ML032530022
| ML032530022 | |
| Person / Time | |
|---|---|
| Site: | Crystal River  |
| Issue date: | 09/03/2003 |
| From: | Florida Power Corp |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 000124352 EM-225, Rev 14, EM-225-E, Rev 6 | |
| Download: ML032530022 (89) | |
Text
PASSPORT DOCUMENT To NRC NRC Facility CR3 Department : TRANSMITTAL Address CR3-01242 / MAIL CODE: N/A DC DESK Inilnl aurn Page: I From Address
- CR3DOCSVCS Attention: DOCUMENT SERVICES - SA2A
- FLORIDA POWER CORPORATION CRYSTAL RIVER COMPLEX 15760 WEST POWERLINE STREET a'lll City : CRYSTAL RIVER State:FL Postal Code: 34428-6708 Country : UNITED STATES Email Contact Date/Time : 09/03/03 11:06 Transmittal Group Id:0000012153 Trans No. : 000124352
Title:
Total Items: 00002 Item Facility Type Sub Document Number Sheet Doc Status Revision Doc Date Copy # Media Copies 0001 CR3 POM EMG EM0225 ACTIVE 014 H 01 0002 CR3 POM EMG EM0225E ACTIVE 006 H 01 If a document was not received or is no longer required check the response below and return to sender.
Documents noted above not received (identify those not received).
I no longer require distribution of these documents (identify those no longer required).
Date: Signature:
1%f
I
, Progress Energy Information Use PROGRESS ENERGY CRYSTAL RIVER UNIT 3 PLANT OPERATING MANUAL EM-225 DUTIES OF THE TECHNICAL SUPPORT CENTER ACCIDENT ASSESSMENT TEAM EM-225 Rev. 14 Page 1 of 35
TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE .................................... 3
2.0 REFERENCES
..................................... 3 2.1 Developmental References ..................................... 3 3.0 PERSONNEL INDOCTRINATION ..................................... 4 3.1 Definitions ..................................... 4 3.2 Responsibilities .................................... 5 3.3 Limits And Precautions .................................... 8 4.0 INSTRUCTIONS ..................................... 9 4.1 Accident Assessment Initiation ...................................... 9 ENCLOSURES (All Enclosures are Optional Records Non-Quality) 1 MT Coordinator Checklist . 10 2 TSC Briefing Guideline .11 3 TSC Ringdown Communicator Checklist ............................... 11 4 MT Operations Support Checklist .13 5 AAT Engineers Checklist .14 6 Control Room Ringdown Communicator Checklist .15 7 NRC Communicator Checklist .16 8 Critical Safety Function Checklist .17 9 Dose Assessment Team Notification ............................................. 22 10 Core Damage Assessment .23 11 TSC Guidance For EOPs .26 12 TSC Acocident Assessment Team OSC Request Form .33 13 SPDS or Recall Display Setup for TSC Projection Screens.34 EM-225 Rev. 14 Page 2 of 35
1.0 PURPOSE This procedure provides guidance for the establishment and 6peration of the Technical Support Center Accident Assessment Team (AAT), for the determination of core and fission product barrier status, and for the interface with the Dose Assessment Team. Information from these assessments will be used in conjunction with other guidance for development of accident mitigation strategies. This procedure also provides guidance to the MT to perform actions described in the EOPs. [NOCS 062718]
2.0 REFERENCES
2.1 Developmental References 2.1.1 Response Technical Manual (RTM-96); USNRC; Volume 1, Rev. 3 2.1.2 Radiological Emergency Response Plan 2.1.3 Emergency Operating Procedures (EOPs) 2.1.4 NUREG-1228, Source Term Estimation During Incident Response to Severe Nuclear Power Plant Accidents 2.1.5 B&W Technical Bases Document 2.1.6 FPC IOC CR97-0122, Dated 12/23/97 2.1.7 NEI 91-04, Revision 1, Severe Accident Issue Closure Guidelines 2.1.8 FPC IOC SE99-0184, Dated 9/14/99 2.1.9 EEM-99-018, Rev. 0 Operating Limits for SWP-1 A/SWP-1 B under Minimum Flow Conditions.
2.1.10 EM-202, Duties of the Emergency Coordinator 2.1.11 EM-102, Operation of Technical Support Center 2.1.12 EM-103, Operation and Staffing of the CR-3 Control Room During Emergency Classification 2.1.13 CP-1 51, External Reporting Requirements EM-225 Rev. 14 Page 3 of 35
3.0 PERSONNEL INDOCTRINATION 3.1 Definitions 3.1.1 Accident Assessment Team (AAT) - Consists of Coordinator, TSC Ringdown Communicator, Control Room Ringdown Communicator, Engineer, Operations Support, and NRC Communicator.
3.1.2 Candidate High Level Actions (CHLA) Actions described in the CR-3 Severe Accident Guideline which could be taken to mitigate a Severe Accident and are deemed appropriate based on Plant Damage Conditions.
3.1.3 Critical Safety Functions (CSFs) - Those functions needed to ensure adequate core cooling and to preserve the integrity of the fission product barriers thereby protecting the health and safety of the general public and plant personnel. They include: reactivity control, coolant inventory control, decay heat removal capability, fission product barrier status, electrical power availability and control complex status.
3.1.4 Emergency Action Levels (EALs - Conditions or indications that may be used as thresholds for initiating specific emergency measures (see EM-202, Enclosure 1).
3.1.5 Plant Damage Conditions (PDC) - Damage conditions used in the CR-3 Severe Accident Guideline to describe the status of the reactor coolant system, reactor core, and the containment during the progression of a Severe Accident.
3.1.6 Protective Action Recommendations (PARs - Emergency measures recommended for purposes of preventing or minimizing radiological exposures to the Energy Complex personnel or members of the general public.
3.1.7 Severe Accident - An accident (beyond that assumed in the CR-3 design and licensing basis) that results in catastrophic fuel rod failure, core degradation and fission product release into the Rx vessel, Reactor Building or the environment.
EM-225 Rev. 14 Page 4 of 35
3.2 Responsibilities 3.2.1 Control Room RingdoWn Communicator
- Reports to the Control Room and establishes communication with the TSC Ringdown Communicator on the Accident Assessment Ringdown phone. Brief TSC Ringdown Communicator on operator actions that are in progress.
- Relays instructions to Control Room Operators for mitigating actions as directed by the Emergency Coordinator (EC).
- If a Severe Accident is occurring, directs Control Room personnel regarding actions to take to mitigate the Severe Accident, based on actions approved by the TSC EC.
- Once TSC is operational, request extra plant operators (if available) be sent to OSC for in plant support.
- Inform TSC of in plant operator actions that are being performed.
EM-225 Rev. 14 Page 5 of 35
3.2.2 AAT Coordinator
- Ensures additional MT members are notified as needed.
- Identifies plant parameters to be tracked.
- Coordinates MT activities and ensures that team members remain focused on objectives.
- Keeps the EC informed of AAT activities.
- If a Severe Accident is occurring, reviews recommended Candidate High Level Actions and mitigation plans prior to submitting to the Emergency Coordinator. NOCS 100056]
- If a Severe Accident is occurring, coordinates efforts of the Accident Assessment team to ensure the development of mitigation strategies using the CR-3 Severe Accident Guideline.
- If additional resources are needed, coordinates with the EOF Technical Support Team to provide required support.
- Establishes communications with the Emergency Operating Facility (EOF) Technical Support Team, if the EOF is staffed.
- Approve Enclosure 12 to request operator actions outside CCHE or maintenance repair activities that have been initiated by the Control Room or MT. This request should be processed through TSC Repairs Coordinator to the OSC.
3.2.3 TSC Ringdown Communicator
- Establishes communications with the Control Room Ringdown Communicator on the Accident Assessment Ringdown phone.
- Relays information on changing radiological conditions and maintenance activities to the Control Room.
- Relays plant conditions from the Control Room to the TSC AAT.
- Maintains the Accident Assessment Team Log.
- Relays information and directions to the Control Room of actions required to mitigate a Severe Accident based on approved Candidate High Level Actions.
- Initiate Enclosure 12 to request operator actions outside CCHE or maintenance repair activities for the OSC that is requested by the Control Room or MT.
EM-225 Rev. 14 Page 6 of 35
3.2.4 AAT Engineers
- Assesses plant conditions and provides engineering support for developing accident mitigation strategies as needed.
- Aids in determining additional Engineering resources.
- Monitors plant parameters for indications of core damage and status of fission product barriers.
- During Severe Accident conditions, evaluates plant parameters, determines Plant Damage Conditions, and develops Candidate High Level Action recommendations using appropriate calculational aids from the CR-3 Severe Accident Guideline.
3.2.5 AAT Operations Support Monitors overall plant status during an emergency with emphasis on Critical Safety Functions.
- Functions as a technical resource for Operations in assessing plant conditions and in development of accident mitigation strategies that are outside the scope of Emergency Operating Procedures (EOPs). [NOCS 13010]
- During Severe Accident Conditions, provides support to the AAT Engineers in determining Plant Damage Conditions and developing mitigation strategies using the CR-3 Severe Accident Guideline.
- Coordinates/processes requests for operator actions or maintenance support activities through the TSC Repairs Coordinator using Enclosure 12.
Determine emergency and non-emergency notifications to the NRC as defined in CP-1 51, External Reporting Requirements.
3.2.6 NRC Communicator NOCS 96042]
- Maintains an open, continuous communication line on the Emergency Notification System with the NRC Operations Center upon request by the Headquarters Operations Officer.
- Log times NRC is notified of Emergency Classification changes and Protective Action Recommendations.
- Make emergency and non-emergency notifications to the NRC as defined in CP-1 51, External Reporting Requirements.
3.2.7 EOF Technical Support Team
- Functions as a technical resource for the EOF Director in development of PARs by monitoring plant conditions (particularly the CSFs).
- Assists the TSC MT team as needed in development of mitigation strategies and in research of solutions to plant problems.
- Responsible for the development of long-term recovery plans.
EM-995 Rev. 14 Page 7 of 35
3.2.8 Emergency Coordinator (EC) or designee
- Controls all activities at CR-3 during activation of the Radiological Emergency Response Plan.
- Implements EM-202.
- Determines EAL and PAR changes based on information obtained from the Accident Assessment Team and Dose Assessment Team.
- Functions as the decision maker during a Severe Accident. The EC will approve all recommended Severe Accident mitigation strategies orior to implementation.
