Text

Response to Request for Additionl Information and Request for Confirmation of Information - LAR to Revise the Licensing Basis and Minimum Basin Water Level for the Ultimate Heat Sink
	ML25267A061
Person / Time
Site:	River Bend
Issue date:	09/24/2025
From:	Couture P; Entergy Operations
To:	; Office of Nuclear Reactor Regulation, Document Control Desk
References
	CNRO2025-00028
	Download: ML25267A061 (1)
	v • d • e

Phil Couture Senior Manager Fleet Regulatory Assurance - Licensing 601-368-5102 Entergy Operations, Inc., 1340 Echelon Parkway, Jackson, MS 39213 CNRO2025-00028 10 CFR 50.90 September 24, 2025 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Subject:

Response to - Request for Additional Information and Request for Confirmation of Information - LAR to Revise the Licensing Basis and Minimum Basin Water Level for the Ultimate Heat Sink River Bend Station, Unit 1 NRC Docket No. 50-458 Renewed Facility Operating License No. NPF-47 Pursuant to 10 CFR 50.90, Entergy Operations, Inc. (Entergy), requested an amendment to the Renewed Facility Operating License Number NPF-47 for River Bend Station (RBS), Unit 1 (Reference 1). Entergy requested the Nuclear Regulatory Commissions (NRC's) review and approval of a change to the RBS Updated Safety Analysis Report (USAR) to credit makeup to the Ultimate Heat Sink (UHS) in less than 30 days. Entergy received a Request for Confirmation of Information (RCI) and Request for Additional Information (RAI) on August 27, 2025, following a clarification call held on August 25, 2025. provides responses to the RCIs. Attachment 2 provides responses to the RAIs. provides the procedure AOP-0004 Loss of Offsite Power. Attachment 4 provides the relevant training tasks for makeup to the UHS.

This letter contains no new regulatory commitments.

Should you have any questions or require additional information, please contact Jack McCoy, Manager, Regulatory Assurance and Emergency Planning, River Bend Station, at 225-378-3310.

CNRO2025-00028 Page 2 of 2 I declare under penalty of perjury that the foregoing is true and correct.

Executed on September 24, 2025.

Respectfully, Phil Couture PC/dlw Attachments: 1. Response to Request for Confirmation of Information

2. Response to Request for Additional Information

3. Procedure AOP-0004 "Loss of Offsite Power"

4. Relevant Training Tasks for UHS Makeup

References:

1. Entergy letter to NRC, "License Amendment Request to Revise the Licensing Basis and Minimum Basin Wate Level for the Ultimate Heat Sink,"

ML24365A265, (RBG-48323) dated December 30, 2024.

2. NRC email to Entergy, "River Bend Station, Unit 1 - Request for Additional Information to Entergy LAR to Revise the Licensing Basis and Minimum Basin Water Level for the Ultimate Heat Sink (L-2024-LLA-0180),"

ML25252A219, dated August 27, 2025.

cc:

NRC Region IV Regional Administrator NRC Senior Resident Inspector - River Bend Station NRC Project Manager - River Bend Station Designated State Official - Louisiana Philip Couture Digitally signed by Philip Couture Date: 2025.09.24 07:55:47 -05'00'

CNRO2025-00028 Response to Request for Confirmation of Information (3 Pages Follow)

CNRO2025-00028 Page 1 of 3 Response to Request for Confirmation of Information BACKGROUND In the license amendment request (LAR) dated December 30, 2024 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML24365A265), Entergy Operations, Inc, (Entergy), the Licensee, requested that the U.S. Nuclear Regulatory Commission (NRC) approve an amendment for River Bend Station, Unit 1 (RBS), respectively for Renewed Facility Operating License No. NPF-47 in the form of changes to the River Bend Station licensing basis through revision to Updated Safety Analysis Report (USAR) and Technical Specifications (TSs). The licensees evaluation of the proposed changes is located in and 2 of the application and referenced as LAR sections in this document.

The proposed USAR change would allow crediting makeup to the ultimate heat sink (UHS) in less than 30 days to account for system leakage and for operation with both standby service water subsystems in operation. The proposed changes also would revise Surveillance Requirement (SR) SR 3.7.1.1 to increase the minimum UHS cooling tower basis water level in order to maximize UHS inventory.

REGULATORY BASIS The UHS is required to meet regulatory requirements of 10 CFR Part 50, Appendix A, General Design Criteria (GDC) 44, Cooling Water. The NRC staff considers that the requirements of the GDCs are met for the UHS if the license amendment request adheres to the guidelines of Regulatory Guide (RG) 1.27.

As indicated in Standard Review Plan (SRP) 9.2.5, information that addresses the requirements of GDC 44 regarding consideration of the cooling water system will be considered acceptable if the guidance of RG 1.27, Positions C.2 and C.3; RG 1.72, Positions C.1, C.4, C.5, C.6, and C.7.; and American National Standards Institute/American Nuclear Society (ANSI/ANS) 5.1 are applied appropriately.

RG 1.27 provides criteria that the capacity of the UHS should be sufficient to provide cooling for the time necessary to evaluate the situation and take corrective action. A period of 30 days is considered adequate for these purposes. In addition, procedures should be available for ensuring the continued capability of the UHS beyond 30 days. A capacity of less than 30 days may be acceptable if it can be demonstrated that replenishment can be effected to ensure the continuous capability of the UHS to perform its safety functions, taking into account the availability of replenishment equipment and limitations that may be imposed following an accident or severe natural event.

CNRO2025-00028 Page 2 of 3 SCPB - RCI 1 The application indicates, The circ water flume is an open channel located between the plant cooling towers which serves to transfer the water from the cooling tower basins to the suction of the circ water pumps. Please confirm which cooling tower basin inventory is being credited for use with FLEX equipment and confirm that adequate inventory is left for the circ water flume for use as makeup if the cooling tower basin inventory is challenged.

Response

As indicated in the submittal, Enclosure 1, the circ water flume is an open channel located between the plant cooling towers which serves to transfer the water from the cooling tower basins to the suction of the circ water pumps. The RBS circulating water system consists of four cooling towers each connected to a central flume which drains into the circulating water basin which serves as a source for the circulating water pumps. Only the basin and the central flume are being credited as a makeup source.

As indicated in the submittal, Enclosure 1 section 3.4, Entergy calculations indicate the required volume to replenish the Standby Cooling Tower (SCT) to meet the 30-day mission time is 2,512,800 gal. Assuming a starting flume level at the minimum operating level of 105 ft mean sea level, the flume has an available volume of at least 2,695,000 gallons. Therefore, the flume has adequate volume to meet the 30-day mission time for the SCT basin.

SCPB-RCI 2 FSAR section 9.2.5.2 system Description indicates The UHS at River Bend Station consists of one 200 percent Seismic Category I cooling tower and one 100 percent capacity water storage basin. The staff is unclear how the 100 percent capacity is defined.

1. Confirm by description or computation that the cooling tower basin is designed or classified as 100 percent capacity basin.

2. Confirm that the cooling tower can meet the 30-day supply of water inventory in event of LOCA, without any single failure and without makeup.

3. Confirm the plant remains capable of meeting the 30 days quantity in event of a loss of one train of SSW or purposeful shutdown of one train, without makeup.

RBS Response

1. The standby cooling tower common storage water basin capacity includes the required makeup. As indicated in the proposed USAR changes (section 9.2.5.2), a total of 6,778,000 gallons with 2,512,800 gallons credited replenishment at the proposed Technical Specification height of El. 114 ft.-5 in. to the minimum submergence level of the standby service water pumps, El. 65 ft. The 2,512,800 gallons represents 100 percent capacity of the water storage. There are two, 100 percent capacity, i.e., 200 percent total, heat removal sections. These sections consist of 10 fans per division

CNRO2025-00028 Page 3 of 3 designed to accommodate a single failure of one division of fans and retain 100 percent of the design cooling capacity.

2. The current design is not capable of ensuring a 30-day supply of water inventory in the event of a LOCA without makeup without assuming a single failure of divisional power.

3. The current licensing basis for RBS includes the assumption of a concurrent loss of one train of Standby Service Water (SSW) (concurrent Diesel Generator Failure) as described in USAR Section 9.2.5.2. The plant remains capable of meeting the 30 days quantity under this condition, without makeup.

CNRO2025-00028 Response to Request for Additional Information (9 Pages Follow)

CNRO2025-00028 Page 1 of 9 Response to Request for Additional Information

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Background===

In the license amendment request (LAR) dated December 30, 2024 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML24365A265), Entergy Operations, Inc, (Entergy), the Licensee, requested that the U.S. Nuclear Regulatory Commission (NRC) approve an amendment for River Bend Station, Unit 1 (RBS), respectively for Renewed Facility Operating License No. NPF-47 in the form of changes to the River Bend Station licensing basis through revision to Updated Safety Analysis Report (USAR) and Technical Specifications (TSs). The licensees evaluation of the proposed changes is located in and 2 of the application and referenced as LAR sections in this document.

The proposed USAR change would allow crediting makeup to the ultimate heat sink (UHS) in less than 30 days to account for system leakage and for operation with both standby service water subsystems in operation. The proposed changes also would revise Surveillance Requirement (SR) SR 3.7.1.1 to increase the minimum UHS cooling tower basis water level to maximize UHS inventory.

Regulatory Basis The UHS is required to meet regulatory requirements of 10 CFR Part 50, Appendix A, GDC 44, Cooling Water. The NRC staff considers that the requirements of the GDCs are met for the UHS if the license amendment request adheres to the guidelines of Regulatory Guide 1.27 As indicated in SRP 9.2.5, information that addresses the requirements of GDC 44 regarding consideration of the cooling water system will be considered acceptable if the guidance of RG 1.27, Positions C.2 and C.3; RG 1.72, Positions C.1, C.4, C.5, C.6, and C.7.; and American National Standards Institute/American Nuclear Society (ANSI/ANS) 5.1 are applied appropriately.

RG 1.27 provides criteria that the capacity of the UHS should be sufficient to provide cooling for the time necessary to evaluate the situation and take corrective action. A period of 30 days is considered adequate for these purposes. In addition, procedures should be available to ensure the continued capability of the UHS beyond 30 days. A capacity of less than 30 days may be acceptable if it can be demonstrated that replenishment can be effective in ensuring the continuous capability of the UHS to perform its safety functions, considering the availability of replenishment equipment and limitations that may be imposed following an accident or severe natural event.

10 CFR, Part 50, Appendix B, Quality Assurance Criteria for Nuclear Power Plants and Fuel Reprocessing Plants, Criterion V, Instructions, Procedures, and Drawings requires, in part, that activities affecting quality shall be prescribed by documented instructions, procedures, or drawings, of a type appropriate to the circumstances.

CNRO2025-00028 Page 2 of 9 Questions from Containment and Plant Systems (SCPB)

SCPB-RAI 1 The licensee described the normal method of replenishing water in the SCT is performed using the installed deep well pumps (located within the yard), which are part of the makeup water treatment system. Raw water is pumped from two deep well pumps (MWS-P1A and MWS-P1B) to maintain level in the SCT basin. The plant has redundant deep well pumps that are each capable of meeting the required makeup flow.

As indicated by licensee, Currently, the RBS standby cooling tower (SCT) basin is designed in accordance with RG 1.27 Revision 2 (Reference 1) to maintain a 30-day inventory assuming the failure of an Emergency Diesel Generator (EDG), thereby limiting operations to one subsystem of SSW and its associated system leakage following a design basis accident (DBA). However, if failure of the EDG does not occur and both subsystems of SSW remain operational, the UHS inventory is depleted within approximately 21 days. Rather than securing an EDG and operating with a single SSW subsystem post-DBA, the preferred approach is to maintain all EDGs operational and instead replenish the UHS inventory as needed. RG 1.27 indicates less than 30 days may be acceptable if it can be demonstrated that plant has continuous replenishment or makeup, while considering the availability of equipment and limitations following accident.

Based on the LAR description of well pumps, the staff is unclear whether these pumps will be available, how they will be maintained, and what actions are taken if they are unavailable.

Based on the makeup supplies being non-safety, provide the following:

1. Provide discussion of actions taken in event one or both makeup sources are found unavailable in the event of an accident. Confirm actions are proceduralized.

2. Provide discussion of inspection, maintenance, and performance testing of the non-safety related makeup sources to ensure availability.

3. Provide any pertinent operating experience of deep well pumps.

4. Confirm whether the makeup sources are included in the program in accordance with the Regulatory Guide 1.160, Maintenance Rule (10 CFR 50.65), or other operational reliability assurance program.

Response

1. Entergy (RBS) proposes to provide two redundant and diverse makeup sources to the Standby Cooling Tower (SCT). The primary source is the normal makeup consisting of one of two deep well pumps (MWS-P1A & B) and the secondary source being one of two portable fire pumps (FPW-P4 & FLX-P3). As described in section 3.1 of the submittal,, replenishment from either of the deep well pumps or either of the portable fire pumps will be started by day 10-post DBA. The makeup water supplies have multiple active redundancies, (one of four pumps is sufficient to provide the necessary makeup) using diesel backed power sources. The makeup water source is diverse in that the deep well pumps take a suction from the Tertiary Zone 3 Aquifer, described in USAR section 2.4.13.1.4, and the portable fire pumps take suction from the circulating water flume. Each source has sufficient capacity to provide for all required makeup to ensure a 30 day UHS inventory.

CNRO2025-00028 Page 3 of 9 The actions are addressed in site procedure AOP-0004 Loss of Offsite Power which requires makeup be initiated by 10-days post-DBA at a rate of 125 gpm which exceeds the required makeup rate of 87.5 gpm and is within the capacity of either of the makeup pumps.

Thus, only one of the four pumps is required to supply makeup. The procedure provides attachments with instructions to the operators to makeup using the Station Blackout (SBO)

Diesel to power the deep well pumps, if normal power is unavailable. If both normal makeup pumps are unavailable, makeup can be provided by using either of the diesel driven portable fire pumps (FPW-P4 or FLX-P3) taking suction from the circulating water basin.

Pump discharge will be aligned to the fire protection system at one of two separate locations. Makeup would flow through the fire protection piping and be provided to the SCT through one of two fire hydrants located near the tower. These fire protection piping flow paths use independent piping with the only common point being the circulating water flume suction.

The deep well pumps will be screened under site preventative maintenance procedures to apply the appropriate maintenance to ensure they can perform their design function. The reliability of the portable fire pumps is tracked through the Technical Requirements Manual (TRM) 3.13.2.

2. Maintenance is performed on both the deep well and portable fire pumps as required based on equipment performance. In addition, the portable fire pumps, FLX-P3 & FPW-P4, have monthly, semi-annual, and yearly preventive maintenance requirements which include visual inspection, engine operational tests and pump operational capacity tests. The inspections and testing ensure that the pumps remain capable of performing their design function.

Discrepancies are reported and assessed as part of the corrective action program. As discussed in item 4 below, RBS will screen the pumps in accordance with Entergy programmatic requirements to ensure the appropriate preventive maintenance requirements are provided.

3. The deep well pumps, MWS-P1A & B, are original installed equipment, are classified as non-critical equipment and are normally used to replenish the well water storage tank which is used as the supply for plant demineralized water as well as makeup to the standby cooling tower. Review of the maintenance history does not indicate any issue within the last 20 years with MWS-P1A. MWS-P1B has had two instances since 2017 of failed control switches. No other previous issues were identified that would have prevented either pump from performing their function. As stated below the pumps will be screened under site preventative maintenance procedures to determine the appropriate preventative maintenance strategy that will ensure their long-term availability to perform their design function.

4. The deep well and portable fire pumps and motors, and in the case of FPW-P4 and FLX-P3 the engines, are non-safety related and, currently, not included within the maintenance rule program. Upon LAR approval, the equipment will be screened under site preventative maintenance procedures to apply the appropriate preventative maintenance to ensure they can perform their design function.

CNRO2025-00028 Page 4 of 9 SCPB-RAI 2 Entergy calculations have determined that, with no EDG failures and both divisions of SSW in operation, the SCT basin inventory is depleted by day 21 following a DBA. Therefore, this scenario requires additional makeup actions to provide cooling and remain in the shutdown condition to meet the 30 days post-LOCA criteria in RG 1.27.

Currently licensee indicates, if failure of the EDG does not occur and both subsystems of SSW remain operational, the UHS inventory is depleted within approximately 21 days. Rather than securing an EDG and operating with a single SSW subsystem post-DBA, the preferred approach is to maintain all EDGs operational and instead replenish the UHS inventory as needed.

The calculated inventory is based on loss of offsite power and the need for EDG, which consumes a large quantity of the water inventory. Upon restoration of offsite power and no longer needed for EDG, the duration of inventory can be extended and need for makeup reduced. The staff is unclear of critical time periods during post-LOCA conditions that result in the highest demand of UHS inventory and whether options are available to conserve the safety related water source.

1. In the event of LOCA, describe what actions are performed to conserve water inventory.

2. In the event offsite power is restored, describe whether any actions are taken with EDG to conserve inventory.

3. Discuss time during a LOCA when the maximum temperature and maximum demand on the cooling tower basin inventory is achieved, as result of accident?

Response

1. Site procedure AOP-0004 provides the following operator actions. These operator actions are accounted for in the basin inventory and required makeup calculation. The purpose of these actions is to preserve SCT basin inventory.

Within 20 min. ensure SWP-MOV96A(B) closed. This is considered a time critical operation as provided in Entergy Procedure EN-OP-123.

IF SWP-MOV96A(B) NORM SVCE WTR RETURN can NOT be closed, THEN close SWP-V1213(V1212), A(B) RETURN HEADER ISOLATION.

Within 20 min. redundant, diesel backed loads, are reduced Additional loads on the diesel are delayed for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after LOCA At 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months post-LOCA secure service water to Div. 2 RHR Heat Exchangers, secure HVR-UC1B Containment Unit Cooler At 90 ft. Standby Cooling Tower water level, reduce Standby Service Water flow through the Division I RHR Heat Exchanger to 3000 gpm

CNRO2025-00028 Page 5 of 9

2. AOP-0004 provides for restoring the Diesel Generators to Standby mode, after offsite power is restored and the buses are reenergized from offsite power. This will remove a major heat load and result in reduced inventory loss from the SCT basin for the remainder of the event.

3. The maximum basin temperature and inventory conditions were analyzed separately under separate assumptions to provide conservatism for each condition as appropriate. The condition resulting in the maximum basin temperature assumes a failure of one division of cooling tower fans and no loss of inventory through the service water return valves (SWP-MOV96A or B), and an initial basin level and temperature of 111 ft.-10 in. and 88°F, consistent with the current technical specifications. Peak basin temperature of 92.64°F occurs at approximately 10 hrs. into the event. The peak basin temperature is not reanalyzed at the 114 5 basin level due to the 111 10 basin level analysis bounding the higher basin level. It is also not affected by makeup flow introduced on day 10 since peak temperature occurs 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months into the event.

Maximum demand on basin inventory was evaluated at an initial basin inventory of 114 ft.-5 in. and an initial basin temperature of 88°F. Maximum evaporation occurs at hour 1 when 1.84E+05 lbm/hr is being evaporated, approximately 367.5 gpm. This in addition to 15 gpm per division of system leakage assumed throughout the event would be the largest demand on the basin inventory.

SCPB-RAI 3 The LAR states, While portions of the deep well pump system are not considered resistant to all flooding, tornado, and seismic events, they represent a highly reliable primary replenishment source. The LAR further concludes makeup from a reliable source by indicating, Based on the Entergy calculations, replenishment of the SCT basin is required in less than 30 days to ensure the continued capability of the UHS to provide its safety functions. To meet the 30-day mission time, replenishment must start by day 10 post-DBA at a minimum rate of 87.25 GPM. The required replenishment total volume needed to reach 30 days is approximately 2,512,800 gallons. In the event the deep well pumps are required to start on the 10th day, this makeup quantity requires the deep well makeup pumps to be running no-stop for 20 days to meet the volume requirements of 30-day supply. As indicated in question 1 above, the NRC staff is concerned about the reliability of the non-safety deep wells pumps and their availability of equipment and limitations following an accident. Provide discussion on whether these well pumps are designed to operate under these continuous conditions for extended duration.

Response

Both deep well pumps are designed for continuous operation per their purchase specification and have a makeup capability of 150 gpm. As noted in the submittal, the required minimum replenishment rate to ensure a 30-day supply is 87.25 gpm for the maximum inventory loss condition beginning at 10 days post-DBA. At a makeup rate of 150 gpm, one pump would not have to operate continuously for the entire 20 days but only for approximately 10 days. There are two deep well pumps available and capable of makeup to the cooling tower at a maximum 150 gpm.

CNRO2025-00028 Page 6 of 9 SCPB-RAI 4 LAR (Attachment A) markup proposed to add, For inventory analysis, the worst-case single failure of either SWP-MOV96A or B (Standby Service Water Return Header Isolation Valves) is postulated to occur immediately after the trip. For temperature analysis, the worst-case single failure of the Div II SCT fans is postulated to occur immediately after the trip. However, the LAR described an inventory analysis only and does not contain any discussion related to temperature analysis or transients. Provide basis or discussion of worst-case single failure related to temperature concerns.

Response

The maximum basin temperature and inventory conditions were analyzed separately under different limiting assumptions to provide conservatism for each condition as appropriate. The condition resulting in the maximum basin temperature assumes a failure of one division of cooling tower fans and no loss of inventory through the service water return valves (SWP-MOV96A or B), and an initial basin level and temperature of 111 ft.-10 in. and 88°F, consistent with the current technical specifications. Peak basin temperature of 92.64°F occurs at approximately 10 hrs. into the event. This temperature is below the maximum service water temperature assumed in the accident analysis of 95°F as indicated in USAR Section 9.2.5.2.

