING COILS CONNECTEDTO THEM. BUSES C AND D EACH HAVE ONE FRVS RECIRCULATING FAN AND ONE UNIT HEATING COIL CONNECTED TO THEM. IN THE CASE OF A DBA, ONE FAN AND ONE UNIT HEATING COIL WILL START ON EACH OF BUSES A,B,C AND D AND THE REMAINING FANS AND HEATING COILS WILL START IN DIESEL BUSES A AND B AT THE TIMES IN THE LOADING CHART.8 MOTOR HORSE POWER SHOWN IS THE MAXIMUM BREAK HORSE POWER REQUIRD FOR THAT PUMP AS SHOWN IN THE ATTACHED LETTER MDE-01-0016 DATED 5/3012001 9 THE AUTOLEAD FAN STARTS AT 30 S, THE AUTO FAN (LAG) WILL START AT 95 S.10 MOTOR HORSE POWER RATING IS 680 HP. HOWEVER, PER M723-18-3 THIS APPLICATION POWER REQUIREMENT IS 506 KW.11 UPON THE OCCURENCE OF A LOCA, NON-CLASS 1E LOADS ARE TRIPPED BY LOCA SIGNAL IN THREE (3) SECONDS BY TRIPPING THE UNIT SUBSTATION CIRCUIT BREAKERS FEEDING THE NON CLASS 1E MCCs AND MOTORS. THESE LOADS CAN BE REENERGIZED MANUALLY AT 10 MINUTES AFTER THE OCCURENCE OF LOCA.12 TWO REDUNDENT 25 HP PUMPS ARE PROVIDED.13 TIMES SHOWN ARE FROM THE OCCURENCE OF LOCA OR LOSS OF OFFSITE POWER.14 LOADS WERE TAKEN FROM CALC. 1.1(Q) AND SINGLE LINE DIAGRAMS FOR MCCs AND UNIT SUBSTATIONS USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby IE Diesel Generator Sizing Attachment 1 SDG Load Assignment Calculation E-9 Rev. 8 Page 7 of 8 15 LOADS ARE NOT SEQUENCED BUT POWER IS REQUIRED TO BE AVAILABLE TO THE LOADS IN THE EVENT OF A LOP OR BE AVAILABLE WITHIN 25 SECONDS AFTER AN ATWS INITIATION SIGNAL. THE TIME SHOWN (13 S) IS WHEN POWER IS AVAILABLE AFTER LOP.16 MOTOR HP RATING IS 430 HP, HOWEVER PER M723-240 EQUIPMENT DESIGN REQUIRES 198 KW INPUT POWER 17 125 VDC BATTERY CHARGERS RATED 132 VDC & 200 ADC OUTPUT WITH 115% CURRENT LIMIT AND EFFICIENCY OF 0.8 PER PE151Q-0023 STATION 120 VOLT INVERTERS ARE INCLUDED IN THE BATTERY CHARGER LOAD 18 250 VDC BATTERY CHARGERS RATED 264 VDC & 50 ADC OUTPUT WITH 115% CURRENT LIMIT AND EFFICIENCYOF 0.8 PER PE151Q-0014 19 125 VDC BATTERY CHARGERS RATED 132 VDC & 300 ADC OUTPUT WITH 115% CURRENT LIMIT AND EFFICIENCY OF 0.8 PER PE05 IQ-0014 20 250 VDC BATTERY CHARGERS RATED 264 VDC & 150 ADC OUTPUT WITH 115% CURRENT LIMIT AND EFFICIENCY OF 0.8 PER PE051Q-0015 21 ESSENTIAL LIGHTING LOAD IS BASED ON MCC BKR FEEDING EACH PANEL (SECT.5.1 1).FOR CASES INVOLVING A DIESEL FAILURE, THAT FAILED CHANNEL IS ASSUMED TO BE MANUALLY APPLIED TO ANOTHER DIESEL PER DRAWING E1421 REV.0 SH 1.22 IF CHANNEL "C" OR 'D" FAILS MINIMUM REQUIRED IS 7; IF CHANNEL "A' OR "B" FAILS MINIMUM REQUIRED IS 8.23 PANEL OOL311 FED BY 50 AMP BKR (37.4 KW); lOLl II FED BY 70 AMP BKR (52.4 KW);1OL211 ANDT 1OL411 EACH FED BY 125 AMP BKR (93.5 KW).
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 1 SDG Load Assignment Calculation E-9 Rev. 8 Page 8 of 8 24 EFFICIENCIES AND POWER FACTORS WERE OBTAINED FROM OPAL -LOAD MANAGEMENT DATA BASE 25 THESE PANELS ARE RATED 75 KVA EACH, BUT BASED ON E1405 THEY ARE NOT FULLY LOADED. THE TOTAL LOAD FOR ALL 4 PANELS FOR CHANNELS A,C AND D IS APPROXIMATELY 24KVA.AND FOR CHANNEL B IS APPROXIMATELY 30 KVA.THEREORE, FOR CONSERVATISM A TOTAL LOAD OF 75*0.50=37.5 KVA IS CONSIDERED 26 FOR CONSERVATISM BREAKER RATING WAS USED FOR THESE LOADS 27 THE LOADING SEQUENCE IS BASED ON HOPE CREEK UFSAR TABLE 8.3-1.28 TIME INDICATED IS SEQUENCE TIME REQUIRED IF CHILLERS ARE OFF PRIOR TO DBA OR LOP. IF CHILLERS ARE ON PRIOR TO DBA OR LOP, SEQUENCE TIME REQUIRED IS 160 SECONDS.29 LOASDS ARE NOT SEQUENCED BUT ARE CONTROLLED BY PROCESS SIGNALS. FOR SDG LOADING PURPOSES THESE LOADS ARE ASSUMED TO START AND RUN AFTER 13 SECONDS FROM THE DBA/LOCA EVENT USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 1 of 12 S~~~~~Standby sdieeGenerAto D dyfislGnrer.
10- <MIN: 106o M :.:->60MIN F.I' MIN -.0.o0:. .. 60MI.Item DESCRIPTION PF KW KVAR; KW KVAR KW KVAR KW KVAR KW KVAR KW KVAR CLASS IE LOADS i I I 1 REACTOR CORE SPRAY PUMPS (Note 8) 0.910 5 525.411 23938: 525.41 239.38 525.41 239,38 2 ;RHRPUMPS (Note 8) 0.890 1002.69' 513.69. 1002.69 513.69i 1002.69i 513.691 1002.69. 513.69!3 1SAFEIYAUX.
CLG. SYS. PUMPS (Not 8) 0.909! 420.62 192.86 420.62i 192.86' 420.62 192.861, 420.62 192.86i 4 ICORE SPRAY PMP. RM. CLR. UNIT 0.8501 12.16. 7.54! i i 12.16 7.541 12.16, 7T54i 12.161 7.54 5 MOTOR OPERATED VALVES 0.4001 14.81! 33.931 14.81! 33.93. 14.81! 33.93 14.81! 33.93i 14-81 33.93 14.811 33.93 6 1SWGR. RM. UNIT CLR. FANS F 0.850o 20.271 12.56 3 2027 12.561 20.27! 12.561 20.271 12.56, 20.27 12.56 20.27! 12.56 7 INTAKE STRUCTURE SUPPLY FANS " 0.850' 32.43' 20.10 32.43; 20.101 32.43; 20.101 32.431 20.101 32.431 20.10i 32.43. 20.10 INTAKE STRUCTURE TRAVELING SCREENS : I I i S AREA FANS 0.8501 6.08! 3.77! 6.08' 3.77 6.081 3.77' 6.08j 3.77! 6-085 3.771 6.081 3.77 9 RHR PUMP RM UNIT COOLER FANS 0.850' 16.22: 10.05: 16.22 10.05; 16.22; 10.05: 16.221 10.05: I 10 !RCrC PUMP RM. UNIT COOLERS 0.850 -' .8.111 5.03! 8.11! 5.03' 8.111 5.03 I1 1HPCI PUMP RM UNIT COOLERS 0.850 12.16 7.54, 12.16! 7.54' 12.16' 7.54 i 12 125-VDCBATTERYCHARGERS 0.600; 75.90 101.20- 75.90: 101.20. 75.90 101.20. 75.90: 101201 75.901 101.20, 75. &#xfd;90 120 13 !DIESEL AREA BATTERY ROOMEXHAUST FANSi 0.850i 0.81' 0.50! 0.81 0.50: 0.81, 0.50 0.81. 0.50; 0.81: 0.50; 0.811 0.50 14 DIESEL FUEL OIL TRANSFER PUMPS 1 0.850' 4-05' 2.51, 1 1 4.051 2.51 15 STATION SERVICE WATERPUMPS (Note 8) i 0.875 634.22; 350.90 634.22' 350.90, 634.22: 350.90! 634.221 350.901 1 i 16 RBFRVSRECIRCULATIONSYSTEMFANS
' 08501 243.26: 150-T6 1l1.631 75.381 121.63k 75381 243-261 150.761 121.63! 75.38, 121.631 75.38 17 CONTROL RM SUPPLY FANS 0.850i 18 1208Y/120-VAC XFMRS TO POWER DIST PANELSI 0.850 37.501 23.241 37.50! 23.24 37.50i 23.24; 37.50, 23-2-4 37.50 23.24 37.50 2324, 19 IRESERVED FOR FUTURE USE 1.000 2.001 I i I 20 INTAKE STRUC1UJRE EXHAUST FANS 0.850 32.43! 20.10' 32.43i 201 32.43 20.10' 32.431 20.10; 32.431 20.10 32.43 20.10 CONTROL ROOM CHILLED WATER I 21 CIRCULATING PUMPS 0.850! ' , I 22 CNTRLRMSUPPLY UNIT HTGcCOILS 1.000! i 23 !CONTROL ROOM WATER CHILLERS (Note 10) 0.878. ..I I 24 1DIESEL GEN RM RECIRC SYSTEMS FANS 0.850 202.72. 125.63 202.72! 125.631 202.72. 125.63 202.72; 125.63. 202.72- 125.631 202,72! 125.63'PRIMARY CONTAINMENT INSTRUMENT GAS 25 'COMPRESSORS 0.850' ' _ _26 BAY1-ERY CHARGERS, 250-V DC 0.600. 19.00, 25.33 19.00 25.33 19.00 25.33' 19.00 25.33! 19.00 2533 19.00. 25.33 CONTROL AREA BATTERY ROOM EXHAUST : : , -I ! I 27 IFANS 0.850' , '28 1RB FRVS RECIRC UNIT HIEATING COILS ! 1.000. 200.00! 100.001 0 0.00' 200.001 100.001 i 100.001 TRAVELING SCREEN SPRAY WATER BOOSTER' I I I 29 PUMPS , 0.8501 16.22i 10.05: 16.22: 10.05: 16.22! 10.05! 16.22 10.051 16.22&#xfd; 10.05&#xfd; 16.22 10.05 30 RB FRVS VENT UNITBEATINO COILS 1.0001 32.o0o : 32.00 32.001 32-00&deg; I i i _CONTROL ROOMSUPPLYSYSTEM MEURN 31 tFANS, 0.850 , I ! .1I'_,__i, 32 ICONTROL ROOM EMERGENCY FILTER FANS 0.8501 i ' I 1 I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 2 of 12 Stanoy~eeenr~rP
~ ~ -Sndby Dieseni&#xfd;O&#xfd; GeiioeraforB Item' DESCRIPTION PF KW KVAR KW KVAR KW KVAR I KW KVAR KW 1 KVAR KW KVAR II 33 jSAFETY AUX COOLING SYSTEM UNIT 0.850: II _________34 !FUEL POOL COOLING PUMPS 0.850I 60.821 37.691 60-8_;CONTROL ROOM EMERGENCY FILTER UNIT , 35 IELECTRIC HEATING COILS 1.000 , i I CONTROL EQUIPMENT ROOM AIR SUPPLY I I 36 FANS 1 0.8501 37 RB FRVS VENT SYS FANS 0.8501 20.27' 12.56. 20.27 .12.56: 20.27 12.561 20.27! 12.561&#xfd;CONTAINMENT HYDROGEN RECOMBINER i 38 iSYSTEM _ 0.850:__ _ _ I _]CONTROL EQIP ROOM SUPPLY UNIT HEATING i' '39 COILS _ ., ! ; I I _40 SERVICEWATER SELF-CLEANIN STRAINERS 0.850 0.50 0.81 0.501 50 0.1, 0.50 0.81: 0.50 0810.50 41 :'STANDBY LIQUID CONTROL PUMPS 60.850 32.43 20.10 32.43. 20.10; 32.43 20.10i 32.43. 20.10: 32.43j 20.10! 32.43; 20.10 42 RESERVED FOR FUTURE USE 1.000: , _ _ _: [ I i 43 RESERVED FOR FUTURE USE 1_000, .._.____;_, I 44 RESERVED FOR FUTURE USE 1.000- .; ___ II 45 RESERVED FOR FUTURE USE T 1.0001 'i_ _ ' , _ _ _ _ _ i,'480 V POWER SUPPLY TO CLASS IE CHILLER 46 &#xfd;PANELS 0 ,850! 4.00, 2.48 4.ooi 2.48i 400 2.481 .00 2.481 4.001 2.48i 4.001 2.48 47 ITRAVELING SCREENS 0.850 4.05 2.51' 4.051 2.51: 4.05 2.51! 4.05 2.511 4.05 2.511 4.05, 2.51 48 !EGCS JOCKEY PUMPS I 0.850! 8.111 5.03. 8.11: 5.03: 8.11; 5.031 8 5.0 5.03! g.1 5.031 8.11: 5.03 MOTOR DRIVEN DIESEL GENERATOR FUEL 49 OIL STANDBY PUMPS I 0.8501 1.62. 1.01 1.62, 1.011 1.621 1.01 1.62! 1.011 1.62 1.011 1.621 1.01 50 STANDBY LIQUID CONTROL PUMP ROOM DUCT 1.0001 ' 45.00i 45.001 I I 5480 V POWER SUPPLY TO HYDROGEN AND .06 "6i 51 OXYGEN ANALYZER PANELS j 0.850. 1.00i 0.62! 1.001 0.62: 1.00, 0.62 1.00 0.621 1.00 0.621 1.00; 0.62 52 1250 V DC BATTERY'ROOM DUCT HEATERS I 1.000: 10.00' i 10.001 10.00, 1 I 125 V DC DIESEL AREA BATTERY ROOM DUCT : I '53 IHEATERS 1.000 21.00 .21.00 2 21.00i 21.00; ! 21.001 54 1EPCI PUMP ROOM DUCT BEATER Lot.OO 11.00 11.00! 11.00!55 IRCIC PUMP ROOM DUCT HEATER 1.000. 7.00: 7.00, 56 1250 V DC BATTERY ROOM DUCT HEATER 1.000 i I s~o: 80ool 8.00o 57 iCLASS 1E PANEL ROOM WATER CHILLERS 1 0.886: 198.001 103.62 198.00! 103.62' 198.00 103.621 198.00. 103.62 ! _!CLASS 1E PANEL ROOM CHILLED WATER , 5a !PUMPS 0.8501 32.43: 20.10' 32.43 20.10: 32.431 20.10 32.431 2o0o.10 _ ,!CLASS I E PANEL ROOM SUPPLY & RETURN I " : [- .I 59 *I FANS 0, 850! 60.82:1 37.69. 60N,13~7.691 60.82: 3 7.69i 60.82:1 37.691 ___60 ,CLASS IE PANEL ROOM ELECTRICHEATERS 1.000: 100.00i 100.006 100.00. , 100-00. ____61 : 1 BATTERY ROOM E[iLAUST FANS I 0.850- 0,81i 0.501 0.81. 0.50 0.81, 0.50, 0.81. 0.50': 0.811 0.501 0.81! 0.50 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 3 of 12________________________
____Standby
'Diesl -Generator A San D~iqesid 03nr1or-l3" ter DESCRIPTION PF 1 KW KVAR KW 1KVAR KW KVAR KW KW _KV__ KW_ KVAR t62 _BATERY ROOM DUCT HEATERSRI
, 63 H2/02 ANALYZER HEAT TRACING PANELS L IOWO ____ _ _64 RESERVED FOR FUTURE USE 1.000, .i _ I ____65 !RESERVED FOR FUTURE USE 1.000; i _ __66 1 RESERVED FOR FUTURE USE ] 1.0001 -67 RESERVED FOR FUTURE USE I 1.000 .I _ _68 1RESERVED FOR FUTURE USE 1_ __000'__ , _i f I " 69 RESERVED FOR FUTURE USE , 1.000. ' " !1 _ , 70 RESERVED FOR FUTURE USE 1.000 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calcufation E-9 Rev. 8 Page 4 of 12_________________________Stnb Dee GnrtorA f tandby Dee eeur1 i~~ ~~~~ ....' ."...L ....:::::::: Item DESCRIPTION PF KW KVAR KW 'KVARi KW KVAR KW I KVAR KW [KVARI KW KVAR NON-CLASS IE LOADS _ _ .. _ __ _ _[_[See Noteh I I I 71 "M GENERATOR TURNING GEAR OIL III II 3~ 9 3  20 98 71 "PUMP i 0.850, 3.00&#xfd; 19-83i 32.00 19.83 STANDBY LIQUID CONTROL SOLUTION i i I I 72 OPERATING HEATER 1.000 10.00 10.00o 73 DRYWELL COOLING UNIT FANS 0.850i : ' ' _ I T 4 74 RADWASTE EXHAUST FANS [ 0.8501 .i ', __ '--75 ESSENTIAL PLANT LIGHTING [ 0.900 52.401 25.38 52.40' 25.38 1 37.40. 18.11: 37.401 18.11 76 1CRD WATER PUMPS I 0.850 i i ! ....... : : !ITURBINE BUILDING BATTERY ROOM 1I ..I " 77 1EX!-AUSTFANS 0.850! .51 2.431 1.51 2.43! 1.51: 2.43' 1.51 TURBINE GENERATOR AUX BEARING LIFT ' I ' 1 78 PUMPS9-SIP EACH AND 0.850' _ _ -_ .I [ I ,TURNING GEAR -60 HP 85.I41 52.77! 85.14 52.77 79 EMERGENCY INSTRUMENT AIR COMPRESSOR 0.850 .I _80 !RADWASTE SUPPLY FANS 0.850,'IREACTOR BUILDING SUPPLY AIR HANDLING ' I 81 IUNITS 0.850i " _ _ _ -_ _ ___82 REACTORBUILDING EXHAUST FANS 0.850 ...... I --83 RADWASTE TANK VENT FILTER FANS 0.850! 6.08 3.771 6.0 8.3.77 ' 6.08i 3.77i 6.08 3.77!TURBINE BUILDING BATTERY ROOM SUPPLY " 84 !FANS 0.850' 4.05' 2,51 4.05 2.51' 4.05; 2.51! 4.053 2.51 i RADWASTE TANK VENT FILTER HEATING I ! 1 I I5 COILS 1.000i 3.60i 3.60 i 3.60: 3'60 86 CHEMICAL LAB EXHAUST FANS 0.850 16.22' 10.05: 16.22; 10.051 16.22 10.05i 16.22; 10.05 DIESEL GENERATOR STARTING AIR I " I I 87 ICOMPRESSORS 0.850I .12.16 7.541 12.161 7.541 _ _ I12.16! 7.54, 12.16: 7.54 88 IREACTOR AUX COOLING SYSTEM PUMPS 0.8501 I ......I '_ ,'__89 11 25-V DCBATTERYCHARGERS I 0.6001 114.00, 152.00. i4.00 152.001 114.00 152.001 114.00; 152.00 90 125-V DC BATTERY CHARGERS 0.600 .38.00: 50.671 38.00 50.67 ; 38.00 50.671 38.001 50.67 91 250-V DC BATTERY CHARGERS 0.600 ' .57.00 76.001 57.001 76.00 STANDBY LIQUID CONTROL SOL MIXING I I I I 1 I 92 HEATER 1.000 _ I I 93 1RFPT AUX LUBE OIL PUNP (NOTE 12) & 0.850. .I TURNING GEAR MOTORS 21.491 13.32: 21.49' 13.32: 1 21.49: 13.32: 21.491 13.32 94 )RESERVED FOR FUTURE USE 1.000 ! _ _ _ i _____95 120 V AC XFMRS TO DIST PANELS 0.850o 30.00. 18.59; 30.00i 18.59: 15.00i 9.30 15.00! 9.30 96 REACTOR BUILDING FLOOR DRAIN SUMP PUMP 0.850 I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 5 of 12: .. .Standby Die'sl Generator A:- --Standby t..B: .1~~N~~6MIN
-[ 0 Mi j 'MIN'Item DESCRIPTION PF KW KVAR ' KW KVAR KW KVAR I KW KVAR W KVARI KW KVAR 97 I DRYWELL EQUIP DRAIN SUMP PUMPS 0.850: 4.05: 2.511 4-05: 2.51' 1 1 4.051 2.511 4.051 2.51 98 iDRYWELL FLOOR DRAIN SUMPPUMPS 0.8501 .4.05 2.511 4.05! 2.51. I 4.05! 2.51 4.05 2.51'POWER SUPPLY FOR UNIT VENT RADIATION i ..I 99 MONITORING SYSTEMS 0.8501 3.501 2.17' 3.50' 2.17! : 3.50; 2.17! 3.50' 2.17 POWER SUPPLY FOR DLD RADIATION i .I , i 100 MONITORING SYSTEMS -0.850: : _ 1 101 TURBINEGENERATORMAIN.SEALOILPUMP 0.8501 16.22; 10.05! 16.221 10.05 102 !TURBINE GENERATOR RECIRC SEAL OIL PUMPi 0.850 1I 6.08' 3.77: 6.081 3.77 URBINE GENERATOR SEAL OIL VACUUM j I ' .]I 103 PUMP __0.850..
I !I 2.43 1.51 2.43t 1.51 RAWASTE + 24V DC BATTERY ROOM DUCT : 1 I i I 104 tHEATER ,, .000 5.00, 5,001 1CONDENSATE STORAGE TANK HEAT TRACING I' I I 105 I(SEE NOTE 26) .L I I ' i i :_ _106 'TSC SUPPLY SYSTEM FAN I i ._ _ [ _ , _107 .TSC SUPPLY SYSTEM HEATING COIL 1.000. '108 .TSC EMERGENCY FILTER FAN 0.850, ___ 1 i !109 ITSC EMERGENCY FILTER HTG COIL 1.000i -..=. ._ ' [110 STEAM TUNNEL UNIT COOLERS 0.850: _ _ 16.00 9.92' 16.00' 9.92!TURBINE BUILDING BATTERY ROOM SUPPLY III [FAN & HTG COIL 1.000' 50_00: 50.00 1 TURBINE BUILDING COMPARTMENT EXHAUST-112 IFANS 0.850;;'CONTROL AREA 125 V DC BATTERY ROOM I , I 113 DUCT HEATER 1 1.000 16.00' I 16.ooj 00i i i i_ ___ .i_ _ _ 1 _REMOTE SHUTDOWN PANEL ROOM SUPPLY I _' _ I ____114 FAN 09850! ' 4.00 2.48 4.001 2.481 _ _ i _ i REMOTE SHUTDOWN PANEL ROOM HEATING I o 1 1 115 COIL 1.000; 10.00 10.00 Iooo __ __ _PLANT LEAK DETECTION SYSTEM EATi 116 TRACING PANEL (SEE NOTE 26) 1.0001 i! .t[ II _ _ i [117 UNIT VENT RMS HEAT TRACING PANEL I 1.0001 15.00: i15.00o' _ i _ I IPOST ACCIDENT SAMPLING SYS BEAT f 1 I I 118 TRACING PANEL I 1.0001 [ I ' I I ELECTRICUNIT HEATERS 10. ' I _. , 120 TSC ELECTRIC PAN HUMIDIFIER (NOTE 26) 0.850' 40.00 _ _ _121 WING AREA EXHAUST FANS i 0.8501 i 16.001 9.921 16.00 9.921 I i _ _122 1WING AREA SUPPLY FANS i 0.8501 40.00 24.79! 40.00i 24.79: I 123 ISPDS UPS 1.000! " '::60.00:
0.00: _ ._
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 6 of 12 I- -Standby Diesel Generaxor A-. I Stnb Wieser- (iener(6r R-<0 IN- I-6MI ] >6OMIN <iMNi-DI __Item DESCRIPTION PF KW KVAR KW ;KVARi KW IKVAR KW KVAR KW IKVAR KW KVAR 124 RESERVED FOR FUTURE USE 1.0001 -_125 1 RESERVED FOR FUTURE USE 1.000: _ _ _ _ _ _KWI 4063.28: 2055.871 3827.121 2063.28. 3951.991 2103.49- 4053.22 2053.36 1811.25 1186.301 1815.30; 1188.91 KVAR: 2055.87. 2063.28 2103.491 1 2053.36 1186.301 1188.81.KVA , 4553.77 4347,87 , 4476.93 i 4543.66 2165.161 2169.931 0.891 0.88 I 0.88I 0.89 I 0.84' o.841 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 7 of 12 Standby Diesel Generator C 110-60 MAN >60 MIN Item DESCRIPTION PF KW KVAR. KW KVAR KW KVAR KW I KVAR KW KVAR KW KVAR CLASS I1E LOADS , 9 I REACTOR CORE SPRAY PUMPS (Note S) 0.910! 525.41! 239.38i i 52541 239.38' 525.41k 239.38! 525.41, 239.38 2 1RHR PUMPS (Note 8) 0.890 0 1002.69! 5 -- 513.69 I 3 SAFETY AUX. CLO. SYS. PUMPS (Note 8) 1 0.909. 420.62! 192.86' 420.621 192.86! 420.62 192.86, 420.62 192.86 420.62 192.86! 420.62' 192.86 4 :CORE SPRAY PMP. RM. CLR. UNIT 0.850! 12.16. 7.54. I 12.16i 7.54 12.16i 7.54! 12.16 7.54 5 MOTOR OPERATED VALVES 0.400' 14.81 33.93. 14.81' 33.93. 14.81: 33.931 14.811 33.93. 14.81: 33.93, 14.81. 33.93 6 SWOR. kM. UNIT CLR. FANS 0.850z 20.271 12.56; 20.27 12.56i 20.27: 12.561 20.27' 12.56! 20.2712.56 2027 12.56 7 ]INTAKE STRUCTURE SUPPLY FANS 0.850 32.43! 20.10: 1 32.43; 20.101 , SINTAKE STRUCTURE TRAVELING SCREENS I I I ' .8 AREAFANS 0.850! I " 9 RIR PUMP RM UNIT COOLER FANS 0.850; 16.22 10.05 ' 16.22i 10.05 I 10 iRCIC PUMP RM. UNIT COOLERS _ 0.850i _ " _ ____' ! I 11 J-PCI PUMP RM UNIT COOLERS 0,8501 ' .I .11.4 12 1125-VDCBATERYCHARGERS I 0.600I 13.85! 151.801 113.851 151.80! 113.85. 151.80 113.85 151.801 113.85: 151.801 113.851 151.80 13 DIESEL AREA BATTERY ROOM EXHAUST FANS 0.8501 0.81' 0.50' 0.811 0.50! 0.81: 0.50; 0.81 0.50, 0.81 0.501 0.81, 0.50 14 DIESEL FUEL OIL TRANSFER PUMPS 1 0.850! I 4.05! 2.511 1 : 4.051 2.51 15 !STATION SERVICE WATER PUMPS (Note 8) 0.875 634.22 350.90&#xfd; 634,22! 350.90, 634.221 350.90i 634.22i 350.90: 634.221 350.90; 634.22: 350.90 16 IRB FRVS RECIRCULATION SYSTEMFANS 0.850- 121.63' 75.38! 121.63, 75.38: 121.63! 75.38! 121.63i 75.381 121.63' 75.389 121.63 75.38 17 CONTROL RM SUPPLY FANS 0.850 32.43! 20.10! 32,43, 20.10! 32A3' 20.10, 32.43: 20.IOi 18 208Y/120-VACXFMRSTOPOWERDISTPANELS!