- Is authorized to declare 10CFR50.54(x and y) to implement emergency actions deemed necessary to protect the health and safety of the public. A separate notification is required to the NRC for each occasion. Once a Severe Accident is declared, only one notification to the NRC is required.
3.2.9 Dose Assessment Team
- Supports the Accident Assessment team with on-site radiological data and with chemical and radiological analysis of samples as needed to assess the accident.
- Provides Plant Radiation Monitor readings and assessments.
- Provides projected radiological data (on-site and off-site doses, dose rates, and deposition) (> 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to obtain).
- Provides RCS PASS data (> 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to obtain) on Radionuclide composition, Chloride concentration, Dissolved Hydrogen concentration, and Boron concentration.
- Provides Reactor Building and/or Auxiliary Building Atmosphere Radionuclide composition
(> 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to obtain).
- Provides in-plant radiological data.
- Provides chemical and radiological analysis of OTSGs and secondary samples.
- Provides Reactor Building sump boron concentration (> 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to obtain).
3.3 Limits And Precautions 3.3.1 Urider Severe Accident Conditions, plant instrumentation may provide false or highly inaccurate readings due to harsh environments beyond their qualifications. Several instruments should be monitored along with trends to assess plant conditions.
EM-225 Rev. 14 Page 8 of 35
4.0 INSTRUCTIONS 4.1 Accident Assessment Initiation 4.1.1 AAT Coordinator or designee: PERFORM the duties of Enclosure 1, MT Coordinator Checklist.
4.1.2 TSC Ringdown Communicator: PERFORM the duties of Enclosure 3, TSC Ringdown Communicator Checklist.
4.1.3 MT Operations Support member: PERFORM the duties of Enclosure 4, AAT Operations Support Checklist.
4.1.4 AAT Engineers: PERFORM the duties of Enclosure 5, MT Engineers Checklist.
4.1.5 Control Room Ringdown Communicator: REPORT to the Control Room and PERFORM the duties of Enclosure 6, Control Room Ringdown Communicator Checklist.
4.1.6 NRC Communicator: PERFORM the duties of Enclosure 7, NRC Communicator Checklist.
EM-225 Rev. 14 Page 9 of 35
ENCLOSURE 1 AAT COORDINATOR CHECKLIST
, ,p Badge IN at TSC card reader and place name on TSC Staffing Board.
0 Notify the EC that the Accident Assessment Team is operational when ALL of the following are accomplished:
O Determine Critical Safety Functions (Enclosure 2) o Ability to brief EC on plant status to include impact of EALs or PARs through use of either SPDS or phone link established with Control Room.
O Determine current plant status and conditions.
0 Ensure Enclosure 2 is complete. (normally by AAT Operations support)
O Ensure Critical Safety Functions Status Board is updated.
o Ensure phone link between Control Room and TSC Ringdown Communicators.
O Evaluate plant conditions and assist the EC in making timely and proper Emergency Classifications and Protective Action Recommendations.
Ol Ensure each AAT position is staffed. Request Security to contact additional AAT members as needed. (Refer to "Emergency Response Personnel Roster".)
o Operations Support:
o TSC Ringdown Communicator:
o Control Room Ringdown Communicator:
0 2 Engineers:
O NRC Communicator:
O Ensure all AAT members have badged in at TSC Card Reader.
o Determine parameters or parameter groups (SPDS and RECALL) to monitor and ensure the desired parameters are displayed.
O Ensure times and results of significant actions are documented throughout the emergency.
O Ensure AAT performs applicable enclosures in EM-225.
o Ensure OSC repair priorities are appropriate for plant conditions.
0 Ensure the EC is informed of significant MT activities and changes in plant status.
o If the EOF is staffed, establish communication with the EOF Technical Support Team using plant extensions (6720, 6205).
o During TSC briefing ensure Critical Safety Functions are addressed.
0 Approve Enclosure 12 requests for operator actions outside CCHE or maintenance repair activities that have been initiated by the Control Room or AAT. This request
- should go through TSC Repairs Coordinator to the OSC.
EM-225 Rev. 14 Page 10of 35
ENCLOSURE 2 TSC BRIEFING GUIDELINE
\,Refer to Enclosures 8 and 10 to aid in this evaluation.
I. REACTOR SHUTDOWN Yes iI NoLI
- 11. CORE ADEQUATELY COOLED Yes n No D III. FISSION PRODUCT BARRIER ASSESSMENT (Use Enclosure 8, Part ll)
Fuel Clad: Intact L Potential Loss I Loss l RCS: Intact L Potential Loss a Loss Containment: Intact E Potential Loss L Loss a IV.EMERGENCY ELECTRICAL POWER STATUS Off-Site Power Available? Yes LI No LI1 ES Bus Energized? Yes Li No LI Emergency Diesel Generator Available? Yes LI No LI1 DC Power Available? Yes L No LI V. CONTROL COMPLEX STATUS Ventilation / Cooling Available? Yes a Nob
- Necessary Instrumentation Available? Yes L No a VLOTHER CONDITIONS / CHALLENGES
- Necessary refers to-specific instruments and annunciators that are needed to identify, diagnose, and track the problems that are causing the emergency.
EM-225 Rev. 14 Page 11 of 35
ENCLOSURE 3 TSC RINGDOWN COMMUNICATOR CHECKLIST Establish contact with the Control Room Communicator via the Accident Assessment Ringdown phone.
O Ensure the Control Room is informed of changing radiological conditions, ongoing TSC maintenance and repair activities, accident mitigation priorities and operator actions outside the CCHE.
NOTE The EOF Technical Support Team can monitor the Accident Assessment Ringdown phone, but cannot speak over it.
o Maintain the Accident Assessment Team log book with all significant events, changes in plant status, and requests to and from the Control Room.
O Relay information and directions to the Control Room as appropriate.
O Monitor progression through EOPs and APs (using a copy of the applicable
's-" procedures), anticipating problems created by unavailable equipment or other unusual plant conditions. Mark place keeping aids as appropriate to allow other AAT members to determine status of procedure usage. Provide periodic status to MT Operations Support member.
O Initiate Enclosure 12 requests for operator actions outside CCHE or maintenance repair activities for the OSC that is requested by the Control Room or AAT.
EM-225 Rev. 14 Page 12 of 35
ENCLOSURE 4 AAT OPERATIONS SUPPORT CHECKLIST
[NOCS 62764]
E't Begin assessment of Critical Safety Functions to ensure adequate core cooling and fission product barrier preservation, using Enclosure 8 as applicable.
O Complete Enclosure 2 and provide the results to the AAT Coordinator. Enclosure 2 should be completed periodically or as conditions change.
O Maintain the CSF Status Board at the TSC.
O Complete Enclosure 9 and provide the results to the Dose Assessment Team Leader. If conditions change, Enclosure 9 should be reassessed and submitted to the Dose Assessment Team.
O Coordinates/processes requests for operator actions or maintenance support through the Repairs Coordinator using Enclosure 12. Refer to SP-306 for a list of EOB and EOL locations and contents.
O If RCS LOCA conditions exist, coordinate performance of EM-225A, Post Accident RB Hydrogen Control.' [NOCS 62767]
o If RCS LOCA conditions exist, coordinate performance of EM-225E, Guidelines For Long Term Cooling."
If SGTR exists monitor BWST depletion rate and initiate BWST MU early in the event if necessary (see Enclosure 11, page 2 of this procedure).
O If EFW or AFW is operating, coordinate performance of EM-225F, Long Term Emergency Feedwater Management."
O If a Severe Accident is in progress, assist engineering in developing appropriate mitigation strategies using the Candidate High Level Actions in the CR-3 Severe Accident Guideline.
[NOCS 100056]
O Provide appropriate input to the Communication/Report Coordinator to update Florida Nuclear Plant Emergency Notification Form Supplemental Data Sheet.
o If any diesel operated equipment is running, evaluate the following parameters (OSC support and local observation might be required to obtain information on support systems and operating parameters):
a Diesel support systems (i.e., ventilation, fuel transfer, cooling, etc.)
- Diesel operating parameters
- Operating EDG load limitation (loaded and unloaded)
- Fuel and lube oil supplies, P Determine emergency and non-emergency notifications to the NRC as defined in CP-151, External Reporting Requirements.
EM-995 Rev. 14 Page 13 of 35
ENCLOSURE 5 AAT ENGINEERS CHECKLIST
[NOCS 62764]
O Perform Enclosure 10. Perform an initial and periodic assessment of core damage and fission product barriers, and provide the results to the MT Operations Support Member and the Dose Assessment Team Leader.
O If RCS LOCA conditions exist, coordinate performance of EM-225B, "Post-Accident Boron Concentration Management."
o If RCS LOCA conditions exist, obtain RB atmosphere j131 concentration and transmit value to control room (for BS pump shutdown decision making).
O Maintain the Plant Parameters Status Board (if required). Based on plant conditions, place key parameters on status board for trending.
O Monitor for conditions listed in Enclosure 11. Provide the AAT Operations Support member with recommended actions.
o If RB temperatures are elevated, coordinate the performance of EM-225C, "Post Accident Monitoring Of Reactor Building Temperature."
o If any OTSG level is < 12.5 inches (indicating a dry OTSG), coordinate the performance of EM-225D, "Guidance For Dry OTSG Tube To Shell Delta T Monitoring And Control."
o Evaluate the effects of proposed maintenance repair activities and operational manipulations on plant equipment.
O Develop contingency plans and support emergency repair efforts as applicable.
o If a Severe Accident is in progress, develop mitigation strategies using the Candidate High Level Actions in the CR-3 Severe Accident Guideline.
o Within 7 days, ensure SW minimum flow requirements are maintained. If ES or RBIC has actuated and either SWV-353 or 354 has failed closed,-establish flow to the RB coolers or ensure only 1 SW pump is running.
O Additional computers may be obtained, as needed, from nuclear administrative building (i.e., engineering laptop computers), that can be used to access documentation on the network.
EM-225 Rev. 14 Page 14 of 35-
ENCLOSURE 6 CONTROL ROOM RINGDOWN COMMUNICATOR CHECKLIST o Establish communication with the TSC Ringdown Communicator on the Accident Assessment Ringdown phone in the Control Room. Brief TSC Ringdown Communicator on operator actions that are in progress.
O Relay status of overall plant conditions, operator activities and questions to the TSC AAT.
o Relay instructions to Control Room Operators for mitigating actions as directed by the EC.
o Inform Control Room Operators of the following:
Changes in Emergency Classifications TSC repair efforts Operators activities dispatched from the TSC/OSC Changing radiological conditions Mitigation priorities o EOPs or APs in use by Control Room.