The peak basin temperature is not reanalyzed at the 114 5 basin level due to the 111 10 basin level analysis bounding the higher basin level. It is also not affected by makeup flow introduced on day 10 since peak temperature occurs 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months into the event.

The USAR will be updated as required by 10 CFR 50.71(e).

Questions from Operator Licensing and Human Factors (IOLB)

IOLB-RAI 1 NRC staff evaluates the use of operator actions and associated procedures with the guidance provided in NUREG-0800, Chapter 18, Attachment A, Standard Review Plan. The NRC staff also reviewed guidance in NUREG-1764, Guidance for the Review of Changes to Human Actions, Revision 1, to access the importance of human actions involved in license amendment requests. The licensee stated that the preferred method for SCT makeup will come from the deep well pumps using the Station Blackout (SBO) generator. Regarding the SCT basin makeup strategy using the circulating water flume, the licensee stated in the LAR that FLEX pumps located in the FLEX building will be deployed and draw suction from the circulating water flume and distribute makeup water through one of two fire protection sources connected to the SCT basin. The NRC staff requests information on the following:

a.

Clarification on whether the existing FLEX strategies involving the FLEX pump and fire protection system associated with the circulating water flume will be similar or modified for SCT basin makeup after a DBA event. Additional clarification is needed for the initiation and execution of the makeup strategy involving the deep well pumps, specifically when the SBO generator is in use if normal power isnt available.

CNRO2025-00028 Page 7 of 9

b.

Through a task analysis, the amount of time operators will have to deploy and stage the equipment for SCT basin makeup from either fire hydrant flow path that is connected to the circulating water flume. A similar task analysis is needed for the initiation and the amount of time operators will have to enact the deep well pump makeup strategy using the SBO generator.

c.

Provide any redundancy or defense in depth strategies if the operator action fails to manually close return header boundary isolation valve or takes too long in setting up the SCT basin makeup from the deep well pumps or circulating water flume.

d.

The importance of operator action for supplying the makeup water from deep well pumps and the circulating water flume to the SCT basin in terms of risk.

e.

The associated procedures and training that will be used to deploy the makeup strategy from the deep well pumps and circulating water flume.

Response

a.

As described in Enclosure 1 of the submittal, the LAR is specifically requesting to credit available makeup systems for the Ultimate Heat Sink (UHS) in accordance with the requirements of NRC Regulatory Guide 1.27, Rev. 2. The basis for compliance with the regulatory guide is that the UHS is credited as a heat sink to absorb reactor residual heat and essential station heat loads after a normal reactor shutdown or a shutdown following an accident or transient including a loss of coolant accident (LOCA).The events requiring use of FLEX components, the fire protection piping and components, and the Station Blackout Diesel (SBO) are Beyond-Design-Basis Events, i.e., FLEX, or are separately defined by the NRC for Station Blackout, RG 1.155, and within the RBS USAR. Each of the events are considered separate from the requirements related to the UHS as defined in NRC RG 1.27, Rev. 2 and are considered mutually exclusive.

No modifications to existing FLEX or SBO strategies are required. All actions are initiated from separate existing plant procedures.

b.

Specific actions for supplying power to the deep well pumps via the station blackout diesel are detailed in site procedure AOP-0004 attachment 14. The SBO diesel is staged at the fire water pump house (location of the deep well pump motor control centers) and connected to welding receptacles to provide power to the MCCs. The required breaker is then closed and the SBO diesel is started to provide power to the deep well pump.

As indicated in section 2.5 of Enclosure 1, replenishment of the UHS basin is not required until day 10 following the event. The SBO diesel generator and FLEX equipment, including cables and hoses are stored on site and are readily available for installation. The actions are procedurally driven, and operators are trained to implement the strategies. The SBO Diesel and portable pumps are mounted on trailers and easily transported to their location with readily available on-site vehicles. The transport route uses recognized travel paths and is typically less than a mile in distance. Entergy estimates that transport, repowering the deep well pumps from the SBO generator, and/or operation of the portable fire pumps with suction from the circulating water flume

CNRO2025-00028 Page 8 of 9 could be accomplished well within the time frame required, as the nature of the actions is such that implementation within one shift would be easily accomplished.

c.

Procedural direction provided in site procedure, AOP-0004, would direct operators to close an additional manual return header isolation valve, if necessary, to isolate the header. Also, as provided in the response to b) above, sufficient time is available within the 10 day period prior to requiring the initiation of makeup, to ensure transport and setup of either the SBO Diesel or the portable diesel powered fire pumps at the circulating water flume. Connection of hoses to and from the pumps and fire protection system is straight forward with all hoses and required connections stored in the FLEX buildings. Note that analysis has indicated that mission dose is acceptable after 4-days post-DBA, as such there is a 6 day period in which makeup water equipment can be installed and makeup flow started.

d.

The operator action, as discussed in Enclosure 1 of the LAR, would not typically be evaluated in terms of risk. PRA risk typically evaluates actions or events within an initial 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period. As described in the submittal makeup to the cooling tower is not required until day-10 post-accident.

e.

Site procedure AOP-0004, Loss of Offsite Power, specifies the requirements and time frame for makeup to the UHS. The procedure contains multiple attachments with detailed instructions on repowering the makeup water pumps and providing makeup to the cooling tower as well as locating, setup and operation of the portable fire pumps at the circulating water flume. Operator training and qualification is performed using the procedure instructions and operators are qualified using On-the-Job-Training (OJT) per qualification requirements specified in ROJT-NLO-QC001, QC002 & QC006. AOP-0004 is included in Attachment 3. The relevant operator OJTs are included in Attachment 4.

Questions from Instrumentation and Controls (EICB)

EICB-RAI 1 In its license amendment request, the licensee proposed to increase the water level of the UHS cooling tower basin from greater than or equal to 78% to greater than or equal to 82.6%. The NRC staff requests the licensee to describe the following:

a) Methodology and sources of data used to account for instrument channel uncertainty, including accuracy and drift, for the devices in the level measurement channel of the cooling tower basin.

Response

The method of determining the loop drift error is derived from the General Electric Setpoint Methodology and specified in the instrument setpoint calculations. The allowance between the process safety limit and the limiting safety system settings is determined by the accuracy errors, calibration errors and environmental effect errors etc. These are combined using the square root, sum of the squares, method.

CNRO2025-00028 Page 9 of 9 The current Technical Specification value of 111 ft.-10 in. includes a minimum water level alarm at 115 ft.-8.5 in. and a limiting safety system setting of 115 ft.-3 in. with a process safety limit 114 ft. -5 in. These values will be updated in accordance with the requested Technical Specification value of 114 ft.-5 in.

CNRO2025-00028 Procedure AOP-0004 "Loss of Offsite Power" (95 Pages Follow)

CONTINUOUS USE RIVER BEND STATION STATION OPERATING MANUAL

ABNORMAL OPERATING PROCEDURE

LOSS OF OFFSITE POWER PROCEDURE NUMBER:

AOP-0004 REVISION NUMBER:

078 Effective Date:

05/07/2025 NOTE : SIGNATURES ARE ON FILE.

TemRev 2 AddCounter 46 Att Enc DS MSet REGULAR KWN OFF CONTINUOUS USE

INDEXING INFORMATION

CONTINUOUS USE AOP-0004 REV - 078 PAGE 1 OF 94 TABLE OF CHANGES LETTER DESIGNATION TRACKING NUMBER DETAILED DESCRIPTION OF CHANGES AOP-0004R077EC-A Added a time limited action that was already in the body of the procedure to the time limited action list on Attachment 17. Refer to step 5.13.2 to secure redundant components with the failure of one division of the Standby Cooling Tower fans concurrent with a LOP/LOCA.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 2 OF 94 TABLE OF CONTENTS SECTION PAGE NO.

1 PURPOSE/DISCUSSION..........................................................................................................3 2

SYMPTOMS..............................................................................................................................3 3

AUTOMATIC ACTIONS..........................................................................................................3 4

IMMEDIATE OPERATOR ACTIONS.....................................................................................4 5

SUBSEQUENT OPERATOR ACTIONS..................................................................................4 6

REFERENCES...........................................................................................................................26 ATTACHMENT 1 - DIVISION I AND II TIMED SEQUENCED LOAD GUIDE........................27 ATTACHMENT 2 - DIVISION I AND II MANUALLY STARTED LOADS GUIDE..................31 ATTACHMENT 3 - DIVISION III LOAD GUIDE.........................................................................32 ATTACHMENT 4 - BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2.............................................33 ATTACHMENT 5 - BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2................................................43 ATTACHMENT 6 - ELECTRICAL LINEUP - MAIN TRANSFORMERS MTX-XM1 AND MTX-XM2..............................................................................................................53 ATTACHMENT 7 - ELECTRICAL LINEUP - NORMAL STATION SERVICE TRANSFORMERS (STX-XNS1A, 1B, AND 1C)..........................................................55 ATTACHMENT 8 - CONTROL BOARD LINEUP - MAIN TRANSFORMERS MTX-XM1 AND MTX-XM2.....................................................................................................56 ATTACHMENT 9 - CONTROL BOARD LINEUP - NORMAL STATION SERVICE TRANSFORMERS (STX-XNS1A, 1B, AND 1C)..........................................................57 ATTACHMENT 10 - MAIN GENERATOR PROTECTION TAGOUT........................................58 ATTACHMENT 11 - HIGH PRIORITY LOAD RESTORATION GUIDE....................................60 ATTACHMENT 12 - MAKEUP TO STANDBY COOLING TOWER WITH FIRE WATER.............................................................................................................................61 ATTACHMENT 13 - MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN...............................................................................................................63 ATTACHMENT 14 - MAKEUP TO STANDBY COOLING TOWER USING TEMPORARY POWER TO THE DEEPWELL PUMPS................................................72 ATTACHMENT 15 - OPERATION OF FPW-P4............................................................................75 ATTACHMENT 16 - OPERATION OF FLX-P3.............................................................................83 ATTACHMENT 17 - TIME LIMITED ACTIONS..........................................................................94

CONTINUOUS USE AOP-0004 REV - 078 PAGE 3 OF 94 1

PURPOSE/DISCUSSION 1.1 To provide instructions in event the Station Normal and Preferred Power Supplies are lost. The procedure directs operator actions for a Loss of Offsite Power (LOP) with or without a concurrent Loss of Coolant Accident (LOCA).

1.2 This procedure assumes at least Division I or Division II Diesel Generator has started, and is supplying its emergency bus. If the HPCS Diesel Generator is the only diesel running, actions are taken per AOP-0050, Station Blackout.

2 SYMPTOMS 2.1 Start of Division I, II, and III Diesel Generators.

2.2 All AC powered control room lighting goes off.

2.3 All operating AC powered equipment stops.

3 AUTOMATIC ACTIONS NOTE AC powered isolation MOVs do not close until the Diesel Generators reenergize the MCCs.

3.1 Reactor scram and isolation signals are generated due to the deenergization of the RPS buses.

3.2 Turbine trips from Main Generator trip.

3.3 Diesel generators for Division I, II, and III automatically start, normal supply breakers trip, and diesel output breakers close to reenergize their respective buses. Equipment is reenergized immediately or sequentially, per Attachment 1, Division I and II Timed Sequenced Load Guide.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 4 OF 94 4

IMMEDIATE OPERATOR ACTIONS 4.1 Manually initiate RCIC.

5 SUBSEQUENT OPERATOR ACTIONS 5.1 Request permission from the CRS to bypass the RCIC High Temperature Isolation signals as allowed by EOP-0005 Encl 33 (Ref. CR-RBS-2020-3193) 5.1.1.

IF CRS provides permission to bypass the RCIC High Temperature Isolation signals, THEN:

1.

At H13-P632, perform the following:

Place E31A-S2A, RCIC ISOLATION BYPASS Switch to BYPASS.

Place E31A-S4A, RHR ISOLATION BYPASS Switch to BYPASS.

2.

At H13-P642, perform the following:

Place E31A-S2B, RCIC ISOLATION BYPASS Switch to BYPASS.

Place E31A-S4B, RHR ISOLATION BYPASS Switch to BYPASS.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 5 OF 94 NOTES Section 5, Steps 5.2 through 5.17 may be performed concurrently as appropriate.

Refer to Attachment 17 for time limited actions.

5.2 Establish diesel generator operations as follows:

5.2.1.

For all diesel generators that started, perform the following:

Dispatch operator to locally monitor diesel generator operation per PEP-0026, Diesel Generator Operating Logs.

Verify all diesel generators are supplying their associated switchgear.

o IF the Division 1(2) Diesel Generator is running AND not supplying the switchgear, THEN Refer To OSP-0053, Emergency and Transient Response Support Procedure, A(2B) for Initiating Division 1(2) Standby Diesel Generator hard cards.

Verify initiation of the Standby Service Water System.

NOTE SWP-MOV96A(B), NORM SVCE WTR RETURN must be closed within 20 minutes to conserve Standby Cooling Tower inventory.

o IF SWP-MOV96A(B) NORM SVCE WTR RETURN can NOT be closed, THEN close SWP-V1213(V1212), A(B) RETURN HEADER ISOLATION.

IF a Loss of Div 1 SSW, THEN operate the following valves to isolate SSW Division I and place redundant SSW Division II in service:

CLOSE OPEN SWP-MOV74A, HVR-UC5 RETURN SWP-MOV74B, HVR-UC5 RETURN SWP-MOV506A, HPCS D/G RETURN SWP-MOV506B, HPCS D/G RETURN

CONTINUOUS USE AOP-0004 REV - 078 PAGE 6 OF 94 IF a Loss of Div 2 SSW, THEN operate the following valves to isolate SSW Division II and place redundant SSW Division I in service:

CLOSE OPEN SWP-MOV74B, HVR-UC5 RETURN SWP-MOV74A, HVR-UC5 RETURN SWP-MOV506B, HPCS D/G RETURN SWP-MOV506A, HPCS D/G RETURN Refer To AOP-0016, Loss of Standby Service Water for additional isolations.

Maintain generator load less than 3130 KW for Div I and Div II, and less than 2600 KW for the HPCS Diesel Generator.

5.2.2.

IF an Emergency Diesel was operating in parallel with Offsite power, THEN perform the following for the diesel that was paralleled:

1.

IF the Div I or II Diesel Generator was operating in parallel with Offsite power, THEN perform the following:

NOTE When the STBY DIESEL ENGINE A(B) EMERGENCY START pushbutton is depressed in the following step, all automatic shutdowns are bypassed except overspeed, generator differential, jacket water out high temperature, and lube oil out high temperature.

To bypass the diesel automatic shutdowns and reset the frequency and voltage, at H13-P877, depress the STBY DIESEL ENGINE A(B) EMERGENCY START pushbutton.

Check the generator steady state and frequency and voltage are:

58.8 Hz AND 60.2 HZ 3740 volts AND 4368 volts

CONTINUOUS USE AOP-0004 REV - 078 PAGE 7 OF 94 2.

IF the Div III Diesel Generator was operating in parallel with Offsite power, THEN, at H13-P601, adjust load and frequency as follows:

Using the HPCS DIESEL GENERATOR VOLTAGE REGULATOR CONT switch maintain voltage 3740 volts AND 4580 volts.

NOTE The Governor speed droop control is sensitive and must not be adjusted rapidly.

At the engine governor, set the speed droop setting to 0.

Using the HPCS DIESEL GENERATOR GOVERNOR CONTROL switch maintain frequency 58.8 Hz AND 60.2 Hz.

5.2.3.

IF any diesel generator is NOT operating, THEN perform the following:

1.

Attempt a manual emergency start of the failed diesel generator by depressing the Emergency Start pushbutton.

2.

IF the diesel generator tripped and locked out on ground fault while running parallel to the grid, AND it is determined the tripped diesel is required to mitigate the consequences of a LOP, THEN Refer To SOP-0053, Standby Diesel Generator and Auxiliaries, section for Manual Start of Standby Diesel with an Automatic Start Signal Present.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 8 OF 94 5.2.4.

IF the Div I or Div II Diesel Generator has tripped on high Jacket Water temperature OR high Lube Oil temperature, THEN perform the following as appropriate:

NOTE Valid trip signals can be verified on EGS-TI64A(B) at the following points or by local indictors near the Jacket Water and Lube Oil heat exchangers. Actual temperature may have drifted down slightly since diesel trip.

Jacket Water point #13 will indicate greater than or equal to 186F.

Lube Oil point #11 will indicate greater than or equal to 195F.

1.

IF trip signal was caused by spurious signal, THEN at EGS-PNL3A(B), place HIGH TEMPERATURE TRIP BYPASS Switch in BYPASS and restart the diesel per SOP-0053.

NOTE If jacket water/lube oil temperatures do not lower with SWP and the diesel running, the temperatures may be allowed to exceed the trip setpoint (JW 186F, LO 195F). However, JW/LO temperatures above 200F may result in damage to the diesel.

2.

IF trip signal was confirmed to be caused by high temperature, THEN perform the following:

1)

IF SWP is in operation, THEN verify Service Water flow through the Jacket Water and Lube Oil heat exchangers.

2)

At EGS-PNL3A(B), place HIGH TEMPERATURE TRIP BYPASS Switch in BYPASS.

3)

Restart the diesel per SOP-0053, section for Restoration of the Standby Diesel from a Tripped Condition.

4)

Verify Service Water flow is restored and jacket water/lube oil temperatures are lowering.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 9 OF 94 CAUTION Prolonged operation of an unloaded DG without cooling water can lead to permanent damage to the DG. Do not allow an unloaded DG to run for more than ten minutes without cooling water.

5.2.5.

IF a Diesel Generator is operating with a loss of SSW in its respective division, THEN perform the following:

1.

Start all available SSW Pumps.

2.

Close supply valves on equipment not required to be cooled in the failed division.

NOTE SSW loop flow may be read on SWP-FR60A(B). Normal SSW loop flow is 13,500 gpm with 2 pumps running and 7,500 gpm with one pump running.

3.

IF amperage can be maintained less than 66 amps, THEN perform the following:

1)

Open SWP-MOV505A and SWP-MOV505B, DIV I and DIV 2 CROSSTIE to cross tie SSW loops.

a)

IF SWP-MOV505A must be manually opened, THEN:

1. Secure the associated Diesel Generator.

2. Manually open SWP-MOV505A.

3. Verify SWP-MOV505B is open.

4. Restart the associated Diesel Generator per SOP-0053.

2)

Open SWP-MOV55A (B), STBY CLG TOWER 1 INLET in the failed division.

3)

Restart the required equipment in the failed division.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 10 OF 94 4.

IF amperage can NOT be maintained less than 66 amps, THEN perform the following:

1)

Trip the associated Diesel Generator.

2)

Secure the equipment in the failed division.

3)

Close SWP-MOV505A and SWP-MOV505B, DIV I and DIV 2 CROSSTIE.

4)

Close SWP-MOV55A(B), STBY CLG TOWER 1 INLET in the failed division.

5.2.6.

IF the Div III DG fails, causing a loss of SWP-P2C, THEN within 20 minutes begin reducing Div I SSW loading by starting the necessary redundant equipment serviced by Div II SSW, AND securing redundant Div I SSW loads as follows:

CAUTION The following operations add significant load to the Div II DG. Excessive loading and a subsequent trip of the Div II DG under these conditions will severely degrade plant recovery ability. Do not exceed 3130 KW on the Div II DG.

All components of Control Building HVAC per SOP-0058, Control Building HVAC System.

All components of Control Building Chilled Water per SOP-0066, Control Building HVAC Chilled Water System.

All components of Fuel Pool Cooling and Cleanup per SOP-0091, Fuel Pool Cooling and Cleanup Sys.

LSV-C3A, PVLC COMPRESSOR A.

IF a LOCA signal is NOT present, THEN perform the following:

1. Shut down HVR-UC1A, CONTMT UNIT CLR A.

2. Close SWP-MOV507A, DW/CONTMT UC SPLY ISOL.

3. Close SWP-MOV81A, DW/CONTMT UC RTN ISOL.

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CONTINUOUS USE AOP-0004 REV - 078 PAGE 11 OF 94 Close the following valves:

o SWP-MOV73A, HVR-UC5 SUPPLY o

SWP-MOV74A, HVR-UC5 RETURN o

SWP-MOV77A, HPCS DG SUPPLY o

SWP-MOV506A, HPCS DG RETURN o

SWP-MOV4A, DRYWELL UC SUPPLY o

SWP-MOV5A, DRYWELL UC RETURN o

SWP-MOV501A, RPCCW LOOP A SUPPLY o

SWP-MOV511A, RPCCW LOOP A RETURN IF LPCS is being maintained for long term cooling, THEN verify Div I SSW flow remains available to supply the Div I D/G and the following Aux Bldg unit coolers.

HVR-UC3, RPCCW, CRD Transfer and LPCS Hatch Areas HVR-UC6, LPCS Pump Room, RCIC Pump Room, RHR A Pump/HX Room HVR-UC7, EL 114', MCC West and RPCCW Area

CONTINUOUS USE AOP-0004 REV - 078 PAGE 12 OF 94 5.3 Verify automatic operation of ECCS.