0.850! 37.50; 23.241 37.50! 23.24' 37.50 23.24 37.50: 23.24j 37.50. 23.24! 37.50 23.24 19 'RESERVED FOR FUTURE USE ! 1.0001 , ' ' , .I 20 :[NTAKE STRUCTURE EXHAUST FANS 0.850; 32.43: 20.10: ' -: 32.43 20.10: CONTROL ROOM CHILLED WATER !21 CIRCULATING PUMPS 0.850i 48.65. 30.151 48.65 30.15 48.65i 30.15! 48.65! 30.15 , 22 -CNTRL RM SUPPLY UNIT HTG COILS 1.000i 90.001 1 90.00 90.00 90.001 '23 CONTROL ROOM WATER CHILLERS (Note 10) ) 0.8781506.01 275.86' 506.00: 275.86' 506.00 275.86 506.00' 275.861 24 1DLESELGENRRMlRECIRC SYSTEMS FANS 0.850i 202.72: 125.63! 202.72! 125.63: 202.72i 125.63. 202.72 125.63! 202.72, 125.631 202.72i 125.63 PRIMARY CONTAINMENT INSTRUMENT GAS : , I I 25o C P SSOR 0850 12.16! 754 12.16! 7.541 12.161 7.54' 12.161 7.54 26 IBATTERY CHARGERS, 250-V DC 0.600' i _ i " !.CONTROL AREA A-fYIERY ROOM EXHAUST ' : , .27 'FANS 0.8501 4.05: 2.511 4.05: 2.51. 4.05 2.51: 4.05 2 .1 405: 2.51, 4.05: 2.51 28 MRBFRVSRECIRCUNITHEATINGCOILS 1.000!1 100-00; 1 100.00 : 100.00. 100.00! 100.00; 100.00i:TRAVELING SCREEN SPRAY WATER BOOSTER! I , 29 IPUMPS 0.850' 16.22i 10.05: 16.22i 10.05!: 16.22! 10.05, 16.22. 10.05! 16.221 10.05! 16.22 10.05 30 IRB FRVS VENT UNIT HEATING COILS 1 1.000 ' I CONTROL ROOM SUPPLY SYSTEM RETURN : ' : 31 'FANS 0.8 5 0 I 24.33; 15.08: 24.33 15.08: 24-33. 15.081 24.331 15.081 32 1CONTROLROOMEMERGENCYFILTERFANS I 0.850j 20271 12.56i 20.27; 12.561 20.27 12.56 20.27! 12.56!,
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 8 of 12_ _St Sandby Disel Generalor C .-S<10MIN 0-60MIN >60MIN Item DESCRIPTION
[ PF KW KVAR KW 'KVAR. KW KVAR KW KVAR KW KVAR KW KVAR 33 ;SAFETY AUX COOLING SYSTEM UN1T 0.8501 12.16, 7.54: 12.16! 7.54: 12.16' 7.541 12.16, 7.54: 12.16' 7.54: 12.16: 7.54 34 IFUEL POOLCOOLING PUMPS 0.8501 I -_ _ _[CONTROL ROOM EMERGENCY FILTER UNIT 35 1ELECTRIC HEATING COILS 1.000 13.00; 13.00 13.00. 13.00i 13.00 I 13.00&#xfd;'CONTROL EQUIPMENT ROOM AIR SUPPLY I ! .i -36 :FANS i 0.8501 202.72' 125.631 202.72 125.63 202.72: 125.63i 202.72 125.63 ! _37 'RB FRVS VENT SYS FANS 0.850' 1-.;___i CONTAINMENT HYDROGEN RECOMBINER 38 SYSTEM 0.850! ' 140.00 86.76 CONTROL EQIP ROOM SUPPLY UNIT HEATING , _
* I 39 COILS 1.0o00 100.00i 100.00 100.00! 100.00, 40 SERVICE WATE7SEPLF-CLEANNGSTRAINERS 0.8501 0.81' 0.50i 0.81' 0.50: 0.811 0.50i 0.81 0.50' 0.81 0.50! 0.811 0.5.0 41 iSTANDBY LIQUID CONTROL PUMPS 0.8501 -I 42 1RESERVED FOR FUTURE USE 1.000! L i W 43 RESERVED FOR FUTURE USE 1.000; " __:_ __ _44 RESERVED FOR FUTURE USE 1.000L ow. .-] i _ _..45 1RESERVED FOR FUTURE USE 1.000 , i !480 V POWER SUPPLY TO CLASS 1E CHILLER 46 JPANELS 0_8501 4.00: 2.481 4.00 2.48] 4.00; 2.481 4.00 2.48&#xfd; 400: 4.001 2.48 47 ]TRAVELING SCREENS 0 0.850 4.05 2.511 4.05! 2.51 4.05, 2.511 4.05 2.51 4.051 2.511 4.051 2.51 48 ECCS JOCKEY PUMPS 0.850, 8.11: 5.03; 8.111 5.031 8.11! 5.031 8.111 5.03. 8.11 5.031 8.11. 5.03 MOTOR DRIVEN DIESEL GENERATOR FUEL I 49 OIL STANDBY PUMPS j 0.850. 1.621 1.01, 1.621 1.01'; 1.62. 1.01' 1.62' 1.01! 1.62' 1.011 1.62i 1.01 50 !STANDBY LIQUID CONTROL PUMP ROOM DUCT 1.000 1 45.00i i _480 V POWER SUPPLY TO HYDROGEN AND I 51 'OXYGEN ANALYZER PANELS 0.8501 52 1250 V DC BATTERY ROOM DUCT HEATERS 1 1.0001 !_1125 V DC DIESEL AREA BATTERY ROOM DUCT 1 53 'HEATERS 1.000. 21.00 21.00: 21.00: 21.00! 21.00 21.00 54 HPCI PUMP ROOM DUCT HEATER 1.000.55 IRCIC PUMP ROOM DUCT HEATER 1.000' i ! : 56 .250 V DC BATTERY ROOM DUCT HEATER 1.000 _ _ _57 CLASS IE PANEL ROOM WATER CHILLERS 0.886I -!CLASS IE PANEL ROOM ClIILLED WATER I ..... I 58 PUMPS 0.850) 'iCLASS IE PANEL ROOM SUPPLY& RETURN ' ' [59 ;AIR FANS 0.850', :, 60 CLASS IEPANEL ROOM ELECTRIC HEATERS 1.000 ___61 I BATERY ROOMEXHAUST FANS 0.850; i USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 9 of 12 Standby Diesel Generator C_________________________
im0M 106Mm >60 MIN Y2 m Item DESCRIPTION L PF KW : KVAR KW KVAR KW KVAR: KW KVAR KW KVAR KW KVAR 62 IBATTERY ROOM DUCT HEATERS 1.0001 14.001 1 14.00 , 14.00! 14.001 I 14.00 i 14.001 63 H2IO2 ANALYZER HEAT TRACING PANELS 1.000; 15.00! 15.00; i 15.001 15.001 15.00 001 64 1RESERVED FOR FUTURE USE 1.000 i I : 65 RESERVED FOR FUTURE USE 1.000 -------------------
-66 RESERVED FOR FUTURE USE 1 1.000 : ____ _____67 RESERVED FOR FUTURE USE I.000' I i ..._68 RESERVED FOR FUTURE USE 1.000'' I : 69 RESERVED FOR FUTURE USE 1.000._ _ ___i_: 70 RESERVED FOR FUTURE USE 1.0 I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 10 of 12 Stan~dby Diesel Generator C T 1 I 10-60OMIN
>60 MIN 2 ~1~ ,Z~~MI ~ .I z... .... M I # 5F '6:I. ' ! "-.'m .... iii:% -. w .Iteml DESCRIPTION PF KW i KVAR' KW .KVAR KW KKVAR KW KVAR NON-CLASS IE LOADS I i -I SeeN-te1-1 iTURBINE GENERATOR TURNING GEAR OIL I 71 PU0.850 STANDBY LIQUID CONTROL SOLUTION " 72 OPERATING HEATER L.0001 .I 73 DRYWELL COOLING UNIT FANS i 0.850i I i I 74 1RADWASTE EXHAUST FANS 0.850 , 75 ESSENTIAL PLANT LIGHTING 0.900 93.50; 45281 93.501 45-28 93.50 45.28: 93.501 4528 76 1CRD WATER PUMPS , 0.850' 202.721 125,63T 202.72! 125.63 ITURBINE BUILDING BAITERY ROOM '77 iEXHAUST FANS '._0-850_i_
_ _ _ __ _ _ " 9TURBINE GENERATOR AUX BE A GLI.FT: 78 RPUMPS 9 L 5HP EACH AND 0.850 I .TURNING GEAR -60 13R32P 2 79 REMERGENCY INSTRUMENT AIR COMPRESSOR 0.850 80 IRADWASTE SUPPLYFR SS I 0.850 0 2 4 2 , 0 96 REACTOR BUILDING SUPPLY AIR HANDLINGM.P 0.850 I 8 .8 .' .1 5 .82 BUILDING EXHAUST FANS , 0.850!, , '" ) I l i 83 iRADWASTE TANK VENT FILTER FANS 0.0[_ , 'I!TURBINE BUILDING BATITERY ROOM SUPPLY : 84 IFN 0.850" ,IRADWASTE TANK VENT FILTER BEATING ii,,: 85 !COILS 1.oo! 0 0i 862,CHEMICAL LAB EXHAUST FANS ...iDiESEL GENERATOR STARTING AIR ! ' i " ]87 !COMPRESSORS 0.850' 12.16' 7,54- 12.1F6" 7.54&#xfd; 7.54i 12.16, .5 88 REATORAUX COOLING SYSTEM PUMPS '0.850 89 125-V DC BATTERY CHARGERS 0.600.90 1 125-V DC BATT'ERY CHARGERS ' .0' -38.00!1 50,671 38.00i 50.67i 38.00'1 50.67T 3800'! 120V ATTERY CHARGERS i 0.00 !N SSTANDBY LIQUID CONTROL SOL MIXING i xoo .iIoo, I4~o 923 HfEATER 1.00 4000 40.0i 9 RFPT AUX LUBE OIL PUMP (NOTE 12) & "0.850:&#xfd;TURNtNGOGEAR MOTORS ' ] 21.A9' 13,321 21.49 '13.321I 94RESERVED FOR FU'IZURE USE i100  95 '.208 V/120 V AC XFMRS TO DIST PANELS 0.850:1 : 45.001 27-89: 45.00! 27.891 : 15-00' 9.30i 15-00i 9.30 96 'REACTOR BUILDING FLOOR DRAIN SUMP PUMP 0.8501 i8.11lj 5.03! 8.11! 5.03: 8.11 5.03i 8.11' 5.03 U USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 11 of 12...... 'L',,. :J I.=::z:;: ..~r .: ..:=,,= -...... , ;. = -:- -....I ~Standby Diesel Generator C 51'4<10 MIN T 10-60 MIN >60) MIN ~ ~ 06~'~ii6 Item. DESCRIPTION L PF i KW KVARi KW .KVAR KW KVARi KW jKVAR I KW KVAR, KW i KVAR 97 DRYWELL EQUIP DRAIN SUMP PUMPS I 0.850: _ -:,1 98 DRYWELL FLOOR DRAIN SUMP PUMPS I 0.850. I , -[' -_IPOWER SUPPLY FOR UNIT VENT RADIATION
.99. &#xfd;MONITORING SYSTEMS 0.850,,i iPOWER SUPPLY FOR DLD RADIATION i I, I 100 MONITORING SYSTEMS 0.8501 3.501 2,171 3.50, 2.171 1 101I TURBIN GENERATOR MAIN SEAL OIL PUMP [ 0.850&#xfd;102 TURBINE GENERATOR RECIRC SEAL OIL PUMI'! 0,850 i_____TURBINE GENERATOR SEAL OIL VACUUM 0 RAWASTE + 24V DC BATTERY ROOM DUCT I 104 HEATER __1.000"+'
:CONDENSATE STORAGE TANK HEAT TRACING i 105 (SEE NOTE 26) 1.000! 12.00 0.00, 12.00 0.00 _106 TSC SUPPLY SYSTEM FAN 0.850. 20.00 12.39. 20.00. 12.39 " i 107 ,TSC SUPPLY SYSTEM HEATING COIL 1.000 30.00; 30,00T _ _108 ITSC EMERGENCY FILTER FAN 0.850: 20.00! 12.39 20.00: 12.39_ I _109 ITSC EMERGENCY FILTER HTG COIL 1.000 13.001 13.00- ___ _ _110 :STEAMTUNNLFUNIFCOOLERS 0.850 :1 i6.00r 992' 16.001 9.92 TURBINE BUILDING BATTERY ROOM SUPPLY : 111 FAN & HTOa COIL 1.0001 TIRBINE BUILDING COMPARTMENT EXHAUST o 112 FANS I_ _ __" CONTROL AREA 125 V DC BAITERY ROOM I 113 DUCT HEATER 1.000: 'REMOTE SHUTDOWN PANEL ROOM SUPPLY 114 'FAN 0.8501 _REMOTE SHUTDOWN PANEL ROOM HEATING 1 I 115 ICOIL 1.000: I 1 PLANT LEAK DETECTION SYSTEM HEAT 116 TRACING PANEL (SEE NOTE 26) 1.000 I 12.00 12.00 117 UNIT VENT RMS HEAT TRACINGPANEL 1.000i I POST ACCIDENT SAMPLING SYS HEAT , .1 118 TRACING PANEL 1.000i 15.00 15.00 1 ! '_119 ELECTRIC UNIT HEATERS 1 1.0001 24.00! 24.001 I 120 ITSC ELECTRIC PAN HUMIDWIER (NOTE 26) 1 0.850i 1 12.971 8.04, 12.97i 8.041 i I 121 IWING AREA EXHAUST FANS 0.850, I _ __ _ _ i _!6.00 992 16.00 9.92 122 WING AREA SUPPLY FANS 0.850 -.40.001 24.79 40.00 24.79 123 ISPDS UPS I 1 IOOO60.001 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby IE Diesel Generator Sizing Attachment 2 All SDG's In Service Calculation E-9 Rev. 8 Page 12 of 12 Standby Diesel Generator C I --__, ._._] -<Io MIN 1 10-60 NUN' 160MN 4W Item DESCRIPTION PF KW KVARI KW KVAR' KW KVAR KW >KVAR KW KVAR KW KVAR 124 !RESERVED FOR FUTURE USE 1.000. _ ____ __125 !RESERVED FOR FUTURE USE 1.0w0_ -_ :__ ___4426.20i 2288.68; 3388.47i 1795.71! 3452.521 1798.22 4426.20 2288.68 141533 2765.01 1504.6 KvARK 2288,681 1795.71' 1798.22 12288.68 415.33 150.60 KVA! I 4982.91,F 3834.881 3892.75, 4982.91, 3018 36 i 3147.88 PF, 0.89 0.88i I 0.89* 0.891 0.881 08 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby CI. 1 E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 1 of 12-Standby Diesel (3eneralor'A
-I tadb ie:IGiiatr
______._._.....__.____I_:_._..__............
-:<10 MIN.10-60 MIN > o-M1N -.0 .IN .0-60M. N .60 .N..Item DESCRIPTION PF KW KVAR KW KVAR KW KVAR I KW KVAR KW i KVARI KW i KVAR CLASS 1E LOADS 525.411 239.38 0 9REACTOR COR SPRAY PUMPS (Note8) ___- 525.41_ 239.W 2__ _" _ _PUMPS_(Note_8)_0,89,1002.69!
513.691 1002.69i 513.691 1002.691 513.69 3 RSAFETYAUX CLG.SYS.P N PUMPS (Note 8) 0.909, 420.62! 192.86 420.62 192.86i 420.621 192.86 4 CORE SPRAY PMP. RM. CLR. UNIT 0.85. _ _ _ " I 12.36&#xfd; 7.54 i 5 IMOTOR OPERATED VALVES 1 0.4 ! _ I 14.81: 3 3.9 3 1 14.811 33.93 14.81 33.93 6 SWGR. RM. UNIT CLR. FANS I 0.851 20.271 12.561 20.271 12.56 20.271 12.56 7 INTAKE STRUCTURE SUPPLY FANS __0.851_ ___ _ ___ 32.43! 20.101 32.431 20.10 32.43 20.10 INTAKE STRUCTURE TRAVELING SCREENS I _ _ I " ' 660 3 8 AREA FANS 0.85! I 6.08 3.77 6 .3 608 3.77 01 RHR Pump RM UNIT COOLER FANS' 0.85. 16.22' 10.05 16.22 10.051 16.22i 10.05 10 RCIC PUMP RM. UNIT COOLERS 0.85! 8.11 5.031 8.11t 5.03! 8_11: 5.03 II HPCIPUMPRMUNMTCOOLERS 0.85I I .7 0.20_, 12 '125-V DC BATTERY CHARGERS 0.61 -75.90 101.20 75.90, 101.20! 75.90 10120 13 :DIESELAREABATTERYROOMEXHAUSTFANS 0.85. i .0.81: 0.50, 0.81 0.50, 0.81 0.50 14 'DIESEL FUEL OIL TRANSFER PUMPS 0.85 4.05! 2.51 15 ISTATION SERVICE WATER PUMPS (Note 8) 0.875! ".634.22" 350.90; 634.22! 350.90, 634.22i 350.90 16 !RB FRVS RECIRCULATION SYSTEM FANS 0.85'3 .24326! 150.76i 243.261 150.76: 243.26, 150.76 17 ICONTROL RM SUPPLY FANS 0.851 ; ' i 18 1208Y/120-V AC XFMRS TO POWER DIST PANELS 0.85! ..37.501 23.24i 37.50! 23-241 37.50 23.24 19 !RESERVED FOR FUTURE USE 1.00 I i I I 20 INTAKE STRUCTURE EXHAUST FANS , 0.85i 32.431! 20.10 32.43; 20.101 32.43t 20.10:CONTROL ROOM CHILLED WATER. .I I 1 21 CIRCULATINGPUMPS 0.85 ' .I 22 CNTRL RM SUPPLY UNIT HTG COLLS I ; -23 CONTROL ROOM WATER CHILLERS (Note 10) 0.878' ...i' -24 DIESEL GEN RM RECIRC SYSTEMS FANS 0.85 ! _ _ _ 202.72; 125.63' 202.721 125.63! 202.72i 125.63'PRIMARY CONTAINMENT INSTRUMENT GAS 25 COMPRESSORS i 0.85. _ ._ , I 26 BATTERY CHARGERS, 250-V DC 0.6 _ '- , _19.00 25.331 19.00i 25.33' 19.00 25.33 CONTROL AREA BATTERY ROOM EXHAUST i ..27 FANS :0.85, I ._ _ _ _ _ _ _ _ _ _ _28 RB FRVS RECIRC UNIT HEATING COILS I 200.001 200-001 200.00!TRAVELING SCREEN SPRAY WATER BOOSTER I I 29 PUMPS I 0.85I ___ II 16-221 lO.05 16.22 10.05 16.22: 10.05 30 RB FRVS VENT UNIT HEATING COILS 1 i 32.001 3 2.32.0 31 CONTROL ROOM SUPPLY SYSTEM RETURN 0.85. .... _ l I ______32.00
_ ____" _ -_ __ __00 32 CONTROL ROOM EMERGENCY FILTER FANS i 0.851 ____ ] , ._ _33 SAFETY AUX COOLING SYSTEM UNIT COOLERS; 0-851 _ _ I_34 F!UEL POOL COOLING PUMPS 0.851 .I I i I .60.82i 37.69 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby Cl. I E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 2 of 12 I St~dby
] :i: :iiis~tnbyDise Gneator 13
...<0MIN [jM-60MN -60MtN <: MIN 1 60mrN >6OMIN Item DESCRIPTION PF KW KVAR KW KVAR KW KVAR , KW KVAR KW KVAR. KW KVAR CONTROL ROOM EMERGENCY FILTER UNIT 35 IELECTRIC HEATING COILS I , 36 1CONTROL EQUIPMENT ROOM AIR SUPPLY 0.85: 37 RB FRVS VENT SYS FANS 0.85 20.27i 12.561 2027! 12.56 20.27 12.56 3 CONTAINMENT HYDROGEN RECOMBINER 0-"2.38 SYSTEM 0.g- I 1 I ICONTROL EQIP ROOM SUPPLY UNIT HEATING I _ __ _ _ _39 lCOILS 40 ISERVICE WATER SELF-CLEANING STRAINERS 0.85 s 0.81i 0.50; 0.811 0.50 41 !STANDBYLIQUIDCONTROLPUMPS 0.851 321431 20.10f 32.43 20.10 32.43 20.10 42 RESERVED FOR FUTURE USE .I _ _ _ _ _43 IRESERVED FOR FUTURE USE I 44 RESERVED FOR FUTURE USE i j .'45 RESERVED FOR FUTURE USE 480 V POWER SUPPLY TO CLASS IE CHILLER : .'I 46 PANELS 0.85 i 4.00 2.48! 4.00' 2.48 4.001 2.48 47 ITRAVELING SCREENS 0.851 4.05; 2.51 4.05- 2.51 4.051 2.51 489 ECCS JOCKEY PUMPS .0.851 _ 8.11! 5.03i 8.11! 5.03 8.11: 5.03 MOTOR DRIVEN DIESEL GENERATOR FUEL OIL I, I I i 49 STANDBY PUMPS I 0.85: .1.62: 1_011 1.62! 1.01' 1.621 1.01!STANDBY LIQUID CONTROL PUMP ROOM DUCT, 50 !HEATERS l1480 V POWER SUPPLY TO HYDROGEN AND T .I 0 2 51 1OXYGEN ANALYZER PANELS 0.85., 1.001 0.62 ,t.00. 0.6 1.001 0.62i .oi 06 52 250 V DC BATTERY ROOM DUCT HEATERS I ,'125 V DC DIESEL AREA BATTERY ROOM DUCT 53 H!EATERS I 21.00 21.001 21.001 54 HPCI PUMP ROOM DUCT HEATER ' I 55 IRCIC PUMP ROOM DUCT HEATER 1 7._00 7.00_ 7.00!_56 &#xfd;250 V DC BATTERY ROOM DUCT HEATER 1 8.00! 8.00, i 8.00', 57 CLASS 1E PANEL ROOM WATER CHILLERS 0.886 198.60! 103.62 198.001 103.621 198.00 103.62 58 CLASS 1EPANELROOM CHILLED WATER 0.8"5! 32.43, 20.10 32.43 20.10 32.431 20.10 ,CLASS IE PANEL ROOM SUPPLY & RETURN AIR'59 FANS 0.851 1 60.921 37-69i 60.82' 37.69 60.82 37.69 60 ' CLASS IE PANEL ROOM ELECTRIC HEATERS ',71 ' ' '100.001 Io00.00 I 100.00: 61 BATIERYROOM EXHAUST FANS 0.85 T 0.81 0.50' 0.81 0.501 0.81: 0.50 62 I BATTERY ROOM DUCT HEATERS I, .i.1 63 &#xfd;111102 ANALYZER HEAT TRACING PANELS .I I 64_ RESERVED FOR FrUTURE USE 1I I I , __I 65 1 RESERVED FOR FUT`URE USE I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby CI. 1 E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 3 of 12<IGMIN~~~
1O-6OMI ti,~l >-66I NC6MN. IN Item DESCRIPTION PF -KW KVAR KW KVAR KW KVAR KW KVARi KW KVARi KW 1_ KVAR 66 RESERVED FOR FUTURE USE I -, _ '67 :RESERVED FOR FUTURE USE 1 , , '68 RESERVED FOR FUTURE USE 1 69 RESERVED FOR FUTURE USE 1' I : 70 JRESERVED FOR FUTUR.EUSE iFII II USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby C). 1 E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 4 of 12 Item I DESCRIPTION PF KW KVAR KW KVAR KW KVAR KW i KVAR KW _VAR, IVA NON-CLASS I ELOADS- KVR K IKA WIf VR I See Note I ._ _ _ _',__ _ _ _ _ _3_ _o I II 71I TURBINEGENERATORTURNINGGEAROIL
] 0.85! 32-00! 19.831 32.001 19.83 STANDBY LIQUID CONTROL SOLUTION I I i I 72 1OPERATING HEATER jI 1 i -;73 'DRYWELL COOLING UNIT FANS 0.85: , 74 jRADWASTE EXHAUST FANS 0.851 I i 75 1 ESSENTIAL PLANT LIGHTING 0.9. F- 37.40 18.111 37.40 18.11 76 IC_ _ WAT INr S TURBINE BUILDING BATTERY ROOM EXHAUST;77 FANS 0.85: ' ! : TURBINE GENERATOR AUX BEARING LIFT ..:...78 'PUMPS 9- 5HP EACH AND 0.85. 2.431 1.511 2.43! 1.51 1TURNING GEAR -60 HP 1 , _ ', 85.14 52.77! 85.141 52.77 79 ,EMERGENCY INSTRUMENT AIR COMPRESSOR 0.851 I 80 IRADWASTE SUPPLY FANS 0.851 __,_ ] I 8 REACTOR BUILDING SUPPLY AIR HANDLING I;81 UNITS " 0.85: , _ _ I 82 REACTOR BUILDING EXHAUST FANS 7 0.85 83 i RADWASIT TANK VENT FILTER FANS 0.85. 6.08' 3.771 6.08, 3.77 TURBINE BUILDNGBATTE ROOM SUPPLYI 84 !FANS _____________________