0 If a Severe Accident is in progress, direct Control Room personnel regarding mitigation strategies, based on actions approved by the TSC Emergency Coordinator.
O Relay requests for support from the Control Room to OSC teams, via the TSC Ringdown Communicator.
E Once TSC is operational, request extra plant operators (if available) be sent to OSC for in plant support. (Ref. EM-1 03, Enclosure 1, Dispatching of Resources During Emergency Plan Entry) 0 Inform TSC of operator actions being performed.
EM-225 Rev. 14 Page 15 of 35
ENCLOSURE 7 NRC COMMUNICATOR CHECKLIST CI Contact the TSC Report Preparation to determine if continuous communication with the NRC is required.
O Obtain copies of any previously submitted NRC reports.
o If the NRC has requested continuous communication, establish communication with the NRC Communicator on the Emergency Notification System (ENS).
[NOCS 3054, 9405]
O Maintain a log book of significant communications between the NRC and CR-3, including a summary of responses to NRC questions and transmittal of information.
0 Maintain an open line on the ENS until the NRC agrees to terminate communications. [NOCS 10528]
O Log time(s) when NRC is notified of Emergency Classification changes.
El Log time(s) when NRC is notified of Protective Action Recommendations.
O When communication with the NRC is not required, provide support to other AAT members as needed.
O Make emergency and non-emergency notifications to the NRC as defined in CP-151, External Reporting Requirements.
EM-225 Rev. 14 Page 16 of 35
ENCLOSURE 8 Page 1 of 5 CRITICAL SAFETY FUNCTION CHECKLIST Monitor the parameters associated with the Critical Safety Functions. The parameter tables below are for reference only. It is not intended that the tables be completed during each evaluation. Plant computer point numbers or SPDS/RECALL point numbers are listed, if available.
Using pre-established RECALL Groups based on accident type in progress is recommended.
Notify the AAT Coordinator immediately if any of the CSFs cannot be verified.
- 1. REACTOR SHUTDOWN STATUS REACTIVITY CONTROL PARAMETER COMPUTER RECALL POINT POINT ,
All Rods at in-limits P057 RECL-375 Y/N Intermediate Range P212 RECL.150 detector NI-3 amps Intermediate Range P213 RECL-151 detector NI-4 amps Source Range P202 RECL-1 52 NI-1 cps Source Range P203 RECL-1 53 NI-2 cps Low Range RECL-NI-14115 102,103 Adequate Shutdown OP-103C l Margin Curve 18&19 EM-225 Rev. 14 Page 17 of 35
ENCLOSURE 8 Page 2 of 5
- 11. CORE COOLING STATUS:
ECCS/SUPPORT STATUS PARAMETER COMPUTER RECALL POINT POINT Subcooling Margin Ml 14 _
A HPI Pump operating RECL-209 B HPI Pump operating RECL-210 C HPI Pump operating RECL-211 MUV-23 flow W704 RECL-52 MUV-24 flow W706 RECL-54 MUV-25 flow W703 RECL-51 MUV 26 flow W705 RECL-53 X06 X064 RECL-207 RECL-208 DHPs operating AB (run/stop) _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _
DHP-1Aflow W409 RECL-55 DHP-1B flow W410 RECL-56 CFT A level P200 CFT B level P201 CFT A press CFT B press BWST level (ft) X335 RECL-57 RWPs operating 1/2A/2B/3At3B DCPs operating AB .
(yes/no) .
SWPs operating SECONDARY SYSTEM STATUS PARAMETER COMPUTER RECALL POINT POINT EFIC OTSG A press W449 RECL-252 :
EFIC OTSG B press W452 RECL-255 .
OTSG A level S285 RECL-92 OTSG B level S286 RECL-93 MFW flow A S301 RECL-100 MFW flow B S302 RECL-101 EFPs operating Yz3/7 EFW flow to A OTSG S300 RECL-245 EFW flow to B OTSG S312 RECL-247
__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __8 _ _ __ _ _ _ _ _ _ _ _ I _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -
EM-225 Rev. 14 Page 18 of 35
ENCLOSURE 8 Page 3 of 5 III. FISSION PRODUCT BARRIER ASSESSMENT:
FUE CPLAD O INTACT 3 POTENTIAL LOSS 0 LOSS
- Does NOT meet the
- RCS condition warrant entry into
- RCS conditions in (or previously in) criteria for "Potential EOP-07 Region 3 or Severe Accident Region Loss" or "Loss"* Core Exit Thermocouples > 700
- RM-G29/30 > 100 Rhr for > 15 minutes
- Enclosure 6 indicates failed fuel REACTOR COOLANT SYSTEM O INTACT E POTENTIAL LOSS 0 LOSS
- Does NOT meet the
- RCS leak resulting in loss of criteria for 'Potential requiring one or more injection adequate-subcooling margin Loss" or"Loss" valves to maintain adequate
- OTSG Tube Rupture resulting in subcooling margin loss of adequate subcooling margin
- RCS pressure ITincore -
- RM-G29/30 >1 OR/hr for > 15 relationship violates NDT limits minutes
- HPIVPORV or HPI/Code Safety valve cooling is in progress
..... ____ ___ -- NTAINMENT O INTACT 0 POTENTIAL LOSS 0 LOSS
- Does NOT meet the
- RB pressure > 54 psig
- Containment isolation is incomplete criteria for "Potential
- RB hydrogen concentration > 4% and release path to environment Loss" or "Loss"'* RB pressure > 30 psig with NO exists. Confirmation may be from building spray available elevated radiation readings in areas
- RMG-29 or 30 reading > 25,000 adjacent to the RB.
R/hr
- OTSG Tube Rupture > 10 gpm
- Core conditions in severe exists and prolonged steaming to accident region of ICC curves for atmosphere or an unisolable steam
>15 min leak outside RB from affected OTSG.
- Rapid unexplained RB pressure decrease following an initial increase Performed By: Time:
EM-225 Rev. 14 Page 19 of 35
ENCLOSURE 8 Page 4 of 5 IV. EMERGENCY ELECTRICAL POWER STATUS:
OFF-SITE POWER PARAMETER AVAILABLE I UNAVAILABLE 500 KV SWITCHYARD 230 KV SWITCHYARD OFF-SITE POWER XFRM.
BEST ES BUSES PARAMETER AVAILABLE UNAVAILABLE A-ES 4160V BUS B-ES 4160V BUS A- ES 480V BUS (Note 1)
B-ES 480V BUS (Note 1)
EMERGENCY DIESEL GENERATOR PARAMETER RECALL PT. LOADED AVAILABLE UNAVAILABLE K%. P MA-EDG RECL-133,171 .A:
B-EDG RECL-134,172 DC ELECTRICAL PARAMETER Note (1) AVAILABLE UNAVAILABLE A-BATTERY B-BATTERYI C-BATTERY Note (1) Battery failure will occur if associated battery chargers are de-energized.
EM-225 Rev. 14 Page 20 of 35
ENCLOSURE 8 Page 5 of 5 V. CONTROL COMPLEX STATUS:
CONTROL COMPLEX VENTILATION STATUS PARAMETER AVAILABLE OPERATING UNAVAILABLE A-TRAIN EMERGENCY RECIRC B-TRAIN EMERGENCY RECIRC A-CHILLER B-CHILLER CONTROL ROOM INSTRUMENTATION STATUS PARAMETER -AVAILABLE UNAVAILABLE NNI-X NNI-Y ICS EFIC RPS ESAS COMMENTS:
I~~~~~~~~~~~~~~~~~~~~~~~~~~~
EM-225 Rev. 14 Page 21 of 35
ENCLOSURE 9 DOSE ASSESSMENT TEAM NOTIFICATION
\ 1. The Accident Assessment Team is responsible for supplying the Dose Assessment Team with an evaluation of the accident type, the release pathway, and the release flow rate. The accident type affects the radionuclide distribution (i.e., percentage of each isotope) used by Dose Assessment to predict off-site doses.
- 2. The accident type is determined by physical parameters and instrument readings throughout the plant.
- 3. Complete the checklist below to the extent possible and give to the Dose Assessment Team Leader.
ACCIDENT TYPE
- LOCA l W G Decay Tank Rupture l __ OTSG Tube Leak
____ Fuel Handling l_ Other:__
O LOSS-OF-COOLANT ACCIDENT TIME OF RX TRIP:_
a.- Normal Activity - Clad damage _ Fuel melt_ (from Enclosure 10)
- b. Release pathway information (leak from where to where)
- c. Release path flow rate (estimated for unmonitored releases)
- d. Estimated duration Unknown_
- e. Reactor Building spray on/off times
- f. Aux. Bldg. Ventilation: Flow rate_ _ Charcoal banks in service A:B:C:D
- g. Containment pressure PSIG
- h. Loose Parts Monitor indications No_ Yes_ Location:_
O WASTE GAS DECAY TANK RUPTURE
- a. Release pathway: Tank rupture_ Valve leakage Other_
- b. Tank volume_ _ pressure
- c. Release rate Unknown__ Estimate CFM
- d. Estimated duration: Unknown Time_
- e. Aux. Bldg. Ventilation: Flow rate_ _ Charcoal banks in service A:B:C:D o STEAM GENERATOR TUBE RUPTURE TIME OF RX TRIP:
- a. Primary-to-secondary leak rate: gpm
- b. Core status: Cladding damage_ _ Fuel melt _ Normal
- c. Leaking OTSG isolated: Yes_ No _
- d. MSSV Open: Yes_ No ADV Open: Yes No_
- e. Condenser vacuum: Yes_ No RM-A2 In Service?: Yes_ No_
- f. Potential for change in status of leak: Yes_ No_
- g. Estimated duration of leak:_
- h. Aux. Bldg. Ventilation: Flow rate_ _ Charcoal banks in service A:B:C:D Cl FUEL HANDLING ACCIDENT
- a. Locatioh of damaged fuel: Pool A_ Pool B_ Number of Elements_
- b. Damage caused by: Mechanical impact Overheating_ Unknown
- c. Aux. Bldg. Ventilation: Flow rate Charcoal banks in service A:B:C:D
- d. Release pathway _ Unknown_
- e. Estimated duration Unknown_ _
Status as of _ _ Date: Completed By EM-225 Rev. 14 Page 22 of 35
ENCLOSURE 10 Page 1 of 3 CORE DAMAGE ASSESSMENT Determine if core damage has occurred using one or more of the following methods. Estimate the extent of the damage. Evaluate the status of the fission product barriers. Report the results of the evaluation to the MT operations support member and the dose assessment team leader. Continue to re-assess core and fission product barrier status as conditions change.
o ESTIMATE CORE DAMAGE BASED ON RCS SAMPLES.