CAUTION If ECCS is secured without resetting the associated logic systems, the ECCS System will not automatically reinitiate. Failure to automatically initiate could lead to loss of vessel inventory and core damage. Subsequent checks of controlling parameters are required when ECCS initiation logic is overridden. Do not manually secure ECCS Pumps without monitoring the controlling parameters until the initiation logic is reset.

NOTE Preferably, secure an ECCS Pump in the same electrical division supplying the Control Building HVAC System.

WHEN adequate core cooling is assured by at least two independent indications, THEN manually secure ECCS Pumps not required for adequate core cooling.

WHEN ECCS initiation signals are clear, THEN reset ECCS initiation signals.

NOTE River Bend design basis requires RHR to be in suppression pool cooling within 30 minutes of the initiation of a LOP/LOCA.

IF a RHR loop is available, THEN place one loop of RHR in the Suppression Pool Cooling Mode per SOP-0031, Residual Heat Removal.

Verify the line fill pumps for the secured ECCS Systems are running.

5.4 Notify Radiation Protection of RCIC and ECCS system operation, and any other plant condition which has the potential to impact plant radiological conditions.

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CONTINUOUS USE AOP-0004 REV - 078 PAGE 13 OF 94 5.5 Establish ventilation operations as follows:

5.5.1.

Within 10 minutes of a LOP, IF only a Div 2 Chilled Water Pump is running and the Div 2 chiller fails to start, THEN secure the Div 2 chilled water pump by taking the control switch for Div 2 HVK chilled water pump from AUTO to STOP.

NOTE Operating diesel generator load indication and Attachment 1, Division I and II Timed Sequenced Load Guide aid in selecting components for shutdown.

5.5.2.

Within 20 minutes of loss of power, verify automatic operation of the following ventilation systems and shut down redundant components as follows:

1.

Standby Gas Treatment:

1)

GTS-FN1A(B), SGT EXH FAN A(B) 2.

Control Building HVAC:

1)

HVC-ACU1A(B), CR AHU A(B) 2)

HVC-ACU2A(B), CONTROL BLDG AHU A(B) 3)

HVC-ACU3A(B), EQPT RM AHU A(B)

NOTE If no remote intake high radiation signal or level 2 LOCA signal is present, HVC-FN1A and FN1B may both be shut down.

4)

HVC-FN1A(B), CR FILTER UNIT FAN A(B)

CAUTION HVK-CHL1A/1B/1C/1D can be restarted after a LOP event within 20 minutes of the previous start. If HVK-CHL1A/1B/1C/1D is restarted after a LOP event within 20 minutes of the previous start, it is required to be run for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be secured for 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to allow the motor to cool before another start attempt. The additional start within 20 minutes should only be used during an actual LOP event.

5)

HVK-CHL1A(B)(C)(D), CONT BLDG CHILLER A(B)(C)(D)

CONTINUOUS USE AOP-0004 REV - 078 PAGE 14 OF 94 NOTE HVC-CH1A, CR AHU A HEATER will remain in STOP to prevent the loss of margin for the Div 1 D/G loading during LOP-LOCA conditions per EC 40578 and Calc E-192. The heater cycles based on the controller setting and should not be placed in START until Div 1 D/G loading margin is available.

6)

HVC-CH1A, CR AHU A HEATER 3.

Fuel Building HVAC:

1)

HVF-FN3A(B), EXH FLTR TRAIN 4.

Standby Cooling Tower:

NOTE The Standby Cooling Tower equipment room fans are 100%

capacity each, therefore only one fan per room is required.

HVY-FN1A is preferred for shutdown on Div I.

1)

HVY-FN1A(C), STBY CLG TWR PUMP RM A 2)

HVY-FN1B(D), STBY CLG TWR PUMP RM B 3)

HVY-FN2A(C), STBY CLG TWR SWGR RM A 4)

HVY-FN2B(D), STBY CLG TWR SWGR RM B 5.

Auxiliary Building Unit Coolers:

1)

HVR-UC11A(B), AUX BLDG UNIT CLR 11A(B).

NOTE Containment Unit Coolers will only start automatically following a LOP if a LOCA exists.

6.

IF a LOCA signal is NOT present, THEN shut down one HVR-UC1A (B)

CONTMT UNIT CLR A (B).

CONTINUOUS USE AOP-0004 REV - 078 PAGE 15 OF 94 NOTE 10 ft sections of rope for blocking/tying doors open can be found in the OSP-0066 tool box next to CB 98 elevation southwest stairs in the area between the T Tunnel 95elevation and the CB 98 elevation.

5.6 IF a loss of Control Building HVAC occurs, THEN within 30 minutes, perform the following:

Block open Control Room doors CB-136-09 and CB-136-10.

Block open Standby Switchgear Room 1A & 1B doors CB-098-08, CB-098-10, CB-098-11, and CB-098-18.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 16 OF 94 CAUTION The operations in Section 5.7 add significant load to the Standby Diesel Generators. Excessive loading and a subsequent trip of a Standby Diesel Generator under these conditions will severely degrade plant recovery ability. Do not exceed 3130 KW on the Standby Diesel Generators.

NOTES, Division I and II Manually Started Loads Guide should be used when loading the Standby Diesel Generators.

During a design basis LOP-LOCA, calculation E-192 anticipates that after 10 minutes, Low Pressure Core Spray (LPCS) will be secured (Div 1 EDG in service) or Residual Heat Removal (RHR) Pump C will be secured (Div 2 EDG in service) assuming that adequate core cooling is established by either reflooding the core above top of active fuel OR by reflooding the core to the jet pump suction with one core spray system in operation, in this case High Pressure Core Spray.

This action will create sufficient margin to allow necessary manual loads to be started without exceeding the continuous rating of 3130 kW for the Div 1 and Div 2 Diesel Generators.

5.7 Operation of Manual Loads 5.7.1.

IF a LOCA exists, THEN perform the following:

WHEN the turbine has been at standstill for at least 15 minutes, THEN lockout the EBOP to reduce battery load.

Operate Fuel Pool Cooling as follows:

1)

Locally monitor Fuel Storage/Area Pools and start a Fuel Pool Cooling Pump per SOP-0091, Fuel Pool Cooling and Cleanup to maintain pool temperature less than 140F.

2)

Within two hours of the LOCA event, cross connect SSW to RPCCW per SOP-0016, Reactor Plant Component Cooling Water System, and place the Fuel Pool Cooling System in service.

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CONTINUOUS USE AOP-0004 REV - 078 PAGE 17 OF 94 CAUTION A high starting current will occur when starting Standby Cooling Tower Fans which could trip the associated EHS-MCC16A(B). Do not start more than one bank of five Standby Cooling Tower Fans at a time.

Start the Standby Cooling Tower fans one hour into the LOP-LOCA.

Delay starting of all other loads listed on Attachment 2, Division I and II Manually Started Loads Guide for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after the LOCA event.

5.7.2.

IF a LOCA does NOT exist, THEN perform the following:

Restore Drywell Cooling as follows:

1)

Reset containment isolation signals.

2)

Open SWP-MOV4A(B), DRYWELL UC SUPPLY and SWP-MOV5A(B), DRYWELL UC RETURN.

3)

Place all DRYWELL UNIT CLR Switches to OFF.

NOTE Approximately 20 KW of security loads will be put on the respective diesel when EJS-ACB25(66), NHS-MCC102A(B)

SPLY BRKR is closed.

4)

Close EJS-ACB25(66), NHS-MCC102A(B) SPLY BRKR.

5)

Start the necessary Drywell Unit Coolers.

Restore Main Turbine Oil System as follows:

1)

Check 175 KW of load is available on Div II.

2) Close EJS-ACB50, NHS-MCC101 SPLY BRKR.

3)

Return EBOP and ESOP to standby auto condition.

4)

Verify Main Turbine is on the Turning Gear.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 18 OF 94 Restore Normal and Information Handling Battery Chargers as follows:

Close EJS-ACB09, BYS-CHGR1A Feeder Breaker.

Close EJS-ACB49, BYS-CHGR1B Feeder Breaker.

Close EJS-ACB77, IHS-CHGR1D Feeder Breaker.

IF Division II power is NOT available to IHS-SWG01D AND the Station Blackout Diesel is NOT needed to supply power to other vital plant loads, THEN consider using the Station Blackout Diesel via the backup charger, BYS-CHGR1D, to supply IHS-SWG01D.

Refer To SOP-0054, Station Blackout Diesel Generator, and SOP-0049, 125 VDC System.

Operate Fuel Pool Cooling as follows:

1)

Locally monitor Fuel Storage/Area Pools and start a Fuel Pool Cooling Pump per SOP-0091, Fuel Pool Cooling and Cleanup Sys to maintain pool temperature less than 140F.

2)

IF required to maintain Fuel Pool Temperatures, THEN cross connect SSW to RPCCW per SOP-0016, Reactor Plant Component Cooling Water System, and place the Fuel Pool Cooling System in service.

NOTE Rated alternate RPS power is 16 KW per division.

5.8 Refer To AOP-0010, Loss of One RPS Bus to restore power to the Reactor Protection System, Nuclear Steam Supply Shutoff System, Process Radiation Monitoring System, and Neutron Monitoring System.

5.9 Contact the System Operations Center to determine where fault exists and when service can be restored.

5.10 IF power is available at Fancy Point, but the preferred transformers are NOT available, THEN commence restoration of offsite power in accordance with, Backfeed to Normal Station Service Transformers Using MTX-XM1 and MTX-XM2

CONTINUOUS USE AOP-0004 REV - 078 PAGE 19 OF 94 5.11 IF the plant is in Modes 1, 2, or 3 AND the IFTS System is in operation, THEN direct the Designated IFTS Drain Valve Operator to close F42-MOVF003, IFTS DRAIN VALVE per FHP-0008, Fuel Transfer Tube Operations When in Modes 1, 2, or 3.

5.12 IF the plant is in Modes 1, 2, or 3 AND the IFTS Blind Flange is NOT installed AND the IFTS Bottom Valve is open, THEN dispatch the IFTS Teams to close the Bottom Valve per FHP-0008, Fuel Transfer Tube Operations When in Modes 1, 2, or 3, Attachment 12.

5.13 Standby Service Water Operations CAUTION A high starting current will occur when starting Standby Cooling Tower Fans which could trip the associated EHS-MCC16A(B). Do not start more than one bank of five Standby Cooling Tower Fans at a time.

5.13.1.

Start the Standby Cooling Tower fans necessary to maintain SSW header temperature less than 90F.

NOTE With the failure of one division of the Standby Cooling Tower Fans concurrent with a LOP/LOCA, heat input into the Standby Cooling Tower must be reduced to prevent exceeding the USAR limiting design maximum Standby Service Water temperature of 95°F.

5.13.2.

IF one division of the Standby Cooling Tower Fans fails, THEN perform the following within one hour of the failure:

Remove the RHR Heat Exchanger, Containment Unit Cooler, and Drywell Unit Cooler heat loads from the division of SSW with the failed fans.

IF Division 1 Standby Cooling Tower Fans fail, THEN perform SOP-0042, Standby Service Water System, section for Transfer from Division 1 to Division 2.

IF Division 2 Standby Cooling Tower Fans fail, THEN perform SOP-0042, Standby Service Water System, section for Transfer from Division 2 to Division 1.

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CONTINUOUS USE AOP-0004 REV - 078 PAGE 20 OF 94 NOTE With the operation of both divisions of Standby Service Water concurrent with a LOCA, makeup to the Standby cooling tower will be required within 10 days to prevent exceeding the USAR design limits.

Required makeup initiated at 10 days post DBA is 125 gpm.

5.13.3.

Provide make up water to the Standby Cooling Tower as needed using external sources prior to 90 ft in the Standby Cooling Tower as follows:

Utilizing the Fire Water Storage Tanks per Attachment 12, Makeup to Standby Cooling Tower with Fire Water.

Temporary power to the deepwell pump using the SBO diesel as available per Attachment 14, Makeup to Standby Cooling Tower Using Temporary Power to the Deepwell Pumps.

Temporary pumps and piping to transfer water from the Circ Water Flume per Attachment 13, Makeup to Standby Cooling Tower from Circ Water Basin Tank trucks to carry water from a nearby supply.

5.13.4.

IF both divisions of Standby Service Water are operating, THEN perform the following:

1.

At 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months post LOCA, perform the following:

Secure Standby Service Water to the Division 2 RHR Heat Exchangers.

Secure HVR-UC1B, CONTMT UNIT CLR B.

Perform SOP-0042, Standby Service Water System, section for Transfer from Division 2 to Division 1.

2.

At 90 ft Standby Cooling Tower water level, perform the following:

Reduce Standby Service Water flow through the Division 1 RHR Heat Exchangers to 3000 gpm.

Secure Standby Service Water to the Division 2 RHR Heat Exchangers.

Secure HVR-UC1B, CONTMT UNIT CLR B.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 21 OF 94 5.14 IF the power outage is expected to exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND no CRD pumps are available, THEN isolate the Reference Leg Backfill System per SOP-0001, Nuclear Boiler Instrumentation.

5.15 IF the power outage is expected to exceed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , THEN perform the following additional items:

Request delivery of diesel fuel.

Fill diesel generator storage tanks per SOP-0053, Standby Diesel Generator And Auxiliaries, and SOP-0052, HPCS Diesel Generator, while observing the following:

Verify the Day tank is full prior to refilling its associated fuel oil storage tank.

Fill the storage tanks on a staggered basis to avoid fuel oil cross contamination.

Allow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months of continuous operation before fill of the first Div I or II storage tank.

Allow an additional 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months settling period before fill of the remaining Div I or II storage tank.

Fill the Div III tank last.

Maintain diesel lube oil levels.

IF the AC powered seal oil pumps are NOT operating, THEN:

1.

Vent hydrogen from the Main Generator by performing the following:

1)

Open GMH-G-02, GENERATOR H2 VENT HEADER ISOLATION.

2)

Open GMH-G-03, GENERATOR H2 VENT HEADER ISOLATION.

2.

Shut down the ESOP.

5.16 IF the power outage is expected to last greater than 2,000 hours0 days 0 hours 0 weeks 0 months , THEN perform the following additional items:

Request portable diesel generator units.

WHEN permanent diesel generators require overhaul, THEN remove them from service.

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CONTINUOUS USE AOP-0004 REV - 078 PAGE 22 OF 94 5.17 WHEN offsite power is available, THEN restore offsite power to the plant as follows:

NOTE This Section implements SOER 03-1 Recommendation 2 Emergency Power Reliability. (Ref. 6.4 )

5.17.1.

Establish communications and coordinate restoration with the System Operator.

5.17.2.

Locate and isolate any fault by opening the proper breakers and disconnects.

5.17.3.

Reset all tripped protective relays and document relay targets per SOP-0080, POST TRIP CHECKS AND RESETS ON RSS#1, RSS#2, AND MAIN GENERATOR/UNIT PROTECTION Attachment.

5.17.4.

At H13-P808, verify the following transformer output breakers are open:

NPS-ACB09, 13.8 KV NORM SUPPLY BRKR NPS-ACB25, 13.8 KV NORM SUPPLY BRKR NNS-ACB06, 4160V NORM SUPPLY BRKR NNS-ACB14, 4160V NORM SUPPLY BRKR NPS-ACB11, 13.8 KV PFD SUPPLY BRKR NPS-ACB27, 13.8 KV PFD SUPPLY BRKR NNS-ACB07, 4160V PFD SUPPLY BRKR NNS-ACB15, 4160V PFD SUPPLY BRKR On NPS-SWG1C, NPS-ACB43 On NPS-SWG1D, NPS-ACB44

CONTINUOUS USE AOP-0004 REV - 078 PAGE 23 OF 94 5.17.5.

At H13-P808, for the following breakers, depress the TRIP pushbutton to reset the breaker trip AND verify the breaker amber light is off:

NPS-ACB09, 13.8 KV NORM SUPPLY BRKR NPS-ACB25, 13.8 KV NORM SUPPLY BRKR NNS-ACB06, 4160V NORM SUPPLY BRKR NNS-ACB14, 4160V NORM SUPPLY BRKR NPS-ACB11, 13.8 KV PFD SUPPLY BRKR NPS-ACB27, 13.8 KV PFD SUPPLY BRKR NNS-ACB07, 4160V PFD SUPPLY BRKR NNS-ACB15, 4160V PFD SUPPLY BRKR 5.17.6.

At H13-P870, depress the LOCKOUT Pushbutton for the following pumps:

CCS-P1A, TPCCW PUMP 1A CCS-P1B, TPCCW PUMP 1B CCS-P1C, TPCCW PUMP 1C CCP-P1A, RPCCW PUMP 1A CCP-P1B, RPCCW PUMP 1B CCP-P1C, RPCCW PUMP 1C GMC-SCPM-A, STATOR CLG WTR PUMP A GMC-SCPM-B, STATOR CLG WTR PUMP B TMB-HFPM-A, EHC PUMP A TMB-HFPM-B, EHC PUMP B

CONTINUOUS USE AOP-0004 REV - 078 PAGE 24 OF 94 5.17.7.

At H13-P808, SUM-PNL1, verify lockout indication for the following pumps:

SWC-P1A LOCKOUT SWC-P1B LOCKOUT SWC-P1C LOCKOUT SWP-P7A LOCKOUT SWP-P7B LOCKOUT SWP-P7C LOCKOUT NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

5.17.8.

At H13-P680, close the Preferred Station Service Transformer supply breakers as follows:

1.

Place PFD XFMR C & E SPLY SYNC SELECTOR SWITCH to N. BUS position.

2.

Close YWC-20620 to energize PFD STA SVCE XFMR C & E.

3.

Place PFD XFMR C & E SPLY SYNC SELECTOR SWITCH to S. BUS position.

4.

Close YWC-20610.

5.

Place PFD XFMR C & E SPLY SYNC SELECTOR SWITCH to OFF.

6.

Place PFD XFMR D & F SPLY SYNC SELECTOR SWITCH to N.

BUS position.

7.

Close YWC-20670 to energize PFD STA SVCE XFMR D & F.

8.

Place PFD XFMR D & F SPLY SYNC SELECTOR SWITCH to HORSESHOE position.

9.

Close YWC-20665.

10. Place PFD XFMR D & F SPLY SYNC SELECTOR SWITCH to OFF.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 25 OF 94 5.17.9.

At H13-P808, close the Preferred Station Transformer output breakers as follows:

1.

Select 13.8 KV on BUS A SYNC CHECK DEFEAT Switch.

2.

Close NPS-ACB11, 13.8 KV PFD SUPPLY BRKR for NPS-SWG1A.

3.

Select OFF on BUS A SYNC CHECK DEFEAT Switch.

4.

Select 4.16 KV on BUS A SYNC CHECK DEFEAT Switch.

5.

Close NNS-ACB07, 4160V PFD SUPPLY BRKR for NNS-SWG1A.

6.

Select OFF on BUS A SYNC CHECK DEFEAT Switch.

7.

Select 13.8 KV on BUS B SYNC CHECK DEFEAT Switch.

8.

Close NPS-ACB27, 13.8 KV PFD SUPPLY BRKR for NPS-SWG1B.

9.

Select OFF on BUS B SYNC CHECK DEFEAT Switch.

10. Select 4.16 KV on BUS B SYNC CHECK DEFEAT Switch.

11. Close NNS-ACB15, 4160V PFD SUPPLY BRKR for NNS-SWG1B.

12. Select OFF on BUS B SYNC CHECK DEFEAT Switch.

5.17.10.

Parallel ENS and E22 buses with offsite power per SOP-0053, Standby Diesel Generator and Auxiliaries, and SOP-0052, HPCS Diesel Generator.

5.17.11.

Restore transformer cooling equipment to normal per SOP-0055, Main and Station Transformers.

5.17.12.

Restart systems as desired per applicable SOPs.

5.17.13.

Restore diesel generators to the Standby mode after being loaded for the minimum time specified in SOP-0053, Standby Diesel Generator and Auxiliaries, and SOP-0052, HPCS Diesel Generator.

CONTINUOUS USE AOP-0004 REV - 078 PAGE 26 OF 94 5.18 IF a Transient has occurred as defined in OSP-0022, THEN gather and submit the following to training for evaluation. (CAPR CR-RBS-2015-4375)

Post transient alarms EN-OP-117, Operations Assessments Resources, transient snapshot assessments ERIS/SPDS TRA data Alarm typer data 6

REFERENCES 6.1 USAR Tables 8.3-1, 8.3-2a, 8.3-2b, 8.3-3 6.2 Calculations 6.2.1.

E-192 6.2.2.

G13.18.12.0*33 6.2.3.

G13.18.12.0*34 6.2.4.

G13.18.2.3-426 6.2.5.

G13.18.12.3*154 6.2.6.

4216.110-996-001 6.3 System Design Criteria 6.3.1.

309 6.3.2.

302 6.3.3.

209 6.3.4.