0-8514.5 2.1 .0;.1 85 IRADWASTE TANK VENT FILTER HEATING IT 3.601 3.60I 86 CHEMICAL LAB EXHAUST FANS 0.851 i 16.22 10.051 16.221 10.05 DIESEL GENERATOR STARTING AIR 1. 7.54 7.54 87 iCOMPRESSORS 0.85! 12.161 7.54 88 1REACTOR AUX COOLING SYSTEM PUMPS 0.85 i ' I 1 89 ;125-VDCL1ATTERYCHARGERS 0.6 i 114.00; 152.001 114.00! 152.00 90 :125-V DC BATTERY CHARGERS 0.61 I 38.00: 50.67; 38.00' 50.67 91 j250-V DC BATTERY CHARGERS 0.6. .57.001 76.00 57.00, 76.00 ISTANDBY LIQUID CONTROL SOL MIXING ., , 92 -HEATER i ., -'93 IRIFPT AUX LUBE OIL PUMP (NOTE 12) & 0.85, " 21.491 13.32i 21.49' 1332 ITURNING GEAR MOTORS i i ___94 'ncRnSERVED FOR FUTURE USE,[It.'cvl.r.aUuL~
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___________
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95 1208 V/120 V AC XFMRS TO D1ST PANELS 0 O.95!, i 15.00' 9.301 15.001 9.30 96 IREACTOR BUILDING FLOOR DRAIN SUMP 0.85&#xfd; ! _ _97 'DRYWELL EQUIP DRAIN SUMP PUMPS 0.85 , 4.05 2.51, .405: 2.51 98 iDRYWELL FLOOR DRAIN SUMP PUMPS 0.85i 4.05; 2.51 4.05! 2.51 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby CI. 1 E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 5 of 12___ _____________________________ILStandby, Dieself 6enerro tuib D~ese (3teneao Itemr DESCRIPTION LPF KW KVAR KW KVAR[ KW KVAR KW ;KVAR KW KVARI KW KVAR iPOWER SUPPLY FOR UNIT VENT RADIATION I j , , 99 MONITORING SYSTEMS ' I _ _ _ 3.50 2.17* 3.50' 2.17 POWERSUPPLY FIORDID RADIATION I 1 MONITORING SYSTEMS 0________5_
I ___101 1 TURBINE GENERATOR MAIN SEAL OIL PUMP 0.i I 1622, 10.051 16.22 10.05 102 TURIE GENERATOR RECIRC SEAL OILPUMP 0.&5 .i 6.08, 3_771 6.08 3.77 103 TURBINE GENERATOR SEAL OIL VACUUM 0-8*243; 151 .31 15 IRAWASTE + 24V DC BATTERY ROOM DUCf i 104 'HEATER 1 -_ _ _ : _ _ _;_ _CONDENSATE STORAGE TANK HEAT TRACING 105 (SEE NOTE 26) ,_l___ __. _ _106 !TSC SUPPLY SYSTEM FAN 0.85 ,_ _ _' __ _ " _'107 !TSC SUPPLY SYSTEM HEATING COIL I " ___._" _108 ITSC EMERGENCY FILTER FAN 0.851 I _ -I :_ _109 TSC EMERGENCY FILTER HTG COIL 1' I i 1 110 ISTEAM TUNNEL UNIT COOLERS 0.851 i 1__ __ _ I ., 16.001 9.92; 16.001 9.92 TURBINE BUILDING BATTERY ROOM SUPPLY i III FAN & HTG COIL..1 _ _ _ ___ _ '_, TURBIN BUILDING COMPARTMENT EXHAUST * ' I I 112 FANS 0.85 _ _ _ L........_
_ _ _ _ I _ _ ... I CONTROL AREA 125 V DC BATTERY ROOM 113 !DUCT HEATER 1: _ _ _ ' 4 _ i _114 REMOTE SHUTDOWN PANEL ROOM SUPPLY 0.85' _____5REMOTE SHUTDOWN PANEL ROOM HEATING 115 icoI , : PLANT LEAK DETECTION SYSTEM HEAT " 116 TRACING PANEL (SEE NOTE 26) I ____ :_I _117 UNITVENT RMS HEAT TRACING PANEL I I _ _I ,"_____ _ _ _ _POST ACCIDENT SAMPLING SYS HEAT i ' I I 118 TRACING PANEL I _______.__
119 ELECTRIC UNIT HEATERS I I I i " 120 TSCELEC-rRICPANIHUIMIDIFIER(NOTE26) i 0-851 i _ _ _ _'_ '_ _ _ _ _ _ _121 WING AREA EXHAUST FANS 0.851 ', ! _ -_ I_ _122 WING AREA SUPPLY FANS 0.851 ,_l ___ , , ._,____ _123 SPDS UPS " _." _ _KW >. ....' 4053.22 2053.36j 4012.57! 2256: 4077.44- 2296.45[KVAR: .2053.36: 2256.25! 2296.45: KVAi " : ..4543.66 .4603.4t1; 4679.65' USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby CI. 1 E Diesel Generator Sizing Attachment 3 SDG "A' off line Calculation E-9 Rev.8 Page 6 of 12-Sady:Diesc-Geneaator A: -Stadbyvsl~tr ItmDESCRIPT7ION PF K VR K VR W KVA KW KVAR KW KVARJ KW IKVAR PF! I0.891 0 .87: 0.87 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby Cl. 1E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 7 of 12____________Standby Diesel Generator C of .......{,0-60.Ml&#xfd;
>60 Item DESCRIPTION P F WR' KW KVAAR KW K.VA R KW KVARJ KW KI 1- -rKVAR I KW KVAR SCLASS 1E LOADS 525 1 REACTOR CORE SPRAY PUMPS (Note 8) 0.911 525.411 239-381 525.41! 239.38: 525.411 239.381 525.41', 239238! 525.41 239.389 2.411 239.38 2 &#xfd;RHR PUMS (Note 8) 10.89! 1002.691 513.69' 1002.69i 513.69, 3SAEYAX L.SYS. PUMPS (Note 8) 1 0_909' 420.62: 192.86, 420.62, 192.86! 420.62! 192,861, 420.621 192.86 420.62 192.86! 420_621 192.86 4 !CORE SPRAY PMP. RM. CLR. UNIT 08] 12.16. 7.54C 12-161 7.54, 12.161 7.54- 12.16 7.54] 12.16&#xfd; 7.541 112.161 7.54 5 MOTOR OPERATED VALVES 0.41 1481 33.93; 14.81, 33.93. 14.81; 33.93; 14.81: 33.93 14.81' 33-93; 14.81! 33.93 7'INTAKE STRUCTURE SUPPLY FANS 0.85. 32.43! 20JO01 32.43' 20.101 32.43; 2.10, 32.43! 20.101'1INTAKE STRUCT1URE TRAVELING SCREENS [ , ] ' {8 iA, E FA N S 0 .5 !1' '";9 R.HR PUMP RM UNIT COOLER FANS I .5 62 00+ :i i 16.221 10.05:, , 10 IRP-CIC PUNT R.M. UN1T COOLERS,'
0.85; ,,.' , i .11 11PCI PUNT RM UNIT COOLERLSogs
:. ; II 12 1125-VIDC BATITERY CHARGERS , 0. 113.851 151.-80i !13.85 151.90: '113.85! 151.80: 113.85:1 51.801 113'-851 151.80:: 113.851 155 08 13 1 IESEL AREA BATTERY ROOM EXHAUST FANS7] 0.8 5 0.81i, 0.501I 0.81&#xfd; 0.50j' 0.81: 0.501 0.81i 0.50: 0.911 0.50. 0.81;. 0.50 14 ;DIESEL FUEL OIL TRANSFER PUMPS " 10.851 .5 .1 4.051 2.51 15 ISTATION SERVICE WATER PUMPS (Note 8) 0.8751 63412 350.9-0 634.221 350.901, 634.22i 350.90' 634.221 350.90] 634E2I 350.90i 634Y22 350.%(16 IRB FRVS RECIRCULATION SYSTEM FANS 0.851 121.63': 75.38! 121.63i 75.38. 121.63' 75.38&#xfd; 121.63 75.381 '121.63] 75-381 12 1.&#xfd;63_ &#xfd;75.-3 8 17 ]CONTROL RM SUPPLY FANS 0.85', 3.43, 20.10i 32.43; 20.10! 32.43, 20.101 32.43! 20.10 i 18 i208Y/120-V AC XFMRS TO POWER DIST PANELS !0.85. 37.501 23.24!, 37.50,,_ 23-24;: 37.50, 23.241, 37.50:. _2324; 37.501 23.24 i 37.50' 19 RESERVED FOR FUTURE USE i1-00 ,. , i , 20 ,INTAKE STRUCTURE EXHAUST FANS 0.85, 32.43, 20.10: 20. 10! 32.43. 20.10. 32.43! .20.101,[_
_SCONTROL ROOM CHILLED WATER i 21 ICIRCULATING PUMPIS i0,85 48.65,. 30.15i 48.65 30.15 48.65 30.15;, 48.k5; 30.15!22 ICNTR'RaM.
SUPPLY UNIT HTG COILS 1 900:9.0 ,9.0I900 ;,}23 !CONTROL ROOM WATER CHILLE1S (Note 10) 0-8781 506.00'; 306.001 275.86, 506.00! 275.86-. 506.00'. 275-.861 027 24' DIESELGEN RMRECIRC SYSTEMS FANS 0.875, 202.72: 125-631 202.72': 125.631 202.72' 125.63i 202.72: 125.631 202-721 125-63 PRIMARY CONTADIMENT
]NS1R.UNENT GAS i 'i TIi'75i 1:11 75 25 COMPRESSORS 1 0.85; 12.16!i 7.54'! 12.16;L 7.54! 1216 7.4 12!, 75 26 -- IATrERY CHARERS, 250V DC o.61 I { 'CONTROL AREA BATITERY ROOM EXHAUST J !{- ! 'i 27 I A S0.851 4.05! 2.511 4.051 2.51 4.05: 2.511' 4.05: 2.51 4.051 2.51: 4.05 2.51 28 R.B FRV S PECIRC UNIT HEATI'NG COILS 1: 100.001 1 100_00. 100.00. 1 100.00i " 1o0.001 1, 1O0.001 TRAVELING SCREEN SPRAY WATER BOOSTER i [ i : I : '..29 085&#xfd; 16.221, 10.05 16.22! 10.051 16.22 10.05' 16-221 10.051 16-221 10.05 16..221 10.05 30 B FV1 b24T UNI HEATING COILS __I"1 " : ': -.31 CONTROL ROOM SUPPLY SYSTEM RETURN 0.85 2 4. 3 3 15-08", 24.33. 15.08: 24-33 15.08i1 24.33, 15.08!32 iCONTROL ROOM FILTER FANS I0.85 20.27: 12.56i 20.27 12.56' 202 7; 12.561 20.27; 12-56, : 33 iSAFETY AUX._COOLING SYST.E.M UNIT COOLERS i 0.85 12.16i 7.541 f2.16, 7.54: 12.161 7.54' 12.16i 7.54 *12.16! 7.54! 12.161: 7.541 34 IFUEL POOL COOLING PUMPS '0.851 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby CI. 1E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 8 of 12 Standby Diesel Generator C a..0 MO.N 10-60 MIN >60MTN item DESCRIPTION PF KW KVAR KW jKVAR KW KVAR KW KVAR' KWI KVAR KW KVAR'CONTROL ROOM EMERGENCY FILTER UNIT 35 'ELECTRIC HEATING COILS 1 L 00&#xfd; 13.00' 13.00: 13.00 13.00 13.001 36. CONTROL EQUIPMENT ROOM AIR SUPPLY-. 0.85i 202.72 125.63; 202.72: 125.63' 202.72 125.63L 202.72! 1 2 5.6 3" 37 RB FRVS VENT SYS FANS 0.85' _CONTAINMENT HYDROGEN RECOMBENER
., ! I 38 ,SYSTEM 0 85' i 140.001 86.76 CONTROL EQIP ROOM SUPPLY UNIT HEATING I i i I 1 I , 39 COILS 1 10000 I100.00: 100.00 100.00; 1 100.00 100.00'40 SERVICE WATER SELF-CLEANING STRAINERS 0.851 081 0.50! 0.811 0.50. 0.811 0.50i 0.81 0.50i 0.81 0.501 0.811 0.50 41 ISTANDBY LIQUID CONTROL PUMPS 0.85 .42 'RESERVED FOR FUTURE USE I ' .i :___ _ _j _ _43 RESERVED FOR FUTURE USE II L ______ _ __44 RESERVED FOR FUTURE USE .1 45 ;RESERVED FOR FUTURE USE I ,,__ _480 V POWER SUPPLY TO CLASS IE CHILLER .: I 46 PANELS 0.851 4.00. 2.48i 4.00i 2.48: 4.00. 2.48! 4.001 2.481 4.001 2.48! 4.00' 2.48 47 ITRAVELING SCREENS 0.85 4.051 4.05!4.05 2.51 4.051 2.511 4.05! 2.51 4.05l 2.511 4.05 2,51 48 IECCS JOCKEY PUMPS i 0.85: 8.11! 5.03 8.11i 5.031 8.11 5.03' 8.11. 5.03 8.11: 5.03'_ 8.1l 5i03 MOTOR DRIVEN DIESEL GENERATOR FUEL OIL!49 STANDBY PUMPS I 0.851 1.62. 1.01! 1.62. 1.01' 1.62' 1.01' 1.62i 1.0' 1.62 1 .1.621 1.01 0STADBY LIQUID CONTROL PUMP ROOM DUCT- i i 4 .0 50 tHEATERS j 1' "1 : 45-00 451 1 480 V POWER SUPPLY TO HYDROGEN AND 5 OXYGEN ANALYZER PANELS 0._55. .' I 52 1250 V DC BATTERY ROOM DUCT HEATERS I 125 V DC DIESEL AREA BATTERY ROOM DUCT. '53 :HEATERS 1. 21.00: 21.00; 21.00: 21.00 21.001 21.00 54 *HIPCI PUMP ROOM DUCT HEATER I I.'_____55 !RCIC PUMP ROOM DUCT HEATER I.56 &#xfd;250 V DC BATTERY ROOM DUCT HEATER I .57 :CLASS IE PANEL ROOM WATER CHILLERS 0.886 i (58 CLASS IE PANEL ROOM CHILLED WATER ! 0.85 _ _____ _CLASS 1E PANEL ROOM SUPPLY & RETURN AIR I L 59 IFANS 0.85! ' ____ ___60 !CLASS 1E PANEL ROOM ELECTRIC HEATERS 1 1 I 61 BATTERY ROOM EXHAUST FANS 0.85 1 i I ., i _ -_ -62 BATTERY ROOM DUCT HEATERS 1 14.00T 14.00' m 14.001 14.005 14.00m 14.00 63 H 2/02 ANALYZER HEAT TRACING PANELS Il1l 15.00 15.00'. 15.00' 15.00, 15.00 I 15.00 64 IRESERVED FOR FUTURE USE .: , -i, , i ! !
USER RESPONSIBLE FOR VERIFYING-REVISION, STATUS AND CHANGES Standby Cl. 1 E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 9 of 12-]" Standby Diesel Generator C_*_<l10MIN
.I0-60MIN >60MIN item I DESCRIPTION PF ! KW ; KVAR KW I KVAR KW ' KVAR 66 I RESERVED FOR FUTURE USE Ii l____________
-+ I 67 1 RESERVED FOR FUTURE USE I L1,________,I 68 !RESERVED FOR FUTURE USE Ii : K----69 'RESERVED FOR FUTURE USE 1 _ _70 'RESERVED FOR FUTURE USE ii I I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby Cl. IE Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 10 of 12 I __Standby Diesel Generator C ---..______________________
'10MIN 10-60 MIN 160 MIN ItmIDESCRIPTION PF KW IKVAR 1 KW KVARI KW KVAR i KW 1KVAR KW KVAR< KW K-VAR__tem NON-CLASS IE LOADS ... ...KIKV " _-V..,__ __ ___'___ ___'____ __ _See Note I I -_71 TURBINE GENERATOR TURNING GEAR OIL I 0.8gF Fi, STANDBY LIQUID CONTROL SOLUTION j I I 72 [OPERATING HEATER 1~ I 73 :DRYWELL COOLING UNIT FANS 0.851 I I '-74 1RADWASTE EXHAUST FANS 0.85' _ , ,_I 75 JESSENTIAL PLANT LIGHTING 0.9. 145.90' 70.66: 145.90 70.66, ,93.501 45-28 93.50: 45.28 76 ICRDWATER PUMPS 0.85 202.72: 125.63 202.72 125.63: TURBINE BUILDING BATTERY ROOM EXHAUST; .77 FANS 0.85: _ _ _ -_._I ITURBINE GENERATOR AUX BEARING LIFT 78 ',PUMPS 9 -5HP EACH AND 0.85:.TURNING GEAR -60 HP : _ '79 1EMERGENCY INSTRUMENT AIR COMPRESSOR 0.8I 80 IRADWASTE SUPPLY FANS .0.85 I ! I REACTOR BUILDING SUPPLY AIR HANDLING II I I 81 UNITS 0.8 51___ _ _ _ I 82 REACTOR BUILDING EXHAUST FANS 0.85: j ____I 83 1RADWAST TANK VENT FILTER FANS 0.85 I I I I'TURBINE BUILDING BATIERY ROOM SUPPLY i : 84 1FANS ,, 85 1RADWASTE TANK VENT FILTER HEATING I 1' iI 86 CHEMICAL LAB EXHAUST FANS 0.85, i _ _ _" IDIESEL GENERATOR STARTING AIR I ; I 87 1COMPRESSORS 0.85! 12.16; 7.54: 12.161 7.54 12.161 7.54! 12.16 7.54 88 REACTOR AUX COOLING SYSTEM PUMPS 0.85: ' __ _ _ _ _89 125-V DC BATTERY CHARGERS 0.6, 909T '125-V DC BATTERY CHAARGERS
&#xfd; 0.61 38.00 50.67' 38.001 50.67. 38.00' 50.67'. 38.00 50.67 91 1250-V DC BATTERY CHARGERS ;0.6i STANDBY LIQUID CONTROL SOL MIXING , ;., I .1 92 !HEATER I I 40.001 40.00o'o 93 'RFPT AUX LUBE OIL PUMP (NOTE 12) & 0.85: 29 3 21.49, 13.32, .9; -13.3.2;_
_;TURNING GEAR MOTORS I.' .i I 94 RESERVED FOR FUTURE USE 1: .i ___95 ;208 V/20 V ACXFMRS TO DIST PANELS 0.85 45.00! 27.891 45.00 27.89i 15.00 9.301 15.00 9.30 96 REACTOR BUILDING FLOOR DRAIN SUMP 0.85! 8.11 5.03; 8.11, 5.03" 8.11 5.03 8.11 5.03 97 DRYWELLEQUIPDRA1NSUMP.PUMPS 0.85 ........98 DRYWELL FLOOR DRAIN SUMP PUMPS 0.85 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby Cl. 1E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 11 of 12 Standby Diesel Generator C- .-<10f MfN A. 10-60 MIN 1 >60 A
* M41N, --Item DESCRIPTION PF I KW i KVAR KW IKVARi KW KVAR KW KVAR l KW I KVAR KW KVAR POWER SUPPLY FOR UNIT VENT RADIATION
'99 MONITORING SYSTEMS ' 85 3.50! 2.17 3.50 2.17'POWER SUPPLY FOR DLD RADIATION5' i 100 MONITORING SYSTEMS 0.8_ _. __ _ .I_ _101 TURBINE GENERATOR MAIN SEAL OIL PUMP 0.851 ' I ___ _ __: 102 ;TURBINE GENERATOR RECIRC SEAL OIL PUMP 0.85 " 103 TURBINE GENERATOR SEAL OIL VACUUM. 085_JC41RAWASTE
+ 24V DC BATTERY ROOM DUCT i ' , : i 104 HEATER .I I I ,_, _ ___ i _ , iCONDENSATE STORAGE TANK HEAT TRACING 105 I(SEE NOTE 26) I _ _12.00' 12.00: , 106 TSC SUPPLY SYSTEM FAN _____5__20.00:
12.391 20.00 12.39 _ _, i_ --107 !TSC SUPPLY SYSTEM HEATING COIL 1 ],
* 30.00' 30.00! .108 TSC EMERGENCY FILTER FAN 0.85' 20.00! 12.39' 20.00; 12.39' i i I 109 iTSC EMERGENCY FILTER HTG COIL 1 13-003.00, -110 S 0AMT EL UNIT COOLERS 61 16.001 9.92 TURBINE BUILDING BATTERY ROOM SUPPLY , I I ' .111 FANJ&HTGCOL 1i I I COIL _ _ _,TURBINE BUILDING COMPARTMENT EXHAUST I , _ [ _ ' _ ! _ I 112 1FANS 0.85 I 1CONTROL AREA 125 V DC BATTERY ROOM " 1 113 DUCT HEATER I i I-F114 !REMOTE SHUTDOWN PANEL ROOM SUPPLY 0.85! ] ._ _ _:REMOTE SHUTDOWN PANEL ROOM HEATING .i _i, 115 ICOIL , 1 .I I IPLANT LEAK DETECTION SYSTEM HEAT -....116 TRACING PANEL (SEE NOTE 26) 1 i -_ _ 12.00' l t _ 2.00 117 [UNIT VENT RMS HEAT TRACING PANEL 1'POST ACCIDENT SAMPLING SYS HEAT ' I I , I , i 5oo 5-oIi 118 ITRACING PANEL j ]5m; 15.0__119 jELECTRIC UNIT HEATERS I 1J ! I 24.00t 24.00: , I_ _120 ITSC ELECTRIC PAN HUMIDIFIER (NOTE 26) 0.851 12.971 8.041 12.97' 8.04! ' __92 1.121 IWING AREA EXHAUST FANS 0.851 i _ _i_ _ 16.001 9.92 122 WING AREA SUPPLY FANS 0.8I' 40.00 24.791 40.001 24.79 123 SPDSUIS 1U P S 60.00i9 ___" __ -I__KW. 4426.20. 2288.68: 4043.31F.2108.211 410737 2110.72' 4426.201 2288.68 2765.96 145.33 2910011 1504.60 KVAR: 2288.68, 2108.21. 2110.72 2288.68; 1415.33 i 1504.60i KVA 4982.91 4559.92: 4617.96i 4982.91! 3107.04: ' 3275.981 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby Cl. 1 E Diesel Generator Sizing Attachment 3 SDG "A" off line Calculation E-9 Rev.8 Page 12 of 12 UK Standby Diesel Generator C__ ..<1 MIN 10-60 MIN >60 MIN _Item DE-SCRIPTION P KW KVAR KW IKVAR jKW I KVAR KW KVAR [W I KVAR KWX [(VAR IF 0.89&#xfd; 0.891 0 .89i .9 8 8 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 1 of 10 SwDiel Gene atr A-  Item DESCRIPTION PF KW KVAR I KW KVAR KW KW I KVAR KW KVAt KW IVAR CLASS IF LOADS 2 1 IEACTOR CORE SPRAY PUMPS (Note 8) I 0.91_, 239.381 _ ' _2 iRHR PUMPS (Note 8) 0.89 1002-69: 513.691 1002.691 513.691 1002.691 S13.69 ' ] __3 ISAFETY AUX. CLG. SYS. PUMPS (Note 8) 0.909f 420.62, 192.86: 420.62! 192.86 420.621 l 9 2.8 6 i .' " _4 ICORESPRAYPMP.
RM. CLR. UNIT 0.85. 12.161 7.54. i. I I !5 :MOTOR OPERATED VALVES **i 0.4 14.811 33,93 j 14.81 33.931 14.81, 33.93; 1 , _6 {SWGRP RM. UNIT CLR_ FANS 0.851 2027 12.56i 20.27? 12.56j 20.27 12.561 .I 7 INTAKE STRUCTURE SUPPLY FANS 0-85: 32.431 20.10: 32.43: 20.10? 32.43, 20.10 _____INTAKE STRUCTURE TRAVELING SCREENS I I I 8 AREAFANS 0.851 6.082 3,771 6.08j 3.771 6.081 3.77i ' I 9 IRHR PUMP RM UNIT COOLER FANS 0.85 16.22; 10.05' 16.221 10.05! 1622 10.052I , 10 RCICPUMPRM.