Core damage assessment based on Reactor Coolant samples will be evaluated by the Dose Assessment Team using CH-632, Enclosure 5. The results will be submitted to the AAT. (May take >2 hours to obtain results)
O ESTIMATE CORE DAMAGE BASED ON RM-G29130 RADIATION LEVELS (NOCS 002153]
NOTE: (1) Use of RM-G29/30 for determining core status requires a failure of the RCS (i.e., LOCA or PORV open).
(2) Low monitor reading does not necessarily Indicate lack of core damage. The release from the core may bypass the Containment, may be retained In the RCS, may be over a long period of time,,
or may not be uniformly mixed.
(3) Inconsistent readings may be due to the uneven mixing in the Containment (e.g., steam rising to the top). IT MAY TAKE SEVERAL HOURS FOR UNIFORM MIXING.
ASSUMPTIONS:
The below table assumes a short release. A long-term release cannot be characterized using these tables.
TIME -: _: _ -_
RM-G29 R/HR R/HR R/HR R/HR R/HR RM-G30 RIHR R/HR R/HR R/HR R/HR o NO CORE DAMAGE
< 100 R/HR O POSSIBLE CLAD FAILURE AND GAS GAP RELEASE 100 - 25,000 RIHR WITH RB SPRAY 100 - 75,000 R/HR WITHOUT RB SPRAY O POSSIBLE CORE MELTING
> 25,000 R/HR WITH RB SPRAY
> 75,000 R/HR WITHOUT RB SPRAY EM-225 Rev. 14 Page 23 of 35
ENCLOSURE 10 Page 2 of 3 CORE DAMAGE PROGRESSION ONCE UNCOVERED 0 IF inadequate subcooling margin exists, THEN determine if the core is uncovered.
Reactor Coolant Inventory Tracking System (RCITS) provides a continuous indication of reactor vessel head and hot leg coolant inventory trend with the reactor coolant pumps Inoperation or tripped. RITS consists of an RCS Hot Leg Level Subsystem, Reactor Vessel Level Subsystem and RC Void Trending Subsystem.
The RCS Hot Leg Level Subsystem (RC-163A1B-LR1) can monitor the top of the hot leg to the bottom of the hot leg with zero flow conditions. The Reactor Vessel Level Subsystem (RC-164A/B-LR1) can monitor the top of the reactor vessel to the bottom of the hot leg with zero flow conditions. The bottom of the hot leg is approximately two feet above the top of the fuel. An off-scale low reading would indicate a high probability of loss of level below core level. Any flow (including natural circulation) in the RCS will result in a lower than actual reading. Thus, any indicated level will provide assurance that coolant level isabove the core.
The Reactor Void Trend Subsystem (RC-1 69-XR) monitors void trends in the RCS when RCPs are running. RCP motor power and Tcold are used to infer average density of fluid passing through the pump (liquid or two-phase).
A 0%reading infers no voiding, while 100% reading infers complete voiding.
Recorders are on the PSA panel inthe Control Room and display on RECALL (points 62,63,64,65,70,71).
A-HOT LEG B-HOT LEG A-VESSEL B-VESSEL VOID TREND RC-163A-LR1 RC-163B-LR1 RC-164A-LR1 RC-164B-LR1 RC-169-XR RECALL PT 63 RECALL PT 70 RECALL PT 62 RECALL PT 65 RECALL PT 64,71 o CORE REMAINS COVERED TINCORE indicates saturated conditions RCITS indicates any level O UNCOVERED FOR 15 TO 45 MINUTES Core temperature 1800-2400OF Fuel cladding failure (occurred in 34 minutes at Three Mile Island)
Rapid hydrogen generation Release of fission products out of fuel pin gap (gas gap failure)
Local fuel melt O UNCOVERED FOR 30 TO 90 MINUTES Core temperature 2400-42000 F Possible uncoolable core Possible slump of molten core Rapid release of volatile fission products (grain boundary release)
O UNCOVERED FOR 1 TO 3+ HOURS Core temperature > 42000 F Maximum core melt and hydrogen generation Maximum in-vessel fission product release Possible melt-through of vessel EM-225 Rev. 14 Page 24 of 35
ENCLOSURE 10 Page 3 of 3 CORE DAMAGE ASSESSMENT BASED ON ICC CURVE 0 ASSESS CORE DAMAGE BY PLOTTING RCS PRESSURE/INCORE TEMPERATURE ON THE ICC CURVE BELOW.
O Regions 1 and 2 indicate no fuel damage (normal RCS activity).
O Region 3 indicates possible gas gap failure.
O Severe Accident Region indicates possible core melt.
2600 2400 Saturationr 2200 2000 1800 1600 FRegioni111111 C,
1400 w Region 2 C. 1200 1000 -- - - - - I ===_==tRegin3 T_ad2.10 4 - - --
800 600
-. - - - Severe Accident Region
- - [ -4 gia n3 WTclad IM IF 400 200 0
200 300 400 500 600 700 800 900 1000 1100 1200 1300 Tincore (F)
EM-225 Rev. 14 Page 25 of 35
26ENGQ- SURE 11
_ ge 1 of 7
[NOCS 62718, 62764. 627671 This enclosure provides the relationship with the EOPs and TSC guidance during emergency events. It Is management's expectation that the guidance steps will be implemented, based on the emergency condition of the plant, by either nvoking 10 CFR 50.54 (x), (y), formal 10 CFR 50.59 reviews and approvals, or by existing approved procedures.
PARAMETER EOP TBD REF. TSC GUIDANCE RB Hydrogen EOP-3, 6, HPIC, 5.4 1. Align hydrogen monitoring equipment using EOP-14, Enclosure 2, PPO Control 7, 8 IlI.F, 6.2,10.0, 12.6b, 13.6b Post Event Actions.
LBLO 4.4, 6.3 2. Monitor hydrogen concentrations using EOP-14, Enclosure 21, SBLO 12.4, 20.3, 9.3 RB Hydrogen Monitor Log.
- 3. Purge RB when authorized per EM-225A. NOCS 627671 Interfacing references are:
EM-206 for telephone number for procurement representative to obtain recombiners MP-575 for installation of recombiners OP-417B for operation of recombiners MP-815 for installing H2 purge flow indicators Building Spray EOP-3, 8 None If RB sump screen blockage occurs consider alternate criteria for BSP shutdown (See EM-225E, Section 4.6)
Termination Criteria EOP-14 Verify all of the following before terminating Building Spray:
Enc 19
- 1. BS has been on for > or equal to 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />.
- 2. RB pressure is < 10 psig.
- 3. RB pressure is stable or lowering.
- 4. RB atmosphere is < 13 icVcc -131.
- 5. RB temperature is stable or lowering (also refer to EM-225C).
- 6. Concurrence is obtained from EC and Dose Assessment to terminate BS.
Continue EOP-6, 8 FF, 11.5 Verify all of the following:
Cooldown With NC, 11.4 1. Begin establishing a Post Accident Recovery Plan (this can be done during DHR System plant cooldown).
- 2. The reactor is being cooled by DHR.
- 3. DHR cooling is consistent with maintaining adequate SCM.
- 4. The RCS is subcooled (use DH cooler outlet temperature for cooldown rates).
- 5. The RCS is depressurized.
- 6. Prohibit establishing any flow path that was isolated by the ES system unless the potential for radioactive releases is evaluated and the release path, doses, and methods have been approved by the EC.
- 7. Control of containment penetrations has been established.
- 8. Monitor and maintain RCS boron concentration for required shutdown margin.
EM-225 Rev. 14 Page 26 of 35
EN ')SURE 11
( C TSC GUIDANCE FOR EOPs t .ge 2 of 7 PARAMETER EOP TBD REF. TSC GUIDANCE Steaming an EOP-6 Il.E Steaming an affected OTSG may be desirable for the following reasons:
Isolated OSTG for o Increase cooldown rate TRACC o Prevent challenging tube to shell dT limits o Prevent idle loop voiding when in natural circulation.
All of the following conditions should be evaluated to determine if steaming an affected OTSG is appropriate:
- 1) BWST > 35 ft*
AND
- 2) Affected OTSG Level < 90%**
AND
- 3) Any of the following conditions exists:
- Steaming is required to avoid core damage
- Estimated OTSG leakage times RCS DE 1-131 concentrations is < 0.4 OTSG Leakaae (aDm) X Initial RCS DE 1-131 (uci/am) c 0.4
- Wind is blowing off-shore (Off-shore winds originate from NNE to SE sectors 01 1.20 to 146.3°)
- If BWST level is < 35 ft. then determine if adequate BWST level Is available for long term cooldown (Ref calc M89-1089) prior to steaming the OTSG.
- If OTSG level is > 90%, then determine if OTSG level Is low enough to prevent water carry-over. As long as water level can be ensured to be below the bottom of the main steam outlet nozzles there should not be any carry-over concern.
BWST Makeup EOP-6 lll.E Monitor BWST level trend and evaluate depletion rate. Ensure adequate BWST inventory is available to support RCS cooldown to DHR. Evaluation should include the following:
o Primary to secondary leak rate o BWST available inventory o BWST depletion rate o Current RCS temperature o BWST volume required to support cooldown (refer to OP-304) o Potential for leak rate increase (leak before break)
IF ECCS water supplies are Insufficient to support cooldown to DHR, THEN, make preparations to initiate BWST makeup from spent fuel pools.
o Refer to EM-225E, Enclosure 11, BWST Refill from Spent Fuel Pool EM-225 Rev. 14 Page 27 of 35
EN SURE 11
( TSC GUIDANCE FOR EOPs O ge 3 of 7 PARAMETER EOP TBD REF. TSC GUIDANCE RCS Leakage No EOP-8 None 1. The RCS is capable of being cooled by DHR.
Longer Exists 2. Prohibit establishing any flow path that was isolated by the ES system unless the potential for radioactive releases is evaluated and the release path, doses, and methods have been approved by the EC.
- 3. Begin DHR.
Break size > 1 HPI EOP-8 None 1. Establish a Post Accident Recovery Plan. This plan is dependent on the Pump Capability or scope of the applicable Emergency Event.