300/830 6.4 SOER 03-1 Recommendation2 Emergency Power Reliability 6.5 ER-RB-2003-0139-000 CAPR

CONTINUOUS USE ATTACHMENT 1 PAGE 1 OF 4 DIVISION I AND II TIMED SEQUENCED LOAD GUIDE AOP-0004 REV - 078 PAGE 27 OF 94 EQUIPMENT DESCRIPTION DIVISION I COMPONENT NUMBER DIVISION II COMPONENT NUMBER SEQUENCE KW RATING DIV I CONTROL BLDG CHILLED WTR PUMP HVK-P1A OR C 180 SEC/BKR CLOSURE 15.6 DIV II CONTROL BLDG CHILLED WTR PUMP HVK-P1B OR D 150 SEC/BKR CLOSURE 15.6 DIV I EQUIPMENT RM AIR COND UNIT HVC-ACU3A 180 SEC 2.1 DIV II EQUIPMENT RM AIR COND UNIT 150 SEC 2.1 CONTROL ROOM CHARCOAL FILTER FAN HVC-FN1A HVC-FN1B BKR CLOSURE 17.3 BATTERY RM EXH FAN HVC-FN3A/3D HVC-FN3B/3E BKR CLOSURE 1.1 DIV I CONTROL ROOM AIR COND UNIT HVC-ACU1A 180 SEC 49 DIV II CONTROL ROOM AIR COND UNIT HVC-ACU1B 150 SEC 49 DIV I STBY SWGR RM AIR COND UNIT HVC-ACU2A 180 SEC 53.2 DIV II STBY SWGR RM AIR COND UNIT HVC-ACU2B 150 SEC 53.2 NOTE Division I Control Building Chiller starts after a 30 second time delay if Division II is not running. This 30 seconds is in addition to the sequencing time.

DIV I CONTROL BLDG CHILLER HVK-CHL1A OR C 231 SEC 202.7 DIV II CONTROL BLDG CHILLER HVK-CHL1B OR D 201 SEC 202.7 DIV I CONTROL BLDG CHILLER - LUBE OIL PUMP HVK-CHL1APL OR CPL 180 SEC 1.4 DIV II CONTROL BLDG CHILLER -

LUBE OIL PUMP HVK-CHL1BPL OR DPL 150 SEC 1.4 DIV I CONTROL BLDG CHILLER - COND RECIRC PMP SWP-P3A OR C 200 SEC 5.9

CONTINUOUS USE ATTACHMENT 1 PAGE 2 OF 4 DIVISION I AND II TIMED SEQUENCED LOAD GUIDE AOP-0004 REV - 078 PAGE 28 OF 94 EQUIPMENT DESCRIPTION DIVISION I COMPONENT NUMBER DIVISION II COMPONENT NUMBER SEQUENCE KW RATING DIV II CONTROL BLDG CHILLER -

COND RECIRC PMP SWP-P3B OR D 170 SEC 5.9 DIV I STBY SWGR RM EXH FAN HVC-FN2A 180 SEC 18.3 DIV II STBY SWGR RM EXH FAN HVC-FN2B 150 SEC 18.3 AUX BLDG UNIT CLR HVR-UC2 N/A BKR CLOSURE 2.74 AUX BLDG UNIT CLR HVR-UC3 N/A BKR CLOSURE 4.6 AUX BLDG UNIT CLR HVR-UC6 N/A BKR CLOSURE 31.68 AUX BLDG UNIT CLR HVR-UC7 N/A BKR CLOSURE 9.9 AUX BLDG UNIT CLR HVR-UC8 N/A BKR CLOSURE 11.74 AUX BLDG UNIT CLR HVR-UC11A HVR-UC11B 20 SEC 54.3 AUX BLDG UNIT CLR N/A HVR-UC4 BKR CLOSURE 3.74 AUX BLDG UNIT CLR N/A HVR-UC9 BKR CLOSURE 21.09 AUX BLDG UNIT CLR N/A HVR-UC10 BKR CLOSURE 1.7 FUEL BLDG EXH FLTR TRAIN FAN HVF-FN3A HVF-FN3B BKR CLOSURE 25.4 STBY SERV WTR PUMPHOUSE FAN HVY-FN1A HVY-FN1B/D BKR CLOSURE 5.77 EACH STBY CLG TWR SWGR FAN HVY-FN2A/C HVY-FN2B/D BKR CLOSURE 1.82 EACH STBY CLG TWR REM INTAKE FAN HVY-FN32A HVY-FN32B BKR CLOSURE 3.1 STBY CLG TWR REM INTAKE HTR HVY-CH6A HVY-CH6B BKR CLOSURE 13.1

CONTINUOUS USE ATTACHMENT 1 PAGE 3 OF 4 DIVISION I AND II TIMED SEQUENCED LOAD GUIDE AOP-0004 REV - 078 PAGE 29 OF 94 EQUIPMENT DESCRIPTION DIVISION I COMPONENT NUMBER DIVISION II COMPONENT NUMBER SEQUENCE KW RATING VITAL BUS (UPS) INVERTER ENB-INV01A/01A1 ENB-INV01B/01B1 BKR CLOSURE 0

125 VDC BATTERY CHARGER ENB-CHGR1A ENB-CHGR1B BKR CLOSURE 47.5 RCIC LINE FILL PUMP E51-C003 N/A BKR CLOSURE 2.8 DIESEL EXCITER CLG FAN HVP-FN6A HVP-FN6B BKR CLOSURE 1.6 / 2.7 STBY D.G. REAR START AIR COMPRESSOR EGA-C4A EGA-C4B BKR CLOSURE 16.2 STBY D.G. FORWARD START AIR COMPRESSOR EGA-C5A EGA-C5B BKR CLOSURE 16.2 DIESEL FUEL TRANSF PUMP EGF-P1A EGF-P1B BKR CLOSURE 2.93 ECCS LINE FILL PMP E21-C002 E12-C003 BKR CLOSURE 2.2 /2.1 AUX BLDG FLOOR DRAIN PUMP N/A DFR-P5A,B,D,E BKR CLOSURE 2.8 EACH CONTMT MONITORING SAMPLE PUMP CMS-P7A CMS-P7B BKR CLOSURE 0.9 NOTE LAC-XLC9 has two sources of power from which it may select. It is normally connected to Div II Diesel Generator. On a failure of the Div II Diesel Generator it can be manually connected to the Div I Diesel Generator, when there is an available margin of 11.3 KW to ensure Div I Diesel Generator remains less than 3130 KW.

LIGHTING TRANSFORMER - CONTROL ROOM LAC-XLC9 BKR CLOSURE 11.3

CONTINUOUS USE ATTACHMENT 1 PAGE 4 OF 4 DIVISION I AND II TIMED SEQUENCED LOAD GUIDE AOP-0004 REV - 078 PAGE 30 OF 94 EQUIPMENT DESCRIPTION DIVISION I COMPONENT NUMBER DIVISION II COMPONENT NUMBER SEQUENCE KW RATING LPCS PUMP E21-C001 N/A 2 SEC 943.1 RHR A PUMP E12-C002A N/A 7 SEC 472.4 RHR B PUMP N/A E12-C002B 7 SEC 476.8 RHR C PUMP N/A E12-C002C 2 SEC 477.9 STDBY GAS TREAT FAN GTS-FN1A GTS-FN1B 30 SEC 44.91 DIESEL ROOM VENT FAN HVP-FN2A HVP-FN2B 24 SEC 34.3 STBY SERV WTR PUMP SWP-P2A N/A 60 SEC 328.8 STBY SERV WTR PUMP N/A SWP-P2D 60 SEC 279.3 STBY SERV WTR PUMP N/A SWP-P2B 30 SEC 269.7 CONTMT UNIT COOLER HVR-UC1A HVR-UC1B 600 SEC 96.6 LEAKAGE CONTROL AIR COMPR LSV-C3A LSV-C3B 590 SEC 43 NOTE Heaters cycle on and off periodically when in service.

HVC-CH1A, CR AHU A HEATER will remain in STOP to prevent the loss of margin for the Div 1 D/G loading during LOP-LOCA conditions per EC 40578 and Calc E-192. The heater cycles based on the controller setting and should not be placed in START until Div 1 D/G loading margin is available.

CONTROL ROOM HEATER HVC-CH1A HVC-CH1B 50 SEC 70.8

CONTINUOUS USE ATTACHMENT 2 PAGE 1 OF 1 DIVISION I AND II MANUALLY STARTED LOADS GUIDE AOP-0004 REV - 078 PAGE 31 OF 94 EQUIPMENT DESCRIPTION DIVISION I COMPONENT NUMBER DIVISION II COMPONENT NUMBER KW RATING STDBY CLG TWR FANS SWP-FN1 A/C/E/G/J/L/N/Q/S/U SWP-FN1 B/D/F/H/K/M/P/R/T/V 29.7 EACH FUEL POOL CLG PMP SFC-P1A SFC-P1B 60.6 HYDROGEN MXG FAN CPM-FN1A CPM-FN1B 0.9 STDBY LIQUID CONTROL PMP C41-C001A C41-C001B 28.4 HYDROGEN RECOMBINER HCS-RBNR1A HCS-RBNR1B 81.7 NORMAL BATTERY CHGRS BYS-CHGR1A IHS-CHGR1D BYS-CHGR1B 58.5 EACH AUX BLDG MCC NHS-MCC102A NHS-MCC102B 26.4 TURB BLDG MCC N/A NHS-MCC101 199.4 DRYWELL UNIT COOLERS DRS-UC1A/C/E DRS-UC1B/D/F 47.3 EACH CONTMT UNIT COOLER N/A HVR-UC1C 96.6 DECAY HT REM FN (CONT RM FILTER)

HVC-FN8A HVC-FN8B 0.3 DECAY HT REM FN (FUEL BLDG)

HVF-FN7A HVF-FN7B 0.3 DECAY HT REM FN (SGTS)

GTS-FN2A GTS-FN2B 0.3 H2 IGNITORS HCS-XD01A HCS-XD01B 15 H2 PURGE FAN N/A CPP-FN1 0.9

CONTINUOUS USE ATTACHMENT 3 PAGE 1 OF 1 DIVISION III LOAD GUIDE AOP-0004 REV - 078 PAGE 32 OF 94 EQUIPMENT DESCRIPTION COMPONENT NUMBER SEQUENCE KW RATING HIGH PRESS CORE SPRAY PUMP E22-C001 BKR CLOSURE 1862.4 BATTERY RM EXH FAN HVC-FN3C/F BKR CLOSURE 1.5 STANDBY SERV WTR PUMP SWP-P2C 30 SEC 325.4 AUX BLDG UNIT COOLER HVR-UC5 BKR CLOSURE 32.0 DIESEL ROOM VENT FAN HVP-FN3A BKR CLOSURE 76.2 VENTILATION SUPPLY FAN HVP-FN6C BKR CLOSURE 0.9 STANDBY GENERATOR FUEL TRANSFER PUMP EGF-P1C INTERMITTENT TO FILL DAY TANK 2.9 DIESEL GEN IMMERSION HTR E22-S001DGH BKR CLOSURE (TEMP CONTROL) 16.3 CIRCULATING OIL PMP CONTROL E22-S001COP BKR CLOSURE 1.0 DIV III HPCS Battery Charger E22-S001CGR BKR CLOSURE 20 STDBY SERV WTR PUMPHOUSE VENT FAN HVY-FN1C BKR CLOSURE (TEMPERATURE CONTROLLED) 5.77 MISC. 120VAC LOADS E22-S002PNL BKR CLOSURE 3.0 57.4 KW max coincident MOV load.

SSW PMP DSCH VLV SWP-MOV40C 30 SEC AFTER DG BKR CLOSURE 1.4 TURBOCHGR LUBE OIL PUMP E22-S001ACP BKR CLOSURE 0.9

CONTINUOUS USE ATTACHMENT 4 PAGE 1 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 33 OF 94 1

PURPOSE 1.1 The purpose of this attachment is to provide instructions for energizing Main Transformers, MTX-XM1 and XM2 from the 230 KV switchyard in the event of a loss of offsite power due to failure of preferred transformers. The main transformers will be used to provide temporary power to Normal Station Service Transformers, STX-XNS1A, B, and C, to energize 13.8 KV switchgear NPS-SWG1A and 1B, and 4.16 KV switchgear NNS-SWG1A, 1B, and 1C.

1.2 Refer To Attachment 5, Backfeed to Normal Station Service Transformers Using MTX-XM1 or MTX-XM2 if only one of the main transformer (MTX-XM1 OR MTX-XM2) will be used to provide backfeed contingency.

2 REFERENCES 2.1 INPO Operation and Maintenance Reminder #365 3

PRECAUTIONS AND LIMITATIONS 3.1 There is no permanently installed instrumentation to detect and provide an alarm for ground faults on the Isophase Bus System when aligned in this backfeed configuration.

Proper maintenance should be performed prior to backfeed in accordance with PMRQ 50036016-02 as directed by System Engineer.

3.2 This procedure will energize the Normal and Main Transformers without cooling for a short period of time. Before a transformer is loaded, the proper cooling must be placed in service immediately to prevent overheating. SOP-0055, Main and Station Transformers, provides instruction for operation of the transformer cooling equipment.

3.3 Performance of this procedure does not satisfy the requirement for a single source of offsite power per T.S. 3.8.2.

CONTINUOUS USE ATTACHMENT 4 PAGE 2 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 34 OF 94 4

PREREQUISITES 4.1 Check the following 125 VDC electrical switchgear and panels are available and energized:

125 VDC Switchgear BYS-SWG01A 125 VDC Switchgear BYS-SWG01B 125 VDC Panel BYS-PNL03A 125 VDC Panel BYS-PNL03B 125 VDC Panel BYS-PNL02A1 125 VDC Panel BYS-PNL02B1 4.2 Check power is available at either the North or South Bus at Fancy Point Switchyard.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

4.3 Verify Main Generator Output breakers are open.

4.4 Place Fire Protection Systems into service per SOP-0037, Fire Protection Water System Operating Procedure and align to Main Transformers, MTX-XM1 and XM2 and Normal Station Service Transformers, STX-XNS1A, XNS1B, and XNS1C.

CONTINUOUS USE ATTACHMENT 4 PAGE 3 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 35 OF 94 NOTE PMRQ 50036016-02 may be waived in emergency cases with concurrence from System Engineering and the Manager - Operations or Maintenance.

4.5 Perform one of the following:

Perform PMRQ 50036016-02 after deenergizing the isophase bus and prior to reenergizing the isophase bus for backfeed.

Obtain System Engineering and Manager - Operations or Maintenance concurrence to waive the performance of PMRQ 50036016-02.

(System Engineer Signature / Print)

(Manager - Operations or Maintenance sign/print) 4.6 Verify personnel briefing has been completed, identifying but not limited to, scope of procedure and safety hazards to equipment and personnel.

4.7 Obtain plant management permission to backfeed.

_________________________/_________

(Management signature / print Date)

CONTINUOUS USE ATTACHMENT 4 PAGE 4 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 36 OF 94 5

PROCEDURE 5.1 Instruct Electrical Maintenance to lift and isolate leads R50 and R54 at the Exciter cabinet (isolates Volts/Hertz and the Max Exc limit).

5.2 Tag out equipment listed on Attachment 10, Main Generator Protection Tagout.

WARNING Closing or opening disconnects under load is extremely dangerous. Do not close disconnects with the associated CBs closed.

NOTE Both North and South Bus disconnects may be closed. However, both sets of disconnects are not required to be closed.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

5.3 Verify the following 230KV switchyard lineups for North or South Bus feed:

IF North Bus feed is to be used, THEN perform the following:

1.

Verify open YWC-20640, BRKR 230 KV GEN.

2.

Verify closed disconnects 20641 and 20639 for North Bus Feed.

IF South Bus feed is to be used, THEN perform the following:

3.

Verify open YWC-20635, BRKR 230 KV GEN.

4.

Verify closed disconnects 20636 and 20629 for South Bus Feed.

CONTINUOUS USE ATTACHMENT 4 PAGE 5 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 37 OF 94 WARNING Closing or opening disconnects under load is extremely dangerous. Do not close Main Transformer disconnects with the associated load side breakers closed.

5.4 Verify open the following breakers:

NPS-ACB11, PFD STA SVCE XFMR RTX-XSR1E NPS-ACB07, AUX STA SVCE XFMR STX-XS2A NPS-ACB09, NORMAL STA SVCE XFMR STX-XNS1A NPS-ACB10, HV SWYDS MISC LOADS AUX STA SVCE XFMR STX-XS3A AND XS4A NPS-ACB13, RECIRC PMP MOT AUX STA SVCE XFMR RCS-X1A NPS-ACB14, CONDENSATE PMP MOT CNM-P1A NPS-ACB15, CONDENSATE PMP MOT CNM-P1C NPS-ACB12, REACTOR FEED PMP MOT FWS-P1A NPS-ACB16, LOAD CENTER XFMR'S NJS-X1A, XIC, AND X1S NPS-ACB04, LOAD CENTERS XFMR'S NJS-X1E, X1G, AND X1Q NPS-ACB03, LOAD CENTERS XFMR'S NJS-X1J, XIL, X1N, AND X1U NPS-ACB05, LOAD CENTER XFMR'S NJS-X2A, X2C, AND X3C NPS-ACB06, LOAD CENTER XFMR'S NJS-X2E, X2G, AND X3A NPS-ACB27, PFD STA SVCE XFMR RTX-XSR1F NPS-ACB23, AUX STA SVCE XFMR STX-XS2B NPS-ACB30, RECIRC PMP MOT AUX STA SVCE XFMR RCS-X1B NPS-ACB28, REACTOR FEED PMP MOT FWS-P1B NPS-ACB29, REACTOR FEED PMP MOT FWS-P1C

CONTINUOUS USE ATTACHMENT 4 PAGE 6 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 38 OF 94 NPS-ACB32, LOAD CENTER XFMRS NJS-X1B, X1F, AND X1T NPS-ACB33, LOAD CENTER XFMRS NJS-X1D, X1K, AND X1R NPS-ACB34, LOAD CENTER XFMRS NJS-X1P, X1H, X1M, AND X1V NPS-ACB22, LOAD CENTER XFMRS NJS-X2B, X2D, AND X3D NPS-ACB21, LOAD CENTER XFMRS NJS-X2F, X2H, AND X3B NPS-ACB31, CONDENSATE PMP MOT CNM-P1B NPS-ACB26, HV SWYDS MISC LOAD AUX STA SVCE XFMRS STX-XS3B AND XS4B NPS-ACB25, NORMAL STA SVCE XFMR STX-XNS1B NNS-ACB06, 4160V NORM SUPPLY BRKR NNS-ACB07, 4160V PFD SUPPLY BRKR NNS-ACB014, 4160V NORM SUPPLY BRKR NNS-ACB15, 4160V PFD SUPPLY BRKR ENS-ACB06, 4160V NORM SUPPLY BRKR ENS-ACB026, 4160V NORM SUPPLY BRKR 5.5 Verify closed the following Main Transformer disconnects:

5.5.1.

Disconnect 21215 5.5.2.

Disconnect 21214 5.6 Perform Attachment 6, Electrical Lineup - Main Transformers MTX-XM1 and MTX-XM2.

5.7 Verify non-essential personnel are clear from Main Transformer Yard and Turbine Building portion of the Isophase Bus Duct prior to energizing the Main Transformer.

5.8 Verify turbine trip isolated to generator lockout relay directed per Step 5.1.

CONTINUOUS USE ATTACHMENT 4 PAGE 7 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 39 OF 94 NOTE Only one of the Main Generator Breakers is required to be closed based on the offsite power supply from the North or South bus.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

5.9 Close the following Main Generator Breakers:

CB 20635 CB 20640 5.10 Close 13.8 KV Feeder Breaker NPS-SWG1A ACB09.

5.11 Record the following voltages on NPS-SWG1A Bus:

A-B VAC B-C VAC C-A VAC 5.12 Notify the OSM/CRS NPS-SWG1A is aligned to STX-XNS1A, NORMAL STATION SERVICE TRANSFORMER.

5.13 Close 13.8 KV Feeder Breaker NPS-SWG1B, ACB25.

5.14 Record the following voltages on NPS-SWG1B Bus:

A-B VAC B-C VAC C-A VAC

CONTINUOUS USE ATTACHMENT 4 PAGE 8 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 40 OF 94 5.15 Notify OSM/CRS NPS-SWG1B is aligned to STX-XNS1B, NORMAL STATION SERVICE TRANSFORMER.

5.16 Verify closed the following breakers:

NJS-ACB075, NHS-MCC1A SUPPLY BREAKER NJS-ACB084, NHS-MCC1B SUPPLY BREAKER NJS-ACB451, NHS-MCC10A1 SUPPLY BREAKER NHS-MCC1A BKR 1CT, SCA-PNL1A1 SUPPLY BREAKER NHS-MCC1B BKR 1BT, SCA-PNL1B1 SUPPLY BREAKER NHS-MCC10A1 BKR 1BT, SCA-PNL10A2 SUPPLY BREAKER NOTE Control switches for Main Transformer cooling equipment are located on Main Transformer Control Panel B. Control Switches for Normal Station Service Transformers are located on Control Panel B STX-XNS1A(1B) and Control Panel D STX-XNS1C.

5.17 Place Main Transformer and Normal Station Service Transformer cooling equipment in service as follows:

Close NJS-ACB450, NJS-LDC1U SUPPLY BREAKER.

Close NJS-ACB472, NJS-LDC1V SUPPLY BREAKER.

Close NJS-ACB071, NJS-LDC1E SUPPLY BREAKER.

Close NJS-ACB091, NJS-LDC1F SUPPLY BREAKER.

CONTINUOUS USE ATTACHMENT 4 PAGE 9 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 41 OF 94 5.17.1.

Verify closed the following 480 VAC cooling supply breakers:

NJS-ACB458 for MTX-XM1 on NJS-SWG1U NJS-ACB468 for MTX-XM1 on NJS-SWG1V NJS-ACB456 for NHS-MCC20A on NJS-SWG1U NJS-ACB470 for NHS-MCC20B on NJS-SWG1V NJS-ACB078 for MTX-XM2 on NJS-SWG1E NJS-ACB085 for MTX-XM2 on NJS-SWG1F NHS-MCC20B Breaker 4A for STX-XNS1A NHS-MCC20B Breaker 4B for STX-XNS1B NHS-MCC20B Breaker 4C for STX-XNS1C NHS-MCC20A Breaker 5B for STX-XNS1A NHS-MCC20A Breaker 5A for STX-XNS1B NHS-MCC20A Breaker 5C for STX-XNS1C 5.17.2.