UNIT COOLERS 0.85: I 11 HPCIPUMPRMUNITCOOLERS 0.85[ 12.16' 7.541 12.16 7.541 12.16. 7.54. I L ', 12 1125-VDCBATTERYCHARGERS 0.6! 75.90' 101.20i 75.90! 101-201 75.90' 101.20! I l 13 DIESEL AREA BATTERY ROOM EXiAUST FANS 0.85 0.811 0.50 0.811 0.50, 0.811 0.50: , 14 !DIESEL FUEL OIL TRANSFER PUMPS 0.851 __ _ _ 4.05 2.51. _15 iSTATION SERVICE WATER PUMPS (Note 8) 0.875; 634.22' 350.901 634.22' 350.90; 634.22: 350.90, 7 16 iRB FRVS RECIRCULATION SYSTEM FANS 0.85 243.26' 150.761 243.26 150.76, 243.26, 150.76, I 17 CONTROL RM SUPPLY FANS 0.85 ., .18 ,208Y/120-V AC XFMRS TO POWER DIST PANELS 0.85' 37.50 23.24? 37.50 23.241 37.50. 23.24, RESERVED FOR FUI'URE USE 1 _, ----- , I 2O INTAKE STRUCTURE EXXHAUSTFANS 0.85. 32.43 20.10: 32.43, 20.10 32.431 20.10 _ _ _'CONTROL ROOM CHILLED WATER CIRCULATINGT 1 , .i 21 PUMPS 0.85: i [22 CNTRLRM SUPPLY UNIT HTG COILS I 1 " i _ _ _ I I 23 !CONTROL ROOM WATER CHILLERS (Note 10) 0.878! ______ ! _, 24 IDIESEL GEN RM RECIRC SYSTEMS FANS 0.85i 202.72' 125.631 20272 125.63 202.72, 125.63i [ ', PRIMARY CONTAINMENT INSTRUMENT GAS 085, I 25 1COMPRESSORS 0.85 I I I I _I .I 26 :BATTERYCHARGERS,250-VDC I 0.61 19.001 25.33. 19.00: 25.33i 19.00' 25.33 1 '27 ICONTROL AREA BATTERY ROOM EXHAUST 0.85' I i _ I R ECJRC UNIT HEATING COILS 1 200.001 200-001 200.O0i ITRAVELING SCREEN SPRAY WATER BOOSTER ' .' I 29 RPUMPS 0.851 16.22. 10.05! 16.22, 10.051 16.22'. 10.05: : +NIT HEATING COILS 32.001 32.001 32.00: _, _31 !CONTROL ROOM SUPPLYSYSTEMRETURNFANSj 0.85 1 I I : 32 CONTROL ROOM EMERGENCY FILTER FANS j 085 I , I : _33 SAFETY AUX COOLING SYSTEM UNIT COOLERS 0.85' I , ! ._ i 34 ,FUEL POOL COOLING PUMPS 0.85, I 60.821 37.69j USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 2 of 10___________________________________________Standby Diesel Generator A.-Sad-DelGnrarB-
<rIOMIN: -j 10-60M1 >6:MIN J IMN ?_ON J 6 D Itemn DESCRIPTION I PF KW KVAR KWA KVAR KW KVAR I KW KVAR KW Y KVAR K W KVAR CONTROL ROOM EMERGENCY FILTER UNIT 35 ELECTRIC HEATING COILS J, , I I 36 CONTROLEQUIPMENTROOMAIRSUPPLYFANS 0.85 ' r -+/- 1 37 :RB FRVS VENT SYS FANS i 0.85' 20.271 12.56! 20.27 12.56 20.27 12.56: 1:CONTAINMENT HYDROGEN RECOMBINER I i ' , i 38 !SYSTEM 0.85' I 1 I!CONTROL EQIP ROOM SUPPLY UNIT HEATING I , I 39 1COILS 1 _ i 40 I SERVICE WATER SELF-CLEANING STRAINERS 0.85 0.81; 0.50&#xfd; 0.81j 0.501 0.81 0.50 .] _41 SfANDBY LIQUID:CONTROLPUMPS 0.85 32413! 20.10, 32-43; 20.10' 32.43 20.10.42 I RESERVED FOR FUTURE USE 11 j ] , 43 RESERVED FOR FUTURE USE I 44 RESERVED FOR FUTURE USE I _ 1 I , i 45 RESERVED FOR FUTURE USE II _ 1 I _ _.... _... ._ -;'1480 V POWER SUPPLY TO CLASS 1E CHILLER i ' I I 46 IPANELS 0.851 4.00 2.481 4-001 2.481 4.00' 2.48. 1 I ,_ _47 ITRAVELINGSCREENS 0.85! 4.051 2.51. 4.05' 2.51' 4.05' 2.51: .48 1ECCS JOCKEY PUMPS 0.851 8.11: 5.03 8.11: 5.031 8.11, 5.03;!MOTOR DRIVEN DIESEL GENERATOR FUEL OIL I .49 !STANDBY PUMPS 0.85. 1.62- 1.01 1.62 1.01 1.62' 1.01 iSTANDBY LIQUID CONTROL PUMP ROOM DUCT 50 iHEATERS.
45.00 45.00 '480 V POWER SUPPLY TO HYDROGEN AND 51 OXYGEN ANALYZER PANELS 0.85: 1.00;; 0.62. 1.004 0.62i 1.00' 0.62' i [52 I250 V DC BATTERY ROOM DUCT HEATERS I 10.00 10.00. 10.00: , I 125 V DC DIESEL AREA BATTERY ROOM DUCT I 53 lHEATERS 1! 21.001 21.00. j 21.00 _ _ _ I ___54 HPCI PUMP ROOM DUCT HEATER I' 11.00! .11.00 11.00I 55 RCIC PUMP ROOM DUCT HEATER 1 : i I .L I I 56 250VDCBATTERY ROOMDUCT HEATER 1 , _i I. ., 57 CLASS IE PANEL ROOM WATER CHILLERS 0.886 198.00 103.62, 198.001 103.62 198.00 103.62; I I ! _ _58 CLASS 1E PANEL ROOM CHILLED WATER PUMPS i 0.85 32.43 20.10! 32.43, 20.10:. 32-43' 20.101 _ _ ,I CLASS 1E PANEL ROOM SUPPLY & RETURN AIR6 3 60.82 37.69 59 !FANS 0.85. 60.82, 37.691 60.82, 37.69 60.82 37.69';--60 CLASS 1E PANEL ROOM ELECTRIC HEATERS 1 1000 100.00' 100.00.61 BATTERY ROOM EXHAUST FANS 0.85 0.8!. 0-50! 0.81. 0.50' 0.81: 0.50'62 BATTERY ROOM DUCT HEATERS I 1 ! -63 H2/02 ANALYZER HEAT TRACING PANELS I 1 ..*64 RESERVED FOR FUTURE USE, 1 .I II __l _
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 3 of 10___ I _________
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.-Stmdidbyfliselfn_
ao p -Sad~ islG nrtr1 Item DESCRIPTION PF i KW KVAR KW KVAR KW KVAR; KW KVAR KW KVAR 65 'RESERVED FOR FUTURE USE -i i _____Ii I 66 iRESERVED FOR FUTURE USE I i I_ _____67 RESERVED FOR FUTURE USE I _ ___-_ _- i 68 RESERVED FOR FUTURE USE 1 i 69 RESERVED FOR FUTURE USE I 70 RESERVED FOR FUTURE USE l I _____I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 4 of 10.I -60OMIN >01W11&#xfd;w Item DESCRIMON IE : KW KVAR WK IKVAR _KW , KVAR KW KVARI KW KVAR NON-CLASS IE LOADS I- i -See Note I I I ________71 'TURBINE GENERATOR TURNING GEAR OILPUMP; 0.85!_ _ _ __-_._ _ _ _'STANDBY LIQUID CONTROL SOLUTION I 72 iOPERATING HEATER I 10.00! 10.00! ____ _ I 73 ,DRYWELL COOLING UNIT FANS 0.85. ' i _ _ _ _ _, I '74 RADWASTEEXHAUSTFANS 0.85! 5.0" [ _ _ _75 ESSENTIAL PLANT LIGHTING 0 o.91,'_ .52.40, 25.38. -2.40 25.38: ,, , , 76 CRD WATER PUMPS .t 0.85 TURBINE BUILDING BATTERY ROOM EXHAUST I , I 77 !FANS I 0.851 2.43 1.51: 2.431 1.511 __ _ i _T TURBINE GENERATOR AUX BEARING LIFT 78 AND 0.85: ._ _ _TURNING GEAR -60 HiP i !i " 79 EMERGENCY INSTRUMENT AIR COMPRESSOR 0 0.85. , I I _80 :RADWASTE SUPPLY FANS U0.851 ;." IREACTOR BUILDING SUPPLY AIR HANDLING i 81 tUNiTS .085 05I 82 iREACTORBUILDINGEXHAUSTFANS 0.85 -- I ____3 1 RADWASTE TANK VENT FILTER FANS.O.85
' 6.08i 3.77i 6.081 3.77, JTURBINE BUILDING BATTERY ROOM SUPPLY.08 84 IFANS 0.5 i 4.05" 2.51: 4.051 2.511 I 85 RADWASTE TANK VENT FILTER HEATING COILS 1' I 3.60i 3.60: ____ _ __86 )CHEMICALLABEXHAUSTFANS , 0.85 1 05 16.221 10.055 16-22 0.05 ..!DIESEL GENERATOR STARTING AIR ' 16.221'10.0 I S__ 4 87 COMPRESSORS 0.851 12.16' 7-54' 12.16' 7.54____ I _88EACTOR AUX COOLING SYSTEM PUMPS o0.85; ________....____-___'
89 1125-V DC BATTERY CHARGERS 0.6 .114.00, 152.00' 114.00: 152.001, 1 _90 '.125-V DC BATTERY CHARGERS 0.6: 38.0 50.67 38.00' 50.67 .91 1250-V DC BATTERY CHARGERS, 0.61. .__ ; _ _ _ _ _: .... ___ ' I I 92 STANDBY LIQUID CONTROL SOL MIXING I ___' '-_ ;) _93 IRFPT AUX LUBE OIL PUMP (NOTE 12) & _0.85 .._ _ ! i ,TURNING GEAR MOTORS .21.49, 13.32 21.49 13.32. _ _ _ _ -94 1RESERVED FOR FUTURE USE I _, _ _ __ , 95 ;208 V/120 V AC XFMRS TO DIST PANELS 7 0.85, -30.00 1 1.59! 30.00:. 18.59 4," _ i 96 REACTOR BUILDING FLOOR DRAIN SUM? PUMPS 0.851 ___ ___-97 DRYWELL EQUIP DRAIN SUMPP.MP 0.,5, .* " I P 98 ,DRYWELLFLOORDRAINSUMPPUMPS 0.85' i 4.05, 2.51' 4.05' 2.511 I 1 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 5 of 10 ,__ _ _ _ _ _ _Standb D idsl ,mtkrA f -encratorR Item DESCRIPTION PF I KW KVAR I KW KVAR! KW KVAR; KW KVAR I KW KVAR KWI KVAR POWER SUPPLY FOR UNIT VENT RADIATION
.'99 MONITORING SYSTEMS 0.851 i 1 405 2.51 4.05 2.51'POWER SUPPLY FOR DLD RADIATION I I 100 MONITORINGSYSTEMS I 0.8 3.501 2.17! 3.501 2.17, i _, 101 FTURBINE GENERATOR MAIN SEAL OL PUMP 0 0.85! ., _ ; [It 102 TURBINE GENERATOR REC]RC SEAL OIL PUMP .0.85i , , I __-'_103 ITURBINE GENERATOR SEAL OIL VACUUM PUMP; o.85 ' I I 0.85i RAWASTE + 24V DCi BATTERY ROOM DUCT .HE4 IEATER 1 ' _ _, CONDENSATE STORAGE TANK HEAT TRACING I 105 -(SEE NOTE 26) 1 5.00! , 5.00 _106 &#xfd;TSC SUPPLY SYSTEM FAN 0.85; I _ , 107 1TSC SUPPLY SYSTEM HEATING COIL 1I I I ___108 ITSC EMERGENCY FILTER FAN 0 .85!, , 109 ITSC EMERGENCY FILTER HTG COIL I _____________
_____110 STEAM TUNNEL UNIT COOLERS 0.85 _ _ , , , I_ _ _ i 111I TURBINE BUILDING BATTERY ROOM SUPPLY FAN 1 50.00 50.00: , ,_'112 TURBINE BUILDING COMPARTMENT EXHAUST FA 0.85: I .'113 'CONTROL AREA 125 V DC BATTERY ROOM DUCT H 1 16.00; 16.00 I _ I _ _114 ',REMOTE SHUTDOWN PANEL ROOM SUPPLY FANi 0.85 4.00! 2.48 4.00, 2.48: 115 REMOTE SHUTDOWN PANEL ROOM HEATING COIL 1 i10.00, 10.00, _ _ _116 i PLANT LEAK DETECTION SYSTEM HEAT TRACING I : , 117 UNIT VENT RMS HEAT TRACING PANEL I 1500i 15.00j , _ _ _ _118 POST ACCIDENT SAMPLING SYS HEAT TRACING 11 1_ _ __ __ _I _ _ _,_ ._ _119 ELECTRIC UNIT HEATERS I. L I L i _ I '120 TSC ELECTRIC PAN HUMIDIF.ER (NOTE 26) 0.851 _ i _ _ I _ , [ I { _ '121 :WING AREA EXHAUST FANS 0.85' F 16.00: 9.92! 16.00, 9.921 I _" 122 iWINGAREASUPPLYFANS
-0.85- 40.00. 24.79; 40.00! 24.791 _ _i. _ __ ___ __ __ __ ' I 60.00:'123 DS V 1 .-_ __ _ __.._ _ _ ___"PE " ib58 218 6 27. .i -.. __ _ _ _ _ _ _ _ _ _ _!KW 4063.28 2055.87: 4 0 4 8.7 5 L322 3 8 6 6: 4173.621 2178.87;.KVA 205.87. 2138.66i _2178.87_,::KVA ,4553.77 ' 4579.89, 4708.141 .',PF " 0.899!.8 : 0.89i,. !! ]
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 6 of 10 I .Standby Diesel Generator C S10 M1N 10-60 MIN >60 M[N Item DESCRIPTION PF I KW KVAR KW K 'VAR KW !KVAR KW 'KVAR, KW CLASS 1ELOADS 1 REACTOR CORE SPRAY PUMPS (Note 8) 0.91: 525.41 239.381 525.41 239.38; 525.41 239.38:; 525.41A 239.38i 525-41' 239.381 525.411 239.31 2 RHR PUMPS (Note 8) 0.89: 1002.69: 513.69! 1002.69: 513.69, 3 SAFETYAUX.
CLO. SYS. PUMPS (Note 8) 0.909 420.62, 192.86! 420.621 192.86: 420.62, 192.86 420.621 192.86! 420.62, 192.86! 420.62' 192.86 4 )CORE SPRAY PMP. RM. CLR. UNIT I 0.85 12.16 7.54: 12.161 7.54 12.16' 7.54 12.16i 7.54; 12.16! 7.541 12.161 7.54 5 IMOTOROPERATEDVALVES 0.4 14.81 33.93: 14.811 33.93 14.811 33.931 14.81; 33-931 14.81 33.93, 14.81 33.93 6 SWGR. RM. UNIT CLR. FANS 1 0.85 20.27 12.56 20.270 1.271 20271 12.6' 20-27; 12.561 20.27 12.56 20.27 12.56 0.851 32.431 2.10,32.4-0 '1013.43120.10324 7INTAKE STRUCTURE SUPPLY FANS 0-0.850)243' 20.]0 .__ 32.43; 32.43 20.10 32.43 20.10 INTAKE STRUCTURE TRAVELING SCREENS I I I I 8 AREA FANS 0.85 , _ I i L _ _9 'RHR PUMP RM UNIT COOLER FANS 1 0.85 16.221 10.051 [. i 16.221 10.05&#xfd; ; _10 !RCIC PUMP RM_ UNIT COOLERS 0.85 i i S11 -VPCIAPUMPRMUNITCOOLERS
' 0.85i_"_ _ " ____.____12 1 25-V DC BATTERY CHARGERS 0.6, 113.851 151.80 113.85! 151.80' 113.851 151.80' 113.85 151.80, 113.851 151.80, 113.85! 151.80 13 IDIESELAREABATTERYROOMEXHAUSTFANS I 0.8! 0.81, 0.50 0.81, 0.501 0.81: 0.50, 0.81 0.50: 0.811 0.50 0.811 0.50 14 IDIESELFUELOILTRANSFERPUMPS 0.85; 4.05, 2.51 : , 4.05 2.51 15 1STATION SERVICE WATER PUMPS (Note 8) 0.875. 634.22 350.90 634.22 350.90 634.22. 350.90: 634.22- 350.901 634.22! 350.90, 634.221 350.90 16 1RB FRVS RECIRCULATION SYSTEM FANS 0.85 121.63: 75.38 121.63; 75.38 121.63 75.38' 121.63! 75.381 121.63! 75.38: 121.631 75.38 17 'CONTROL RM SUPPLY FANS ! 0.85 32.43 20.10' 32.43. 20.10 32.43 20.10, 32.43: 20.10, i 18 208Y/120-V AC XFM!RS TO POWER DIST PANELS 0.85, 37.50, 23.24. 37.501 23.24 37.50; 23.241 37.50: 23.24* 37.50; 23.241 37.50: 23.24 19 RESERVED FOR FUTURE USE '20 INTAKE STRUCTRE EXAUST FANS 0 32.431 20.10. I 32.43; 20.10!. 32.4 20.101 32.43; 20.10 CONTROL ROOM CHILLED WATER CIRCUIATING[
~2.0 241 2.0 23 01 21 PUMPS 0.85! 48.65. 30.15' 48.65, 30.15i 48.65 30.15: 48.651 30.15 [_I 22 CNTRLRMSUPPLY UNITHTGCOILS 1 90.00' i 90.00 90.001 ' 90-00! 1 I [23 !CONTROL ROOM WATER CHILLERS (Note 10) 0.878: 506.00: 275.861 506.00. 275.86 506.00, 275.86W 506.001 275.86F _ _ I 24 1DIESELGENRMRECIRCSYSTEMS FANS 0.85' 202.72, 125.63; 202.72; 125.63 202.72 125.631 202-721 125.631 202.72: 125.631 202.721 125.63'PRIMARY CONTAINMENT INSTRUMENT GAS I, 25 jCOMPRESSORS 0-850. I 12.16, 7.54, 12.16' 7.541 12.16: 7.54i 12.16: 7.54 26 IBATTERY CHARGERS, 250-V DC 0.61 I ' ., I 27 I CONTROL AREA BATrERY ROOM EXHIAUST I 0.85, 4.051 2.51' 4.05 2511 4.05 2.51! 4.051 2.51. 4.051 2.511 4.051 2.51 28 RB FRVS RECIRCsUNIT HEATING COILS O 1 100.001 100.001 100.00, 100.00 100.00! i 100.00.ITRAVELING SCREEN SPRAY WATER BOOSTER 29 PUMPS 0.8511 16.22 10.05. 16.22 10-051 16.221 10.0 16.221 10.05&#xfd; 16-221 10.05&#xfd; 16.221 10.05 30 RiB FRVS VENT UNIT HEATING COILS ' 1. : I ____31 CONTROL ROOM SUPPLY SYSTEM RETURN FANS: 0.85 24.331 15.08! 24.33' 15.08' 24.33' 15.08! 24.331 15.081 _ i.32 CONTROL ROOM EMERGENCY FILTER FANS i 0.85. 2027! 12.56, 20271 12.56* 20.27- 12.56 20.271 12.561 '33 SAFETY AUX COOLING SYSTEM IUNIT COOLERS j 0.851 12.16, 7.54; 12.161 7.34! 12.16 7.54; 12.161 7.54: 12.161 7.541 12.16i 7.54 34 IFUEL POOL COOLING PUMPS 0 o.851 i ' i i i I _ _
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 7 of 10 Standby Diesel Generator C R. ,. .,.<10 MINI [0-60 MIN >60 MNI 5-H4 j~~ d.i: Itemrn DESCRIPTION PF KW KVAR KW KVAR KW ;KVAR KW i KVAR KW KVAR KW ' KVAR CONTROL ROOM EMERGENCY FILTER UNIT , I 35 ELECTRIC hIEATING COILS lj 13.00: 13.001 13.00 13.-00: 13.00 13.001 36 !CONTROLEQUIPMENTROOMAIRSSUPPLYFANS 0.851 202.72, 125.63' 202.72, 125.63 202.72' 125.63i 202.721 125.63 ! i 37 RB FRVS VENT SYS FANS 0.85' ; _________, CONTAINMENT HYDROGEN RECOMBINER
' I 38 jSYSTEM I 0.851 ' 140.001 86.76 SCONTROL EQIP ROOM SUPPLY UNIT HEATING I , II 39 &#xfd;COILS I 1' ., 100.00 100.00 ' 100.00 f I 40 SERVICE WATER SELF-CLEANING STRAINERS 0.851 0.811 0.50 0.811 0.5 0.81o1 0.50! 0.811 0.501 0.81 0.50 0.81' 0.5 41 JSTANDBY LIQUID CONTROL PUMPS I 0.85 ! i _ ! _ !42 &#xfd;RESERVED FOR FUTURE USE I I ___i 43 RESERVED FOR FUTURE USE 1. .I , " I _ ._ i: i!44 RESERVED FOR FTUR USE 1 I ___ I i _45 IRESERVED FOR FUTUREUSE IF, ! _ _ _ _ _!480 V POWER SUPPLY TO CLASS IE CHILLER 46 PANELS 0.85! 4.00 2.48! 4.00: 2.48. 4.00 2.48: 4.00, 2.48, 4.00 2.48 4.001 2.48 47 jTRAVELING SCREENS 0.851 4.05- 2.51' 4.05, 2.51, 4.05 2.51 4.051 2.51 405, 2.51 4,05' 2.51 48 IECCS JOCKEY PUMPS 0.85, 8.11 5.03 8.1 5.03' 8.11 5.03 8.11: 5.031 8111 5.03: 8.11. 5.03:MOTOR DRIVEN DIESEL GENERATOR FUEL OIL , 49 STAND1YPUMPS 0.85; 1.621 1.01 1.62, 1.011 1.62 1.01 1.62; 1.01. 1.62' 1.01 1.6 2 1 o01 ,STANDBY LIQUID CONTROL PUMP ROOM DUCT j .I 50 JHEATERS I .I 45-00, 480 V POWER SUPPLY TO HYDROGEN AND i I I ' , 51 'OXYGEN ANALYZER PANELS 0.851 I I j : 52 1250 V DC BATTERY ROOM DUCT BEATERS 1, 1125 V DC DIESEL AREA BATTERY ROOM DUCT 2 2 21.00 2 O 53 HEATERS 1 21.00' 21.00, 2 -00. ' 21.00! 21.00, 54 HPCI PUMP ROOM DUCT HEATER I :. I ' i _ _55 iRCIC PUMP ROOM DUCT HEATER Il i _ _ _56 :250 V DC BATTERY ROOM DUCT HEATER I .II 57 CLASS 1E PANEL ROOM WATER CHILLERS 2 0.886' i 58 CLASS IE PANEL ROOM CHILLED WATER PUMPS' 0.85: ' _CLASS 1E PANEL ROOM SUPPLY& RETURN AIR..II 59 FANS 0.8s1 I _ I 60 !CLASS IE PANEL ROOM ELECTRIC HEATERS J I ' I 61 BA ROOM EXHAUST FANS 3 0.85! ' I '62 BATTERYROOMDUCT HEATERS 1' 14.001 14.00r 14.00 14.00 14.00 14.00 63 1,2/02 ANALYZER HEAT TRACING PANELS ; 15.001 j 15.00 is .0oo; 15.00 15.00' ' 100'64 jRESERVED FOR FUTURE USE I 1 ' I ' I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 8 of 10 Standby Diesel Generator C V p<10 MIN 10-60 MINJ >60 MIN -Item DESCRIPTION PF KW i KVAR KW KVAR KW KVAR i KW KVAR KW KVAR KW I KVAR 65 !RESERVED FOR FUTURE USE 1 _ _ _ _I_ _ _ _ _ _66 RESERVED FOR FUTURE USE I _ _, 67 IRESERVED FOR FUTURE USE I ___,__68 RESERVED FOR FUTURE USE , ,__69 RESERVED FOR FUTURE USE Ii ..I I 70 RESERVED FOR FUTURE USE ' 1 I I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 9 of 10 Item DESCRIPTION PF KW KVAR KW KVAR KW KVARi KW IKVARI KW IKVAR KW i KVAR SNON-CLASS
.l.E LADSa See Note I 1I'71 TURBINE GENERATOR TURNING GEAR OIL PUMP 0.85> I _STANDBY LIQUID CONTROL SOLUTION 72 :OPERATING HEATER I- i , 73 jDRYWELL COOLING UNIT FANS 0.85, I 130.90 74 RADWASTE EXHAUST FANS 0.85. I I I 75 1ESSENTIAL PLANT LIGHTING 0.9 93.501 45.28 93.50' 45.281 130.901 63.401 130.9O! 63.40 76 1CRD WATER PUMPS 0.851 1 202.72' 125.63! 202.721 125.63 TURBINE BUILDING BATTERY ROOM EXHAUST I 77 IFANS 0.85' , I _ __. _TURBINE GENERATOR AUX BEARING LIFT 78 'PUMPS 9H- 5HP EACH AND 0.85 1 I I TURNING GEAR -60 HPI 79 1 EMERGENCY INSTRUMENT AIR COMPRESSOR 0.85' !__80 &#xfd;RADWASTE SUPPLY FANS 0.85 I:REACTOR BUILDING SUPPLY AIR HANDLING I I 81 UNITS 0.85! I 82 REACTOR BUILDING EXHAUST FANS 0.85; __ ,_83 RADWASTE TANK VENT FILTER FANS 0.85! .- , TURBINE BUILDING BATTERY ROOM SUPPLY I i!4 iFANS 0.851, i I 85 &#xfd;RADWASTE TANK VENT FILTER HEATING COILS I I .___ I _86 CHEMICAL LAB EXHAUST FANS 0.85.DIESEL GENERATOR STARTING AIR I I -87 COMPRESSORS 0.85 12.16. 7.54j 12,16: 7.54! 12.16j 7.54, 12.16! 7.54 88 ',REACTOR AUX COOLING SYSTEM PUMPS 0.85; : : i _ _ _ _89 .125-V DC BATTERY CHARGERS 0.6, _ , -i i _90 :125-V DC BATTERY CHARGERS 0.6: 38.00! 50.67 38.00: 50.67 __38.00_ 50_67_, 38-00i 50.67 91 :250-V DC BAITERY CHARGERS 0.6: .,______92 i STANDBY LIQUID CONTROL SOL MIXING 1 , 40.00: 40.001 93 IRFPTAUX LUBE OIL PUMP (NOTE 12) & 0,85 ._.__ _ _TURNING GEAR MOTORS 21.49 13.32, 21.49 13.3 2 1 _ _ _ _ _ _94 RESERVED FOR FUTURE USE -_ _ _ __ _ _95 ,208 V/120 V AC XFMRS TO DIST PANELS 0.85j 45.00: 27.89, 45.001 27.891 15.001 9.30: 15.00, 9.30 96 REACTOR BUILDING FLOOR DRAIN SUMP PUMPSI 0.851 8.11, 5.03 &.1i 5.03 8.11! 5-03; 8.11[ 5.03 97 DRYWELL EQUIJ DRAIN SUMP PUMPS 0.851 I .F__ -,__98 IDRYWELL FLOOR DRAIN SUMP PUMPS 0.85 3
* I I I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 4 SDG "B" Off Line Calculation E-9 Rev.8 Page 10 of 10 I ~~Standby Diesel Getiralor C U, y '~'10 MIN .I10~T~ >6OMIN___Iem! DESCRIPTION PF KW I KVAR KW KVAR KW KVAR KW i KVAR KW KVAR' W VAR POWER SUPPLY FOR UNIT VENT RADIATION I i I , -99 MONITORING SYSTEMS 0.85; 3.50! 2.17 3.50' 2.17 I POWER SUPPLY FOR DLD RADIATION I i I 100 iMONITORING SYSTEMS L 0.85s I i 101 TURBINEGENERATOR MAIN SEAL OIL PUMP : : I I __ __102 TURBINE GENERATOR RECIRC SEAL OIL PUMP 0.15 ---- 5 '103 !TURBINE GENERATOR SEAL OIL VACUUM PUMP 0.85, i _ -_ !'RAWASTE + 24V DC BATTERY ROOM DUCT I 104 HEATER 11 I CONDENSATE STORAGE TANK HEAT TRACING 105 (SEE NOTE 26) 1 12.00; 12.001 106 :TSC SUPPLY SYSTEM FAN 0.85 20 00 12.39 20.00! 12.39 ! _____107 !TSC SUPPLY SYSTEM HEATING COIL : 30.00 30.00: 108 !TSC EMERGENCY FILTERFAN i 0.85! .20.00i 12,39_ 20.00 12.39' i 1 109 ITSC EMERGENCY FILTER HTG COIL i 13.00. 13m0 _110 STEAM TUNNEL UNIT COOLERS 0.85. ___ _ '. 16.001 9.921 16.00; 9.92 III TURBINE BUILDING BATTERY ROOM SUPPLY FAN I i , : [ ____112 iTURBINE BUILDING COMPARTMENT EXHAUST F4 0.85: I _____113 .CONTROL AREA 125 V DC BATTERY ROOMDUCTH DC 1ViR' L i 114 !REMOTE SHUTDOWN PANEL ROOM SUPPLY FAN:! 0.851 , ] j I 115 !REMOTE SHUTDOWN PANEL ROOM HEATING COIL 1' I I [ _ _: 116 PLANT LEAK DETECTION SYSTEM HEAT TRACING 1. i i 12.00! 12.00__1i_17 luNrr VENT RMS HEAT TRACING PANEL I',.I 118 IPOST ACC1DENT SAMPLING SYS HEAT TRACING 1] 15.00&#xfd; 15.00' I ___119 &#xfd;ELECTRIC UNIT HEATERS 1 24.00. 24.00 ._ 1 : 120 TSC ELECTRIC PAN HUMIDIFIER (NOTE 26) 0.85: 12.971 8.04I 12.97+ 8.04' , _121 1WINGAREAEXHAUSTFANS