Unable to transition 2. The Post Accident Recovery Plan is approved by the PNSC, and applicable to DHR regulatory agencies as determined by FPC Management.
- 3. Prohibit establishing any flow path that was isolated by the ES system unless the potential for radioactive releases is evaluated and the release path, doses, and methods have been approved by the EC.
- 4. The availability of borated water sources for required shutdown margin is maintained until the actions of the Post Accident Recovery Plan are completed or to the extent that plant and public safety Is ensured.
- 5. Post and label protected train boundaries for the borated water sources and components that are available.
EM-225 Rev. 14 Page 28 of 35
( C TSC GUIDANCE FOR EOPs gnSfRE 11 PARAMETER EOP TBD REF. TSC GUIDANCE Break size 1 HPI EOP-8 None 1. Transition to DHR cooldown.
Pump Capability 2. Establish a Post Accident Recovery Plan. This plan is dependent on the and able to scope of the applicable Emergency Event.
transition to 3. The Post Accident Recovery Plan is approved by the PNSC, and applicable DHR regulatory agencies as determined by FPC Management.
- 4. Prohibit establishing any flow path that was isolated by the ES system unless the potential for radioactive releases is evaluated and the release path, doses, and methods have been approved by the EC.
- 5. The availability of borated water sources for required shutdown margin is maintained until the actions of the Post Accident Recovery Plan are completed or to the extent that plant and public safety is ensured.
- 6. Post and label protected train boundaries for the borated water sources and components that are available.
Establishing SS-2 1. Refer to the entry conditions and recommendations of the Emergency Primary to Operating Procedures Technical Basis Document (TBD), Section SS-2 for Secondary Heat guidance related to establishing primary to secondary heat transfer to one Transfer to One or or both OTSGs.
Both OTSGs 2. Accident Assessment personnel in the TSC will provide recommended guidance to the EC for when and how to establish heat transfer using one or both OTSGs.
- 3. The EC will approve any actions recommended.
Termination of HPI EOP-8 LBLO, 2.2, 3.0 1. Recommended guidance is to stop HPI pumps and trip running RCPs and Shutdown of when LPI flow has been in excess of 1400 gpm in each injection line for at RCPs least 20 minutes. Accident Assessment personnel will evaluate plant conditions and provide recommendations to the EC.
- 2. The EC will approve any actions recommended.
Control of EOP-8 SBLO 12.0 1. Prohibit establishing any flow path that was isolated by the ES system Radioactive Release unless the potential for radioactive releases isevaluated and the release Paths from path, doses and methods have been approved by the EC.
Containment Penetration Valves Monitoring of RB EOP-8 None NOTE: With the installation of the TSP baskets, pH data Is not required Sump Level, RB but still desired If feasible.
Sump Boron Other: IOC CR 97-0122 1. Accident Assessment personnel to monitor and trend RB sump level, boron Concentration, and concentration, and pH at ntervals recommended by the EC.
RB Sump pH 2. Data for sump pH and boron concentration to be obtained using CH-632 or other PNSC approved alternate methods dependent on the Emergency Event.
EM-225 Rev. 14 Page 29 of 35
( ( (
ENCLOSURE 11 TSC GUIDANCE FOR EOPs Page 5 of 7 PARAMETER EOP TBD REF. TSC GUIDANCE Venting of Non- EOP-8 None 1. Once subcooling margin is regained, all of the noncondensable gas Condensable Gases production will have ceased. However, as the RCS is depressurized these gases will come out of solution and should be vented. If natural circulation is lost to an available OTSG, Accident Assessment personnel will recommend to the EC when to vent noncondensable gases.
- 2. The EC will approve any actions recommended.
Reactor Is Being EOP-8 SBLO, 17.7 1. Verify TBVs/ADVs are closed.
Adequately Cooled 2. Fill available OTSGs to 90%.
Using HPI or LPI and 3. Close EFW/AFW/MFW Valves.
OTSG Cooling Is No 4. Stop all EFW/AFW Pumps.
Longer Desired 5. Stop MFWPs and MFWBPs.
Boron EOP-8 None Refer to EM-225B Concentration EOP-14, Management When Enc. 20 NOTE: If a failure of ES MCC 3AB has occurred, ensure repair efforts are Adequate Sub Initiated to repower auxiliary pressurizer spray valve RCV-53 prior Cooling Margin to the onset of boron precipitation.
Does Not Exist (Boron Precipitation) _ __ _i RB Temperature Refer to EM-225C Monitoring (To Preserve EQ Standards)
Feeding a Dry OTSG EOP-5, 9 III.D, 12.0 Refer to EM-225D (Tube to Shell EOP-14, III.E, 17.7 Delta T Monitoring Enc. 3 NC, 5.2, 5.3, 6.4 and Control)
Long-Term Core EOP-8 LBLO, 6.4a, 6.4b, 6.6, 6.7 Refer to EM-225E Cooling Using the RB Sump EFW or AFW is EOP-14, Refer to EM-225F Operating Enc. 7
_ _ _ _ _ _ _ _ _ _ _ E n c. 22 _ _ _ _ _ _ _ _ _ _ _ _ _ _
TBP-3 Is Running. EOP-14, TBP-3 will drain non-1 E battery during LOOP. Stopping TBP-3 before 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> TBP-2 Is Not Enc. 14 may result in Turbine bearing damage.
Running. Generator Pur e Com lete Refer to IOC SE-99-0184 EM-225 Rev. 14 Page 30 of 35
( ( (
ENCLOSURE 11 TSC GUIDANCE FOR EOPs Page 6 of 7 PARAMETER EOP TBD REF. TSC GUIDANCE Concentrated BA EOP-14, None If concentrated BA is allowed to remain in the boron injection path piping addition made and Enc 18 (letdown/DH purification piping) the BA will eventually cool down and solidify.
flush water not Timely action is required to preclude this condition.
available.
- 1. Direct the control room to reestablish a continuous BA injection at a flow rate of 2 - 3 GPM (Batch controller is the preferred method).
- 2. Monitor RCS boron concentration. DO NOT allow RCS boron concentration to exceed the values listed in FSAR Table 4-10.
- 3. Evaluate the following options.
- If plant conditions permit, expedite restoration of RCS letdown (or DHW purification).
- If plant condition permit expedite restoration of power to at least one source of flush water (DWP-1A, DWP-1B, WDP.5A, WDP-5B, or WDP-5C.
- If BA flow rate and AB temperature conditions permit, evaluate securing continuous BA addition and performing periodic batch additions to prevent boron solidification.
- 4. IF letdown or DH purification flow is established, THEN direct the control room to STOP concentrated BA additions.
- 5. IF any flush water source becomes available, THEN direct the control room to STOP concentrated BA additions and perform a line flush using EOP-14, Enclosure 18.
Refer to EEM-01 -021, FSAR Table 4- 10 EM-225 Rev. 14 Page 31 of 35
( (: (
ENCLOSURE 11 TSC GUIDANCE FOR EOPs Page 7 of 7 PARAMETER EOP TBD REF TSC GUIDANCE Indications of RB EOP-14 None ECCS pumps have been aligned to the RB sump and are now showing signs sump screen Enc. 19 of sump screen blockage (flow oscillations, pump amp swings). Per EOP-14, blockage have Enclosure 19, LPI flows should have been reduced to 1400 gpm per pump. At occurred. least one BSP should be secured. If both trains of LPI are in service HPI should be secured. If only one train of LPI is in service, one train of HPI must be aligned to the operable LPI pump in piggy back mode.
- 1. Verify proper ECCS pump configuration
- 2. Closely monitor ECCS pump parameters and Incore temperatures
- 3. Expedite BWST refill operation from spent fuel pool using EM-225E Enclosures 11 and 12.
- 4. Expedite mixing of boric acid for BAST makeup per OP-403B, Section 4.2, Boric Acid Production.
- 5. Refer to EM-225E, Section 4.6, Contingency Actions for RB Sump Screen Blockage, for specific guidance.
EM-225 Rev. 14 Page 32 of 35
ENCLOSURE 12 (SAMPLE)
TSC ACCIDENT ASSESSMENT TEAM OSC Reguest Form REQUEST NO. INITIATED BY: TIME DATE (UNIQUE NUMBER) (MT MEMBER)
REQUESTED ACTION(S):
CONSEQUENCES IF NOT PERFORMED:
TIME FRAME lTAG NO: TRAIN: LOCATION:
REQ'D APPROVAL TIME:
(MT COORDINATOR)
RECEIVED BY: TIME:
(TSC REPAIR COORDINATOR)
INSTRUCTIONS:
- 1. Use this form for each requested action from the Control Room, or Accident Assessment Team (multiple steps of EOPs/APs may be covered by one request)
- 2. Obtain approval from the AAT Coordinator
- 3. Obtain acknowledgement from TSC Repairs Coordinator
- 4. Make copy and give original to TSC Repairs Coordinator
- 5. Give copy to TSC Ringdown Communicator
- 6. Feedback to the Control Room on status of request.
EM-225 Rev. 14 Page 33 of 35
ENCLOSURE 13 SPDS OR RECALL DISPLAY SETUP FOR TSC PROJECTION SCREENS NOTE: REBOOTING ANY OF THE TSC COMPUTERS WILL RESULT IN AN ALARM IN THE MAIN CONTROL ROOM. CALL THE CONTROL ROOM BEFORE REBOOTING ANY TSC COMPUTER.
O GO TO "TSC-1" COMPUTER IN THE MT ROOM. TURN ON THE MONITOR. TSC-1 TELLS THE COMPUTERS IN THE PROJECTION ROOM (CALLED SPARE AND RECALL 2) WHAT TO DISPLAY.
O IF PICS MMr (THE CONTROLLING PROGRAM) IS NOT RUNNING, THEN DOUBLE CLICK ON THE "PICS MM{' ICON TO START THE CONTROLLING PROGRAM. (NOTE: IF A FULL SCREEN DISPLAY OF SPDS PREVENTS SEEING ANY WINDOWS BUTTONS, MINIMIZE THE SPDS DISPLAY USING CONTROL M")
O IF SELECTING AN SPDS DISPLAY, THEN GO TO LAUNCh" AND "SPDS REMOTE TO DISPLAY THE CONTROLLER WINDOW.
O IF SELECTING A RECALL DISPLAY, THEN GO "LAUNCH' AND "DISPLAY CONTROL" TO DISPLAY THE CONTROLLER WINDOW.