Perform Attachment 8, Control Board Lineup - Main Transformers MTX-XM1 and MTX-XM2.

5.17.3.

Perform Attachment 7, Electrical Lineup - Normal Station Service Transformers (STX-XNS1A, 1B, and 1C).

5.17.4.

Perform Attachment 9, Control Board Lineup - Normal Station Service Transformers (STX-XNS1A, 1B, and 1C).

5.18 Notify OSM/CRS transformer cooling is aligned.

5.19 Establish cooling by closing the following feeder breakers:

Close NPS-ACB03, LOAD CENTER XFMRS NJS-X1J, X1L, X1N, and X1U.

Close NPS-ACB04, LOAD CENTER XFMRS NJS-X1E, X1G, and X1Q.

Close NPS-ACB034, LOAD CENTER XFMRS NJS-X1P, X1H, X1M, and X1V.

Close NPS-ACB032, LOAD CENTER XFMRS NJS-X1T, X1B, and X1F.

CONTINUOUS USE ATTACHMENT 4 PAGE 10 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 42 OF 94 5.20 Energize NNS-SWG1A and 1B from the Normal Station Service Transformers per SOP-0046, 4.16 KV System.

5.21 Place Isophase Bus Duct Cooling into service per SOP-0067, Isolated Phase Bus Duct Cooling System.

6 RESTORATION 6.1 Transfer 13.8 KV SWGR from Normal Station Service Transformers to Preferred Station Service Transformers per SOP-0045, 13.8 KV System.

6.2 Transfer 4.16KV SWGR from Normal Station Service Transformers to Preferred Station Service Transformers per SOP-0046, 4.16 KV System.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

6.3 Open the following Main Generator Breakers:

CB 20635 CB 20640 6.4 Instruct Electrical Maintenance to unisolate and reland leads R50 and R54 at the Exciter cabinet (restoration from Step 5.1).

6.5 WHEN directed by the OSM/CRS, THEN restore the Main Generator and Main Transformers, MTX-XM1 and XM2.

CONTINUOUS USE ATTACHMENT 5 PAGE 1 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 43 OF 94 1

PURPOSE 1.1 The purpose of this attachment is to provide instructions for energizing Main Transformers, MTX-XM1 OR MTX-XM2 from the 230 KV switchyard in the event of a loss of offsite power due to failure of preferred transformers. The Main Transformers will be used to provide temporary power to Normal Station Service Transformers, STX-XNS1A, B, and C, to energize 13.8 KV switchgear NPS-SWG1A and 1B, and 4.16 KV switchgear NNS-SWG1A, 1B, and 1C.

2 REFERENCES 2.1 INPO Operation and Maintenance Reminder #365 3

PRECAUTIONS AND LIMITATIONS 3.1 There is no permanently installed instrumentation to detect and provide an alarm for ground faults on the Isophase Bus System when aligned in this backfeed configuration.

Proper maintenance should be performed prior to backfeed in accordance with PMRQ 50036016-02 as directed by System Engineer.

3.2 This procedure will energize the Normal and Main Transformers without cooling for a short period of time. Before a transformer is loaded, the proper cooling equipment must be in operation to prevent overheating. SOP-0055, Main and Station Transformers, provides instruction for operation of the transformer cooling equipment.

3.3 Performance of this procedure does not satisfy the requirement for a single source of offsite power per T.S. 3.8.2.

CONTINUOUS USE ATTACHMENT 5 PAGE 2 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 44 OF 94 4

PREREQUISITES 4.1 Check the following 125 VDC electrical switchgear and panels are available and energized:

125 VDC Switchgear BYS-SWG01A 125 VDC Switchgear BYS-SWG01B 125 VDC Panel BYS-PNL03A 125 VDC Panel BYS-PNL03B 125 VDC Panel BYS-PNL02A1 125 VDC Panel BYS-PNL02B1 4.2 Check power is available at either the North or South Bus at Fancy Point Switchyard.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

4.3 Verify Main Generator Output breakers are open.

4.4 Place Fire Protection Systems into service per SOP-0037, Fire Protection Water System Operating Procedure and align to Main Transformers, MTX-XM1 OR MTX-XM2 and Normal Station Service Transformers, STX-XNS1A, XNS1B, and XNS1C.

CONTINUOUS USE ATTACHMENT 5 PAGE 3 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 45 OF 94 NOTE PMRQ 50036016-02 may be waived in emergency cases with concurrence from System Engineering and the Manager - Operations or Maintenance.

4.5 Perform one of the following:

Perform PMRQ 50036016-02 after deenergizing the isophase bus and prior to reenergizing the isophase bus for backfeed.

Obtain System Engineering and Manager - Operations or Maintenance concurrence to waive the performance of PMRQ 50036016-02.

(System Engineer Signature / Print)

(Manager - Operations or Maintenance sign/print) 4.6 Verify personnel briefing has been completed, identifying but not limited to, scope of procedure and safety hazards to equipment and personnel.

4.7 Identify Main Transformer to be used for backfeed.

MTX-XM1 / MTX-XM2. (Circle one) 4.8 Obtain plant management permission to backfeed.

_________________________/_________

(Management signature / print Date)

CONTINUOUS USE ATTACHMENT 5 PAGE 4 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 46 OF 94 5

PROCEDURE 5.1 Instruct Electrical Maintenance to lift and isolate leads R50 and R54 at the Exciter cabinet (isolates Volts/Hertz and the Max Exc limit).

5.2 Tag out equipment listed on Attachment 10, Main Generator Protection Tagout and perform Attachment 10 step 1.1 to use MTX-XM1 OR step 1.2 to use MTX-XM2 WARNING Closing or opening disconnects under load is extremely dangerous. Do not close disconnects with the associated CBs closed.

NOTE Both North and South Bus disconnects may be closed. However, both sets of disconnects are not required to be closed.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

5.3 Verify the following 230KV switchyard lineups for North or South Bus feed:

IF North Bus feed is to be used, THEN perform the following:

1.

Verify open YWC-20640, BRKR 230 KV GEN.

2.

Verify closed disconnects 20641 and 20639 for North Bus Feed.

IF South Bus feed is to be used, THEN perform the following:

3.

Verify open YWC-20635, BRKR 230 KV GEN.

4.

Verify closed disconnects 20636 and 20629 for South Bus Feed.

CONTINUOUS USE ATTACHMENT 5 PAGE 5 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 47 OF 94 WARNING Closing or opening disconnects under load is extremely dangerous. Do not close Main Transformer disconnects with the associated load side breakers closed.

5.4 Verify open the following breakers:

NPS-ACB11, PFD STA SVCE XFMR RTX-XSR1E NPS-ACB07, AUX STA SVCE XFMR STX-XS2A NPS-ACB09, NORMAL STA SVCE XFMR STX-XNS1A NPS-ACB10, HV SWYDS MISC LOADS AUX STA SVCE XFMR STX-XS3A AND XS4A NPS-ACB13, RECIRC PMP MOT AUX STA SVCE XFMR RCS-X1A NPS-ACB14, CONDENSATE PMP MOT CNM-P1A NPS-ACB15, CONDENSATE PMP MOT CNM-P1C NPS-ACB12, REACTOR FEED PMP MOT FWS-P1A NPS-ACB16, LOAD CENTER XFMR'S NJS-X1A, XIC, AND X1S NPS-ACB04, LOAD CENTERS XFMR'S NJS-X1E, X1G, AND X1Q NPS-ACB03, LOAD CENTERS XFMR'S NJS-X1J, XIL, X1N, AND X1U NPS-ACB05, LOAD CENTER XFMR'S NJS-X2A, X2C, AND X3C NPS-ACB06, LOAD CENTER XFMR'S NJS-X2E, X2G, AND X3A NPS-ACB27, PFD STA SVCE XFMR RTX-XSR1F NPS-ACB23, AUX STA SVCE XFMR STX-XS2B NPS-ACB30, RECIRC PMP MOT AUX STA SVCE XFMR RCS-X1B NPS-ACB28, REACTOR FEED PMP MOT FWS-P1B NPS-ACB29, REACTOR FEED PMP MOT FWS-P1C

CONTINUOUS USE ATTACHMENT 5 PAGE 6 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 48 OF 94 NPS-ACB32, LOAD CENTER XFMRS NJS-X1B, X1F, AND X1T NPS-ACB33, LOAD CENTER XFMRS NJS-X1D, X1K, AND X1R NPS-ACB34, LOAD CENTER XFMRS NJS-X1P, X1H, X1M, AND X1V NPS-ACB22, LOAD CENTER XFMRS NJS-X2B, X2D, AND X3D NPS-ACB21, LOAD CENTER XFMRS NJS-X2F, X2H, AND X3B NPS-ACB31, CONDENSATE PMP MOT CNM-P1B NPS-ACB26, HV SWYDS MISC LOAD AUX STA SVCE XFMRS STX-XS3B AND XS4B NPS-ACB25, NORMAL STA SVCE XFMR STX-XNS1B NNS-ACB06, 4160V NORM SUPPLY BRKR NNS-ACB07, 4160V PFD SUPPLY BRKR NNS-ACB014, 4160V NORM SUPPLY BRKR NNS-ACB15, 4160V PFD SUPPLY BRKR ENS-ACB06, 4160V NORM SUPPLY BRKR ENS-ACB026, 4160V NORM SUPPLY BRKR 5.5 Verify closed one of the following Main Transformer disconnects:

Disconnect 21214 if using MTX-XM1 Disconnect 21215 if using MTX-XM2 5.6 Perform applicable portions of Attachment 6, Electrical Lineup - Main Transformers MTX-XM1 and MTX-XM2 for the Main Transformer being lined up.

5.7 Verify non-essential personnel are clear from Main Transformer Yard and Turbine Building portion of the Isophase Bus Duct prior to energizing the Main Transformer.

5.8 Verify turbine trip isolated to generator lockout relay directed per Step 5.1.

CONTINUOUS USE ATTACHMENT 5 PAGE 7 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 49 OF 94 NOTE Only one of the Main Generator Breakers is required to be closed based on the offsite power supply from the North or South bus.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

5.9 Close the following Main Generator Breakers:

CB 20635 CB 20640 5.10 Close 13.8 KV Feeder Breaker NPS-SWG1A ACB09.

5.11 Record the following voltages on NPS-SWG1A Bus:

A-B VAC B-C VAC C-A VAC 5.12 Notify the OSM/CRS NPS-SWG1A is aligned to STX-XNS1A, NORMAL STATION SERVICE TRANSFORMER.

5.13 Close 13.8 KV Feeder Breaker NPS-SWG1B, ACB25.

5.14 Record the following voltages on NPS-SWG1B Bus:

A-B VAC B-C VAC C-A VAC

CONTINUOUS USE ATTACHMENT 5 PAGE 8 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 50 OF 94 5.15 Notify OSM/CRS NPS-SWG1B is aligned to STX-XNS1B, NORMAL STATION SERVICE TRANSFORMER.

5.16 Verify closed the following breakers:

NJS-ACB075, NHS-MCC1A SUPPLY BREAKER NJS-ACB084, NHS-MCC1B SUPPLY BREAKER NJS-ACB451, NHS-MCC10A1 SUPPLY BREAKER NHS-MCC1A BKR 1CT, SCA-PNL1A1 SUPPLY BREAKER NHS-MCC1B BKR 1BT, SCA-PNL1B1 SUPPLY BREAKER NHS-MCC10A1 BKR 1BT, SCA-PNL10A2 SUPPLY BREAKER NOTE Control switches for Main Transformer cooling equipment are located on Main Transformer Control Panel B. Control Switches for Normal Station Service Transformers are located on Control Panel B STX-XNS1A(1B) and Control Panel D STX-XNS1C.

5.17 Place Main Transformer and Normal Station Service Transformer cooling equipment in service as follows:

Close NJS-ACB450, NJS-LDC1U SUPPLY BREAKER.

Close NJS-ACB472, NJS-LDC1V SUPPLY BREAKER.

Close NJS-ACB071, NJS-LDC1E SUPPLY BREAKER.

Close NJS-ACB091, NJS-LDC1F SUPPLY BREAKER.

5.17.1.

IF using MTX-XM1, THEN verify closed the following 480 VAC cooling supply breakers:

NJS-ACB458 for MTX-XM1 on NJS-SWG1U NJS-ACB468 for MTX-XM1 on NJS-SWG1V

CONTINUOUS USE ATTACHMENT 5 PAGE 9 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 51 OF 94 5.17.2.

IF using MTX-XM2, THEN verify closed the following 480 VAC cooling supply breakers:

NJS-ACB078 for MTX-XM2 on NJS-SWG1E NJS-ACB085 for MTX-XM2 on NJS-SWG1F 5.17.3.

Verify closed the following 480VAC cooling supply breakers for the Normal Station Service Transformers:

NJS-ACB456 for NHS-MCC20A on NJS-SWG1U NJS-ACB470 for NHS-MCC20B on NJS-SWG1V NHS-MCC20B Breaker 4A for STX-XNS1A NHS-MCC20B Breaker 4B for STX-XNS1B NHS-MCC20B Breaker 4C for STX-XNS1C NHS-MCC20A Breaker 5B for STX-XNS1A NHS-MCC20A Breaker 5A for STX-XNS1B NHS-MCC20A Breaker 5C for STX-XNS1C 5.17.4.

Perform Attachment 8, Control Board Lineup - Main Transformers MTX-XM1 and MTX-XM2.

5.17.5.

Perform Attachment 7, Electrical Lineup - Normal Station Service Transformers (STX-XNS1A, 1B, and 1C).

5.17.6.

Perform Attachment 9, Control Board Lineup - Normal Station Service Transformers (STX-XNS1A, 1B, and 1C).

5.18 Notify OSM/CRS transformer cooling is aligned.

5.19 Establish cooling by closing the following breakers:

Close NPS-ACB03, LOAD CENTER XFMRS NJS-X1J, X1L, X1N, and X1U.

Close NPS-ACB04, LOAD CENTER XFMRS NJS-X1E, X1G, and X1Q.

Close NPS-ACB034, LOAD CENTER XFMRS NJS-X1P, X1H, X1M, and X1V.

Close NPS-ACB032, LOAD CENTER XFMRS NJS-X1T, X1B, and X1F.

CONTINUOUS USE ATTACHMENT 5 PAGE 10 OF 10 BACKFEED TO NORMAL STATION SERVICE TRANSFORMERS USING MTX-XM1 OR MTX-XM2 AOP-0004 REV - 078 PAGE 52 OF 94 5.20 Energize NNS-SWG1A and 1B from the Normal Station Service Transformers per SOP-0046, 4.16 KV System.

5.21 Place Isophase Bus Duct Cooling into service per SOP-0067, Isolated Phase Bus Duct Cooling System.

6 RESTORATION 6.1 Transfer 13.8 KV SWGR from Normal Station Service Transformers to Preferred Station Service Transformers per SOP-0045, 13.8 KV System.

6.2 Transfer 4.16KV SWGR from Normal Station Service Transformers to Preferred Station Service Transformers per SOP-0046, 4.16 KV System.

NOTE All Fancy Point substation breaker status indication lights on H13-P808-85B and H13-P680-9C are powered from SCA-PNL10A2 NHS-MCC10A1 NJS-LDC1U NPS-SWG1A. Breaker operation can be performed provided breaker control power is available and all permissives are met, however breaker status indication lights will not be available unless SCA-PNL10A2 is powered.

6.3 Open the following Main Generator Breakers:

CB 20635 CB 20640 6.4 Instruct Electrical Maintenance to unisolate and reland leads R50 and R54 at the Exciter cabinet (restoration from Step 5.1).

6.5 WHEN directed by the OSM/CRS, THEN restore the Main Generator and Main Transformers, MTX-XM1 and XM2.

CONTINUOUS USE ATTACHMENT 6 PAGE 1 OF 2 ELECTRICAL LINEUP - MAIN TRANSFORMERS MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 53 OF 94 EQUIPMENT NUMBER EQUIPMENT DESCRIPTION POWER SUPPLY REQD POSITION THE FOLLOWING ARE LOCATED ON MTX-XM1 CONTROL PANEL A GROUP 1 AND 3 MTX-XM1 COOLING FANS BRKR 8-14 OFF GROUP 1 AND 3 MTX-XM1COOLING FANS BRKR 8-13 ON GROUP 3 MTX-XM1 COOLING FANS BRKR 8-11 ON GROUP 1 MTX-XM1 COOLING FANS BRKR 8-9 ON COOLER 6 MTX-XM1 COOLING FANS BRKR 8-6 ON COOLER 5 MTX-XM1 COOLING FANS BRKR 8-5 ON COOLER 2 MTX-XM1 COOLING FANS BRKR 8-2 ON COOLER 1 MTX-XM1 COOLING FANS BRKR 8-1 ON GROUP 2 AND 4 MTX-XM1 COOLING FANS BRKR 8-16 OFF GROUP 2 AND 4 MTX-XM1 COOLING FANS BRKR 8-15 ON GROUP 4 MTX-XM1 COOLING FANS BRKR 8-12 ON GROUP 2 MTX-XM1 COOLING FANS BRKR 8-10 ON COOLER 8 MTX-XM1 COOLING FANS BRKR 8-8 ON COOLER 7 MTX-XM1 COOLING FANS BRKR 8-7 ON COOLER 4 MTX-XM1 COOLING FANS BRKR 8-4 ON COOLER 3 MTX-XM1 COOLING FANS BRKR 8-3 ON THE FOLLOWING ARE LOCATED ON MTX-XM1 CONTROL PANEL B GROUP 1, 2 AND 3 CONTROL SWITCHES POWER SUPPLY 8-17 ON THE FOLLOWING ARE LOCATED ON MTX-XM2 CONTROL PANEL A GROUP 1 AND 3 MTX-XM2 COOLING FANS BRKR 8-14 OFF GROUP 1 AND 3 MTX-XM2 COOLING FANS BRKR 8-13 ON GROUP 3 MTX-XM2 COOLING FANS BRKR 8-11 ON GROUP 1 MTX-XM2 COOLING FANS BRKR 8-9 ON COOLER 6 MTX-XM2 COOLING FANS BRKR 8-6 ON COOLER 5 MTX-XM2 COOLING FANS BRKR 8-5 ON COOLER 2 MTX-XM2 COOLING FANS BRKR 8-2 ON

CONTINUOUS USE ATTACHMENT 6 PAGE 2 OF 2 ELECTRICAL LINEUP - MAIN TRANSFORMERS MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 54 OF 94 EQUIPMENT NUMBER EQUIPMENT DESCRIPTION POWER SUPPLY REQD POSITION COOLER 1 MTX-XM2 COOLING FANS BRKR 8-1 ON GROUP 2 AND 4 MTX-XM2 COOLING FANS BRKR 8-16 OFF GROUP 2 AND 4 MTX-XM2 COOLING FANS BRKR 8-15 ON COOLER 8 MTX-XM2 COOLING FANS BRKR 8-8 ON GROUP 4 MTX-XM2 COOLING FANS BRKR 8-12 ON GROUP 2 MTX-XM2 COOLING FANS BRKR 8-10 ON COOLER 8 MTX-XM2 COOLING FAN BRKR 8-8 ON COOLER 7 MTX-XM2 COOLING FAN BRKR 8-7 ON COOLER 4 MTX-XM2 COOLING FAN BRKR 8-4 ON COOLER 3 MTX-XM2 COOLING FANS BRKR 8-3 ON THE FOLLOWING ARE LOCATED ON MTX-XM2 CONTROL PANEL B GROUP 1, 2 AND 3 CONTROL SWITCHES POWER SUPPLY 8-17 ON THE FOLLOWING BREAKERS ARE LOCATED ON THE ASSOCIATED PANELS SPUN02 UNIT TRIP RELAY CKT BYS-PNL03B DISC 10 ON SPUN03 SUDDEN PRESS TRIP RELAYS BYS-PNL03A DISC 9 ON SPUN04 ANTI-MOTORING PROTECTIVE CKT BYS-PNL02B1 DISC 17 ON STXA01 TRANSFER COOLING AUX PWR CONTROL SHUNT TRIPS SCA-PNL1A1 BKR 7 ON STXB01 TRANSFER COOLING AUX PWR CONTROL SHUNT TRIPS SCA-PNL1B1 BKR 1 ON YWCN02 230KV SWYD BREAKER INDICATION SCA-PNL10A2 BKR 7 ON SPGN07 GENERATOR PRIMARY TRIP RELAYS BYS-PNL03A DISC 7 ON SPRN08 GENERATOR BACKUP TRIP RELAYS BYS-PNL03B DISC 7 ON SPGN09 GENERATOR TRANSFER TRIP CIRCUIT BYS-PNL03A DISC 20 ON

CONTINUOUS USE ATTACHMENT 7 PAGE 1 OF 1 ELECTRICAL LINEUP - NORMAL STATION SERVICE TRANSFORMERS (STX-XNS1A, 1B, AND 1C)