'85. 16.00: 9.92: 16.00 9.92 122 _WING AREA SUPPLY FANS 0.851 -40.00! 24.79 40.00 24.79 123 SPDS UPS 1 l 60.00 _ _ , ,KW 4426.201 2288.68. 3723.32 1917.00 3787.38 1919.51, 4426.20: 2298.68&#xfd; 2970.95! 1599.281 3070.00[ 55 KVAR 2288.681 1917.00 1919.51; 2288.681 1599.281 1688.55;!KVA 4982.91' 4187.84i : 4246.03! I4982.91i 3374.051 3503.71: I PF 0.89. 0.89i ' 0.89' 0.89! 0.88] 0.881 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 1 of 12 V 'tndyDiesel Generator A:Sanb D rese weeatr< [ <10 MIN 16N::--'I04 1 "!: b" ->GMIN < N -O6 N ->6oMIN Item[ DESCRIPTION PF KW KVAR KW KVAR I KW KVAR KW KVAR KW ,KVAR KW I KVAR CLASS IE LOADS.1 REACTOR CORE SPRAY PUMPS (Note 8) 0.911 525.411 239.381 525.41] 239.381 525.41 239.38i 525.41 239.381, 2 RHPUMPS 'Note 8) 0.8 9 L.1002.69; 513.69 ' 1002.691 513.693 1002.691 513.69 1002.69: 513.69 3 SAFETY AUX- CLG. SYS. PUMPS (Note 8) 0.9091 420.62 192.86 420.62 192.86. 420.62 192.861 420.621 192.861 420.621 192.86: 420.62 192.86 4 :CORE SPRAY PMP. RM. CLR. UNIT 0.g5i 12.16 7.54 12.16' 7.54. 12.16, 7.54 12.161 7.541 1 5 MOTOR OPERATED VALVES 0.4: 14.81 33.93 14.81 33.93 14.81' 33.93. 14.81: 33-93: 14.811 33.93i 14.81. 33.93 6 -SWGR. RM. UNIT CLR. FANS 0.85: 20.271 12.56: 20.27: 12.56. 20.27 12.56 20.27' 12.56. 20.271 12.56! 20.27: 12.56 7 INTAKE STRUCTURE SUPPLY FANS i 0.85 32.43, 20.10: 32.431 20.10 32.431 20.10 32.43&#xfd; 20.10&#xfd; 32.43: 20.101 32.43, 20.10!INTAKE STRUCTURE TRAVELING SCREENS I ' .j I 8 AREAFANS 0.85: 6-08! 3.77i 6.08! 3.771 6.081 3.771 6.08! 3.77! 6.081 3.771 6.08! 3.77 9 IRHRRPUL RMUNITCOOLERFANS 0.85; 16.221 10.051 I i i 16.22i 10.05. 16.22, 10.051 1622 -- 10.05 10 RCIC PUMP RM. UNIT COOLERS 0.85: , 8.11i 5.031 8.11! 5.031 8-11! 5.03 11 HPCIPUMPRMUN1TCOOLERS 0.85: 12.16! 7.54! 12.161 7.541 12.16, 7.541 1 12 1125-V DC BATTERY CHARGERS 0.61 75.90: 101.20 75.90: 101.20: 101.20 101.20 75.901 75.90: 101.202 75.901 101.20 13 !DIESEL AREA BATTERY ROOM EXHAUST FANS 0.85, 0.81, 0.50 0.81 0.50i 0.81' 0.50, 0.81: 0.501 0.811 0.50: 0.811 0.50 14 IDIESEL FUEL OIL TRANSFER PUMPS 0.851 ' 4.051 2.51! I .4.05 2.51 I5 STATION SERVICE WATER PUMPS (Note 8) 0.8751 634.221 350.90 634.22' 350.90: 634.22: 350.901 634.22 350.90 634.22: 350.90W 634.22, 350.90 16 RB FRVS RECIRCULATION SYSTEM FANS 0.851 243-26 150.76 243.26' 150.76! 243.26, 150.76; 243.26 150.761 121.63i 75.38: 121.63! 75.38 17 !CONTROL RM SUPPLY FANS 0.85: i 18 208Y/120-V AC XFMRS TO POWER DIST PANELS 0.85. 37.50! 23.24 37.50. 23.24- 37.50: 23.24' 37.501 23.24! 37.50! 23.24, 37.501 23.24 19 RESERVED FOR FUTURE USE I , I I 20 IlNTAKE STRUCTURE EXHAUST FANS 0.85 32.43' 20.10. 32.43: 20.10 32.43 20.10 32.431 20.10' 32.431 20.10 32.43: 20.10 COrlROL ROOM CHILLED WATER : ' ., I , 21 ICIRCULATING PUMPS 0.85, I , -.! -1 F 22 CNTRL RM SUPPLY UNIT HTG COILS 1 i -I , 23 CONTROL ROOM WATER CHILLERS (Note 10) 0.878 _ _ _ _ _ , I 24 IDIESEL GEN RM RECIRC SYSTEMS FANS 0.85, 202.'- 125.63! 202.72; 125.63 202.721 125.63: 202.72: 125.63, 20 202.721 125.63 PRIMARY CONTAINMENT INSTRUMENT GAS i , .25 iCOMPRESSORS 0.85' I '26 ]BATTERY CHARGERS, 250-V DC 0.61 19.001 25.33; 19.00! 25.33! 19.00' 25.33i 19.00! 25.33; 19-00! 25.331 19.001 25.33&#xfd;CONTROL AREA BATfERY ROOM EXHAUST I i '27 TFANS 0.85, i 28 &#xfd;RB FRVS RECIRC UNIT HEATING COILS I i 200.001 200.00: 200.00, i 200.00 100.00 100.00i TRAVELING SCREEN SPRAY WATER BOOSTER 29 :PUMPS 0.85: 16.22 10.05 16.22 10.05: 16.22- 10.05: 16.22! 10.051 16.22 10.05, 16.22! 10.05 30 RB FRVS VENT UNIT HEATING COILS 1 32.00 32.00 3, 32.001 3 31 2CON UL ROOM SUPPLY SYSTEM RETURN 0.85, 1,'32 ICONTROL ROOM EMERGENCY FILTER FANS I 0.85 , i 33 SAFETY AUX COOLING SYSTEM UNIT COOLERS' 0.5' .... _ I0. 5 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 2 of 12 I -Standby D iese G66eraorA:
0 tnb isl(eeao H <IMIN ----- 0-6OIN 60MIN <IMN10TMN 6MN Item , DESCRIPTION PF KW KVAR KW KVAR KW KVAR KW KVAR .KW KVARi KW KVAR 34 FUEL POOL COOLING PUMPS 0.85 .60"82 37"691 5'CONTROL ROOM EMERGENCY FILTER UNIT .' " '35 ELECTRIC BEATING COILS 1 '36 CONTROL EQUIPMENT ROOM AIR SUPPLY FANS. 0.85 37 RBFRVSVENTSYSFANS 0.85 20.27! 2.256 2027 12.56. 20.271 12.56 20.27' 12.56!1 CONTAINMENT HYDROGEN RECOMBINER 38 SYSTEM 0.85 140,00, 86.76 , CONTROL EQIP ROOM SUPPLY UNIT HEATING I i 39 COILS i : i i_0_40 SERVICEWATERSELF-CLEANINGSTRAINERS I 0.85! 0.81, 0.50. 0.81. 0.50! 0.81: 0.50, 0.81 0.50: 0.81 0.50 0.811 0.50 41 .STANDBY LIQUID CONTROL PUMPS 0.851 32.43. 20.10. 32.431 20.10:; 32.43! 20.10, 32.43' 20.10, 32.43; 20.10i 32.431 20.10 42 IRESERVED FOR FUTURE USE I 1' .I I 43 [RESERVED FOR FUTURE USE ' ! ' .1 i 44 &#xfd; RESERVED FOR FUTURE USE Ir 45 RESERVED FOR FUTURE USE i , ., .!480 V POWER SUPPLY TO CLASS 1E CHILLER I i 46 iPANELS 0.85+ 4.00, 2.48: 4.00' 2.48 4.00, 2.481 4.00i 2.481 4.001 2.481 4.00: 2.48 47 TRAVELING SCREENS 0.85! 4.05 2.51 4.051 2.51 4.05 2.51! 4.05 2.511 4.05! 2.51: 4.05' 2.51 48 'ECCS JOCKEY PUMPS 0.85. 8.11 5.03 8.11. 5.03. 8.11 5.03: 8.11' 5.03' 8.11', 5.031 8.11; 5.03 MOTOR DRIVEN DIESEL GENERATOR FUEL OIL 49 STANDBY PUMPS 0.85' 1.621 1.01, 1.62 1.01' 1.62, 1.011 1.62j 1.01' 1.621 1.01i 1.62&#xfd; 1.01 50STANDBY LIQUID CONTROL PUMP ROOM DUCT! I : I HEATERS 11 45.00, i 45.00! II 1480 V POWER SUPPLY TO HYDROGEN AND , I .51 IOXYGEN ANALYZER PANELS I 0.85; 1.00 0.62! 1.00 0.62! L.00 0.62! 1.00j 0.621 1.00! 0.621 1.00 0.62 52 ;250 V DC BAT!"ERY ROOM DUCT HEATERS I i 10.00! .10.00 10.001 1 ' [ __1125 V DC DIESEL AREA BATTERY ROOM DUCT , I I I 53 ;HEATERS 11 21.00! 21.00' 21.0!1.00 , 21.00' 21.00 54 IHPCI PUMP ROOM DUCT HEATER I 1! 11.001 1.00; .11.00! ._55 :RCIC PUMP ROOM DUCT HEATER I 7.00 7.00' 7.001 56 :250 V DC BATTERY ROOM DUCT HEATER 1 1- , 8.00 8.00, 8.00i 57 'CLASS 1E PANEL ROOM WATER CHILLERS 0.8861 198.00, 103.62 198.00: 103.62 198.00, 103.621 198.00 103.62': 58 iCLASS IE PANEL ROOM CHILLED WATER 0.85! 32.43 20.10: 32.43: 20.10: 32.43' 20.10 32.43; 20.10; _,___,--CLASS IE PANEL ROOM SUPPLY & RETURN AIR 59 jFANS 0.85. 60.82" 37.69 60.82' 37.69 60.82. 37.69: 60.82 37.69: 60 ICLASS 1E PANEL ROOM ELECTRIC HEATnRS 1 100.00 100.00' 100.00 .100.00 .. 081 61 IBATrERY ROOM EXHAUST FANS 0.85 0.81 0.50 0.81! 0.50 0.81; 0.50. 0.81 0.50, 0.81 0.501 0.811 0.50-62BATTERY ROOM DUCT HEATERS 1 :_;_ _ _ _ _ _ _ _ _63 , H2102 ANALYZER HEAT TRACING PANELS 1' .I I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 3 of 12 v>!!:;: , DL ieW!o !,.Gend t,;. DESCRIPTION PF I KW KVAR KW KVAR KW K VAR I W KVAR KW I KVAR KW I KVAR 64 RESERVED FOR FUTURE USE I _1'___ I_'______65 RESERVED FOR FUTURE USE 1:I 66 !RESERVED FOR FUTURE USE I i 67 &#xfd;RESERVED FOR FUTURE USE I I 68 IRESERVED FOR FUTURE USE I , 69 RESERVED FOR FUTURE USE 1 70 !RESERVED FOR FUTURE USE 1 I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby IE Diesel Generator Sizing Attachment 5 SOG "C" Off Line Calculation E-9 Rev. 8 Page 4 of 12-~ --I Stndby Dcsel.enemtr.A Stand1by Disel Goherat&r~--itemI~MI DE&#xfd;nTINmP DESCRIPTION PF KVAR KW KVAR, KW KVAR 1  KW IKVARI KW IKVAR KW KVAR* I NON-CLASS IE LOADS I I See Note 11 i i __9_20-32.001 13 320 19.83 71 &#xfd;TURBINE GENERATOR TURNING GEAR OIL 0.85. 32-00 19-831 31_0 1983 STANDBY LIQUID CONTROL SOLUTION I I I 72 OPERATING HEATER 1 10.00 10.00. I I 73 DRYWELL COOLING UNIT FANS 0.851 I_ _ _ _ _ _ _'74 IRADWASTE EXHAUST FANS 0.8I_75 ESSENTIAL PLANT LIGHTNG 0.9, 145.90 70.66b 145.901 70.661 37. 1 8.111 37.40! 18.11 76 jCRD WATER PUMPS 0.851 j1 ITURBINEBUILDING BATTERY ROOM EXHAUST ; I I I 77 FANS 0.85- 2.43. 1.5 1  2.43[ 1.51. I 2.431 1.511 2.43:. 1.51 TURBINE GENERATOR AUX BEARING LIFT
* I I 78 PUMPS 9-SHP EACH AND 0.851 I I I TURNING GEAR -60 HP i .I85.141 5277 854 52.77 79 'EMERGENCY INSTRUMENT AIR COMPRESSOR 0.85: ,_I__80 !RADWASTE SUPPLY FANS 0.85 " _, IREACTOR BUILDING SUPPLY AIR HANDLING i 81 'UNITS 0.85: I 82 REACTOR BUILDING EXHAUST FANS (0.85;, i ! i 83 RADWASTE TANK VENT FILTER FANS 0.85 608 3.77 6.08: 33.77 O60 3.7 6.08: 3.77-TURBNE BUILDING BATTERY ROOM SUPPLY.. _84 IFANS 0.85 4.05 2.51; 4.051 2.51! 4.051 2.511 4.05' 2.51 85 1RADWASTE TANKVENT FILTER HEATING 3.60: 3.60; 3.60! ! 3.60, 86 :CHEMICA LLABEXHAUSTFANS 0.85&#xfd; 1 16.22i 10.05, 16.22! 10.05 DIESEL GENERATOR STARTING AIR -.I I 87 COMPRESSORS 0.85 .. 12.16 7.541 12.161 7.54I 1 12.161 7.54 12.161 7.54 88 REACTOR AUX COOLING SYSTEM PUMPS 0.85&#xfd; , .'89 125-V DC BATTERY CHARGERS 0-61 I 114.00! 152.00 114.00- 152.001 I 114.00 152.00 114.00 2 90 !125-V DC BATTERY CHARGERS 0_61 38.00' 50.67, 38.00& 50.67 38.00, 50.67- 38.00 50.67 91 1250-V DC BATTERY CHARGERS 0.61 57.001 76.00; 57.00i 76.00 STANDBY LIQUID CONTROL SOL MIXING , 92 HEATER I :.,,I!1
* _ _ _93 PJPTAUXLU3EOILPUMJ)(NOTE12)&
0.85i ., , I , , TURNING GEAR MOTORS i 21.491 13.32, 21.49; 13.32! 1 21.491 13.321 21.49' 13.32 S94 RESERVED FOR FUTURE USE 1 .' i i 95 208 V/120 V AC XFMRS TO DIST PANELS 0.85 30.00. 18.59i 30.00k 18.59 15.00i 9.30; 15.001 9.30 96 IREACTOR BUILDING FLOOR DRAIN SUMP 0.85; , I 1 .I 97 DRYWELL EQUIP DRAIN SUMP PUMPS 0.85! 4.05! 2.51 4.05 2.511 4.05 2.51!. 4.05: 2.51 98 DRYWELL FLOOR DRAIN SUMP PUMPS 0.851 4.051 2.51, 4.05, 2.51! I 4.05i 2.51! 4.05: 2.51 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 5 of 12~~~~t 1 I~Nl-0I ~ >0[ MINZ 10}-60MIN
&#xfd;0MN Item DESCRIPTION PF KW 'KVAR KW *VR K KA KW KVAR KW IKVR K KVAR IPOWER SUPPLY FOR UNIT VENT RADIATION , I 99 MONITORING SYSTEMS 0.85 3.50 2.17 3.501 2.171 i 3.501 2.171 3.50 2.17 POWER SUPPLY FOR DLD RADIATION 100 MONITORING SYSTEMS 0.95 ' ______,_____
101 TURBINE GENERATOR MAIN SEAL OIL PUMP 0.85 .i 16.22; 10.05! 16.22' 10.05 102 !TURBINE GENERATOR RECIRC SEAL OIL PUMP 1 0.85: _ I " 6.08i 3.77. 6.08' 3.77 103 TURBINE GENERATOR SEAL OIL VACUUM 0.85 i L ' 2.43j 1.51, 2.43, 1.51 RAWASTE + 24V DC BATTERY ROOM DUCT ., 104 *IHEATER 11 : I ' _ L ]CONDENSATE STORAGE TANK HEAT TRACING -, T I 105 (SEE NOTE 26) 1: I 5.00' 5.001 , I _106 j TSC SUPPLY SYSTEM FAN 0.85. _ _ _ _ _ .i _ "" 107 ITSC SUPPLY SYSTEM HEATING COIL 1 _ , .I 108 iTSC EMERGENCY FILTER FAN 0-o85: 109 :TSC EMERGENCY FILTER HTG COIL I_1__ ..110 iSTEAM TUNNEL UNIT COOLERS _ 0.857 1. .9 2&#xfd; 16j.01 9.92 TURBINE BUILDING BATTERY ROOM SUPPLY , 111 FAN& HTGCOIL 50.00!;TURBINE BUILDING COMPARTMENT EXHAUST ' -, ., 112 FANS 0.85: I I____.CONTROL AREA 125 V DC BATTERY ROOM 13U DUCT HEATER, 1 16.00i 16.00 114 'REMOTE SHUTDOWN PANEL ROOM SUPPLY 0.85 4.00! 2.48: 4.00. 2.48' _ i '_REMOTE SHUTDOWN PANEL ROOM HEATING .115 ICOIL , 1 .10.00: 10.00i _ _ I __ _ _ _PLANT LEAK DETECTION SYSTEM HEAT 116 ;TRACING PANEL (SEE NOTE 26) 1 __ _ _ _ _ _ _ _ _ _ , _ _117 'UNIT VENT RMS HEAT TRACING PANEL 1. j 15.00 15.00: ......__ ...___iPOST ACCIDENT SAMPLING SYS HEAT TRACING I i 118 -PANEL J 1 .... +/- [119 ELECTRIC UNIT HEATERS ........__ .120 !TSC ELECTRIC PAN HUMIDIFIER (NOTE 26) 0.85: ' I i I 121 !WING AREA EXHAUST FANS 0.85, 16.00 9.92 16.00 9.92 .I 122 WING AREA SUPPLY FANS I 0.851 40.00. 24.79: 40.00: 24.79i I ___[ [ _123 SPDS UPS .I 60.00i I t '___I I I _ _ _ I _ _ _ _ _-7...T _ _ _ _ i[ II USER RESPONSfSLE FOR VERIFY'fNG REV(S(ON, STATUS AND CHANGES Standby I E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 6 of 12' ' I. : : -.:.:": : S.. dbytDb fie,[en ,torA .:I. .; .i an : iet-<10 M64 19-60;MIN
>60:MIN <IMNI-OI 6MIN'DESCRIPTION
-PF KW KVAR KW KVAR KW KVAR , KW KVAR: KW
* KVAR KW KVAR*KW:- 4063.28' 2055.87: 3660.92 1907.121 3925.78' 2034.091 4053.22' 2053.36, 3347.42. 2006.899 335!,47/ 2009.40-- -i --_ _ _ _ _ KVA i 2055.8T, 1907.12; 2034.09: 2053.36: 2006.891 2009.40" KVA. 4553.77 4127.88i 4421.46, 1 4543.661 3902.92j 3907.69.PF 0.89; 0.89; i 0,891 0.86K 0.861, USER RESPONSIBLE FOR VERJFY)NG REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 7 of 12 l ..StdbylDielncralorC
<10 MIN 10-60 MIN >60 MAIN I"i'ilN ."- .Item DESCRIPTION PF 1KW KVAR KW KVAR KW KVAR KW KVAR i KW , KVAR KW KVAR CLASS IE LOADS ______ _ 'I REACTOR CORE SPRAY PUMPS (Note 8) 0.91. 525.41 239.38, 525.41i 239.38i 525.411 239.38 2 RIRPUMPS(Note
: 8) 0.89 1002.691 513.691 3 SAFETY AUX. CLU. SYS. PUMPS (Note 8) 0.909, 420.62' 192.86 4.62 192.86 420.62i 192.86 4 iCORE SPRAY PMP. RM. CLR. UNIT , 85 -12.16i 7.541 12.161 7.541 1216' 7.54 5 iMOTOR OPERATED VALVES ] 0.4', I 14.81 33.93; 14.811 33.931 14.81 33.93 MOO OPRTDVLVI 9 6 SWGR. RM. UNIT CLR. FANS 0.85 i 20.27 12.56: 20.27i 12.56i 20.271 12.56 7 INTAKE STRUCTURE SUPPLY FANS 0.85.1 0. 3. 2101-INTAKE STRUCTURE TRAVELING SCREENS I , , 8AREA FANS I 0.85. , 9 RHR PUMP RM UNIT COOLER FANS 0.85, , 16-221 10.051 _ _ , _107RClC PUMP RM. UNIT COOLERS : 0.851 '_11 iHPCI PUMP RM UNIT COOLERS 0.851 12 125-V DC BATTERY CHARGERS 0.6 ., 113.85. 151.80 113.85, 151.80! 113.85T 151.13 DIESEL AREA BATTERY ROOM EXHAUST FANS i 0.85. 0.81 0mo 0.00 0.81 0.50 14 IDIESEL FUEL OIL TRANSFER PUMPS 0.85, i ' ' 4.051 2.51 15 STATION SERVICE WATER PUMPS (Note 8) 0.875i I .j I 634.221 3.2215..16
.2 350.90; 63422- 350.90 16 RB FRVS RECIRCULATION SYSTEM FANS i 0.85] , .121.631 75.38I 121.63 7538 121.63 75.38 17 ICONTROL RM SUPPLY FANS 0.85; 32.431 20.101 32.43: 20.10 32.43 20.10 18 208Y/120-V AC XFMRS TO POWER DIST PANELS 0.85. I 37.501 23.24. 37.501 23.24 37.$0 23.24 19 oRESERVEDFoR USE 1F , USE I ________3__20_i___
20 ll',TrKESTRUCTURE EXHAUST FANS ' 0.85' i 3 20.1'0i_ _CONTROL ROOM CHILLED WATER a , I i 21 ICIRCULATING PUMPS 0.85: 48.65- 30.15' 48.65, 30.151 48.65! 30.15 22 CNTRL RM SUPPLY UNIT HTGCO-iLS 1 .90.00' 90.00i 90.001 23 :CONTROL ROOM WATER CHIILLERS (Note 10) 0.878. -506.001 275.861 506.001 275.86, 506.001 275.86 24 :DIESEL GEN RM RECIRC SYSTEMS FANS 0.85 ! 202.72! 125.63' 202.72; 125.63 202.72' 125.63 PRINMARY CONTAINMENT INSTRUMENT GAS -: -25 !COMPRESSORS os .-5: 12.16i 7.54' 12.161 7.54 26 ,BATTERY CHARGERS, 250-V DC .0.6. ' i I:CONTROLARE BATTERY ROOM EXHAUST , " 27 FANS 0.85! _______, 4.051 2.51 4.051 2.51' 4.051 2.51 28 RBFRVSRECIRCUNIT HEATINGCOILS
.1 100.00; 100.00; 100.00i TRAVELING SCREEN SPRAY WATER BOOSTER 29 PUMPS 0.85. : 1 i 16-221 10.05: 16.221 10.051 16.22 10.05 30 iRB FRVS VENT UNIT HEATING COILS I1'
* I I I 2 31 CONTROL ROOM SUPPLY SYSTEM RETURN 0.85; "- _ 1 .j J 24.33 15.08 24.33 15.08' 24.33 15.08 32 CONTROL ROOM EMERGENCY FILTER FANS 0.85. I I 20-27 12.56 20.271 12.564 20-271 12.56 33 SAFETY AUX COOLING SYSTEM UNIT COOLERS! 0.85 .12.16; 7.541 12.16: 7.541 12.161 7.54 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANCES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 8 of 12_____ 'Standby Diesel Generator C<10 MIN 1060 MIN >60 MIN Item I DESCRIPTION PF KW iKVAR KW KVAR KW A KW KVAR KW I KVAR 34 FUEL POOL COOLING PUMPS 0.85 !CONTROL ROOM EMERGENCY FILTER UNIT t " 35 ELECTRIC HEATING COILS i 1_ _ _ _ _ 13.001 13.00:; I3.00 36 'CONTROL EQUIPMENT ROOM AIR SUPPLY FANS! 0.851 -_ _ _ _ 202.72, 125.63&#xfd; 202.72: 125.631 202.721 125.63 37 :RB FRVS VENT SYS FANS i 0.85' T I _ _ _CONTAINMENT HYDROGEN RECOMBINER 38 :SYSTEM 0.85i 1 _ i-CONTROL EQIP ROOM SUPPLY UNIT HEATING 39 :COILS I 1 I _ _ _100.001 I 100.00. 100.001 40 SERVICE WATER SELF-CLEANING STRAINERS 0.85 0.811 0.50_ 0.81_ 0.50, 0.___] 0.50 41 STANDBY LIQUID CONTROL PUMPS 0.85 I--42 jRESERVED FOR FUTURE USE 1 t: J _ , I 43 RESERVED FOR FUTURE USE I I _ _ _ _!I 44 iRESERVED FOR FUTURE USE I _ _ _ _ _ __45 i RESERVED FOR FUTURE USE 1. I I -i 1480 V POWER SUPPLY TO CLASS I E CHILLER 7 I 404.0 46 PANELS , 0.853 4.00' 2.48 4.00 2.481 4.00 2.48 47 'TRAVELING SCREENS 0.895 .4.05 2.51, 4.051 2.511 4.05i 2.51 48 1 ECCS JOCKEY PUMPS 0.851 8.11. 5.03 8.111 5.03i 8.11! 5.03 IMOTOR DRIVEN DIESEL GENERATOR FUEL OIL' i I I 49 STANDBY PUMPS 0.851 1.62I 1.011 1.62! 1.0 .62I 1.01]STANDBYLIQUID CONTROL PUMP ROOM DUCT: I i 1[ 6 .50 HEATERS 11 I I I L 45_00', 480 V POWER SUPPLY TO HYDROGENAND ANI D 51 OXYGEN ANALYZER PANELS 0.851 _ _ _ _ I I_ _ _52 1250 V DC BATTERY ROOM DUCT HEATERS ]I ' i i 125 V DC DIESEL AREA BATTERY ROOM DUCT I I I 53 HEATERS 1! t 21.001 21.00: 21.00i 54 1I-PCI PUMP ROOM DUCT HEATER : I1___ [55 IRCIC PUMP ROOM DUCT HEATER 1 !56 1250 V DC BATTERY ROOM DUCT HEATER I 1 : i 57 'CLASS 1E PANEL ROOM WATER CHILLERS 0.886, 58 !CLASS 1E PANEL ROOM CHILLED WATER 0.85 i ]!CLASS IE PANEL ROOM SUPPLY & RETURN AIR .1 59 'FANS 0.85" J i 60 CLASS 1E PANEL ROOM ELECTRIC HEATERS 1 " _61 'BATTERY ROOM EXHAUST FANS 0.851
* i ' I 62 'BATTERY ROOM DUCT HEATERS II I 14.00, 14.00, 14.0o1 63 H2/O2 ANALYZER HEAT TRACING PANELS I, 1 15.00! 15.00: 1 5.00, USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 9 of 12*- ...... .... Standby Diesel Generator C ..1" -___.-_Item ISDESCRIPTION PF KW KVAR KW KVAR KW KVAR l KW KVAR KW KV KVAR 64 RESERVEDFOR FUTURE USE 1' i _, i_'_:___ " 65 RESERVED FOR FUTURE USE1, I T V 66 RESERVED FOR FUTURE USE I i L_ _ _ _67 RESERVED FOR FUTURE USE i 1 [ ,' _ ....... I _'_ _ _68 RESERVED FOR FUTURE USE I 1________
i _ I 69 RESERVED FOR FUTURE USE II _'______ _ _70 RESERVED FOR FUTURE USE 1 , _ _ _ _,
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Szing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 10 of 12.__Standby Diesel Generator C<10 MIN ,0-60 MIN >60.MIN Item DESCRIPTION PF KW KVAR KW KVAR KW KVAR KW i KW I KVAR KW :KVAR NON-CLASS 1E LOADS .I ___-__,___'_" See Note .I _ _ _ __ _ I I -71 ;TURBINE GENERATOR TURNING GEAR OIL 0.85i I__ __ i__7STANDBY LIQUID CONTROL SOLUTION I t -72 OPERATING HEATER _ _t _ _i______73 JDRYWELL COOLING UNIT FANS I 0.851 1 _ _ _, _74 RADWASTE EXHAUST FANS 0.85 .[ I_ _ I_'75 ESSENTIAL PLANT LIGHTING 09'..76 CRD WATERp PUP I&#xfd;5 202.7211 125.631 202.71' 125.63 TURBINE BUILDING BATTERY ROOM EXHAUST! '5 77 FANS 0.5 ITURBINE GENERATOR AUX BEARING LIFT .I 78 IPUMPS9-s5HP EACH AND 0.85___TURNING GEAR- 60 HJP _ , _ _79 EMERGENCY INSTRUMENT AIR COMPRESSOR 0.85!80 :RADWASTE SUPPLY FANS 0.85.iREACTOR BUILDING SUPPLY AIR HANDLING 81 ;UNITS 0.851 I 82 IREACTOR BUILDING EXHAUST FANS 0.85, 1.-!83 RADWASTE TANK VENT FILTER FANS __0_85_____
TURBINE BUILDING BATTERY ROOM SUPPLY 84 IFANS 0.85 I 85 IRADWASTE TANK VENT FILTER HEATING I I .,_____86 1CHEIMICAL LAB EXHAUST FANS 1 0.85, I ,,!DIESEL GENERATOR STARTING AIR 87 COMPRESSORS 0.851' 12.16 7.541 12-16: 7.54 88 REACTOR AUX COOLING SYSTEM PUMPS 0.854 , -_ , _ .89 ,125-V DC BATTERY CHARGERS 0.6i .I '_38.00_____
90 125-V DC BATTERY CHARGERS 06 ... , 3800 50.67! 38.001 50.67 91 250-V DC BATTERY CHARGERS 0.61 _ , , _ I ;'STANDBY LIQUID CONTROL SOL MIXING 92 iHEATER I 1_ _ __ 40.00! 40.00!.93 IRFPT AUX LUBE OIL PUMP (NOTE 12) & .----'0.851 I _ { _TURNING GEAR MOTORS I _ 1 _94 iRESERVED FORFUTURE USE I _ _ i i 95 1208 V/12o V AC XFMRS TO DIST PANELS 0.85 i-ii 15.00! 9.30 15.00i 9.30 96 ;REACTOR BUILDING FLOOR DRAINSUMP 0.85 I ._ 1 8.11' 5.03 8.11 5.03 97 JDRYWELL EQUIP DRAIN SUMP PUMPS 085 , I i 9.8 9DRYWELL FLOOR DRAIN SUMP PUMPS 0.851 i I I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 11 of 12 Standby Diesel Generator C-I.<I 0 MIN 1 10-60 MIN 1>60 MIN l',1,j u A~~i7&#xfd;., Item! DESCRIPTION PF KW KVAR KW KVAR KW KVAR KW KVAR KW KVAR KW KVAR POWER SUPPLY FOR UNIT VENT RADIATION 99 MONITORING SYSTEMS 0.85: _,___",___
I j I POWER SUPPLY FOR DLD RADIATION I j I 100 MONITORING SYSTEMS 0.851 I i 101 TURBINE GENERATOR MAIN SEAL OIL PUMP [.s1 i t'..........................