O SELECT THE COMPUTER IN THE PROJECTION ROOM THAT WILL DISPLAY THE SPDS OR RECALL GROUP. CLICK ON EITHER SPARE OR RECALL 2. (DON'T USE RECALL 1)
O SELECT THE SPECIFIC DISPLAY DESIRED:
- FOR RECALL, SELECT ONE OF THE PRE-ESTABLISHED DISPLAYS FROM THE "WORKSPACES DROP DOWN MENU, AND CLICK "OPEN"
- FOR A SPECIFIC-SPDS DISPLAY, JUST CLICK ON THE DESIRED BUTTONS OR USE THE KEYBOARD (REFER TO THE LAMINATED CARD FOR COMMANDS).
O CLICK "BRING TO FRONT" BUTTON ON EITHER THE SPDS OR RECALL CONTROL WINDOW.
O3 GO TO THE TOUCH SCREEN (LOCATED IN THE MAIN TSC ROOM) WHICH CONTROLS THE PROJECTION SCREENS. SELECT THE LEFT, CENTER, OR RIGHT SCREEN THAT YOU WANT TO USE, USING THE FOLLOWING RELATIONSHIP:
IF THE DESIRED DISPLAY IS ON THIS THEN SELECT THIS LABEL ON THE TOUCH SCREEN COMPUTER IN THE PROJECTION ROOM FOR THE DESIRED PROJECTION SCREEN.
SPARE 2 SPARE RECALL 2 RECALLSPDS 2 RECALL 1 I RECALL/SPDS 1
- NOTE: RECALL 1 CAN ONLY BE CONTROLLED FROM THE PROJECTION ROOM AND IS NORMALLY ALIGNED TO SPDS. TO CHANGE THE DISPLAY ON RECALL 1, GO INSIDE THE PROJECTION ROOM AND TURN ON THE MONITOR. ENSURE THE MONITOR PLUG IS CONNECTED TO RECALL 1. USE THE KEY BOARD TO SELECT THE DESIRED DISPLAY.
O TO CHANGE TO DIFFERENT COMPUTERS, (I.E. SPARE OR RECALL 2) "DISCONNECT" AND RE-PERFORM THE ABOVE STEPS AS DESIRED.
O IF SPDS AND RECALL ARE RUNNING ON THE SAME COMPUTER (SPARE OR RECALL 2) USE THE "BRING TO FRONT" BUTTON ON TSC-1 TO SELECT WHAT DISPLAY WILL BE SHOWN.
VALIDATION TEST CASE DISPLAY THE STATION BLACKOUT RECALL GROUP ON THE LEFT PROJECTION SCREEN AND DISPLAY THE ICC CURVES FROM SPDS ON THE CENTER DISPLAY EM-225 Rev. 14 Page 34 of 35
Revision Summary SECTION CHANGE Step 2.1.6 Editorial corrections Step 3.1.6 Step 3.2.9 Deleted responsibility to perform CH-362, Enclosure 5. This is not a DAT responsibility. PRR#101845 written to add responsibility to EM-102 and/or 104 as applicable.
Enclosure 2 Revised Enclosure 2, section IlIl to eliminate "regained' column. Change is being made in support of a similar change being made to the state notification form (see EM-202, Enclosure 2).
Section IV, "ES Buses" changed to ES Bus". "Diesel Generator's" changed to "Diesel Generator." (PRR# 93338)
Enclosure 4 Deleted the words "for plant condition information" from bullet 11. (PRR# 84385)
Deleted reference to Enclosure 8 which is not required for the new notification form.
Enclosure 5 Added step to obtain and transmit RB 1131 concentration to control room for BS pump shutdown decision making.
Enclosure 8 Revised page 5 to eliminate uregained column. Change is being made in support of a similar change being made to the state notification form (see EM-202, Enclosure 2) .
Revised wording slightly to clarify "Intact" description. PRR# 93338)
Enclosure 11 Page 1, Building Spray Termination - Added bullet stating that >5 hour requirement may be waived if indications of sump screen blockage exist with a reference to EM-225E.
Page 2, BWST Makeup - revised guidance to perform BWST refill lAW EM-225E, Enclosure 11. This is a new enclosure that allows BWST refill from the SF pools using a main SF pump. Use of this method allows for quicker addition of borated water and eliminates the feed for BWST recirculation prior to injection.
Page 7, Indications of RB Sump Blockage - this section provides basic response actions to TSC personnel if they are notified by the control room that indications of RB sump blockage have occurred. Enclosure 11 references EM-225E for primary mitigation actions.
Enclosure 12 Revised instructions to allow multiple EOP/AP actions to be performed with single request. (PRR# 94902). Corrected position title for MT Coordinator.
Enclosure 13 (new) Added new Enclosure 13 to provide guidance for setting up SPDS/Rocall displays on TSC displays (PRR# 94271)
EM-225 Rev. 14 Page 35 of 35
a Progress Energy Information Use PROGRESS ENERGY CRYSTAL RIVER UNIT 3 PLANT OPERATING MANUAL EM-225E GUIDELINES FOR LONG TERM COOLING EM-225E Rev. 6 Page 1 of 53
TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE ......................... 3
2.0 REFERENCES
.......................... 3 2.1 Developmental References ......................... 3 3.0 PERSONNEL INDOCTRINATION............................................................................4 3.1 Definitions ..................... 4 3.2 Responsibilities ...................... 4 3.3 Limits And Precautions ...................... 5 4.0 INSTRUCTIONS ...................... 6 4.1 Emergency LPI Crosstle And Piggyback Operations .6 4.2 Long Term Cooling Requirements .7 4.3 RB Water Level Control .8 4.4 Long Term Core Cooling Mode Alignment Changes .9 4.5 Maintenance During Long Term Cooling .10 4.6 Contingency Actions for RB Sump Screen Blockage .10 4.7 Long Term Cooling Termination .13 ENCLOSURES 1 ECCS Flow Log ......................... 14 2 Long Term Cooling Equipment Log ......................... 15 3 Operator Enclosure Functional Goals ......................... 17 4 A LPI Train Crosstie ......................... 18 5 B LPI Train Crosstie ..................... . 23 6 Starting A Train LPI Pump ..................... 28 7 Starting B Train LPI Pump ..................... 31 8 Establishing ATrain Piggyback ..................... 34 9 Establishing B Train Piggyback ..................... 37 10 Emergency LPI Crosstie And Piggyback Operations ............ ........................... 40 11 BWST Refill From SF Pool ....................................... 42 12 SF Pool Refill....................................4......................................................................................46 13 Minimum ECCS Flows Required to Remove DH .................................... 48 14 HPI From BWST During RB Sump Screen Blockage .................................... 49 EM-225E Rev. 6 Page 2 of 53
1.0 PURPOSE The purpose of this procedure is to provide guidance to the TSC Accident Assessment Team for maintaining long term core cooling post LOCA.
2.0 REFERENCES
2.1 Developmental References 2.1.1 Babcock and Wilcox Topical Report BAW-1 01 03A, Rev. 3, ECCS Analysis of B&W's 177-FA Lowered-Loop NSS 2.1.2 Calculation M90-0021, Building Spray and Decay Heat Pump NPSH a/r 2.1.3 Calculation 197-0008, LPI Crossover Flow Loop Accuracy Calculation 2.1.4 Calculation 191-0001, DH (LPI) Flow Indication and Control Loop Error Calculation 2.1.5 Calculation M98-0003, TSC Guidance For LPI Cross-Connect (Framatome Technologies Document 51-5001075-01) 2.1.6 Framatome Technologies Document 74-1152414, Emergency Operating Procedures Technical Bases Document 2.1.7 Calculation 190-0021, Decay Heat Removal Heat Exchanger Outlet Temperature Loop Accuracy Calculation 2.1.8 Calculation 188-0011, Containment Sump and Building Flood Level Indication 2.1.9 Calculation 191-0012, BWST Level Accuracy 2.1.10 Calculation M94-0053, Allowable MUT-1 Indicated Overpressure vs. Indicated Level 2.1.11 Calculation M95-0005, Minimum BWST Level to Prevent Vortexing during Drawdown 2.1.12 MAR 90-06-10-02, Reactor Building Instrument and Valve Relocation 2.1.13 Calculation M90-0023, Reactor Building Flooding 2.1.14 Calculation F98-0015, Minimum HPI flow for CR-3 at 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> post-LOCA 2.1.15 EEM98-001, MU/HPI Pump Qualification 2.1.16 Calculation 189-0036, Make-up/HPI Flow Loop Accuracy (High Range) 2.1.17 Calculation 189-0037, Make-up/HPI Flow Loop Accuracy (Low Range) 2.1.18 EEI98-001, HPI Total Flow Uncertainty 2.1.19 BAW-2374, Rev.1, Risk-informed Assessment of Once-Through Steam Generator Tube Thermal Loads due to Breaks in Reactor Coolant System Upper Hot Leg Large-Bore Piping.
EM-225E Rev. 6 Page 3 of 53
3.0 PERSONNEL INDOCTRINATION 3.1 Definitions
- Duration of Lona Term Core Cooling - The time period between the Onset of Long Term Core Cooling, and the End of ECCS Cooling.
- ECCS Suction Transfer - This necessary operator action involves manual alignments to allow the active ECCS, and Reactor Building Spray components to take suction from the Reactor Building sump.
- Emercency Core Cooling Systems (ECCS) - Active components (i.e., High Pressure Injection, Low Pressure Injection, associated flow paths), combined with the passive systems (i.e., Core Flood Tanks (CFT) and the Borated Water Storage Tank), required to be operable to ensure the initial condition assumptions of the accident analysis are met.
- End of ECCS Cooling - The time after a LOCA, when the core has been removed from the Reactor Vessel or other permanent means of core cooling has been established.
- Lona Term Cooling Modes - There are three methods that may be available for long term core cooling. The three methods In their order of preference are:
- Both LPI trains operating and providing flow through their respective injection lines.
- One LPI train operating and providing flow through its respective injection line, and providing a suction source for the associated HPI pump.
- One LPI train operating and providing flow through both LPI injection paths through the discharge cross-tie line.
- Onset of Lona Term Core Cooling - The time after a LOCA, when operator action is required to ensure the ECCS systems are properly aligned, and the minimum performance requirements are met.
3.2 Responsibilities
- The TSC Accident Assessment Team is responsible for the following:
Monitoring ECCS system performance and providing recommendations to the EC regarding changes in the established flow paths.
- Provide input to recovery plans for failed equipment, placing emphasis on the need for at least two ECCS injection paths before, during, and after required maintenance activities.