AOP-0004 REV - 078 PAGE 55 OF 94 EQUIPMENT DESCRIPTION POWER SUPPLY REQD POSITION THE FOLLOWING ARE LOCATED ON STX-XNS1A CONTROL PANEL B GROUP 1 AND 2 STX-XNS1A COOLING FANS BRKR 8-2 OFF GROUP 1 AND 2 STX-XNS1A COOLING FANS BRKR 8-1 ON GROUP 1 STX-XNS1A OIL PPS SUPPLY BRKR 8-5 ON GROUP 2 STX-XNS1A OIL PPS SUPPLY BRKR 8-6 ON GROUP 3 STX-XNS1A COOLING FANS BRKR 8-4 OFF GROUP 3 STX-XNS1A COOLING FANS BRKR 8-3 ON GROUP 3 STX-XNS1A OIL PPS SUPPLY BRKR 8-7 ON GROUP 1, 2 AND 3 CONTROL SWITCH POWER SUPPLY 8-8 AND 8-9 ON THE FOLLOWING ARE LOCATED ON STX-XNS1B ON CONTROL PANEL B GROUP 1 AND 2 STX-XNS1B COOLING FANS BRKR 8-2 OFF GROUP 1 AND 2 STX-XNS1B COOLING FANS BRKR 8-1 ON GROUP 1 STX-XNS1B OIL PPS SUPPLY BRKR 8-5 ON GROUP 2 STX-XNS1B OIL PPS SUPPLY BRKR 8-6 ON GROUP 3 STX-XNS1B COOLING FANS BRKR 8-4 OFF GROUP 3 STX-XNS1B COOLING FANS BRKR 8-3 ON GROUP 3 STX-XNS1B OIL PPS SUPPLY BRKR 8-7 ON THE FOLLOWING ARE LOCATED AT STX-XNS1B INSIDE CONTROL PANEL B GROUP 1, 2 AND 3 CONTROL SWITCH POWER SUPPLY 8-8 AND 8-9 ON THE FOLLOWING ARE LOCATED IN STX-XNS1C ON CONTROL PANEL D GROUP 1 AND 2 STX-XNS1C COOLING FAN BRKR 8-2 ON GROUP 1 AND 2 STX-XNS1C COOLING FAN BRKR 8-1 ON GROUP 1 AND 2 STX-XNS1C COOLING FAN BRKR 8-3 ON GROUP 1 COOLING FANS AND OIL PUMPS SUPPLY BRKR 8-5 ON GROUP 2 COOLING FANS AND OIL PUMPS SUPPLY BRKR 8-6 ON THE FOLLOWING ARE LOCATED AT STX-XNS1C INSIDE CONTROL PANEL D GROUP 1 AND 2 CONTROL SWITCHES POWER SUPPLY 8-4 ON

CONTINUOUS USE ATTACHMENT 8 PAGE 1 OF 1 CONTROL BOARD LINEUP - MAIN TRANSFORMERS MTX-XM1 AND MTX-XM2 AOP-0004 REV - 078 PAGE 56 OF 94 PANEL ITEM PANEL ITEM POSITION THE FOLLOWING ARE LOCATED ON MTX-XM1 CONTROL PANEL B 43-1 AUTO 43-2 AUTO 43C-1 POS 1 OR POS 2 43C-2 GP 1/2 OR GP 3/4 THE FOLLOWING ARE LOCATED ON MTX-XM2 CONTROL PANEL B 43-1 AUTO 43-2 AUTO 43C-1 POS 1 OR POS 2 43C-2 GP 1/2 OR GP 3/4

CONTINUOUS USE ATTACHMENT 9 PAGE 1 OF 1 CONTROL BOARD LINEUP - NORMAL STATION SERVICE TRANSFORMERS (STX-XNS1A, 1B, AND 1C)

AOP-0004 REV - 078 PAGE 57 OF 94 PANEL ITEM PANEL ITEM POSITION THE FOLLOWING SWITCHES ARE LOCATED ON STX-XNS1A CONTROL PANEL B 5

ON 43 AUTO 43C POS 1 OR POS 2 THE FOLLOWING SWITCHES ARE LOCATED ON STX-XNS1B CONTROL PANEL B 5

ON 43 AUTO 43C POS 1 OR POS 2 THE FOLLOWING SWITCHES ARE LOCATED ON STX-XNS1C CONTROL PANEL D 43 AUTO 43C POS 1 OR POS 2

CONTINUOUS USE ATTACHMENT 10 PAGE 1 OF 2 MAIN GENERATOR PROTECTION TAGOUT AOP-0004 REV - 078 PAGE 58 OF 94 COMPONENT POSITION GROUND ON GENERATOR SIDE OF LINKS INSTALLED MAIN GENERATOR LEAD LINKS ØA REMOVED MAIN GENERATOR LEAD LINKS ØB REMOVED MAIN GENERATOR LEAD LINKS ØC REMOVED GENERATOR POTENTIAL TRANSFORMER ØA UPPER FUSE REMOVED GENERATOR POTENTIAL TRANSFORMER ØA LOWER FUSE REMOVED GENERATOR POTENTIAL TRANSFORMER ØB UPPER FUSE REMOVED GENERATOR POTENTIAL TRANSFORMER ØB LOWER FUSE REMOVED GENERATOR POTENTIAL TRANSFORMER ØC UPPER FUSE REMOVED GENERATOR POTENTIAL TRANSFORMER ØC LOWER FUSE REMOVED SPG-N08-21G RELAY REMOVED SPG-N08-40G RELAY REMOVED SPG-N08-32G RELAY REMOVED SPG-N04-32G1 RELAY REMOVED

CONTINUOUS USE ATTACHMENT 10 PAGE 2 OF 2 MAIN GENERATOR PROTECTION TAGOUT AOP-0004 REV - 078 PAGE 59 OF 94 1.1 IF MTX-XM1 will be the only transformer being energized, THEN have Electrical Maintenance perform the following on MTX-XM2 CTs:

Unit Differential CTs - In transformer MTX-XM2 cabinet, short terminals W74 to W75, W78 to W79, and W82 to W83. Remove and insulate wires W73, W77, and W81, delta jumper shall remain in place.

Transformer Differentials - Remove BDD relays 87M2A, 87M2B, 87M2C from CES-PNL1C (Relay Room 95 EL Turbine Building)

Pilot Wire Relaying - Open TS2 and isolate, located in lower left corner CES-PNL1C Neutral CTs - Open and isolate test switch TS right side blades ONLY, located in lower left corner CES-PNL1A.

1.2 IF MTX-XM2 will be the only transformer being energized, THEN have Electrical Maintenance perform the following on MTX-XM1 CTs:

Unit Differential CTs - In transformer MTX-XM1 cabinet, short terminals W74 to W75, W78 to W79, and W82 to W83. Remove and insulate wires W73, W77, and W81, delta jumper shall remain in place.

Transformer Differentials - Remove BDD relays 87M1A, 87M1B, 87M1C from CES-PNL1C (Relay Room 95 EL Turbine Building)

Pilot Wire Relaying - Open TS1 and isolate, located in lower left corner CES-PNL1C Neutral CTs - Open and isolate test switch TS left side blades ONLY, located in lower left corner CES-PNL1A.

CONTINUOUS USE ATTACHMENT 11 PAGE 1 OF 1 HIGH PRIORITY LOAD RESTORATION GUIDE AOP-0004 REV - 078 PAGE 60 OF 94 The following table provides a guideline for prioritizing the restoration of station loads.

HIGH PRIORITY LOAD REASON FOR RESTORATION POWER SUPPLY RPS A NORMAL SUPPLY ISOLATIONS NJS-LDC1U RPS B NORMAL SUPPLY ISOLATIONS NJS-LDC1D HVR-UC8 STM. TUNNEL TEMP.

EJS-SWG2A HVT-UC21A MSR AREA TEMP.

NJS-LDC1L HVT-UC21B MSR AREA TEMP.

NJS-LDC1M HVT-UC19A MSR AREA TEMP.

NJS-LDC1N HVT-UC19B MSR AREA TEMP.

NJS-LDC1F MSS-MOV35A ISOL. STEAM LOADS NJS-LDC1E MSS-MOV35B ISOL. STEAM LOADS NJS-LDC1F HVN-CHL1A Cooling to S.T. and MSRs NNS-SWG1A HVN-CHL1B Cooling to S.T. and MSRs NNS-SWG1B HVN-CHL1C Cooling to S.T. and MSRs NNS-SWG1C

CONTINUOUS USE ATTACHMENT 12 PAGE 1 OF 2 MAKEUP TO STANDBY COOLING TOWER WITH FIRE WATER AOP-0004 REV - 078 PAGE 61 OF 94 1

Perform the following to supply makeup to the Standby Cooling Tower with Fire Water:

(Ref. ER-RB-2002-0431) 1.1 Verify the Fire Protection System is not needed for fire fighting operations prior to continuing with this procedure.

1.2 Verify at least one of the Diesel Driven Fire Pumps is running.

1.3 Connect 21/2 inch fire hoses to one of the following.

FPW-FHY10, FIRE HYDRANT located on the East side of the Standby Cooling Tower FPW-FHY9, FIRE HYDRANT located on the West side of the Standby Cooling Tower.

1.4 Secure the fire hoses in a position to fill the Standby Cooling Tower.

1.5 IF using FPW-FHY10 THEN Open the FPW-FHY10 to establish a fill.

1.6 IF using FPW-FHY9 THEN Open the FPW-FHY9 to establish a fill.

NOTE Step 1.8 may be performed at any time during the performance of this procedure.

1.7 Provide makeup to the Fire Water Storage Tanks as needed per the following:

1.7.1.

Remove the SBO Diesel from the storage location and place at the east door of the Fire Pump House.

1.7.2.

Verify open NJS-LDC1J ACB136, NHS-MCC7A FIRE PROT PMP HOUSE supply breaker.

1.7.3.

Open all breakers on NHS-MCC7A except for BKR 2AR.

NOTE The temporary power cable is stored in the AOP-0004 toolbox in the Fire Pumphouse Building, in the Well Water Transfer and Domestic Water Pump Room.

1.7.4.

Connect the temporary power cable from the SBO Diesel to welding receptacle POP-WR7A01 for NHS-MCC7A.

CONTINUOUS USE ATTACHMENT 12 PAGE 2 OF 2 MAKEUP TO STANDBY COOLING TOWER WITH FIRE WATER AOP-0004 REV - 078 PAGE 62 OF 94 1.7.5.

Start the SBO Diesel per SOP-0054, Station Blackout Diesel Generator.

1.7.6.

Close NHS-MCC7A BKR 3C to start the Shallow Well Pump.

1.7.7.

Verify the Shallow Well Pump starts.

1.7.8.

WHEN makeup is no longer needed to the Fire Water Storage Tanks from the Shallow Well Pump, THEN perform the following:

1.

Open NHS-MCC7A BKR 3C to secure the Shallow Well Pump.

2.

Secure the SBO Diesel per SOP-0054.

3.

IF no additional makeup will be required, THEN disconnect the power cable.

4.

IF no additional makeup will be required, THEN place the SBO Diesel back in the normal storage location.

1.8 WHEN makeup is no longer needed to the Standby Cooling Tower, THEN perform the following:

1.8.1.

IF FPW-FHY10 was used THEN Close the FPW-FHY10.

1.8.2.

IF FPW-FHY9 was used THEN Close the FPW-FHY9.

1.8.3.

Disconnect hoses

CONTINUOUS USE ATTACHMENT 13 PAGE 1 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 63 OF 94 NOTE Section 1 performs Standby Cooling Tower makeup using FPW-FHY29. Section 2 performs Standby Cooling Tower makeup using FPW-FHY1. Only one section is required to be performed. Section 1 is the preferred method.

1 Align and operate a diesel driven pump to fill the Fire Water Header via Hydrant 29 as follows:

(Ref. ER-RB-2002-0431)

NOTE Hoses stored in the North or South FLEX Building will provide sufficient hose lengths for all required connections.

1.1 Obtain Diesel Driven Pump and place on the West side of the Circ Water Basin per one of the following:

Refer to Attachment 15, Operation of FPW-P4.

Refer to Attachment 16, Operation of FLX-P3.

1.2 Hook up the non collapsible hose to the pump suction from the CWS Basin.

1.3 Unplug AND open FPW-V3523, Flume to Fire Hydrant 29 Makeup Upper Vent Valve to relieve any pressure, THEN close FPW-V3523, Flume to Fire Hydrant 29 Makeup Upper Vent Valve.

1.4 Remove plugs from SOCA pipe upstream Wye connection.

1.5 Connect two 2 1/2 fire hoses from the discharge of the pump to the Wye connection of the upstream SOCA pipe.

1.6 Verify closed FPW-V3522, Flume to Fire Hydrant 29 Makeup Lower Vent Valve.

1.7 Verify closed and remove plugs at the downstream SOCA pipe Wye connections from the following valves:

FPW-V3521A, Flume to Fire Hydrant 29 Makeup Isolation vlv FPW-V3521B, Flume to Fire Hydrant 29 Makeup Isolation vlv

CONTINUOUS USE ATTACHMENT 13 PAGE 2 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 64 OF 94 1.8 IF FPW-FHY10 is being used, THEN Unlock and Close the following valves:

FPW-V19, Yard Header Isolation Valve (Outside of SOCA near MAC 4)

FPW-V32, Yard Header Isolation Valve (Inside PA east of CST)

FPW-V50, Fire Header to Rad. Waste Building Isolation Valve (Inside PA west of RW rollup door)

FPW-V51, Fire Header to Fuel Bldg. Isolation Valve. (In CST berm)

FPW-V73, Yard Header Isolation Valve. (Inside PA northeast of CST) 1.9 IF FPW-FHY9 is being used, THEN Unlock and Close the following valves:

FPW-V17, Yard Header Isolation Valve (Outside SOCA west of Vehicle Gate).

FPW-V31, Yard Header Isolation Valve (Outside SOCA near MAC 4) 1.10 Unlock and Close the following valves:

FPW-V37, Yard Header Isolation Valve (Northeast of Services Bldg between Protected Area fences)

FPW-V23, Yard Header Isolation Valve (95 Southeast of Brown Warehouse between Protected Area fences)

FPW-V64, FHY14 Isolation Valve (East of Brown Warehouse between PA fences, T-handle needed)

FPW-V962, FHY28 Isolation Valve (Southeast of GSB near FHY-28)

FPW-V963, Fire Header Iso. Valve to Brown Whse (Southeast of Brown Warehouse between PA fences)

FPW-V3082, Yard Header Isolation Valve (North of GSB between SOCA fences, T-handle needed)

FPW-V3084, Fire Header Isolation Valve to GSB, (Southeast of GSB in grass) 1.11 Connect two 2 1/2 fire hoses from the Wye connection of the downstream SOCA pipe to the FPW-FHY29, FIRE HYDRANT located by the road east of the brown warehouse.

CONTINUOUS USE ATTACHMENT 13 PAGE 3 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 65 OF 94 1.12 Connect 21/2 inch fire hoses to one of the following and secure them to fill the Standby Cooling Tower.

FPW-FHY10, FIRE HYDRANT located on the East side of the Standby Cooling Tower FPW-FHY9, FIRE HYDRANT located on the West side of the Standby Cooling Tower.

1.13 Start the Diesel Driven Pump per one of the following while limiting pump discharge pressure to 100 psig max to prevent SOCA pipe damage.

5, Operation of FPW-P4 6, Operation of FLX-P3 1.14 Unplug AND open FPW-V3522, Flume to Fire Hydrant 29 Makeup Lower Vent Valve until solid stream of water issues, THEN close AND plug FPW-V3522, Flume to Fire Hydrant 29 Makeup Lower Vent Valve.

1.15 Open FPW-V3523, Flume to Fire Hydrant 29 Makeup Upper Vent Valve until solid stream of water issues, THEN close AND plug FPW-V3523, Flume to Fire Hydrant 29 Makeup Upper Vent Valve.

1.16 Slowly open the following valves:

FPW-V3521A, Flume to Fire Hydrant 29 Makeup Isolation vlv FPW-V3521B, Flume to Fire Hydrant 29 Makeup Isolation vlv 1.17 Slowly open FPW-FHY29 2 1/2 gate valves.

1.18 Slowly open the FPW-FHY29 located by the road east of the brown warehouse.

1.19 At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1A SELECTOR SWITCH to OFF.

1.20 At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1B SELECTOR SWITCH to OFF.

1.21 IF using FPW-FHY10 THEN Open the FPW-FHY10 on the East side of the Standby Cooling Tower.

1.22 IF using FPW-FHY9 THEN Open the FPW-FHY9 on the West side of the Standby Cooling Tower.

1.23 Makeup to Standby Cooling Tower as needed.

CONTINUOUS USE ATTACHMENT 13 PAGE 4 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 66 OF 94 1.24 WHEN makeup is no longer needed, THEN perform the following:

1.24.1.

IF FPW-FHY10 was used THEN Close the FPW-FHY10 on the East side of the Standby Cooling Tower.

1.24.2.

IF FPW-FHY9 was used THEN Close the FPW-FHY9 on the West side of the Standby Cooling Tower.

1.24.3.

At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1A SELECTOR SWITCH to AUTO.

1.24.4.

Close the FPW-FHY29 located by the road east of the brown warehouse.

1.24.5.

Secure the Diesel Driven Pump per one of the following:

5, Operation of FPW-P4 6, Operation of FLX-P3 1.24.6.

At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1B SELECTOR SWITCH to AUTO.

1.24.7.

Close FPW-FHY29 2 1/2 gate valves.

1.24.8.

Close the following valves:

FPW-V3521A, Flume to Fire Hydrant 29 Makeup Isolation vlv FPW-V3521B, Flume to Fire Hydrant 29 Makeup Isolation vlv 1.24.9.

IF FPW-FHY10 is being used, THEN Open and Lock the following:

FPW-V19, Yard Header Isolation Valve FPW-V32, Yard Header Isolation Valve FPW-V50, Fire Header to Rad. Waste Building Isolation Valve FPW-V51, Fire Header to Fuel Bldg. Isolation Valve FPW-V73, Yard Header Isolation Valve 1.24.10.

IF FPW-FHY9 is being used, THEN Open and Lock the following:

FPW-V17, Yard Header Isolation Valve FPW-V31, Yard Header Isolation Valve

CONTINUOUS USE ATTACHMENT 13 PAGE 5 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 67 OF 94 1.24.11.

Open and Lock the following valves:

FPW-V37, Yard Header Isolation Valve FPW-V23, Yard Header Isolation Valve FPW-V64, FHY14 Isolation Valve FPW-V962, FHY28 Isolation Valve FPW-V963, Fire Header Iso. Valve to Brown Whse FPW-V3082, Yard Header Isolation Valve FPW-V3084, Fire Header Isolation Valve to GSB 1.24.12.

Disconnect hoses from SOCA pipe Wye connection valves, FPW-FHY29 and Diesel Driven Pump.

1.24.13.

Coordinate with Mechanical Maintenance, utilizing sump pump, to remove any standing water inside SOCA pipe from the lower SOCA pipe flange.

1.24.14.

Replace plugs on all SOCA pipe Wye connection valves.

2 Align and operate a diesel driven pump to fill the Fire Water Header via Hydrant 1 as follows:

(Ref. ER-RB-2002-0431)

NOTE Hoses stored in the North and South FLEX Buildings, the two hose houses at the south end of the Main Admin, and in FPW-FHY1 hosehouse will provide sufficient hose lengths for all required connections.

2.1 Obtain Diesel Driven Pump and place on the West side of the Circ Water Basin Flume per one of the following:

5, Operation of FPW-P4 6, Operation of FLX-P3 2.2 Hook up the non collapsible hose to the pump suction from the CWS Basin.

2.3 Remove plugs from SOCA pipe upstream Wye connection.

CONTINUOUS USE ATTACHMENT 13 PAGE 6 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 68 OF 94 2.4 Connect two 2 1/2 fire hoses from the discharge of the pump to the Wye connection of the upstream SOCA pipe.

2.5 Verify closed and remove plugs at the downstream SOCA pipe Wye connections from the following valves:

FPW-V3520A, Flume to Fire Water Storage Tank Makeup Isolation vlv FPW-V3520B, Flume to Fire Water Storage Tank Makeup Isolation vlv 2.6 Unlock and Close the following valves:

FPW-V4, Fire System Header to Yard Piping Cross Tie Valve (North of Fire Water Pump House)

FPW-V67, Fire System to Auxiliary Control Building Isolation Valve (Outside TB near Instrument Air skid)

FPW-V9, Yard Header Isolation Valve (West Creek near spare transformers south of field admin)

FPW-V921, Fire Header to Construction Warehouse Isolation Valve (Outside SOCA north of Unit 2 hole by road)

FPW-V14, Fire Header to Main Admin Area Valve (Outside SOCA north of Unit 2 hole by road)

FPW-V16, Fire Header to Main Admin Area (Outside SOCA west of vehicle gate)

FPW-V27, Fire Protection Bldg. Isolation WS-10B, D Isolation Valve (South of D/F transformers)

FPW-V28, Fire System To LLRW Yard Isolation Valve (East of OS oil storage bldg)

FPW-V43, FHY-5 Isolation Valve (West creek south of field admin)

FPW-V45, Spare Yard Isolation Valve (West creek north of field admin)

FPW-V57, FHY-2 Isolation Valve (Outside TB near Instrument Air skid, T-handle needed)

FPW-V966, Fire Header to Field Admin Warehouse Isolation Valve (West Creek southside of field admin)

CONTINUOUS USE ATTACHMENT 13 PAGE 7 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 69 OF 94 2.7 IF FPW-FHY10 is being used, THEN Unlock and Close the following valves:

FPW-V20, Yard Header Isolation Valve (Outside SOCA near MAC 4)

FPW-V30, Yard Header Isolation Valve (Outside SOCA west of vehicle gate)

FPW-V32, Yard Header Isolation Valve (Inside PA east of CST)

FPW-V50, Fire Header to Rad. Waste Building Isolation Valve (Inside PA west of RW rollup door.)