i D lk n u.I _______ _______________________
____ _________
____102 1TUNE.GErNERATOR RECIRC SEAL OIL PUMP -0.85 ! L ' ! ! ,_____I 103 :TURBINE GENERATOR SEAL OIL VACUUM 0.85j __:____ _I RAWASTE + 24V DC BATERY ROOM DUCT q ' I i I 104 !HEATER I , CONDENSATE STORAGE TANK HEAT TRACING 105 (SEE NOTE 26) , I j _106 TSC SUPPLY SYSTEM FAN 0.51 _ " _ _ I 107 ITSC SUPPLY SYSTEM HEATING COIL 1 I I 1 10 ITSCEE~~GENCYFILTER AN 0.8 o __ _ _ _ I_ _109 TSC EMERGENCY FILTER HTG COIL 1 I ' " COOLERS 0.8. i 16.001 9.921 16.00; 9.92 ITURBINE BUILDING BATTERY ROOM SUPPLY , III 'FAN & HTG COIL I ; , , , TURBINE BUILDING COMPARTMENT EXHAUST i i I 112 :FANS 0-85j , I;CONTROL AREA 125 V DC BATTERY ROOM I ,, i 113 :DUCT HEATER I I i_ _ i i 114. REMOTE SHUTDOWN PANEL ROOM SUPPLY J 0:851 ---------IREMOTE SHUITDOWN PANEL ROOM HEATING 115 !COIL i i i IPLANT LEAK DETECTION SYSTEM HEAT , 116 ITRACING PANEL (SEE NOTE 26) I , I 12.00: 1-01 117 UNIT VENT RMS HEAT TRACING PANEL i I _POST ACCIDENT SAMPLING SYS HEAT TRACING, ,I 118 iPANEL .1 : ; ' , I _ _ ....._ _ _ I 119 iELECTRIC UNIT HEATERS iii. -____:____
i I 120 iTSC ELECTRIC PAN HUM1DIF-IER (NOTE 26) 0.85i '. _ _ : _ __ ___ ___'__121 iWINGAREAEXH-IAUSTFANS 0.85 16.001 9.92 16.00 9.92 122 :WING AREA SUPPLY FANS 0.85' .____ i 40.001 2479I 40.00 24.79 123 iSPDS UPS* 1 _ __,...........
___ _ __ _ _ __ _ __ _ __ _ __ _ __ _ __ _ _ __ __ i ___ _"___ __ __ ___ __ ___ _ _ _ __ _ _ _ _ __ _ _ _ _ __ __ _ I __ _ _ __ _ __ _ __*_ __ _ __ _ __ _ _
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 5 SDG "C" Off Line Calculation E-9 Rev. 8 Page 12 of 12 Standby Ditei Generator C .-<10MIN I0-60 MIN >60 MIN Fi. R!Item DESCRIPTION PF ,KW KVAR KW KVAR KW KVAR KW ,KVAR KW KVAR KW KVAR-- KV R 4426.20 2298.68i 3893.08&#xfd; 2020.34i 3952.13! 2022.85 KVARj 2288.68 2020.34 2022.85i KVA i j 14982.91, j 4386.10 4350.961 PF I I. 0.891 0.89, 0.89 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 1 of 12 Item DESCRIPTION PF KW K[VAR KW KVAR KW KW [VAR KW KVARi KW [KVAR CLASS I E LOADS I , 1 'REACTOR CORE SPRAY PUMPS (Note 8) 0.91;s 525.41 239.38, i 525.41 239.381 525.A1 239.381 525.41 239.38 2 RHR PUMPS (Note 8) 0.89' 1002.69 513.691 1002.69' 513.69 1002.691 5131691 1002.69,.
513.69-3 iSAFETY AUX. CLG. SYS. PUMPS (Note 8) 0.909' 420,62 192.86, 420.62! 192.86 420.621 192.86: 420.62, 192.86 420.621 192.86i 420.62' 192.86 4 ICORE SPRAY PMP. RM. CLR. UNIT 0.85 12.16. 7.54: I 12.16k 7.54 12.167 7.541 12.16: 7.54_5 MOTOROPERATEDVALVES 0.4 14.81 33.93' 14.81 33.93. 14.S1[ 33.93' 14.81 33.93: 14.811 33.93; 14.81' 33,93 6 SWGR. RM. UNIT CLR. FANS 0.85- 20.27 12.56: 20.27: 12.56 20.271 12.561 20.27. 12.561 20271 12,56; 20.27! 12.56 7 !INTAKE STRUCTURE SUPPLY FANS 0.851 32.43. 20.10i 32.43: 20.10: 32.43L 20.10 32.43: 20.101 32.43[ 20.10i 32.431 20.10!INTAKE STRUCTURE TRAVELING SCREENS AREA '.I! I 8 FANS .0.85, 6.08: 3.77, 6.08 3.77 6.08! 3.77; 6.08! 3.77: 6.081 3.77' 6.08! 3.77 9 jRHR PUMP RM UNIT COOLER FANS 0.85- 16.22' 10.05 16.221005 16.22, 10.05, 16-22 10.05i 10 '1 RCIC PUMP RM. UNIT COOLERS 0.85! 8.11 5.03; 8.11: 5.03' 8tll 5.03 11 !HPCIPUMPRM.
UNITCOOLERS 0.85; 12.16: 7.54, 12.16 7.54 12.16! 7.54 '12 125-V DCBATTERY CHARGERS 0.6! 75.90 101.20 75.90 101.20 75.90! 101.20 75.90. 101.201 75.901 101.20: 75.90' 101.20 13 1 DIESEL AREA BATTERY ROOM EXHAUST FANS 0.85: 0.81; 0.501 0.81. 0.50 0.8ti 0.50 .0.81' 0.50i 0.811 0.50. 0.81: 0.50 14 !DIESEL FUEL OIL TRANSFER PUMPS 0.851 1 4.051 2.51. ' 4.05i 2.51 15 i STATION SERVICE WATER PUMPS (Note 8) 0.8751 634.22, 350.90: 634.22 350.90 634.221 350.90 634.22: 350.901 634.221 350.90! 634.221 350.90 16 RB FRVS RECIRCULATION SYSTEM FANS 0.85j 243.26, 150.76. 121.63 75.38: 121.63 75.38: 243.261 150.761 24326 150.76&#xfd; 243_26; 150.76 17 !CONTROL RM SUPPLY FANS 0.851 I '1.8 208Y/120-VACXFMRS TO POWER DIST PANELS 085' 37.50i 23.24 37.50. 23.24 3750.50 23.24 37.501 23.2T. 37-501 2324 19 1 RESERVED FOR FUTURE USE.4 1 l 20 IINTAKE STRUCTURE EXHAUST FANS 0.851 32.431 20.10 32.43 20.10: 32.43 20.10: 32.43' 20.101 32-43 20.101 32.43I 20.10!CONTROL ROOM CHILLED WATER CIRCULATING F I '21 :PUMPS 0.85 ' I L _' ,I 22 ICNTRL RM SUPPLY UNIT HTG COILS 1; : : ; ' _ _ I 23 .CONTROL ROOM WATER CHILLERS (Note 10) 0.8781 F *F: 24 DIESEL GEN RMRECIRC SYSTEMS FANS 0.855 202.72' 125.63. 202.72, 125.63: 202.72i 125.63 202.72. 125.631 202.721 125.63" 202.721 125.63 PRIMARY CONTAINMENT INSTRUMENT GAS 25 'COMPRESSORS 0.85' ' , .26 'BATFERY CHARGERS, 250-V DC 0.6! 19.00' 25.33 19.00 25.33: 19.001 25.33 19.00! 25.331 19.00! 25.33: 19.001 25.33 27 :CONTROL AREA BATTERY ROOM EXHAUST FANS! 0.85 .28 'RB FRVS RECIRC UNIT HEATING COILS ' 1 200.00: 100.00 100.001 200.00:' 200.0ol ; 200.00':TRAVELING SCREEN SPRAY WATER BOOSTER I 29 :PUMPS 0.851 16.22! 10.05 16.22' 10.05 16.221 10.05' 1622: 10.051 16.22' 10.051 16.22, 10,05 30 IRB FRVS VENT UNIT HEATING COILS , I 3200' 32.00 32.001 : 32.00 l___ __3__.0____
_ _ 32.00_3.00__*_2.00_
I __ _31 jCONTROLROOMSUPPLY SYSTEM RETURN FANS! 0.851 , r .: 32 CONTROL ROOM EMERGENCY FILTER FANS 0'0.85L , I ! '33 [SAFETY AUX COOLING SYSTEM UNIT COOLERS 0.851 L _ _ _ _'34 IFUEL POOL COOLING PUMPS , 0.85zi :60.821 37.69 i USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 2 of 12 F I...MI -Standb.y A, SnCdby D B ,________
! IO-6OMIN:
>60 <MIN.N v >0NON: Item I DESCRIPTION PF I KW KVAR KW KVAR KW KVAR KW KVAR KW KVAR KW j KVAR 3 CONTROL ROOM EMERGENCY FILTER UNIT I T I I 35 ELECT1UCHEA.INCOILS
_____1 II 36 CONTROL EQUIPMENT ROOM AIR SUPPLY FANS 085' 1 .5 : 2 12.56: 37 RB FRVS VENT SYS FANS 0.85! 20.271 12.561 20.27. 12.56 ! 20.27 ' 12.56 20.27, 12.561 38 CONTAINMENT HYDROGEN RECOMBINER 0.85 i 140.00; 86.76i I I CONTROL EQIP ROOM SUPPLY UNIT HEATING I .39 COCLSII 2.3 .! !40 SERVICE WATER SELF-CLEANING STRAINERS 0.85F 0.811 0.50' 0.81 0.50: 0.81 0.50' 0.81! 0.50' 0.81i 0.50:o 0.81. 0.50 41 STANDBY LIQUID CONTROL PUMPS i 0.85 32.43i 20.10i 32.43 20.10. 32.43 20.101 32.431 20101 32.43: 20.101 32.43: 20.0 42 !RESERVED FOR FUTURE USE I 1 43 'RESERVED FOR FUTURE USE j 1_ .44 RESERVED FOR FUTURE USE , 45 RESERVED FOR FUTURE USE ., ._ .. : [ !'480 V POWER SUPPLY TO CLASS 1E CHILLER 46 'PANELS , 0.85' 4.00. 2.48 4.00, 2.48: 4.00, 2.481 4.00 2.48' 4.00! 2.48! 4.00! 2.48 47 !TRAVELING SCREENS " 0.85: 4.05 2-51 4.05' 2.5]1 4.05, 2.51: 4.05, 2.511 4.05i 2.51 48 !ECCS JOCKEY PUMPS 0.85 8.11; 5.03 8.11', 5.03' 8.11 5.03! 8.1I 5.031 8.11I 5, A 5.03'MOTOR DRIVEN DIESEL GENERATOR FUEL OIL i .,.8.11,5.3 1 I I I 49 STANDBY PUMPS I 0.85' 1.62 1.01. 1.62' 1.01! 1.62 1.01: 1.62! 1.011 1.62! 1.011 1.621 1.01'STANDBY LIQUID CONTROL PUMP ROOM DUCT I , I I 50 HEATERS 1 45.001 45.001 I I 1480 V POWER SUPPLY TO HYDROGEN AND 51 OXYGEN ANALYZER PANELS 0.85 1.00 0.62 1.00&#xfd; 0.62i 1.001 0.62! 1.0 0.62i 1.00i 0.62i 1001 062 52 '250 V DC BATTERY ROOM DUCT HEATERS I 10.00 10.001 10.001 -___ _ _ _1125 V DC DIESEL AREA BATTERY ROOM DUCT " I i 53 HEATERS 1 21.00 21.00; 21.001 , 21.00! 21.00! , 21.00: 54 ; HPCI PUMP ROOM DUCT HEATER 11.00, 11.00: 11.001 I 55 [RcIC PUMP ROOM DUCT HEATER I 1, , ' 1 7.00: 7.001 7.001 56 1250 V DC BATTERY ROOM DUCT HEATER 1',. .,, 8.00, ' 8.0_ _ -8.00 57 &#xfd;CLASS 1E PANEL ROOM WATER CHILLERS 0.886 198.00, 103.62: 198.00 103.621 198.00 103.621 198.001 103.62 58 !CLASS I E PANEL ROOM CHILLED WATER PUMPS 1 0.851 32-431 20.101 32A3 20.101 32.43' 20.10 32-43 20.10i 1CLASS lE PANEL ROOM SUPPLY & RETURN AIR :.I 59 FANS o0.85 60.821 37.69i 60.82' 37.69! 60.82! 37.691 60.82' 37.69i 60 !CLASS IEPANELROOMELECTRICTHEATERS 1] 100.00; 100.00: 100.00; ' 100.00. 5 61 'BAIT-ERY ROOM EXHAUST FANS 0.851 0.81i 0.50! 0.81: 0.50: 0.81: 0.50! 0.81 0.501 0.81: 0.50! 0.81' 0.50 62 BATTERY ROOM DUCT HEATERS I i , L 63 IH2102 ANALYZER HEAT TRACING PANELS i f ; :, _ :, ! ! _ ,
FOR FUTURE USE I ---'-:.............
_ ! ' _65 !RESERVED FOR FUTURE USE .j I i _ _ : _ ,,
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev- 8 Page 3 of 12______________________________61 IN MN J- 6MN<O iNOMIN IN41NMI Item] DESCRIPTION PF KW KVAR KW K'AAR KW KVAR KW I KVAR KW [KVAR 66 RESERVED FOR FUTURE USE I 67 RESERVED FOR FUTURE USE I ! ,. 1 68 RESERVED FOR FUTURE USE 69 RESERVED FOR FUTURE USE I_ _ _ _ _ _ __ _"_ _70 IRESERVED FOR FUTURE USE I 1 '__
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 4 of 12-Stanidby D eieGneratorA.
-- ...'.uMLN..*
StandbyDieseI(-e eraor >OI P J .l0MI -1 7 60MN -->60MN MIN"M, Item DESCRIPTION PF KW I KVAR KW KVAR KW KVAR i KW KVAR KW KVAR KW KVAR I NON-CLASS 1E LOADS -4 See Note I1. ,I_ _ __ " 71 -TURBINE GENERATOR TURNING GEAR OIL PUMP i 0.85 .'32.00. 19.831 32.00: 19.83 STANDBY LIQUID CONTROL SOLUTION ' I I 72 :OPERATING HEATER 1i 10.00! 10.001 73 IDRYWELL COOLING UNIT FANS 0.85, 74 1RADWASTE EXHAUST FANS .'0.85!1'.
'75 ESSENTIAL PLANT LIGHTING 0.9' 1 52.406 25.38 520 253813090 63.40 76 CRD WATER PUMPS 0.85: .,I TURBINE BUILDING BATTERY ROOM EXHAUST I , I .2'43'77 FANS 0.85 2.43k 1.51i 2.431 1.511 2.431, .51: 243 151'TURBINE GENERATOR AUX BEARING LIFT PUMPS; I I !78 9 -5H- EACH AND 0.851 i , ITURNING GEAR -60 HP ! I , 85.14, 52.77, 85.14- 52.77 79 1 EMERGENCY INSTRUMENT AIR COMPRESSOR
' 0.85j _ _ : '80 !RADWASTE SUPPLY FANS 0.85i I.REACTOR BUILDING SUPPLY AIR HANDLING 81 UNITS 0.85' _, 82 REACTOR BUILDING EXHAUST FANS 0.85 : I : 83 RADWASTE TANK VENT FILTER FANS 0.85 6.08' 3.77 6.08 3.77: 6.08: 3.77, 6.08! 3.77 84 TURBINE BUILDING BATTERY ROOM SUPPLY 0.85: 4.05' 2.51 4.05 2-51' 4.05; 2.51 4.05: 2.51 85 IRADWASTE TANK VENT FILTER HEATING COILS 1' 3.60: 3.60, 3.601 , 3.60: 86 CHEM1CAL LAB E UST FANS 0.85! 16,221 10.05! 16.22: 10.05 16.22; 10.05: 16.22 10.05 DIESEL GENERATOR STARTING AIR I , I 87 COMPRESSORS I M5 12.16 7.54' 12.16' 7.54 12.161' 754 12.16: 7.5 88 7REACTOR AUX COOLING SYSTEM PUMPS 0.85 ! ! [89 1125-VDCBATTERYCHARGERS 0.6! 114.00. 152.001 114.00: 152.00. f 114.001 152.00! 114.001 152.00 90 : 125-V DC BATTERY CHARGERS 0.6 i 38.00: 50.67 38.00 5 50.67! 38.-0J 50.67 91 :250-V DC BATTERY CHARGERS 0.6 57. , :700! 76.001 57.00 76.00 92 'STANDBY LIQUID CONTROL SOL MIXING 1 I i.- I I 93 ,RFPT AUX LUBE O1L PUMP (NOTE 12) & 0.85 1 , i i ---3 ITURNING GEAR MOTORS j _ I 21-491 13-321 21.49 13.321 21.49' 13.32, 21.49, 1332 94 RESERVED FOR FUTURE USE ii 95 208V/I120VACXFMRSTODISTPANELS 1 0.851 ., 30.00! 18.59i 30.00: 18.591 15.00! 9.30 15.00! 930 96 !REACTORBUILDINGFLOORDRAIN SUMP PUMPS 1 0.85, ! ! _ '. ! i , 97 DRYWELLEQUIPDRAINSUMPPUMPS I 0.851 _ , 4.05' 251, 4-05 2.51. 4.05: 2.51: 4.05 2.51 98 ;DRYWELL FLOOR DRAIN SUMP PUMPS 0.85, ' 4.05 2.51I 4.05! 2.51 4.05, 2.511 4.05 2.51 iPOWER SUPPLY FOR UNIT VENT RADIATION
.I ' I 99 iMONITORING SYSTEMS 0.85 :, 3.50 2.17' 3.50 2.17: 3.50 2,17I 3.50j 2.1 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 5 of 12~~~~~~~~~~~hi SndyDelGeeaoAStdyDislGnrator-W-I ~ ~~~ A1MN 106MN 61N L N iO6MIN >OM Item I DESCRIPTION PF KW ;KVAR KW KVAR KW ,KVAR KW KVAR KW iKVAR KW KVAR IPOWER SUPPLY FOR DLD RADIATION I I I 100 ;MONITORINGSYSTEMS 0.85' I I 101 iTURTNE GENERATOR MAIN SEAL OIL PUMP 0.85' _ __16.22' 10.051 16.22' 10.05 102 !TURBINE GENERATOR RECIRC SEAL OIL PUMP 0.85: , 6.08' 3.77i 6.08&#xfd; 3.77 103 TURBINE GENERATOR SEAL OIL VACUUM PUMP 0.85 I ',__ f 2.43 1.51! 2.43 1.51'RAWASTE + 24V DC BATTERY ROOM DUCT I 104 'HEATER 1 i____ ___ _.CONDENSATE STORAGE TANK HEAT TRACING 105 I(SEE NOTE26) 1, 5.001 5.001 ; _106 TSC SUPPLY SYSTEM FAN 0.85; I , 107 TSC SUPPLY SYSTEM HEATING COIL It 108 TSC EMERGENCY FILTER FAN 0.851 I I t ._I 109 ITSC EMERGENCY FILTER HTG COIL 1, I.]110 STEAMTUNNELUNITCOOLERS 0.85 I I .16.00: 9-92' 16.00 ' 9.92 ,TURBINE BUILDING BATTERY ROOM SUPPLY I 111 IFAN & HTG COIL 1 ' i 50.00' 50.00'TURBINE BUILDING COMPARTMENT EXHAUST 112 iFANS 0.85! I ,CONTROL AREA 125 V DC BATTERY ROOM DUCT " -113 'HEATER , i 16.00- 16.00 114 !REMOTE SHUTDOWN PANEL ROOM SUPPLY FAN 0.85 4.00' 2.48 4.00' 2.48!REMOTE SHUTDOWN PANEL ROOM HEATING 115 !COIL .I 10.00o 10.00oo: PLANT LEAK DETECTION SYSTEM HEAT I ' I 116 ITRACING PANEL (SEE NOTE 26) 1 1[ i i _117 UNIT VENT RMS HEAT TRACING PANEL Il 15.00: 15.00! r POST ACCIDENT SAMPLING SYS HEAT TRACING I "T i 118 PANEL 1 ! I I 119 ,ELECTRIC UNIT HEATERS 1 ' __ _120 ;.TSC ELECTRIC PAN HUMIDIFIER (NOTE 26) 0.85: I _ '121. :WING AREA EXHAUST FANS 0.851 16.00&#xfd; 9.92 16.001 9.92 -122 WING AREA SUPPLY FANS 0.85 40.00' 24.79! 40.00: 24.79'123 ;SPDS UPS I : i 60.00:____ I I .KW _ !i4063.28 2055.87! 3827.121 2063.28 4091.99i 2190.251 4053.221 2053.36' 3181.21! 1850-73! 3185-27: 1853.24 KVARI i 2055.87. ' 2063.281 2190.25. I 2053.361 1850.731 1853.24!