- Assess plant conditions and equipment availability to determine the safest and most effective method to achieve LPI injection through both injection paths.
EM-225E Rev. 6 Page 4 of 53
3.3 Limits And Precautions
- To ensure adequate NPSH is maintained, total actual decay heat pump flow from RB sump must be maintained
- 2986 gpm. This is derived from the following:
- 2200 gpm indicated LPI flow (plus instrument uncertainties)
- - 600 gpm HPI flow (derived from hydraulic analysis)
- Total HPI flow must be limited 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> post accident to ensure long term mission time requirements are met.
- Any changes to the flow limits associated with Enclosures 4 through 10 must consider the following:
- Instrumentation uncertainty
- Required LPI flow
- Required HPI flow
- HPI pump mission time limitations
- If more than 5 consecutive bumps are required, 1 bump may be performed every 7 minutes.
- After a cooling period of 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />, 5 consecutive bumps may again be performed.
- If piggyback operations are in progress, do not perform LPI crosstie until one of the following is met:
- DHHE outlet temperature S 130SF AND > 32 hours3.703704e-4 days <br />0.00889 hours <br />5.291005e-5 weeks <br />1.2176e-5 months <br /> since shutdown.
- DHHE outlet temperature > 1302F to 5 1752 F AND > 81 hours9.375e-4 days <br />0.0225 hours <br />1.339286e-4 weeks <br />3.08205e-5 months <br /> since shutdown.
- Prior to starting equipment, ensure adequate EDG load margin is available per EOP-1 3, Rule 5, EDG Control".
- For work located in the Radiation Control Area, due consideration must be given to the ALARA program. This will likely result in special precautions and preparations.
- If indicated RB water level exceeds 6.0 feet, instrumentation may be lost.
- The HPI pump mission time study has qualified the pumps for a two month period. This analyzed mission time, relative to previous operational time, should be considered during decisions related to alignment changes.
EM-225E Rev. 6 Page 5 of 53
4.0 INSTRUCTIONS 4.1 Emergency LPI Crosstle And Piggyback Operations IF HPI piggyback operations are required, AND multiple failures result in the inability to align the ECCS systems for piggyback operation, THEN obtain EC concurrence and perform Enclosure 10, Emergency LPI Crosstie.
IF only HPI pumps are taking suction from the BWST, THEN level can be lowered to 2.5 feet (actual) or 3.5 feet (indicated).
E E EM-225E Rev. 6 Page 6 of 53
4.2 Long Term Cooling Requirements NOTE Refilling the BWST will provide additional ECCS inventory for RCS injection in the unlikely event that severe RB Sump screen blockage occurs.
- As soon as possible after ECCS SUCTION TRANSFER is complete notify the OSC to begin refilling the BWST from the spent fuel pools by performing Enclosures 11 and 12 of this procedure.
- Notify OSC to commence Boric Acid production per OP-403B, Section 4.2
- The most desired long term cooling mode of operation is to supply LPI injection through both injection lines. Review plant conditions for the safest method for achieving this alignment NOTE
- Adequate SCM may be lost during HPI flow reduction. Analysis has shown the flow rates listed below will ensure continued core cooling. Loss of adequate SCM during establishment of the flow rates below is acceptable.
- The flow limits below are only valid when the flow path is limited to the HPI valves.
Other configurations (recirc, seal injection, normal makeup) must be individually evaluated.
- IF total HPI flow is > 500 gpm, THEN provide direction to the Control Room to maintain HPI flow within the following limits (balanced between available digital low range indicators):
>64 hours G 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> R-ule~ 2withinapplicable without with
- . 64 hours7.407407e-4 days <br />0.0178 hours <br />1.058201e-4 weeks <br />2.4352e-5 months <br /> andAdqae dqut
<72 hours Aea~~SC MV A SCM 1 HPI pump Per EOP-13, Control HPI flow > 440 gpm < 500 gpm Rule 2 within applicable > < 500 gpm 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> limit.
2 HPI pumps 4 Per EOP-13, Control HPI flow > 440 gpm < 760 gpm Indicators Rule 2 within applicable > < 760 gpm 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> limit.
2 HPI pumps 3 Per EOP-1 3, Control HP I flow > 440 gpm < 560 gpm Indicators Rule 2 within applicable > < 560 gpm
______________ ~~72 hour lim it. _ _ _ _ _ _ _ _ _ _ _ _ _
- After the EOP has been completed, request Control Room trending of the operating components by performance of:
- Enclosure 1, ECCS Flow Log, every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />
- Enclosure 2, Long Term Cooling Equipment Log, every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> EM-225E Rev. 6 Page 7 of 53
4.3 RB Water Level Control
- Monitor and maintain the RB water level in the appropriate level limits. Consult with engineering personnel for the minimum and maximum levels for current plant conditions.
- If RB water level is lowering, perform walk downs of accessible areas to determine leakage location. If the AB is not accessible, the Control Room radiation monitoring reading may be helpful in determination.
NOTE Analysis indicates that a large break LOCA may result in steam generator tube failure due to stresses induced by tube to shell differential temperatures.
- Inadvertent pumping, i.e., RB sump pumps, RCDT pumps
- Leaking ECCS flow path isolation valves, i.e., DHP recirc to BWST, DHP recirc to SF pools, HPI pump recirc to MUT, RB spray recirc to BWST, etc.
- Possible SGTR
- If the leaking component is found, review available equipment to determine possible Long Term Core Cooling alignments to allow faulted equipment isolation.
- If RB water level loss has occurred consult with engineering personnel to ensure remaining ECCS water inventories (RB sump and BWST) are sufficient to support Long Term Core Cooling.
- IF ECCS water supplies are insufficient to support Long Term Core Cooling, THEN, make preparations to initiate BWST makeup from an available source.
Spent Fuel Pool (refer to OP-406)
DW/boric acid addition (refer to OP-403B)
- Reduction in RB sump boron concentration may be indicative of the need to perform boron precipitation mitigation.
- Rising RB water level and lowering boron concentration may be indicative of unborated water leaking to containment. The following are possible sources of unborated water:
- SW system
- Cl system DW system
- DC system via DHHEs
- RB sump boron concentration must be maintained to ensure the Rx remains shutdown. If unborated water is leaking to the RB, attempt isolation efforts.
- IF RB sump water must be drained/pumped to prevent exceeding RB flood plane, THEN the storage location must be evaluated to prevent excessive dose rates and releases.
EM-225E Rev. 6 Page 8 of 53
4.4 Long Term Core Cooling Mode Alignment Changes
- The most desired long term cooling mode of operation is to supply LPI injection through both injection lines.
- Enclosure 3 describes the "Functional Goals0 of the alternate cooling modes established by Enclosures 4 through 10 of this procedure.
- If power failures exist, using OP-700 series procedures ensure required equipment is energized.
- During transitions to LPI crosstie mode of operation, the Control Room will ask for TSC assistance for HPI termination. Ensure all the following exist prior to allowing HPI pump shutdown:
- Stable LPI crosstie flow with in the limits of the applicable enclosure.
- Tincore is NOT rising.
- RCS pressure is NOT rising.
- If the above conditions are not observed, direct the Control Room to re-establish HPI injection flow by performing the following:
- 1. Throttle the injection valves until total injection flow is > minimum pump flow.
- 2. Close the recirc valves.
- 3. Establish maximum allowable injection flow.
During LPI crosstie operations, if stable LPI flow within the limits of the applicable enclosure can not be maintained, provide direction to the Control Room to establish HPI piggyback.
- If Enclosures 8 or 9 are used to establish piggyback, the status statement will not be met. The two status statements regarding LPI system alignment are intended for normal transitions with adequate core cooling.
- Provided the associated LPI train indicated flow is s 2200 gpm, adequate NPSH margin exists for HPI pump operation.
IF RB water level losses threaten the ability to maintain Long Term Core Cooling, THEN, consider establishing core cooling using normal decay heat removal.
EM-225E Rev. 6 Page 9 of 53
4.5 Maintenance During Long Term Cooling
- Prior to performing maintenance activities, any necessary temporary shielding must be installed, and the associated piping flushed.
- Storage location for draining and flushing operations must be evaluated to prevent excessive dose rates and releases.
- A possible flushing activity may be to drain or pump water from the BWST or SF pools to a suitable storage location.
4.6 Contingency Actions for RB Sump Screen Blockage CAUTION
- Contingency actions contained in EOP-14, Enclosure 19 mitigate symptoms of RB sump screen blockage by significantly reducing ECCS flow through the sump screen. As long as ECCS pumps are aligned to the RB sump, the potential for further blockage exists.
- Actions specified In this section are outside the CR3 design basis and must be performed In accordance with 10 CFR 50.54 sections X and Y.
- IF notified by the control room that indications of RB sump screen blockage have occurred, THEN perform the following:
- Notify EC that sump blockage has occurred.
- Notify the OSC to expedite BWST refill operations (Enclosures 11 and 12).
- Ensure Boric Acid Production is in progress per OP-403B.
NOTE
- RCITS reactor vessel level Instrumentation Indicates the water level from the top of the reactor vessel head to the bottom of the hot leg. A hot leg or cold leg LOCA In the nozzle belt region may result In no indicated reactor vessel level even with full ECCS flow rate.
- ECCS flow may Impact RCITS reactor vessel level Indication.
Notify AAT to closely monitor RCS / ECCS conditions:
- ECCS pump flow rates for symptoms of cavitation/ vortexing
- RCS incore temperature trends
- RCS subcooling margin
- RCITS reactor vessel level indication
- RB pressure / temperature
- RB radiation levels / Iodine activity EM-225E Rev. 6 Page 10 of 53
4.6 Contingency Actions for RB Sump Screen Blockage (Cont'd)
IF one train of RB spray is still in operation (per EOP-14, Enclosure 19),
THEN consult with engineering personnel and dose assessment to determine if alternate shutdown criteria can be established.
- Consider actual plant radiation levels
- Consider RB atmospheric 1131 trend (if available).
- Consider status of ECCS systems and Incore thermocouple trends. If ECCS systems are functioning normally-and Incore trends indicate adequate core cooling the potential for a delayed release is low.
- Consider the projected offsite thyroid dose from airborne RB releases. If the dose projection exceeds 5 REM thyroid, RB spray should be maintained, if possible, to reduce RB Iodine concentrations (the 5 REM limit should preserve DBA assumptions for both dose and CR Habitability calculations.