FPW-V51, Fire Header to Fuel Bldg. Isolation Valve (In CST berm)

FPW-V73, Yard Header Isolation Valve (Inside PA northeast of CST) 2.8 IF FPW-FHY9 is being used, THEN Unlock and Close FPW-V18, Yard Header Isolation Valve. (Outside SOCA west of vehicle gate) 2.9 Connect two 2 1/2 fire hoses from the Wye connection of the downstream SOCA pipe to the FPW-FHY1, FIRE HYDRANT located by the road west of the Demin Water Pumphouse, behind WTW-TK2B.

2.10 Connect 21/2 inch fire hoses to one of the following and secure them to fill the Standby Cooling Tower.

FPW-FHY10, FIRE HYDRANT located on the East side of the Standby Cooling Tower FPW-FHY9, FIRE HYDRANT located on the West side of the Standby Cooling Tower.

2.11 Start the Diesel Driven Pump per one of the following while limiting pump discharge pressure to 100 psig max to prevent SOCA pipe damage.

5, Operation of FPW-P4 6, Operation of FLX-P3 2.12 Slowly open the following valves:

FPW-V3520A, Flume to Fire Water Storage Tank Makeup Isolation vlv FPW-V3520B, Flume to Fire Water Storage Tank Makeup Isolation vlv 2.13 Slowly open FPW-FHY1 2 1/2 gate valves.

2.14 Slowly open the FPW-FHY1.

CONTINUOUS USE ATTACHMENT 13 PAGE 8 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 70 OF 94 2.15 At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1A SELECTOR SWITCH to OFF.

2.16 At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1B SELECTOR SWITCH to OFF.

2.17 IF using FPW-FHY10 THEN Open the FPW-FHY10 on the East side of the Standby Cooling Tower.

2.18 IF using FPW-FHY9 THEN Open the FPW-FHY9 on the West side of the Standby Cooling Tower.

2.19 Makeup to Standby Cooling Tower as needed.

2.20 WHEN makeup is no longer needed, THEN perform the following:

2.20.1.

IF FPW-FHY10 was used THEN Close the FPW-FHY10 on the East side of the Standby Cooling Tower.

2.20.2.

IF FPW-FHY9 was used THEN Close the FPW-FHY9 on the West side of the Standby Cooling Tower.

2.20.3.

At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1A SELECTOR SWITCH to AUTO.

2.20.4.

Close the FPW-FHY1.

2.20.5.

Secure the Diesel Driven Pump per one of the following:

5, Operation of FPW-P4 6, Operation of FLX-P3 2.20.6.

At the Fire Pump House, place the DIESEL DRIVEN FIRE PUMP FPW-P1B SELECTOR SWITCH to AUTO.

2.20.7.

Close FPW-FHY1 2 1/2 gate valves.

2.20.8.

Close the following valves:

FPW-V3520A, Flume to Fire Water Storage Tank Makeup Isolation vlv FPW-V3520B, Flume to Fire Water Storage Tank Makeup Isolation vlv 2.20.9.

IF FPW-FHY10 is being used, THEN Open and Lock the following:

FPW-V20, Yard Header Isolation Valve FPW-V30, Yard Header Isolation Valve

CONTINUOUS USE ATTACHMENT 13 PAGE 9 OF 9 MAKEUP TO STANDBY COOLING TOWER FROM CIRC WATER BASIN AOP-0004 REV - 078 PAGE 71 OF 94 FPW-V32, Yard Header Isolation Valve FPW-V50, Fire Header to Rad. Waste Building Isolation Valve FPW-V51, Fire Header to Fuel Bldg. Isolation Valve FPW-V73, Yard Header Isolation Valve 2.20.10.

IF FPW-FHY9 is being used, THEN Open and Lock FPW-V18, Yard Header Isolation Valve 2.20.11.

Open and lock the following valves:

FPW-V4, Fire System Header to Yard Piping Cross Tie Valve FPW-V67, Fire System to Auxiliary Control Building Isolation Valve FPW-V9, Yard Header Isolation Valve FPW-V921, Fire Header to Construction Warehouse Isolation Valve FPW-V14, Fire Header to Main Admin Area FPW-V16, Fire Header to Main Admin Area FPW-V27, Fire Protection Bldg. Isolation WS-10B, D Isolation Valve FPW-V28, Fire System To LLRW Yard Isolation Valve FPW-V43, FHY-5 Isolation Valve FPW-V45, Spare Yard Isolation Valve FPW-V57, FHY-2 Isolation Valve FPW-V966, Fire Header to Field Admin Warehouse Isolation Valve 2.20.12.

Disconnect hoses from SOCA pipe Wye connection valves, FPW-FHY1 and Diesel Driven Pump.

2.20.13.

Coordinate with Mechanical Maintenance, utilizing sump pump, to remove any standing water inside SOCA pipe from the lower SOCA pipe flange.

2.20.14.

Replace plugs on all SOCA pipe Wye connection valves.

CONTINUOUS USE ATTACHMENT 14 PAGE 1 OF 3 MAKEUP TO STANDBY COOLING TOWER USING TEMPORARY POWER TO THE DEEPWELL PUMPS AOP-0004 REV - 078 PAGE 72 OF 94 1

Perform the following to supply makeup to the Standby Cooling Tower using temporary power to the Deepwell Pumps. (ER-RB-2002-0431) 1.1 IF MWS-P1A is to be used, THEN perform the following:

1.1.1.

Remove the SBO Diesel from the storage location and place at the east door of the Fire Pump House.

1.1.2.

Verify open NJS-LDC1J ACB136, NHS-MCC7A FIRE PROT PMP HOUSE supply breaker.

1.1.3.

In the Standby Service Water Pump Room, open MWS-V350, WELL WATER TO STANDBY SERVICE WATER SYSTEM OUTBOARD ISOL VALVE.

1.1.4.

Open all breakers on NHS-MCC7A except for BKR 2AR.

NOTE The temporary power cable is stored in the AOP-0004 toolbox in the Fire Pumphouse Building, in the Well Water Transfer and Domestic Water Pump Room.

1.1.5.

Connect the temporary power cables from the SBO Diesel to welding receptacle POP-WR7A01 for NHS-MCC7A.

1.1.6.

Place the MWS-P1A Control Switch in the OFF position.

1.1.7.

Start the SBO Diesel per SOP-0054, Station Blackout Diesel Generator.

1.1.8.

Close NHS-MCC7A BKR 2B, for MWS-P1A.

1.1.9.

In the Fire Pump House, close MWS-V9, WELL WATER TO STORAGE TANK TK1 ISOLATION VALVE.

1.1.10.

Place the Control Switch for MWS-P1A to RUN.

1.1.11.

In the Fire Pump House, open MWS-V11, WELL WATER TO STANDBY COOLING TOWER SYSTEM INBOARD ISOL VALVE to supply makeup to the Standby Cooling Tower.

CONTINUOUS USE ATTACHMENT 14 PAGE 2 OF 3 MAKEUP TO STANDBY COOLING TOWER USING TEMPORARY POWER TO THE DEEPWELL PUMPS AOP-0004 REV - 078 PAGE 73 OF 94 1.2 IF MWS-P1B is to be used, THEN perform the following:

1.2.1.

Remove the SBO Diesel from the storage location and place at the west door of the Fire Pump House.

1.2.2.

Verify open NJS-LDC1K ACB148, NHS-MCC7B FIRE PROT PMP HOUSE supply breaker.

1.2.3.

In the Standby Service Water Pump Room, open MWS-V350, WELL WATER TO STANDBY SERVICE WATER SYSTEM OUTBOARD ISOL VALVE.

1.2.4.

Open all breakers on NHS-MCC7B except for BKR 3AL.

NOTE The temporary power cable is stored in the AOP-0004 toolbox in the Fire Pumphouse Building, in the Well Water Transfer and Domestic Water Pump Room.

1.2.5.

Connect the temporary power cables from the SBO Diesel to welding receptacle POP-WR7B01 for NHS-MCC7B.

1.2.6.

Place the MWS-P1B Control Switch in the OFF position.

1.2.7.

Start the SBO Diesel per SOP-0054, Station Blackout Diesel Generator.

1.2.8.

Close NHS-MCC7B BKR 2B, for MWS-P1B.

1.2.9.

In the Fire Pump House, close MWS-V9, WELL WATER TO STORAGE TANK TK1 ISOLATION VALVE.

1.2.10.

Place the Control Switch for MWS-P1B to RUN.

1.2.11.

In the Fire Pump House, open MWS-V11, WELL WATER TO STANDBY COOLING TOWER SYSTEM INBOARD ISOL VALVE.

CONTINUOUS USE ATTACHMENT 14 PAGE 3 OF 3 MAKEUP TO STANDBY COOLING TOWER USING TEMPORARY POWER TO THE DEEPWELL PUMPS AOP-0004 REV - 078 PAGE 74 OF 94 1.3 WHEN transfer of makeup water to the Standby Cooling Tower is complete, THEN perform the following:

1.3.1.

Place MWS-P1A(B) DEEP WELL PUMP A(B) control switch to OFF.

1.3.2.

In the Fire Pump House, open MWS-V9, WELL WATER TO STORAGE TANK TK1 ISOLATION VALVE.

1.3.3.

In the Fire Pump House, close MWS-V11, WELL WATER TO STANDBY COOLING TOWER SYSTEM INBOARD ISOL VALVE.

1.3.4.

In the Standby Service Water Pump Room, close MWS-V350, WELL WATER TO STANDBY SERVICE WATER SYSTEM OUTBOARD ISOL VALVE.

1.3.5.

Secure the SBO Diesel per SOP-0054, Station Blackout Diesel Generator.

1.3.6.

IF no additional makeup will be required, THEN disconnect the power cable.

1.3.7.

IF no additional makeup will be required, THEN place the SBO Diesel back in the normal storage location.

CONTINUOUS USE ATTACHMENT 15 PAGE 1 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 75 OF 94 1

PURPOSE Provide generic operating instructions for the Portable Diesel Driven Pump.

2 PRECAUTIONS AND LIMITATIONS 2.1 Do not run primer more than 45 seconds. IF prime is NOT achieved in 45 seconds, THEN stop engine and check for vacuum leaks.

2.2 Unit is compatible with standard and ultra low sulfur diesel fuel per ASTM D975 and EN590.

2.3 Sufficient fuel shall be maintained on site for the pump to run at least 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Maintaining the fuel level in the pump tank at least 3/4 full ensures it will run for 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months prior to needing refueling.

2.4 Contingency Toolboxes have been staged in the following locations:

FPW-P4, CONTIGENCY/MITIGATION STRATEGY PUMP (South FLEX Building)

SRV-1, SRV Battery Cart (Aux Building 141 el West side)

Fire Brigade Van 3

OPERATION 3.1 Relocate the pump as follows:

NOTE Pump is stored at the South FLEX Building.

3.1.1.

Unplug the battery charger power cable from the receptacle.

3.1.2.

Secure all cables on the diesel trailer to prevent any damage while moving the pump.

3.1.3.

Verify tongue support jack is lowered to support hitching to tow vehicle.

3.1.4.

Raise the lifting jacks and verify they are full up.

3.1.5.

Inspect the trailer tires for flats.

3.1.6.

Hitch the vehicle to the trailer and raise the tongue support jack full up.

C

CONTINUOUS USE ATTACHMENT 15 PAGE 2 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 76 OF 94 3.1.7.

Release trailer brake.

3.1.8.

Position the pump adjacent to the circulating water basin.

3.1.9.

Set trailer brake.

3.1.10.

Lower the lifting jacks as necessary to level the pump and unhitch the vehicle, if required.

3.1.11.

Remove engine compartment side panels.

3.1.12.

Attach a suction line to the pump and install a strainer on the opposite end.

3.1.13.

Submerge the strainer in the water approximately 18 ft below the water level and above the bottom of the reservoir.

NOTE The friction loss of a 2 1/2 rubber-lined fire hose flowing at 250 gpm is 12.5 psi per 100 feet.

3.1.14.

Attach discharge hoses as necessary to the discharge and attach the hose to the appropriate discharge fitting or connection.

3.1.15.

Close the discharge drains (4).

3.1.16.

Close pump drain.

3.1.17.

Attach tubing to cooling water; route to water source.

3.1.18.

Check the following:

Place the ignition key in ON and check the adequate Engine FUEL level, then place the ignition key in OFF.

Engine OIL level, between MIN and MAX.

Engine COOLANT level, (visible by removing radiator cap)

CONTINUOUS USE ATTACHMENT 15 PAGE 3 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 77 OF 94 3.2 Start the engine as follows:

CAUTION Do not run primers more than 45 seconds. If prime is not achieved in 45 seconds, the engine should be stopped and checked for vacuum leaks.

CAUTION The pump could be damaged from overheating due to low flow if the minimum flow valve is not open. Ensure the pump cooler valve (blue handle) is open at all times.

NOTE The following parameters should be maintained during the operation of FPW-P4:

Engine Oil Pressure

>10 psi

Engine Water Temp High

<250 deg. F 3.2.1.

Place the ignition key in START.

3.2.2.

WHEN the engine has started, THEN release the key which will spring return to ON.

3.2.3.

Immediately pull both primers until water discharges And pressure shows on the discharge gauge, THEN close the primer valves.

3.2.4.

Open the discharge valves and the hoses to the system or components.

3.2.5.

Press MODE on governor to enter RPM mode.

NOTE With the Governor in RPM Mode, the engine will maintain a constant RPM.

3.2.6.

Check the RPM indicator lamp light comes on and the MESSAGE CENTER shows RPM Mode.

3.2.7.

Press the INC or DEC to vary pressure as needed.

CONTINUOUS USE ATTACHMENT 15 PAGE 4 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 78 OF 94 NOTE With the Governor in PSI Mode, the engine will maintain a constant discharge pressure.

The pressure governor will not control pressure until a discharge pressure of 70 psi is attained. It will act as a throttle until this pressure point is achieved.

A target discharge pressure of 100 psi is recommended in most applications in order to ensure a net nozzle pressure of greater 5 psi, unless an inordinate hose run is required.

3.2.8.

Press MODE on governor to enter PSI mode.

3.2.9.

Check the PSI indicator lamp light comes on and the MESSAGE CENTER shows PSI Mode.

3.2.10.

Press the INC or DEC to vary pressure as needed.

4 POST OPERATION PROCEDURES 4.1 Depress the IDLE push button.

4.2 Slowly close all discharge valves.

4.3 Place the ignition key in OFF.

4.4 Drain the pump to bucket as follows:

4.4.1.

Open the pump drain.

4.4.2.

Open the 4 discharge drains.

4.5 Remove tubing attached in Step 3.1.17 of this attachment.

4.6 Remove suction and discharges hoses.

4.7 Install the engine compartment side panels.

4.8 Raise the lifting jacks and verify they are full up.

4.9 Hitch the vehicle to the trailer and raise the tongue support jack full up.

4.10 Release trailer brake.

CONTINUOUS USE ATTACHMENT 15 PAGE 5 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 79 OF 94 CAUTION If the diesel fuel tank is completely filled, thermal expansion of the fuel and spillage during transportation is possible. Monitoring the fuel level frequently during refueling can prevent overfilling. Do not fill above 95%.

4.11 IF the fuel tank is less than 3/4 full, THEN add diesel fuel to restore level between 75%

and 95% prior to storing the pump.

4.12 Locate the trailer in its storage area.

4.13 Set trailer brake.

4.14 Lower the tongue support jack and unhitch the trailer.

4.15 Lower the lifting jacks to decrease weight on the tires.

4.16 Ensure pump is level to prevent diesel leakage.

4.17 Plug in the battery charger to a 120 VAC outlet.

5 INDICATIONS AND ALARMS 5.1 Electronic Engine Pressure Governor 5.1.1.

Alarms 1.

Low Oil Pressure 10 psi 2.

Engine Water temperature High 250F 3.

Voltage Less Than 11.9 VDC 5.1.2.

Modes of Operation 1.

Power On - When the unit is first powered up, the display will show

[MODE] and the engine will remain at idle until the mode switch is pressed to select the desired operating mode (PSI MODE or RPM MODE). If the pump is engaged and the OK to Pump LED is illuminated, PRESSURE will be the first mode selected otherwise THROTTLE will be the first mode.

CONTINUOUS USE ATTACHMENT 15 PAGE 6 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 80 OF 94 2.

RPM Mode - When the unit is in RPM mode, the display will read RPM Mode and the green RPM LED will be illuminated. Engine speed is controlled by the INCrease and DECrease switches, the display will indicate INCREASE or DECREASE as appropriate when these switches are depressed. The governor will maintain the last output signal attained with these switches. The engine will maintain an RPM appropriate for the throttle signal being sent.

1)

NOTE: If while operating in rpm mode the pressure increases more than 50 psi from the pressure logged at the last switch press, the governor will limit the pressure increase to no more than a 50 psi differential. The governor may reduce engine rpm to achieve this and the message psi limit will be displayed in the message center.

2)

Note: The governor will not attempt to regulate pressure in this mode; only limit the differential pressure to 50 psi from the pressure present when the last switch was pressed.

3.

Pressure Mode - When the unit is operating in the Pressure mode, the display will show PSI Mode and the amber PRESSURE LED will be illuminated. Pump pressure is set by using the INCrease and DECrease switches. The governor will attempt to maintain the last pressure achieved with these switches. The display will indicate INCREASE or DECREASE as appropriate. The governor maintains pump pressure by controlling engine RPM in response to a signal from the pressure transducer mounted on the pump. When controlling in this manner, the display will show CTRL DEC or CTRL INC.

4.

Switching between modes Pressing the mode switch will change the governor from RPM to Pressure mode without a significant change in engine speed or pump pressure. The message center will indicate PRESSURE or THROTTLE as appropriate once the mode change has been made. When switching to PRESSURE, the pressure setpoint is whatever pressure is on the transducer at the change.

5.

Preset Mode Pressing the PRESET switch in either mode will control the engine to attain the preset RPM or pump pressure programmed in governor memory. If there is more than 10 PSI pressure on the pump, the RPM Preset is disabled and the Message Center will display DISABLED.

CONTINUOUS USE ATTACHMENT 15 PAGE 7 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 81 OF 94 6.

High Idle Mode - An input is available to bring the engine speed to a PRESET RPM (High Idle) from a remotely mounted switch. While operating in this mode, the display will show HIGHIDLE. This function is inoperative when the pump engaged input is active, there is more than 10 PSI on the pressure transducer or if the MODE switch on the governor has been pressed. Pressing the IDLE switch causes the high idle to drop out and the high idle input must be toggled off and then on again to reinstate high idle. The INC and DEC switches are active in high idle mode and the engine speed can be adjusted, changing engine speed in this manner will not change the preset RPM that is set in memory.

7.

Idle Mode - Pressing the IDLE switch at any time returns the engine to idle speed. NOTE: a firm, positive switch depression is necessary to activate this feature and a quick press might be ignored.

8.

Switch Session Pressure Increase If the INC switch is held the governor will not allow a change greater than 80 PSI without releasing the INC switch and pressing it again. This is only applicable when the discharge pressure is above 90 PSI. This function prevents high pressures from being introduced by a distracted operator.

9.

Pressure / Water Loss If the discharge pressure drops below 30 PSI for any reason, engine speed will not be increased. The governor output voltage will reduce to the last known value (engine RPM) where the pressure setpoint was obtained. The display will flash -INTAKE-during this low pressure condition. If the pressure increases above 30 PSI, OPERATOR will flash and the governor will not increase output unless the operator presses the INC or PRESET switches. If pressure above 30 PSI is not regained within 5 seconds, the governor will return the engine to idle and display LoSupply. The operator must make certain that the water supply is adequate and then reinstate governing using the MODE, INC and/or PRESET switches.

10. Pressure Recovery / Cavitation (TRIM) The governor has a trim adjustment, this can be set between 5% and 20% of maximum throttle.

This parameter limits the governors maximum increase in a pressure recovery attempt. The message center will flash OPERATOR when this limit is reached and the RPM will not increase further. The operator must take positive action to restore discharge pressure. If pressure is not restored within 4 seconds, the governor will reduce output to the last known output where pressure was maintained. The operator must input a new setpoint with the INC/DEC or PRESET switches. If the pressure rises above the original setpoint and the governor controls a decrease in engine speed, the governor will return to normal operation and PSI MODE is displayed.

CONTINUOUS USE ATTACHMENT 15 PAGE 8 OF 8 OPERATION OF FPW-P4 AOP-0004 REV - 078 PAGE 82 OF 94

11. Pressure Preset While the governor is attempting to reach the preset PSI, the increase is tested at intervals and if the pressure is not increasing, the governor will maintain the engine speed at the point the pressure stops increasing and uses that as the pressure setpoint.

12. High Idle The High Idle feature is disabled if there is > 10 PSI at the pump transducer.

13. Switch Session Pressure If the INC switch is held and the operating pressure is above 90 PSI, the governor will not allow a change greater than 80 PSI without releasing the INC switch and pressing it again. This is to prevent high pressures from being introduced by a distracted operator.