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 6 of 12.. ..... &#xfd;&#xfd;Standby Diesel-encratoi A::,- --S~b Dee n~ir Item DESCRIPTION PF KW ! KVAR KW 'KVAR- KW ; KVAR KW 'KVARI KW :KVAR KW ' KVAR KVAi 14553.77, 4347.87, 4641.29i 4543.66i 3680.40I 3685.16: PF! i 6.890 0.8, 0.888 0.89' 0.861 0.86t -
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 6 SDG D" Off Line Calculation E-9 Rev. 8 Page 7 of 12 Standby Diesel Generator C Er wktr~z+/-z.<10 MIN 10-60 MIN >60 MIN i  InteI DESCRIPTION PF KW KVAR KWA KVAR KW iKVAR.KWiKVAR KW IKVARIKWKVAR CLASS lE LOADS I'I REACTOR CORE SPRAY PUMPS (Note S) 1 0.91- 525.41. 239.38! 525.4I 239.38 525.41. 239.38' ." 2 IRHRPUMPS (Note 8) 0.89 1002.69, 513.69, ' ; _ ', 3 'SAFETY AUX. CLG. SYS. PUMPS (Note 8) ' 0.909 420.62 192.86 420.62 192.86 420.62' 192.86 4 iCORE SPRAY PMP. RM. CLR. UNIT 0.85 12.16: 7.54 12.16 7.54 12.16, 7.54 5 MOTOR OPERATED VALVES 0.4 14.81. 33.93: 14.81 33.93 14.81 33.93 6 SWGR. RM. UNIT CLR. FANS 0.85. 20.27 123562 20.27 12.56 20.27 12.56: !7 INTAKE STRUCTURE SUPPLY FANS 0.85 32.43. 20.10, INTAKE STRUCTURE TRAVELING SCREENS AREA I 8 'FANS 0.85 i 9 1RHR PUMP RM UNIT COOLER FANS 0.852 16.22 1.0.05j 10 !RCIC PUMP RM. UNIT COOLERS 0.851 1 i I , I I HPC] PUMP RM UNIT COOLERS 0.85 i _ [ I _12 125-V DC BATTERY CHARGERS 0.61 113.851 151.80: 113.85i 151.80: 113.85: 151.801 I '_ 1 i 13 ,DIESEL AREA BATERY ROOM EXHAUST FANS 0.851 0.91, 0.501 0.81! 0.50! 0.81' 0.501 ] I _ i' _ _ -I , --14 !DIESEL FUEL OIL TRANSFER PUMPS 0.85' , 4.05 2.51, i * ' ;15 'STATION SERVICE WATER PUMPS (Note 8) 0.875; 634.22: 350.90' 634,22, 350.90i 634.22! 350.901 I ._ _ i 16 iRB FRVS RECIRCULATION SYSTEM FANS 0.85 121.631 75.38, 121.63! 75381 121.63&#xfd; 75-38i ...........
1 17 CONTROL RM SUPPLY FANS a 0.85, 32.431 20.10 32.43; 20.10! 32.43, 20.101 _ ! " i 18 1208Y/120-V AC XFMRS TO POWER DIST PANELS 0.85, 37.50! 23.24 37.50, 23.24, 37.50. 23.24; -_ 1 _ [19 :RESERVED FOR FUTURE USE 1. [ _,___20 INTAKE STRUCTURE EXHAUST FANSI 0.85' 32.431 20.10: ' : ' i _ , 'CONTROL ROOM CHILLED WATER CIRCULATING I , ' ' F I 21 PUMPS 0.85 48.65! 30.15' 48.65' 30.15; 48.65[ 30.15' 1 _ _22 JCNTRL RM SUPPLY UNIT HTG COILS L 1 90.00' 90.00; 90.00! .i , .......23 ICONTROL ROOM WATER CHILLERS (Note 10) ! 0.878' 506.00i 275.86. 506.00i 275.86' 506.001. 275.86: i _24 DIESELGENRMRECIRCSYSTEMS FANS 0.85. 202.72: 125.63: 202.72 125.63' 202.721 125.63 _ _ 1 PRIMARY CONTAINMENT INSTRUMENT GAS F ____25 iCOMPRESSORS
.0.85 12.16. 7.54 1 2.16; 7.54: i , I ;26 IBATTERY CHARGERS, 250-V DC 0.6 : ... 1 27 CONTROL AREA BATTERY ROOM EXHAUST FANS 1  0.85 4.051 2.51 4.05 2.51; 4.051 2.51, I 28 RB FRVS RECIRC UNIT HEATING COILS 1 100.00 100.00 100.00! _ : _ !:TRAVELING SCREEN SPRAY WATER BOOSTER i 29 PUMPS 0.85 16.22 10.05 16.22 10.05 16.22 10.05 i .__*____30 'RB FRVS VENT UNIT HEATING COILS 1 ' -i _31 -CONTROL ROOM SUPPLY SYSTEM RETURN FANS 0.85 -24.33 15.08- 24.33 15.08 2-4.331 15.08 i _ _32 CONTROL ROOM EMERGENCY FILTER FANS 0.85 20.27 12.S6i 20.27 12.56 20.27: 12.56 ..33 SAFEIY AUX COOLING SYSTEM UNIT COOLERS : 0.85 12.16' 7.54' 12.16 7.54 12.16i 7.54 C I 3PI0_ I w 34 1FUEL POOL COOLING PUMPS 0.83,III __________
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 8 of 12 I .Standby Diesel Generator C<IOMIN 10-60OMIN
>60M]N itemI DESCRIPTION PF KW I KVAR KW KVAR KW KVAR K VA KW KVAR IKW KVAR iCONTROL ROOM EMERGENCY FILTER UNIT I ' I 35 ;ELECTRCHEATINGCOIS 1 13.001 13001 13.00 36 tCONTROL EQUIPMENT ROOM AIR SUPPLY FANS 0.85 202.72! 125.63 202-721 125.63; 202.721 125-63'37 &#xfd;RB FRVS VENT SYS FANS _ 0.951 _ _ i _ I 38 [CONTAINMENTf HYDROGEN RECOMBINER , 08i ' i , SCONTROL EQIP ROOM SUPPLY UNIT HEATING ' iI ,,39 'COILS I 1! 10.00, 100.001 100.00!, 40 ,SERVICE WATER SELF-CLEANING STRAINERS , 0.85: 0,81 0.50. 0.81! 0.50; 0.91! 0.5 41 !STANDBY LIQUID CONTROL PUMPS 0.R5OOMD ,42 ARESERVED FOR FUTURE USE 1 43 iRESERVED FOR FUTURE USE I 44 rRESERVED FOR FUTURE USE 1, i, 45 RESERVED FOR FUTURE USE 5480 V POWER SUPPLY TO CLASS 1E CHILLERS 46 HPANELS 0.85 4.001 2.48 1 4.00: 2248 4.00' 2.48!61 'TR Y R EEESNS 0.85 4.05 2.51i 4,05 2.51 4.05 2.51i 48 IECCS JOCKEY PUMPS 0.85: 8-11 9.11 5.03 8_11i 5.03.MOTOR DRIVEN DIESEL GENERATOR FUEL OIL 49 .ISTANDBY PUMPS 0.85. 1.62i 1.01i 1.62 1.01' 1.62, [!STANDBY LIQUID CONTROL PUMP ROOM DUCT II !50 ,HEATERS , , I 40V POWER SUPPLY TO HYDR.OG'EN AND i !51 OXYgGEN ANAL.YZER PANELS 0.85, ' ! J I 52 1250 V DC BATTERY ROOM DUCT H EATERS I 14.00 I 4--:125 V DC DIESEL AREA BATITERY ROOM DUCTi !. I 3 'E0 ATENS 1H EA.TAC I o 1.o000 21500 54 EPCI PUMP ROOM DUCT HEATER 1 : 55 CIC PUMP ROOM DUCT HEATER S RV ED-RU 56 k250 V DC BATTERY ROOM DUCT HEATER 1] , 57 ,CLASS I1E PANEL ROOM WATER CHILLERS 0.8-86, 58 ICLASS I E PANEL ROOM CHILLED WATER PUMPS no. 8955 1i ICLASS I1E PANEL ROOM SUPPLY & RETURN AIR 59 ;FANS 0 .85: : , , 60 ',CLASS 1E PANEL ROOM ELECTRIC HEATERS 1 61 i BATTERY ROOM EXHAUST FANS 0.85, 62 iBATTRY ROOM DUCT ]EATERS 11 14.001 14.00! 14.00.63 'H21O2 ANALYZER HEAT TRACING PANELS .._.. 11 15.00l i 15.001 Z64 RESERVED oFORFTURE USE' 1 ! i i65 IRESERVED FOR FUTURE USE [ l USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing.Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 9 of 12 Standby tWIMst cltntroy C<10 ~ MIN 16-60MI >60LNUN Item DESCRIPTION PF : KW : KVAR j KW 1 KVAR I JCw I k'VAT?66 1RESERVED FOR FUTURE USE 1!I ~ K 1~' KVA I 67 RESERVED FOR FUTURE USE 1 I 68 RESERVED FOR FUTURE'USE
...i .'69 RESERVED FOR FUTURE USE 1 r , 70 RESERVED FOR FUTURE USE I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby I E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 10 of 12_ Standby Diesel Generator C .. .m.....____ ~<10 MIN 10-60) MIN >6O MIN 4I*Nn Item DESCRIPTION PF KW KVAR KW KVAR KW KVAR f KW KVAR I KW KVAR KWI KVAR I NON-CLASS 1E LOADS I I See Note I1 I______71 ITURBINE GENERATOR TURNING GEAR OIL PUMP 0.85._'STANDBY LIQUID CONTROL SOLUTION 72 !OPERATING HEATER 1 .73 IDRYWELL COOLING UNIT FANS 0.85 i _74 IRADWASTE EXHAUST FANS 0.85 75 !ESSENTIAL PLANT LIGHTING 0.9. 93.50: 45281 93.50: 45.28i _76 ICRD WATER PUMPS j 0.85: .202.72 125.631 202.72: 125.631 i'TURBINE BUILDING BATTERY ROOM EXHAUST I [ I 77 jFANS 0.851 I I IURBINE GENERATOR AUX BEARING LIFT PUMPS,'78 9 -5HP EACH AND I 0.85! I TURNING GEAR -60 IF 79 1EMERGENCY INSTRUMENT AIR COMPRESSOR 0.85 80 IRADWASTE SUPPLY FANS 0.85i'REACTOR BUILDING SUPPLY AIR HANDLING 81 IUNITS 0.85 82 REACTOR BUILDING EXHAUST FANS 0.55.83 IRADWASTE TANK VENT FILTER FANS 0.85, 84 ITURBINE BUILDING BATTERY ROOM SUPPLY 0.85!85 RADWASTE TANK VENT FILTER HEATING COILS 1___,__86 CHEMICAL LAB EXHAUST FANS 0.851 .1/2!DIESEL GENERATOR STARTING AIR , 87 ICOMPRESSORS 0.851 12.16' 7.54. 12.16 7.54. _'_88 IREACTOR AUX COOLING SYSTEM PUMPS 0.851 ' .'I 89 125-V DC BATTERY CHARGERS 0.6! ,i I _90 1J25-V DC BATTERY CHARGERS 0.6:: 38.00' 50.67, 38.001 50.67, 91 1250-V DC BATTERY CHARGERS 0.6;92 STANDBY LIQUID CONTROL SOL MIXING I______ ___93 1RFPT AUX LUBE OIL PUMP (NOTE 12) & 0.85: _ _' !'TURNING GEAR MOTORS 21.49: 13.32 21.49: 13.32 94 'RESERVED FORFUTURE USE I ' , i 95 !208 V/120 V AC XFMRS TO DIST PANELS 0.85; 45.00! 27.89i 45.00i 27.89'96 REACTOR BUILDING FLOOR DRAIN SUMP PUMPS 0.85; 8.111 5.031 8.111 5.03 : '_97 DRYWELL EQUIP DRAIN SUMP PUMPS 0.85! i 98 DRYWELL FLOOR DRAIN SUMP PUMPS 0.85' ': ;POWER SUPPLYFORUNIT VENT RADIATION i -I 99POWE SUPL FOP 99 MONITORING SYSTEMS 0.85, I _
USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 11 of 12_ ..Standby Diesel Generator C i. l-.. =i i ~~~~~<10 MIN '
* 10-60 MIN.........>0MN
...
gC#,= Item DESCRIPTION PF KW KVAR KW KVAR KW KVAR KW KVAR KW KVARK POWER SUPPLY FOR DLD RADIATION A I 100 MONITORINGSYSTEMS o.851 3.501 2.I71 3.50; 2.171 _ i 101 TURBINE GENERATOR MAIN SEAL OIL PUMP N 0.851 i __ _ __t _ _ _ _102 TURBINE GENERATOR RECIRC SEAL OIL PUMP 0-85.103 !TURBINE GENERATOR SEAL OIL VACUUM PUMP 0.85' ' -I _ ....... _,__WASTE + 24V DC BATTERY ROOM DUCT ." 40 1 HEATER .. ..... .._ __!_ _._ _ _ _ _ _ _ _ _ _ :_ _CONDENSATE STORAGE TANK HEAT TRACING , : iI : 105 !(SEENOTE
: 26) 11 , 12.00! 12.00' , ,. _ _ I 106 ,TSC SUPPLY SYSTEM FAN : 85 20.00' 1239 20.001 1239' i _ _ ___107 ;TSC SUPPLY SYSTEM HEATING COIL 1 30.00 30.001 I j _ i 108 :TSC EMERGENCY FILTER FAN O.851 20.00' 12.391 20.001 12.39 .I il__109 rTSC EMERGENCY FILTER HTG COIL I .I 13.00 13.001SOO____
'110 &#xfd; STEAM TJNNEL UNIT COOLERS 0.851 .i '_iI_;JTURBINE BUILDING BATTERY ROOM SUPPLY ' I I Ill ]FANi & H COIL , I j 'I TURBINE BUILDING COMPARTMENT EX] AUST I , I 112 FANS 0.85: iCONTROL AREA 125 V DC BAT'TERY ROOM DUCT: 113 'HEATER I 114 1REMOTE SHUTDOWN PANEL ROOM SUPPLY FAN 0.85 1 , I ___I REMOTE SHUTDOWN PANEL ROOM HEATING 115 ICOIL 1 _ _,__ _ _.PLANT LEAK DETECTION SYSTEM HEAT ,' i 116 TRACING PANEL (SEE NOTE 26) 1 .. ._ _ _ _ _; _ _117 UNIT VENT RMS HEAT TRACING PANEL I I' _ _ " .....
* _ __ T_IPOST ACCIDENT SAMPLING SYS HEAT TRACING i I 118 IPANEL I' I 15.001 15.00. I 119 1 ELECTR.IC UNIT HEATERS 1______ 24.001 24.00! T ___ _____120 ITSC ELECTRIC PAN HUMIDIFIER (NOTE 26) 0.85,; 12.971 8.04' 12.97 8.041 _ _ I 121 1w NG AREA EXHAUST ANS 0.85 +/- , ,__, 122 :WING AREA SUPPLY FANS 0.85 " ___ I _123 1SPDS UPS I .0 I I 60.00 i I _ __ _I _ _ _ _ _ _ _ _ _____ __- .- ..-... .. ........ ...- --_ __ __ _ __ __ __ _ __ _ I ___ ___, I .I _ _ _ _ _ _ _ _: KW, 4426.20! 2288.68* 3926.041 2042. 3990.10 2045.14: I -;KVAR' 2288.691 2042.63 .2045.14f i _ __ r I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 6 SDG "D" Off Line Calculation E-9 Rev. 8 Page 12 of 12 Standby Diesel Cienerator C V ,2<10MIN 0O-60OMIN
>6OMMN Item DESCRIPTION PF KW KVAR KW I KVAR KW KVAR KW j KVAR KW KVAR KWIKVAR KVA: 4982.91. 4425.62, 4483.69! i PF 0.89! 0.89, 0.89' USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 7 MOV Load on SDG "A" Calculation E-9 Rev. 8 Page 1 of 3 7 RHR PP 1AP202 SUCT I BC-HV-F004A 1.00; I 1.001 8 RHRPP 1AP202MINFLBYP iBC-HV-F007A I 0.33i I ' 0.33 9 RHR INJECTION IBC-HV-F017A 780 7.80, 10 RHRCNNMNTSPRAYOUTBD I BC-HV-F016A 12.80. 12.801 12 1R-R CONTMNT SPRAY IBC-HV-F027A 0.70: 0.70 13 ,RNR HX SHELL SIDE INLET IBC-HV-F047A 4.00! 4.00: 14 1RHX SHELL SIDE BYPASS IIBC-HV-F048A 0.24! 0.24, 15 iRHR1HX IAE205 OUT I EG-HV-2512A 0.331, 0.331 16 RHR. TEST RETURN IBC-HV-F024A 9.990 9.90 1 Test Mode 17 iRWCU DISCH TO MAIN COND &#xfd;1BG-HV-F034 0.333; i 0.33i 18 .!RWCU INBD SUCT ISLN IBG-HV-F001 1.60' 1.60! Rev. 7 19 UPCISTSPLYOUTBD ISLN ,IFD-HV-F003 3.90. I 3.90rev.7 20 IHPCI BYP V TO COND I FD-HV-4922 0.13 I 0.13'21 IRACS RETURN ISLN IED-HV-2598 0.33: 0.33 1 22 iRACS SUPPLY ISLN !IED-HV-2599 I 0.33, 0_33 23 IRACS HX CLG LP "A" SPLY IIEA-HV-2203 1.60. 1.60. Rev. 6 24 ISPLY HDR INBD iSLN 1KL-HV-5152A 0.13 0.13. .25 IFDW TEST CHECK I IAE-HV-F032A 13.001 13.001 26 SLC STOP CHECK 1BH-HV-F006A 0.331 : 0.331 27 JRCTR WELL SERV SHUT OFF 0BN-HV-2069 0.701 0.70!28 IHX1AE202CLGWTR IIEG-HV-2314A 0.13! I 0.13'29 fHX 1AE202 CLGWTR IIEG-HV-7921A 0.13i 0.13, 30 HX 1AE202 CROSS CONN IEG-RV-2317A
* 0.13i 0.131 31 IHX IAE202CROSSCONN IIEG-HV-7922A 0.13. 0,131 _32 ISACS IAIE20I IN !IEG-HV-2491A 0.70. 0.701 33 'SACSLP "A" CLGOUTTOTWR 1EA-HV-2357A I 2.60 2.60 Rev. 6 34 SACS LP "A: HX AIE20I OUT IEA-HV-2371A
':1.60IRev.
6 35 !SACS LP "A" RETURN I1EG-HV-2496A 2.601 2.60 36 SERVICE WTR LOOP "A" DUMP IEA-HV-2356A 0.331 : 0.33!37 H2102 ANALY "A" H2 SPLY I1GS-HV-5741A 0.33' 0.33 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Sizing Attachment 7 MOV Load on SDG "A" Calculation E-9 Rev. 8 Page 2 of 3 3 8 H2/02ANALY -A" 1SLN lI(S-HV-4955A U.4j.! (033, 1 39 H2/02 ANALY "A" ISLN 1GS-0V-4959A I 0.33 033'40 IH2/02 ANALY"A" 1SLN 1GS-HV-4966A 0.331 0.331 41 H2/02 ANALY "A" 1SLN 1GS-HV-5019A 0.331 033, 42 RECON -"A' GAS INBD ISLN jIGS-HVI-5050A I 0.331 0.33, 43 RECOMB "A" GAS INBD 1SLN IGS-HV-5054A I 0.33! i 0.33 " I 44 RECO048 "A" SCBBR WTR 1SLN IBC-HV-5055A 0.33 I 0331 45 &#xfd;NBP INBD DR TO MN COND i1AB-HV-FO16 0.33' 0.33: 46 !CPRSRSUCT 1NBD ISLN IKL-HV-5148 0.13 0.131 47 1FUEL POOL CLO MKUP WTR I EA-HV-2234 033 I 0.33'48 IFUEL POOL CLG MKUP WTR 'IEA-HV-2236 033, ! 0.33.49 ISUPPR_ POOL ISLN I EE-HV-4652 0.33 -0.33.50 ISUPPR. POOLISLN IEE-HV-4680 033, 0.33!51 !TORUS HI INSTR CUTOFF ' 1BJ-HV-4R03 0A .iT 3 0.13'52 iTORUS LO LVLINSTR CUTOFF I BJ-HV-4804 0.13; 0.13 53 EMER PNEUMATIC SPLY VALVE I1KL-HV-5172A 0.13: 0.13i 54 ,TURB EXN VAC BRKR !1FD-HV-FO75, 0.33' 033 55 'F? FILTER DEMIN BYPASS 1IEC-HV-4689A
' 0.7: 0.7'56 ,CTMT INBOARD ISLN VALVE jISK-HV-4957 I 0.331 033 '. ', 57 'CTMT INBOARD ISLN VALVE I1SK-FW-5018 0.13: 0.13 ' -_ _58 'FUELPOOL MAKE-UP V "A" :IEC-HV-4647 0.13. i ,, 0.131 59 EXPANSION TKAT205 MAKEUP 'IEG-HIV-2446 0.13 .0.13;60 RHR HEAD SPRAY INBD 'I BC-HV-F022 1 ..t 1I 61 RHR SHUTDOWN CLG IBC-HV-FO06A I , 1.62 RHR SHUTDOWN CLG SUCT 1NBD 18C-HV-F009 7.80 ! ' 7.80 63 .R CJ.ONTAINMENT SPRAY 18C-HV-F02IA 12.80, 12.8S 64 STNSERVICEWTRSYSBKWASH
'1EA-HV-2197A 0.13: ' 0,13'65 ISTN SERVICE WTR SYS DIS MOV I IEA-HV-2198A 2.66- 2.66.66 SSWS SPRAY PP DISH MOV 1EA-HV-2225A 0.13, 0.13 USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1E Diesel Generator Sizing Attachment 7 MOV Load on SDG "A" Calculation E-9 Rev. 8 Page 3 of 3 Summary Totals 139.28 .19.26 ....34.06 ...28.94 "58.02"__ Conversion.
to KW (0.746*HP10.92) 112.94 14.81 27.62 23.47 47.05 ITOTAL 139.411 18.261 34.06; 28.941 58.15j81.26 1 KW=0.746*HP/0.92 f113.041 14.91. 27.62 .23.471 47.15165.89 SIi I I Notes__ _ _ _ __ _ _ _ _1) This Valve does not change position on receipt of a LOCA signal under non-test mode.The load has been included for conservatism-
_ _ 1! ,I i 2) Since all MOVs are of intermittent duty, the worst MOV loading, operating at the same time,_ during LOCA is 18.26 HIP (14.81 KW).r I I I USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Standby 1 E Diesel Generator Attachment 8 Summary OF SDG Loading Calculation E-9 Rev. 8 Page 1 of 1SUG'A X,.. .SDG'B. ... SDG "'C ... S)G'D 0" ALL SDGs In Service -Table 2 I S G I_....<10 MEN 110.0 MIN >60 MIN <10 MIN I 10-60 MIN >60 MIN <10 MIN 10-60AIIN
>60 MIN <IOMIN 10-60 MIN >60 MIN Max. lead KW 1 4063.28 3827.12 3951.9 4053221 1811.25' 1815-30 442620 3388.471 3452.52 442620 2665.96 2765.01 4426.20 KVAR: 2055.871 2063.28 2103.41 2053.36 1186301 1188.81 2288.68 1795.71' 1798.24 2288.68; 141533 1504.64 2288.68 KVA 4553.771 4347.871 4476.91 4543.661 2165 16&#xfd; 2169.93 4982.911 3834.881 3892.71 4982-911 301836 3147.88 4982.91 SD 0.891 0.881 0.8 0.891 0.84 0.84 0.89! 0.881 o.8S 0.89 0o88 0.88 0.89"A" Out Of Service -Table 3 1 i _ ___.....<10 MIN 10-60 MIN >60 MIN <10 MIN 1 10-60 MIN >60 ENU1 <10 MIN 10-60 MIN >60 MIN <10 MIN 10-60 MEN >60 MIN Max. load KW 0.00 0.00 0.01 4053.221 4012.571 4077.44 4426.20i 4043.311 4107.34 4426.20. 2765.96 2910.04 4426.20 KVAR 0.00 0.00 0.01 2053.361 2256251 2296.4. 2288.68! 2108.211 2110.74 2288.68; 1415.33 1504.60 2296.45 KVA 0.00 0.001 0.0( 4543.661 4603.41i 4679.6. 4982.91 i 4559.921 4617-9 4982.911, 3107.04 3275.98 4982.91 PF f 0.00 0.00! 0.01 0.89t 0.87! 0.81 0.89; 0.89 0.891 0.89 0.89 0.89 0.89 SDG "B" Out Of Service -Table 4<IOMIN 10-60MIN >60MIN <1OMIN ' 10-60MIN >60MIN <10 MIN 10-60MIN >60MIN <10 MIN I 10-60MIN I >60MIN Max.oad KW 4063.28 4048.75, 4173.64 0.000 0 00 0.0 4426.20: 3723.321 3787.3 4426.20; 2970.95 3070.0 4426.20 KVAR 2055.87 2138.66& 2178.8 0,00. 0&#xfd;00 0.0 228868' 1917.001 1919.51 2288.68: 159928 1688.5 2288.68 KVA I 4553.77 4578.89i 4708.1 0.00o 0.00 o0c 4982.91, 4187.941 4246.04 4982.911 3374.051 3503.7 4982.91 PF 0.89 0.88i 0.8 000 000 00 0.89 0.89: 0.8 0.891 0.881 0.8 0.89 SDG "C" Out Of Service -Table 5<10 MIN 1 10-60 MIN ! >60 MIN <10 MIN ; 10-60 MIN >60 MIN <10 MIN 10-60 MIN >60 MIN <10 MIN I 10-60 MIN >60 MIN Max. load KW 4063-81 3660.921 3925.7w 4053.22: 3347.42: 3351.41 0.001 .00 0.00 4426201 3893.08;.
3852.1 4426.20 KVAR 1 2055.871 1907.121 2034.01 2053.36'1 2006.89; 2009.41 0.00: 0.00! 0.. 2288.681 2020.34; 2022.8 2288.68 KVA i 4553.771 4127.881 4421.44 4543.661 3902.92; 3907.6 0.00i 0.001 0.. 4982.91: 4386.10 4350.9 4982.91 PF 0.891 0.891 0.81 0.891 0.861 0.81 0.001 000 0.0 0 89 0.89: 0.81 0.89 SDG "D" Out Of Service -Table 6 _ ____" _1 <10MIN 10-60MIN >60MIN <IOMIN 10-60MINI
>60M`IN <1OMIN 10-60MIN ->60MIN <10M NI10-60MIN W >60MIN Max. load KW ! 4063.28' 3827.121 4091.9 4053.22' 3181.211 3185.2 4426.201 392604, 3990.11 0.001 0.00, >10.0 4426.20 KVAR i 2055.87i 2063.281 219022 2053.361 1850.731 1853.2 2288.681 2042.63' 2045.1 0.00 0.00 0.0 2288.68 KVA 4553.771 4347.87 46412 4543.66 3680.40 3685.1 4982.911 4425.62: 4483.6 000j 0.00 00 4982.91 PF 0.881 0.8 0.89 0.986, 0.8 0 .8 0.00 0.001 0.0 0.89 cont. 2000 Hr I2Hr j' 3 0 Min.T -2 iM......K-w 4430 4737 4873! 5316 4426"-AR 3323 35531 36551 39871 f 2296 _ ___ I I k'VA 5538 5921 1 60911 66451 4983 _ i F 0.801 0.80 0.801 0.80 -.________________!_
PSEG Nuclear LLC P.O. Box 236, Hancocks Bridge, New Jersey 08038-0236 0 PSEG Nudut'r.1.I (1 MDE-01-0016 TO: FROM: S. Kobylarz Supervisor
-Ee -cal/l&C Group D. Longo Supervisor-M Group
 
==SUBJECT:==
DATE: MAXIMUM MOTOR LOADING FOR LOCA & LOP FOR CS, RHR, SACS, SSWS PUMPS May 30, 2001 (.-5 Li!z C)z H-H--z" 0 LLI 1.&#xfd;U 0 U-Ld]I m z 0 03-Ld w'We have evaluated the maximum brake horsepower for the above safety related pumps as requested for input in the revision of the current Hope Creek diesel load calculation.
The results are tabulated as follows: LOCA LO P Pump Rating Core Spray Pump 655 Bhp. N.A. 700 Ahp (AB,C,D, P-206)RHR Pump 1,250 Bhp. 1,250 Bhp 1,250 Bhp (A.,B,C,D, P-202)SAC Pump 530 Bhp 530 Bhp 600 Bhp (A,B,C,D, P-210)SSWS Pump 800 Bhp* 850 Bhp* 800 Bhp (A, B, C, D P-502)*See description at section 4 (SSWS Pump).60 4,16.41 011 Al 5 E-9 /~V elv] 0' ;z 95-2168 REV. 7/99 M S. Kobylarz 2 5/30/D1 In arriving at the above result, the following analysis for each pump has been done and is presented for your reference:
: 1. Core Sprav Pump (A. B. C, D P-206)The two independent Core Spray System (CSS) loops (A&C, B&D), each consisting of two motor driven centrifugal pumps are designed to start upon LOCA signal (i.e. > 1.68 psig high drywell pressure or Low Reactor Pressure Vessel (RPV) level at -129"). The four pumps are sequenced onto the respective vital bus (A, B, C & D). The brake horsepower drawn by the CS pump of a particular loop will be at a maximum when the pump delivers the highest flow into the drywell via the spargers.
This occurs when one of the CS pumps in the loop fails to start upon receiving a LOCA signal (single failure), leaving the remaining CS pump in operation against a minimum drywell backpressure (assumed to be at atmospheric pressure or 0 psig). The minimum backpressure is caused by rapid containment depressurization with cooling. The high CS flow is limited by the orifice in the CS pumps common discharge line (Ref: M-52-1). From the CS certified pump data (Ref: PN 1-E21-C001-0378), the highest flow for the pump at 4,015 (1) gpm requires brake hp peaked at 655 h.p. The CS pumps are not required to be operational during LOP event. (Ref: FSAR: 6.3.2.2.3, BE-0016 CS -Hydraulic Analysis).
*Note (1): This is consistent with max. flow value used in FSAR in order to minimize the available NPSH for the pump.2. RHR Pump (A, B, C. D P-202)The most limiting mode for the RHR pump flow during a LOCA accident is operation in-the LPSI mode in conjunction with other ECCS pumps when the required pump flow rate is at its highest in order to restore RPV water level. The LPSI mode of the RHR is automatically activated by a LOCA signal and all above RHR pumps are sequenced onto their respective vital bus.However, because RHR pump is driven by a non-overloading motor (i.e. loading does not increases with pump flow), a maximum brake horsepower is provided which occurs when the opump is operating at approx. 8,500 gpm. (2) From the certified RHR pump curve (Ref: PSBP 324225), this peak motor power is estimated to be 1,250 Bhp. For the same reason that RHR pump loading peaks at lower flow rate, the same peak brake horsepower is given for LOP event during the shutdown cooling mode.H--*Note (2): T.S. surveillance testing for each RHP pump at LPSI mode is at 10,000 gpm.z 0 CD> 3. SAC Pump (A, B, C, D P-210)0 LOCA z 7-ry Upon receiving a LOCA signal, all four SAC pumps (two from each independent loop) start and>" are sequenced onto their respective vital bus to provide cooling water to the RHR heat r&#xfd;' exchangers and other safety-related coolers. Analysis (Ref: EG-0046) has been performed to o &#xfd;determine the SACS pump run out operating conditions following a LOCA. The most limiting Li_ scenario for a SACS pump to maximize its operating flow rate is as follows: one SACS pump is I 0_(f)0i U9PA'#
S. Kobylarz 3 5/30/01 placed in operation in a loop due to failure of the standby SACS pump to start concurrent with (4)loss of instrument air (Ref: EG-0047).
In such postulated scenario with only one SACS pump in operation to provide flow to all operable heat exchangers (including standby (3) heat exchangers), the maximum flow, as detailed in the calculation EG-0046, is presented in the table below: Note: 3) T.S. LCO condition (Ref: 3/ 4.7) allows one operable SACS pump be placed in operation in a loop.4) Postulated loss of instrument air during a LOCA results in the loss of ability of AOV to isolate the standby heat exchangers (Ref: EG-0047).A SACS Pump B SACS Pump C SACS Pump D SACS Pump 15,887 gpm 15,820 gpm 15,898 gpm 15, 674gpm The above high flow rate experienced by the operating SACS pump is expected during the ten minutes operation following a LOCA accident during which time operator intervention cannot be credited to isolate the standby heat exchangers or to restore the standby SACS pump.The certified SACS pump test data (Ref: PM0700-0043) demonstrates the SACS pump operability below its trip set point (low Dp) at 17,000 gpm. At the flow rate, the maximum brake ,horsepower drawn by the motor has been measured to be 529.3 Bhp. or approx., 530 Bhp.Brake horsepower does not vary significantly between 14,000 to 17,000 gpm.LOP z Under a postulated LOP event, the instrument air system is assumed to be operational (Ref: o-EG-0047), the FRVS cooling coils, CS pump room coolers and PASS coolers, which are not required during a LOP event, are isolated (Ref: EG-0047, FSAR 9.2.2.3).
The flow rate across the SACS pump in the worst scenario (i.e. one SACS pump per loop per EG-0047) is approx., S14,000gpm.
At this flow rate, the brake horsepower drawn by the motor is estimated from the certified pump curve to be 530Bhp (see LOCA section).t--4. SSWS Pump A ,B ,C, D P-502)z"_LOCA w During LOCA coincident with LOP event, the non-safety RACS is isolated by the motor-z operated valve HV-2203 from the SACS heat exchangers (Ref: J-10-0). Sufficient cooling is>_- provided with either two (2) SSWS pumps in (1) loop with (2) SACS heat exchangers or one (1)C- SSWS pump in each independent loop with four (4) SACS heat exchangers. (Ref: EA-003).J> Therefore, the worst case power consumption is the one SSWS pump operation.
From the r. manufacturer pump curve, this is estimated to be approx. 19,000 gpm with a brake horsepower 0 o -approx at 794 for B,C & D pump and 834 for A pump (Ref: Appendix I).c-f Z ..&#xfd;')hi Cno~~
C L C 0-Li Li a LLJ C:D C&#xa3;ad aJ S. Kobylarz 4 5/30/01 LOP The SSWS pump run out condition has been analyzed (Ref: EA-003) under the most limiting boundary conditions in order to determine the NPSH adequacy for the SSWS pump. During LOP event, the isolation valve (HV-2207) does not receive a LOCA to isolate the RACS from the TACS. Plant condition (e.g. winter) requires only one SSWS pump in each loop be placed in operation.
This can result in a single SSWS pump in each loop to service all the operable heat exchangers in both TACS and RACS. In worst boundary case scenario (such as consideration of maximum river level, clean strainers, minimum cooling tower basin level, no fouling in operable heat exchangers), a SSWP can experience high flow rate at approx 25,000gpm (Ref: EA-0003).
The manufacturer (Hayward Tyler) factory performance testing on pump of this design indicates brake horsepower requirement at the pump run out condition is 825 Bhp for 8,C& D pump and 850 Bhp for A pump (Ref: Appendix I).Please do not hesitate to let us know should you have any question relative to the power consumption for the above pumps.PK:imv Attachment C Barkley, B.Crawford, M.Danak, M.Fregonese, V.Kwok, P.Nag, 1.Morrison, G.Murphy, J..Rowey, J.NEMFS (N64)Dept Files Ut w C a-4 a C a a 4 ,0 D 4 0 7 D (~)LI C-j~2qog 4or%
Appendix 1.Cr)wL Based on manufacturer data, the brake horsepower of SSWS pump for LOCA case can be computed as follows: AP-502: S/N UG 49050246-04 (Ref: PSBP 334-42 Brake horsepower 798 + [ (846 -798 )/(19826 -16519)i *[19000 -165191 834 CP-502:_S/N UG49050246-03 (Ref: P1&1 33440)Brake horsepower
= 773 + [ (820 -773)/(21635
-16811)] * [19000- 16811 ]= 794 BP-502: S/N UG.49050246-02 (Ref; PSBP 33443)Brake horsepower
= 764.69 + [ (801 -764)/(19820
-16511)) * [19000 -16517 j 792 DP-502: S/N UG49050246-01 (Ref PSBP3344-1 Brake horsepower
= 766 + [(804 -766 )/( 19820 -16516)] * [19000 -16516]= 794 mde-0 1-00 16a.doc S Cr)0 L-Cr)z 0-LU 0 Li-u-i-J 0 W LJ 0 U Service Water Flow vs. Pressure Flow (gpm)15500 17000 15500 17000 Head (ft) Head (ft) Pressure Pressure 05/30/2001 Pump VTD S/N Spare 322848 UG04950246-05 164.26 157.96 71.41 68.67 AP502 322442 UG04950246-04 162.96 155.55 70.84 67.62 BP502 322440 UG04950246-03 164.03 155.77 71.31 67.72 CP502 322443 UG04950246-02 158.96 150.52 69.10 65.43 DP502 322441 UG04950246-01 158.88 150.99 69.07 65.64 average 161.82 154.16 70.35 67.02 or mdeO-01-0016b.xis wy Dn USER RESPONSIBLE FOR VERIFYING REVISION, STATUS AND CHANGES Hope Creek SW Pump BHP 900 850 800 750 0.-700 650 600 550 500 S I oi o i i I 7* A i
* I C A I A I C C I I C I A A A A I I I C C C C i C I A A Ai A A A i A i A A A A C A -I A A A A A I C A i A I A a A A A I A A. I I A A I A A C C A A A A AI A A C A A IIII A A A A A C A A i A I A i i i A i A i I i A A A A A A I A A C A I A I I , 1 I I A C II I I I C A I A I I A C A A IAIC I* C A I I I C , C I A I I I A A I I-L I I A, -.., ..,, ..... .... ..... L C* C A i C A AA I Ai A A A CC C A A I C C A A I AX C C A A I i A C C C A C A A A I A C A A A C A C A A A C I ---C A A A i A A iA /r ---- --- I-- J----------A A A A A A A A* I i I C A A A C A A A C A A A A A A A A A A A I K A I I A A A A A 1 I t I r I i I A A A A C A A I A I A A rA 1 / -' I A A C C A I A A A A C A A A C I C A C A A C C I C I C A A I C I A C C i C A IC I A A A I C I I C A A i A i A C C C t i A A I A i A A A C C I A I.....A C A C C A A A A i i A C A C C C r A A i.. .. .iC. .. .i. ....L ...... i ** i I i IC i i C C C C I C 0 5000 10000 15000 Flow (gpm)20000 25000 30000 mde0-01-0016b.xls
---- AP502 -BP502 -a- CP502-u- DP502 --c-- SPARE -Motor Rating NC.NA-AS.ZZ-0059(Q)
FORM-1 REGULATORY CHANGE PROCESS DETERMINATION Document I.D.: E-9(Q)Title: STANDBY DIESEL GENERATOR SIZING Revision:
8 Page 1 of 3 Page 1 of 3 Activity
 
== Description:==
 
Revision 6 of this calculation incorporates the outstanding changes posted against the calculation.
See Reference 3Y for the list of CD's. These changes have already received al OCFR50.59 Screen or Evaluation under the respective Design Change Package.Note that more than one process may apply. If unsure of any answer, contact the cognizant department for guidance.Activities Affected No Yes Action Does the proposed activity involve a change to the Technical 1 r If Yes, contact Licensing; process in Specifications or the Operating License? accordance with NC.NA-AP.ZZ-0035(Q)
LCR No.2. Does the proposed activity involve a change to the Quality [ W If Yes, contact Quality Assessment; process Assurance Plan? Examples:
in accordance with ND.QN-AP.ZZ-0003(Q) 0 Changes to Chapter 17.2 of UFSAR 3. Does the proposed activity involve a change to the Security Plan? [ *] If Yes, contact Security Department; process Examples:
in accordance with NC.NA-AP.ZZ-0033(Q)" Change program in NC.NA-AP.ZZ-0033(Q)
* Change indoor/outdoor security lighting* Placement of component or structure (permanent or temporary) within 20 feet of perimeter fence" Obstruct field of view from any manned post* Interfere with security monitoring device capability
* Change access to any protected or vital area" Modify safeguards systems or equipment 4. Does the proposed activity involve a change to the Emergency Z fl If Yes, contact Emergency Preparedness Plan? Examples: " Change ODCM/accident source term* Change liquid or gaseous effluent release path* Affect radiation monitoring instrumentation or EOP/AOP setpoints used in classifying accident severity" Affect emergency response facilities or personnel, including control rm" Affect communications, computers, information systems or Met tower 5. Does the proposed activity involve a change to the ISI Program Z f] If Yes, contact Reliability Programs IST/IST;Plan? Examples:
process in accordance with a Affect Nuclear Class 1, 2, or 3 Piping, Vessels, or Supports NC.NA-AP.ZZ-0027(Q)(Guidance in NC.DE-AP.ZZ-0007(Q)
Form- 11)6. Does the proposed activity involve a change to the IST Program Z E] If Yes, contact Reliability Programs ISMIST;Plan? Examples:
process in accordance with* Affect the design or operating parameters of a Nuclear Class 1, NC.NA-AP.ZZ-0070(Q) 2, or 3 Pump or Valve (Guidance in NC.DE-AP.ZZ-0007(Q)
Form- 15)Nuclear Common Rev. 6 NC.NA-AS.ZZ-0059(Q)
FORM-1 REGULATORY CHANGE PROCESS DETERMINATION Document I.D.: E-9(Q)Title: STANDBY DIESEL GENERATOR SIZING Revision: 8 Page 2 of 3 Activities Affected No Yes Action 7, Does the proposed activity involve a change to the Fire Protection
[ [f If Yes, contact Design Engineering; process Program? Examples:
in accordance with NC.DE-PS.ZZ-000 (Q)" Change program in NC.DE-PS.ZZ-0001(Q)" Change combustible loading of safety related space* Change or affect fire detection system* Change or affect fire suppression system/component
* Change fire doors, dampers, penetration seal or barriers" See NC.DE-AP.ZZ-0007, Forms 3, 4 and 14 for details 8. Does the proposed activity involve Maintenance which restores M If Yes, process in accordance with SSCs to their original design and configuration?
Examples:
NC.WM-AP.ZZ-0001(Q)
* CM or PM activity* ImpIements an approved Design Change?* Troqbleshooting (which does not require 50.59 screen per SH.MD-AP.ZZ-0002)
Is the proposed activity a temporary change (T-Mod) which meets r [ If Yes, contact Engineering; process in all the following conditions?
accordance with NC.DE-AP.ZZ-0030(Q)
* Directly supports maintenance and is NOT a compensatory measure to ensure SSC operability." Wilibe in effect at power operation less than 90 days.* Plant will be restored to design configuration upon completion.
* SSCk will NOT be operated in a manner that could impact the function or operability of a safety related or Important-to-Safety system.10. Does the proposed activity consist of changes to maintenance l E] If Yes, process in accordance with procedures which do NOT affect SSC design, performance, NC.NA-AP.ZZ-OO0l(Q) operation or control?Note: Procedure information affecting SSC design, performance, operatioq or control, including Tech Spec required surveillance and inspection, require 50.59 screening.
Examples include acceptance criteria for valve stroke times or other SSC function, torque values, and types of materials (e.g., gaskets, elastomers, lubricants, etc.)11. Does the proposed activity involve a minor UFSAR change Z El If Yes, process in accordance with (including documents incorporated by reference)?
Examples:
NC.NA-AP.ZZ-0035(Q)
* Reformatting, simplification or clarifications that do not change the meaning or substance of information
* Removes obsolete or redundant information or excessive detail* Corrects inconsistencies within the UFSAR* Minor correction of drawings (such as mislabeled ID)12. Does the proposed activity involve a change to an Administrative
[ *E If Yes, process in accordance with Procedure (NAP, SAP or DAP) governing the conduct of station NC.NA-AP.ZZ-0001(Q) and operations?
Examples:
NC.DM-AP.ZZ-000 1(Q)* Organization changes/position titles* Work controL modification processes Nuclear Common Rev. 6 IIUUIIIUidLIUI IM UIJU1JJ .,J 0l C11 A .VUL..JU..J I.-
NC.NA-AS.ZZ-0059(Q)
FORM-i REGULATORY CHANGE PROCESS DETERMINATION Document I.D.: E-9(Q)Title: STANDBY DIESEL GENERATOR SIZING Revision:
8 Page 3 of 3 Page 3 of 3 Activities Affected No Yes Action 13. Does the proposed activity involve a change to a regulatory Z H] If Yes, contact Licensing and process in commitment?
accordance with NC.NA-AP.ZZ-0030(Q)
: 14. Does the activity impact other programs controlled by regulations, [ fl If Yes, process in accordance with operating license or Tech Spec? Examples:
applicable procedures such as: " Chemical Controls Program NC.NA-AP.ZZ-0038(Q)
* NJ "Right-to-know" regulations NC.LR-AP.ZZ-0037(Q)
* OSHA regulations" NJPDES Permit conditions a State and/or local building, electrical, plumbing, storm water management or "other" codes and standards" IOCFR20 occupational exposure 15. Has the activity already received a IOCFR50.59 Screen or E] Z Take credit for lOCFR50.59 Screen or Evaluation under another process? Examples:
Evaluation already performed.
a Calculation a Design Change Package or OWD change ID: See Explanation Below a Procedure for a Test or Experiment a DR/Nonconformance a Incorporation of previously approved UFSAR change If any other program or regulation may be affected by the proposed activity, contact the department indicated for further review in accordance with the governing procedure.
If responsible department determines program is not affected, attach written explanation.
If ALL of the answers on the previous pages are "No," then check A below: A. [ ] None of the activity is controlled by any of the processes above, therefore a 10CFR50.59 review IS required.
Complete a 10CFR50.59 screen.If one or more of the answers on the previous pages are "Yes," then check either B or C below as appropriate and explain the regulatory processes which govern the change: B. [ X ] All aspects of the activity are controlled by one or more of the processes above, therefore a 10CFR50.59 review IS NOT required.C. [ ] Only part of the activity is controlled by the processes above, therefore a 1OCFR50.59 review IS required.
Complete a 50.59 screen.Explanation:
This activity incorporates outstanding change papers. These changes have already received a1 OCFR50.59 Screen or Evaluation under the respective Design Change Package. The outstanding change papers incorporated are associated with modifications 80003623 and 80003631 Preparer: Reviewer: S. Savar 4 xec61LZ Printed NamnL<A"JL9 L-&#xfd;'- Signature Date Nuclear Common Rev. 6 NC.CC-AP.ZZ-0010(Q)
FORM-2 COMMENT I RESOLUTION FORM FOR DESIGN DOCUMENT REVIEW/CHECKING OR DESIGN VERIFICATION (SAP Standard Text Key "NR/CDV2")
REFERENCE DOCUMENT NO. /REV. Calculation E-9/Rev. 8 COMMENTS The comments ranged from minor typo, to clarifying the attachments vs. tables.RESOLUTION Correcting typos, and revised tables to add as attachments.
ACCEPTANCE OF RESOLUTION The correction is acceptable.
No impacts were found on other calculation that is either considered input or output to this calculation.
The margin for is not affected.SUBMITTED BY DATE RESOLVED BY DATE U~)w 0 z 0 0 z Page 25 of 27 Nuclear Common Rev. 2 NC.CC-AP.ZZ-0010(Q)
FORM-I (Page 2 of 3)CERTIFICATION FOR DESIGN VERIFICATION (SAP Standard Text Key "NR/CDVI")
Reference No. E--9/t,7 I.
 
==SUMMARY==
STATEMENT This Design Verification was performed on revision 8 of this Calculation.
Revision 8 incorporates outstanding changes to this Calculation.
This verification is a combined Independent Design Verification and a line by line peer review of incorporated changes, in accordance with NC.CC-AP.ZZ-001 0(Q).The changes incorporated by this revision include changes to MOV stroke time and the notes associated with it.The changes incorporated by this revision do not change the scope or intent of this design calculation.
No impact on other calculations and procedures.
General changes were made to the calculation to bring it up to date with current calculation procedure.
The design verification checklist was reviewed to ensure that all issues have been addressed.
Based on the level of verification performed, as described above, this Design Calculation is correct, the outputs (conclusions) are correct based on the inputs, proper procedures were used in its preparation, and comments were satisfactory resolved.Page 1 of 2 0 Wi 0 z L.4 0 n H-L.--F--Q0 a LiJ a i, 0_(./L0 aY 0J U-3 Nuclear Common Page 23 of 27 Rev. 2 NC.CC-AP.ZZ-0010(Q)
FORM-1 (Page 2 of 3)CERTIFICATION FOR DESIGN VERIFICATION (SAP Standard Text Key "NR/CDVI")
Each individual named below in the right column hereby certifies that the design verification for the subject document or document portion has been completed, the questions from the generic checklist have been reviewed and addressed as appropriate, and all comments have been adequately incorporated.
The top right column individual is the Lead Design Verifier.
SAP Order/Operation final confirmations are the legal equivalent of signatures.
Mehdi Tadijalli Design Verifier Assigned By (print name of Manager/Director)*
Lamis Fleischeruz
-e/!/Name of Design Verifier*
/ bate Design Verifier Assigned By (print name of Manager/Director)*
Design Verifier Assigned By (print name of Manager/Director)*
Name of Design Verifier/
Date Name of Design Verifier*
/ Date Design Verifier Assigned By (print name of Manager/Director)*
Name of Design Verifier'
/ Date*If the Manager/Supervisor acts as the Design Verifier, the name of the next higher level of technical management is required In the left column.Page 2 of 2 0 nz w w-Nuclear Common Page 23 of 27 Rev. 2 KY- COOL S [0/ [09 I 00000 0000*.... .... MO ....e0-&#xb6;2 .M0.....v~
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~ *nr... )----------------- ---------------------0 4 0 4 0 0 4 A1.1 A, A,~l' A-A'A I I.. T. I ONO ST- SVCE G 2 MR IAX5,40401 aI Saoaa TRNSaRF IG 4 ~~~ ~- 30 xa-)m"a ~ ~ ~ ~ ~ 1 t.fE9 KitMutW;i V 4"Jl c__acmanacm.
I' FU71 L11 T STA. SATE. TEAR mIFS.~ <L 'STA. SATE EAR RA51~4041 TRC L V CHANREL V DoaCANNEL -A" qH6 im AN c pA-F A A]a~ Acm2 ATTENTION:
-4 Ba 444;234, a.,aa.&#xfd;, AS TO HOPE CREEK GENERATING STATION SINCLE LINA  STATION DIAGRAM ELECTRICAL PSEG MJCLEPRS LLC FORMERLY BECHTEL POWER CORPORATION DRAWING E-O001-O REV. 9 E-O001-O (Q)- 24 0 0 0 Attachment 4 LR-N 10-0294 LIST OF REGULATORY COMMITMENTS The following table identifies those actions committed to by PSEG in this document.
Any other statements in this submittal are provided for information only purposes and are not considered to be regulatory commitments.
Commitment Type Committed One- Programmatic Regulatory Commitment Date Time (Yes/No)Action (Yes/No)The following compensatory actions, which will be included in the TS Bases, will be applicable during the extended AOT for EDG A&B: 1. When the A EDG is removed from service for an extended 14 day AOT, the C EDG shall be operable.
When the B EDG is removed from service for an extended 14 day AOT, the D EDG shall be operable.2. When either the A or B EDG is removed from service for an extended 14 day AOT, both HPCI and RCIC shall be operable.3. Any component testing or maintenance that increases the likelihood of a plant transient shall be avoided during the extended 14 day AOT. This encompasses work activities categorized as Production Risk.4. Voluntary entry into this LCO action statement should not be scheduled if adverse weather conditions are expected.5. Availability of the GTG will be checked before entering any A or B EDG extended 14 day AOT.Concurrent with approval and subsequent implementation of this proposed license amendment No Yes}}

Latest revision as of 04:30, 13 April 2019

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