14. New Messages 1)

OPERATOR will be flash anytime the governor cant achieve a desired pressure. This indicates that the governor will not increase engine speed until the pump operator intervenes.

2)

INTAKE will be displayed anytime the governor is operating in pressure mode and the discharge pressure drops below 30 PSI. If pressure remains below 30 PSI, the display will change to LoSupply and engine speed will be reduced to idle. When LoSupply is displayed the governor is no longer active and the operator must ensure an adequate water supply and reinstate governing using the MODE Switch and either INC or PRESET.

3)

OPERATOR will be flashed anytime the governor cant achieve a function or pressure. This indicates that the governor will not increase engine speed until the pump operator intervenes.

4)

CTRL INC will be flash in the display if the governor cannot regain the set pressure. It will change to OPERATOR flashing if pressure cannot be regained within 4 seconds. During these periods, the governor will not command an increase in engine speed and will return to the last known engine speed command where the setpoint was achieved.

CONTINUOUS USE ATTACHMENT 16 PAGE 1 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 83 OF 94 1

PURPOSE Provide generic instructions for operation of the SFP Makeup FLEX Pump FLX-P3.

2 PRECAUTIONS AND LIMITATIONS 2.1 Do not run primer more than 45 seconds. IF prime is NOT achieved in 45 seconds, THEN stop engine and check for vacuum leaks.

2.2 Unit is compatible with standard and ultra low sulfur diesel fuel per ASTM D975 and EN590.

2.3 The engine should be cool to remove the radiator cap when checking fluid level.

3 OPERATION 3.1 Relocate the pump as follows:

NOTE Pump is stored at the North FLEX Building.

3.1.1.

Unplug the battery charger power cable from the receptacle.

3.1.2.

Secure all cables on the diesel trailer to prevent any damage while moving the pump.

3.1.3.

Verify tongue support jack is lowered to support hitching to tow vehicle.

3.1.4.

Raise the lifting jacks and verify they are full up.

3.1.5.

Inspect the trailer tires for flats.

3.1.6.

Hitch the vehicle to the trailer and raise the tongue support jack full up.

3.1.7.

Release trailer brake.

3.1.8.

Position the pump adjacent to the circulating water basin.

3.1.9.

Set trailer brake.

3.1.10.

Lower the lifting jacks as necessary to level the pump and unhitch the vehicle, if required.

3.1.11.

Attach a suction line to the pump and install a strainer on the opposite end.

3.1.12.

Submerge the strainer in the water approximately 18 ft below the water level and above the bottom of the reservoir.

CONTINUOUS USE ATTACHMENT 16 PAGE 2 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 84 OF 94 NOTE The friction loss of a 2 1/2 rubber-lined fire hose flowing at 250 gpm is 12.5 psi per 100 feet.

3.1.13.

Attach discharge hoses as necessary to the discharge and attach the hose to the appropriate discharge fitting or connection.

3.2 Perform the following pre-start checks:

3.2.1.

Verify suction and discharge hoses have been installed.

3.2.2.

Close the Master drain valve.

3.2.3.

Check the following:

Place the ignition key in ON and check the adequate Engine FUEL level, then place the ignition key in OFF.

Engine OIL level, between MIN and MAX.

Master Drain valve Ignition switch Oil dipstick

CONTINUOUS USE ATTACHMENT 16 PAGE 3 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 85 OF 94 NOTE The engine has to be cool to remove radiator cap.

Engine COOLANT level, (visible by removing radiator cap thru hole on top of engine cabinet)

Fuel Water Separator: Ensure diesel fuel is present in sight glass area at bottom of separator o

IF sediment is observed, THEN notify Control Room the fuel filter will need to be serviced. A judgment would be needed based on the level of water in the filter to continue to run the engine.

Fuel/water separator sight glass

CONTINUOUS USE ATTACHMENT 16 PAGE 4 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 86 OF 94 3.3 Start the engine as follows:

CAUTION Do not run primers more than 45 seconds. If prime is not achieved in 45 seconds, the engine should be stopped and checked for vacuum leaks.

CAUTION To avoid starter damage, do not operate starter for more than 30 seconds at a time. Wait at least 2 minutes for starter to cool be trying again.

NOTE The following parameters should be maintained during the operation of FLX-P3: The Shift Manager is to be notified if the oil pressure is low or jacket water temp is high.

Engine Oil Pressure

>15 psi at idle Expect at 2200 rpm

~35 - 65 @ rated

Engine Water Temp High

<250 deg. F NOTE The message center will indicate THROTTLE.

NOTE If using for an emergency function:

1. Multiple starts may be necessary and should be attempted.

2. If a fault trips the device, the condition should be evaluated and if safe for the operator, additional starts should be attempted.

In all cases, when time permits, notify management team about the conditions.

CONTINUOUS USE ATTACHMENT 16 PAGE 5 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 87 OF 94 3.3.1.

Place the ignition key in ON and check governor initializes and in the RPM Mode.

1.

IF NOT, THEN Press MODE on governor to enter RPM mode and verify RPM lite is lit.

NOTE With the Governor in RPM Mode, the engine will maintain a constant RPM.

3.3.2.

Monitor engine parameters on the ENFO IV.

3.3.3.

Place the ignition key in START.

3.3.4.

WHEN the engine has started, THEN release the key which will spring return to ON.

Engine parameters monitor Ignition switch

CONTINUOUS USE ATTACHMENT 16 PAGE 6 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 88 OF 94 3.3.5.

Immediately pull ONE primer until water discharges AND pressure develops on the pump discharge gauge, THEN close the primer valve. The suction pressure will be negative in the draft mode.

3.3.6.

Slowly Open the discharge valves to the system or components. Monitor hoses to ensure they are not kinked.

NOTE With the Governor in PSI Mode, the engine will maintain a constant discharge pressure.

The pressure governor will not control pressure until a discharge pressure of 70 psi is attained. It will act as a throttle until this pressure point is achieved, A target discharge pressure of 100 psi is recommended in most applications in order to ensure a net nozzle pressure of greater 5 psi, unless an inordinate hose run is required.

3.3.7.

Press the INC or DEC to vary pressure as needed to 70 psig.

3.3.8.

Press MODE on governor to enter PSI mode.

1.

Use the Governor INC or DEC pushbuttons to obtain the desired 100 psig discharge pressure MAX.

Primer valves Discharge valves

CONTINUOUS USE ATTACHMENT 16 PAGE 7 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 89 OF 94 4

POST OPERATION PROCEDURE 4.1 Depress the IDLE pushbutton.

4.2 Close all discharge valves.

4.3 Allow the engine to idle for at least 2 minutes if possible.

4.4 Place the ignition key in OFF.

4.5 Drain the pump to bucket by opening the pump drain valve.

4.6 Remove suction and discharges hoses.

4.7 Raise the lifting jacks and verify they are full up.

4.8 Hitch the vehicle to the trailer and raise the tongue support jack full up.

4.9 Release trailer brake.

CAUTION If the diesel fuel tank is completely filled, thermal expansion of the fuel and spillage during transportation is possible. Monitoring the fuel level frequently during refueling can prevent overfilling. Do not fill above 95%.

4.10 IF the fuel tank is less than 3/4 full, THEN add diesel fuel to restore level between 75%

and 95% prior to storing the pump.

4.11 Locate the trailer in its storage area.

4.12 Set trailer brake.

4.13 Lower the tongue support jack and unhitch the trailer.

CONTINUOUS USE ATTACHMENT 16 PAGE 8 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 90 OF 94 4.14 Lower the lifting jacks to decrease weight on the tires.

4.15 Ensure pump is level to prevent diesel leakage.

4.16 Plug in the battery charger to a 120 VAC outlet.

5 INDICATIONS AND ALARMS 5.1 ENFO Monitor 5.1.1.

Alarms (Engine warning light) 1.

Low Oil Pressure 10 psi 2.

Engine Water temperature High 250F 3.

Voltage Less than 11.9 VDC or Greater than 23.8 VDC 5.1.2.

Modes of Operation, Governor Overview 1.

Power On - When the unit is first powered up, the display will show

[MODE] and the engine will remain at idle until the mode switch is pressed to select the desired operating mode (PSI MODE or RPM MODE). If the pump is engaged and the OK to Pump LED is illuminated, PRESSURE will be the first mode selected otherwise THROTTLE will be the first mode.

2.

RPM Mode - When the unit is in RPM mode, the display will read RPM Mode and the green RPM LED will be illuminated. Engine speed is controlled by the INCrease and DECrease switches, the display will indicate INCREASE or DECREASE as appropriate when these switches are depressed. The governor will maintain the last output signal attained with these switches. The engine will maintain an RPM appropriate for the throttle signal being sent.

1)

NOTE: If while operating in rpm mode the pressure increases more than 50 psi from the pressure logged at the last switch press, the governor will limit the pressure increase to no more than a 50 psi differential. The governor may reduce engine rpm to achieve this and the message psi limit will be displayed in the message center.

2)

Note: The governor will not attempt to regulate pressure in this mode; only limit the differential pressure to 50 psi from the pressure present when the last switch was pressed.

CONTINUOUS USE ATTACHMENT 16 PAGE 9 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 91 OF 94 3.

Pressure Mode - When the unit is operating in the Pressure mode, the display will show PSI Mode and the amber PRESSURE LED will be illuminated. Pump pressure is set by using the INCrease and DECrease switches. The governor will attempt to maintain the last pressure achieved with these switches. The display will indicate INCREASE or DECREASE as appropriate. The governor maintains pump pressure by controlling engine RPM in response to a signal from the pressure transducer mounted on the pump. When controlling in this manner, the display will show CTRL DEC or CTRL INC.

4.

Switching between modes Pressing the mode switch will change the governor from RPM to Pressure mode without a significant change in engine speed or pump pressure. The message center will indicate PRESSURE or THROTTLE as appropriate once the mode change has been made. When switching to PRESSURE, the pressure setpoint is whatever pressure is on the transducer at the change.

5.

Sensor Failure Whenever the transducer signal is below.3VDC or above 4.8 VDC, a SENSOR failure will be logged and SENSOR will be displayed in the MESSAGE Center. The governor can no longer maintain a pressure setting. It will hold the current engine RPM and only operate as a throttle. Once the SENSOR message is displayed it will not clear until the power to the governor is reset. It is extremely important that the cause be investigated. The governor cannot control discharge pressure until the problem is corrected.

6.

Preset Mode Pressing the PRESET switch in either mode will control the engine to attain the preset RPM or pump pressure programmed in governor memory. If there is more than 10 PSI pressure on the pump, the RPM Preset is disabled and the Message Center will display DISABLED.

7.

High Idle Mode - An input is available to bring the engine speed to a PRESET RPM (High Idle) from a remotely mounted switch. While operating in this mode, the display will show HIGHIDLE. This function is inoperative when the pump engaged input is active, there is more than 10 PSI on the pressure transducer or if the MODE switch on the governor has been pressed. Pressing the IDLE switch causes the high idle to drop out and the high idle input must be toggled off and then on again to reinstate high idle. The INC and DEC switches are active in high idle mode and the engine speed can be adjusted, changing engine speed in this manner will not change the preset RPM that is set in memory.

CONTINUOUS USE ATTACHMENT 16 PAGE 10 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 92 OF 94 8.

Idle Mode - Pressing the IDLE switch at any time returns the engine to idle speed. NOTE: a firm, positive switch depression is necessary to activate this feature and a quick press might be ignored.

9.

Switch Session Pressure Increase If the INC switch is held the governor will not allow a change greater than 80 PSI without releasing the INC switch and pressing it again. This is only applicable when the discharge pressure is above 90 PSI. This function prevents high pressures from being introduced by a distracted operator.

10. Pressure / Water Loss If the discharge pressure drops below 30 PSI for any reason, engine speed will not be increased. The governor output voltage will reduce to the last known value (engine RPM) where the pressure setpoint was obtained. The display will flash -INTAKE-during this low pressure condition. If the pressure increases above 30 PSI, OPERATOR will flash and the governor will not increase output unless the operator presses the INC or PRESET switches. If pressure above 30 PSI is not regained within 5 seconds, the governor will return the engine to idle and display LoSupply. The operator must make certain that the water supply is adequate and then reinstate governing using the MODE, INC and/or PRESET switches.

11. Pressure Recovery / Cavitation (TRIM) The governor has a trim adjustment, this can be set between 5% and 20% of maximum throttle.

This parameter limits the governors maximum increase in a pressure recovery attempt. The message center will flash OPERATOR when this limit is reached and the RPM will not increase further. The operator must take positive action to restore discharge pressure. If pressure is not restored within 4 seconds, the governor will reduce output to the last known output where pressure was maintained. The operator must input a new setpoint with the INC/DEC or PRESET switches. If the pressure rises above the original setpoint and the governor controls a decrease in engine speed, the governor will return to normal operation and PSI MODE is displayed.

12. Pressure Preset While the governor is attempting to reach the preset PSI, the increase is tested at intervals and if the pressure is not increasing, the governor will maintain the engine speed at the point the pressure stops increasing and uses that as the pressure setpoint.

CONTINUOUS USE ATTACHMENT 16 PAGE 11 OF 11 OPERATION OF FLX-P3 AOP-0004 REV - 078 PAGE 93 OF 94

13. High Idle The High Idle feature is disabled if there is > 10 PSI at the pump transducer.

14. Switch Session Pressure If the INC switch is held and the operating pressure is above 90 PSI, the governor will not allow a change greater than 80 PSI without releasing the INC switch and pressing it again. This is to prevent high pressures from being introduced by a distracted operator.

15. New Messages 1)

OPERATOR will be flash anytime the governor cant achieve a desired pressure. This indicates that the governor will not increase engine speed until the pump operator intervenes.

2)

INTAKE will be displayed anytime the governor is operating in pressure mode and the discharge pressure drops below 30 PSI. If pressure remains below 30 PSI, the display will change to LoSupply and engine speed will be reduced to idle. When LoSupply is displayed the governor is no longer active and the operator must ensure an adequate water supply and reinstate governing using the MODE Switch and either INC or PRESET.

3)

OPERATOR will be flashed anytime the governor cant achieve a function or pressure. This indicates that the governor will not increase engine speed until the pump operator intervenes.

4)

CTRL INC will be flash in the display if the governor cannot regain the set pressure. It will change to OPERATOR flashing if pressure cannot be regained within 4 seconds. During these periods, the governor will not command an increase in engine speed and will return to the last known engine speed command where the setpoint was achieved.

CONTINUOUS USE ATTACHMENT 17 PAGE 1 OF 1 TIME LIMITED ACTIONS AOP-0004 REV - 078 PAGE 94 OF 94 10 Minute Actions Refer to Step 5.2.5 to ensure Diesel Generators running unloaded without cooling water are supplied with cooling water.

Refer to Step 5.5.1 to ensure the Div 2 HVK Chiller is operating with the Div 2 Chilled Water Pump that is running.

15 Minute Actions Refer to Step 5.7.1 to secure the EBOP to reduce battery load.

20 Minute Actions Refer to Step 5.2.1 third bullet if SSW initiations fails to close SWP-MOV96A(B) NORM SVCE WTR RETURN to conserve Standby Cooling Tower inventory, then close SWP-V1213(V1212),

A(B) RETURN HEADER ISOLATION.

Refer to Step 5.2.6 if the Div III DG fails causing a loss of SWP-P2C to begin reducing Div I SSW loading by starting the necessary redundant equipment serviced by Div II SSW, AND securing redundant Div I SSW loads as follows.

Refer to Step 5.5.2 to ensure automatic operation of ventilation systems and shut down redundant components.

30 Minute Actions Refer to Step 5.3 because River Bend design basis requires RHR to be in suppression pool cooling within 30 minutes of the initiation of a LOP/LOCA.

Refer to Step 5.6 to perform actions required if a loss of Control Building HVAC occurs.

1 Hour Actions Refer to Step 5.7.1 for starting the Standby Cooling Tower fans one hour into a LOP-LOCA.

Refer to Step 5.13.2 to secure redundant components with the failure of one division of the Standby Cooling Tower Fans concurrent with a LOP/LOCA.

2 Hour Actions Refer to Step 5.7.1 within two hours of the LOCA event to cross connect SSW to RPCCW per SOP-0016, Reactor Plant Component Cooling Water System, and place the Fuel Pool Cooling System in service.

CNRO2025-00028 Relevant Training Tasks for UHS Makeup (7 Pages follow)

Page 23 of 30 ROJT-NLO-QC001 Rev 33 TRAINEE NAME:

LOGIN ID:

TASK TITLE:

Operate the HALE Portable Diesel Driven Fire Pump.

TASK #:

200203005001 TASK STANDARD Operate the HALE Portable Diesel Driven Fire Pump per SOP-0037 or OSP-0066 and EN-IS-120.

OE CR-RBS-2018-06296 (Leak During Hale Fire Pump Run)

SAFETY/PPE All required PPE.

Management Observation required?

N/A OJT TPE Observer (Print Name and Sign)

Observation #

INITIAL CONDITIONS Diesel Driven Fire Pumps FPW-P1A(B) and Motor Driven Fire Pumps FPW - P2 are unavailable, and a Backup Fire Pump is required to fight a fire.

INITIATING CUES You are directed to operate the HALE Portable Diesel Driven Fire pump to fight a fire.

TERMINATING CUE The HALE Portable Diesel Driven Fire Pump is running and pumping water.

ALT PATH EVALUATED Yes or No N/A BRANCHING STEP OR ALTERNATE PATH CUE (IF REQUIRED)

ALT PATH EVALUATED N/A OJT has been completed /

challenged per EN-TQ-204 for the listed task Qualified Trainer (Print Name & Sign Date P / S Qualified Evaluator (Print Name and Sign)

Date TPE UNSUCCESSFUL (DOCUMENT TPE FAILURES PER EN-TQ-204)

Feedback

N/A

TRAINEE NAME:

LOGIN ID:

Page 28 of 50 ROJT-NLO-QC002 Rev 33 TASK TITLE:

Makeup to Standby Cooling Tower Using Temporary Power to the Deepwell Pumps.

TASK #:

RBS-NL-256-EMERG-2 TASK STANDARD Makeup to Standby Cooling Tower using temporary power to the Deepwell Pumps per AOP-0004.

OE N/A SAFETY/PPE Appropriate required PPE Management Observation required?

N/A OJT TPE Observer (Print Name and Sign)

Observation #

INITIAL CONDITIONS Standby Cooling Tower low level alarm has been received.

INITIATING CUES You are directed to makeup the Standby Cooling Tower level using temporary power to the Deepwell Pumps per AOP-0004.

TERMINATING CUE Standby Cooling Tower no longer requires makeup.

ALT PATH EVALUATED Yes or No IF MWS-P1B is to be used, THEN perform the following:

BRANCHING STEP OR ALTERNATE PATH CUE (IF REQUIRED)

ALT PATH EVALUATED MWS-P1B is to be used per AOP-0004 OJT has been:

Completed Challenged Qualified Trainer (Print Name & Sign Date P / S Qualified Evaluator (Print Name and Sign)

Date TPE UNSUCCESSFUL (DOCUMENT TPE FAILURES PER EN-TQ-204)

Feedback

TRAINEE NAME:

LOGIN ID:

Page 29 of 50 ROJT-NLO-QC002 Rev 33 TASK TITLE:

Makeup to Standby Cooling Tower from Circ Water Flume.

TASK #:

RBS-NL-256-EMERG-4 TASK STANDARD Makeup to Standby Cooling Tower from Circ Water Flume per AOP-0004.

OE N/A SAFETY/PPE Appropriate required PPE Management Observation required?

N/A OJT TPE Observer (Print Name and Sign)

Observation #

INITIAL CONDITIONS Standby Cooling Tower low level alarm has been received.

INITIATING CUES You are directed to makeup the Standby Cooling Tower level from Circ Water Flume per AOP-0004.

TERMINATING CUE Standby Cooling Tower no longer requires makeup ALT PATH EVALUATED Yes or No N/A BRANCHING STEP OR ALTERNATE PATH CUE (IF REQUIRED)

ALT PATH EVALUATED N/A OJT has been:

Completed Challenged Qualified Trainer (Print Name & Sign Date P / S Qualified Evaluator (Print Name and Sign)

Date TPE UNSUCCESSFUL (DOCUMENT TPE FAILURES PER EN-TQ-204)

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N/A

TRAINEE NAME:

LOGIN ID:

ROJT-NLO-QC006 Rev 30 Page 15 of 60 TASK TITLE:

Makeup to Standby Cooling Tower with Fire Water TASK #:

RBS-NL-256-EMERG-3 TASK STANDARD Makeup to Standby Cooling Tower with Fire Water per AOP-0004 OE N/A SAFETY/PPE Appropriate required PPE Management Observation required?

N/A OJT TPE Observer (Print Name and Sign)

Observation #

INITIAL CONDITIONS A loss of Offsite power has occurred, and Standby Cooling Tower level is lowering.

INITIATING CUES You have been directed by the Control Room to add makeup to Standby Cooling Tower with Fire Water per AOP-0004 Attachment 12.

TERMINATING CUE Fire Water is lined up and being supplied to the Standby Cooling Tower.

ALT PATH EVALUATED Yes or No N/A BRANCHING STEP OR ALTERNATE PATH CUE (IF REQUIRED)

ALT PATH EVALUATED N/A OJT has been:

Completed Challenged Qualified Trainer (Print Name & Sign Date P / S Qualified Evaluator (Print Name and Sign)

Date TPE UNSUCCESSFUL (DOCUMENT TPE FAILURES PER EN-TQ-204)

Feedback

ML25267A061

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