- If containment temperature I pressure are elevated consider using two RB cooling units (in ES mode) in lieu of RB spray.
- IF indications of sump blocking retum, THEN provide direction to the Control Room to further reduce ECCS injection flow.
- Throttle ECCS flow as required to achieve a stable operating point. The minimum flow to provide assured core cooling Is full flow (4 nozzles) from 1 HPI pump.
- At LPI-flow rates < 800 gpm LPI instrument uncertainty becomes significant.
Consider going to HPI piggy back mode.
- Closely monitor ECCS pump parameters and Incore temperatures.
- IF only one train of ECCS is in operation, AND HPI is operating in piggy back mode, THEN direct the control room to OPEN all available HPI valves and CLOSE the LPI valve.
EM-225E Rev. 6 Page 11 of 53
4.6 Contingency Actions for RB Sump Screen Blockage (Cont'd)
CAUTION
. If ECCS suction must be realigned to the BWST, ECCS flow rates significantly greater than two times WVAP are undesirable since they will accelerate BWST depletion.
- Because break location is unknown ECCS flow must be injected through at least 2 nozzles.
- 200 gpm minimum HPI flow allows MUP recirculation valves to remain closed.
IF ECCS pump suction flow from RB sump is interrupted due to sump blockage, OR ECCS flow cannot be maintained >full flow (4 nozzles) from 1 HPI pump),
THEN provide direction to the Control Room to reestablish ECCS injection flow from the BWST.
- Ensure BWST level sufficient to support HPI pump operation.
- Align one HPI pump to BWST per Enclosure 14.
- Maintain ECCS total flow rate two times WVAP (Enclosure 13) OR 200 gpm (Whichever is greater).
- Direct the Control Room to divide ECCS flow evenly between all available HPI nozzles.
- Closely monitor ECCS pump parameters and Incore temperatures
- WHEN HPI flow from BWST has been established, THEN calculate time to BWST depletion based on initial BWST level and HPI flow rate.
- Notify control room of minimum allowable BWST level to support HPI pump operation at current flow rate.
- Reg. Guide 1.97 instrumentation will be submerged by the additional inventory, and may subsequently fail. Consult with engineering personnel to predict potential instrument failures and identify any available alternate instrumentation.
- Additional borated water inventory may adversely affect RB sump water chemistry. Consult with chemistry and engineering personnel to develop a plan for maintaining RB water chemistry within expected post accident range.
- Develop alternative methods for recovering the RB sump or continuing injection from alternate source.
- Consider back washing the RB sump screen by performing a DH drop line dump to sump evolution per EOP-1 4, Enclosure 20.
- Consider cyclic operation of an LPI pump from RB sump. Direct pump operation on RB sump level indication. Ensure pump is stopped if indications of pump distress are observed.
- Consider aligning 1 HPI pump to MUT. Maintain MUT level by feeding from RCBTs and BASTs.
- Consult with engineering personnel to determine minimum acceptable HPI flow rate. Maintain injection flow rate > WVAP (Enclosure 13).
- If CFTs were isolated before being fully depleted consider reopening CF isolation valves.
- Consult with engineering personnel to determine if plant conditions will support a transition to DHR.
- Refer to the CR3 Severe Accident Guideline EM-225E Rev. 6 Page 12 of 53
4.7 Long Term Cooling Termination
- WHEN the End of ECCS Cooling occurs, THEN exit this procedure.
EM-225E Rev. 6 Page 13 of 53
ENCLOSURE 1 ECCS FLOW LOG Time HPI flow A ILPI flow B LPI flow LPI Crosstie flow Note 1 Notes 2 and 3 Note 2 Note 2 Note 2
- 1) Suggested minimum time interval is 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
- 2) If an increasing trend is noted without a corresponding decrease in RCS pressure or increase in valve position, notify the TSC.
- 3) HPI flows must be maintained within the limits of Section 4.2 EM-225E Rev. 6 Page 14 of 53
ENCLOSURE 2 Page 1 of 2 LONG TERM COOLING EQUIPMENT LOG DHP-1 A Comnuter Points (See Note 11 R250 _ - . __._ ____ ____
X318 _____ _
X319 =_=__ _ _ _ = _
X 3 2 0_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
DHP-1B Corputer Points See Note 1)
R251 l l X32 1 I T : _ I l 1 _ _
X 322_ _ _ _ _ _ _ _ __ _ _
X3 23_ _ __ _ __ _ __ __ __
MUP-1 A Co r uter Points See Note 1)
X 3 24 _ _ _ _ _ _ _ _ _ _ _ _
X 32 6 _ _ _ _ _ _ _ ______
X 3 25 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
X 0 7 0_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
X366 _ -
T217 _
S2942 = == _ =_ = -
MU P-1 B Co mputer Points (See Note 1)
X327 _ _ P - i I X329 _ _ _
X328 = = =-=- __1 T X 0 7 1_ _ _ _ _ __ _ _ _ _ _ _ _ _ _ __ _ _
X367 .
T253 .
S311 =
S295 _ i l_________ MUP-1C Computer Points (See Note 1)
X330 X332 l _ ___rr __-
X3 31 _ _ _ _ _ _ _ _ _ _
X072__ _ __ _ _ _
A 298 _ _ _ _ _ _ _ _ _ _ _ _ __ _ _
T236 r _ _ _ _ _ _ _ _____
T216 _ _ - l-_
S29 6 _ _ _ _ _ _ _ _ _ _
EM-225E Rev. 6 Page 15 of 53
ENCLOSURE 2 Page 2 of 2 LONG TERM COOLING EQUIPMENT LOG (CONT'D)
BSP-1A Computer Points (See Note 1)
X313 _ {.
X314 _ _ T I -r ____-_
BSP-1 B Computer Points (See Note 1) .
X316 I I I I I_
X315 -_TI I _1 I I X317 I _ I I I I__r_
Note 1: These instruments are not safety related or EQ qualified. However, this data may be useful for trending equipment condition.
EM-225E Rev. 6 Page 16 of 53
ENCLOSURE 3 OPERATOR ENCLOSURE FUNCTIONAL GOALS Enclosure Functional Goal To provide LPI flow through both injection lines using DHP-1A.
This alignment allows maintenance on the following equipment:
- All HPI pumps
- DHP-1 B, provided the recirculation fluid down stream of DHV-11 1 does not result in excessive dose rates.
The only alignment that should be performed from this alignment is starting the opposite LPI train.
To provide LPI flow through both injection lines using DHP-1 B.
This alignment allows maintenance on the following equipment:
- All HPI pumps 5
- DHP-1A, provided the recirculation fluid down stream of DHV-110 does not result in excessive dose rates.
The only alignment that should be performed from this alignment is
_______________starting the oposite LPI train.
To provide LPI flow through A Train LPI using DHP-1A.
6 Provided DHP-1 B is operating, this alignment allows maintenance activities on all HPI pumps.
To provide LPI flow through B Train LPI using DHP-1 B.
7 Provided DHP-1A is operating, this alignment allows maintenance activities on all HPI pumps.
To provide HPI injection using the A Train ES selected HPI pump.
This alignment allows maintenance on the following equipment:
8
- Secured HPI pumps
This alignment allows maintenance on the following equipment:
9
- Secured HPI pumps
- DHP-1 A 10 To provide emergency alignments should Piggyback alignments fail.
EM-225E Rev. 6 Page 17 of 53
ENCLOSURE 4 Page 1 of 5 A LPI TRAIN CROSSTIE ACTIONS DETAILS STATUS
- ECCS suction transfer has been completed.
- DHP-1A Is operating.
- A Train ES selected MUP Is operating In piggyback.
- BSP-1B is shutdown.
- LPI crosstie NOT In progress.
- DHHE outlet TEMP is 5 130 2 F AND > 32 hours3.703704e-4 days <br />0.00889 hours <br />5.291005e-5 weeks <br />1.2176e-5 months <br /> have elapsed since Rx shutdown.
OR DHIHE outlet TEMP is > 1302F to < 1752F AND > 81 hours9.375e-4 days <br />0.0225 hours <br />1.339286e-4 weeks <br />3.08205e-5 months <br /> have elapsed since Rx shutdown.
NOTE Tincore should be closely monitored while changing ECCS alignments.
4.1 - Ensure B ES selected MUP WMUP-1 is stopped.
MUP-1C
- 4.2 IF both LPI pumps are running, THEN stop DHP-1 B.
EM-225E Rev. 6' Page 18 of 53
ENCLOSURE 4 Page 2 of 5 A LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS 4.3 - Isolate B LPI Train.
- Ensure the following valves closed:
DHV-35 DHV-40 DHV-43 DHV-211 DHV-12
- ___ Select BSV-4 to "MAN" and closed.
- Select DHV-1 11 to "MAN" and closed.
EM-225E Rev. 6 Page 19 of 53
ENCLOSURE 4 Page 3 of 5 A LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS 4.4 - Adjust DHV-1 10 setpoint to 1600 gpm.
NOTE During crosstie DHV-111 must remain in manual.
4.5 - Establish LPI crosstie. 1 _ Ensure DHV-6 is open.
2 Open LPi crosstie valves:
DHV-8 DHV-7 3 _ Throttle DHV-1 11 to achieve LPI crosstie flow of 900 (800 to 1000) gpm on DH-38-FI1 4 -Adjust DHV-1 10 setpoint to obtain A Train LPI flow of 2100 (2000 to 2200) gpm on DH-1-Fl1 EM-225E Rev. 6- Page 20 of 53
ENCLOSURE 4 Page 4 of 5 A LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS 4.6 - Stop HPI flow. 1 - IF HPI flow is > 300 gpm, THEN throttle HPI flow to 300 (200 to 400) gpm.
2 Open all HPI recirc to sump valves:
MUV-543 MUV-544 MUV-545 MUV-546 3 Close all HPI valves:
MUV-23 MUV-24 MUV-25 MUV-26 4.7 ___ WHEN the TSC directs 1 Stop the A ES selected MUP:
termination of the MUP, THEN stop the operating MUP-1A MUP.
MUP-1 B 2 _Close DHV-1 1 EM-225E ReV. 6 Page 21 of 53
ENCLOSURE 4 Page 5 of 5 A LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS NOTE-During crosstieDOHV-11llmust remain in manual.
4.8 Increase LPI flow. 1 _ Throttle DHV-1 11 to obtain LPI crosstie flow of 1250 (1150 to 1350) gpm on DH-38-FI1 2 _ Adjust DHV-1 10 setpoint to achieve A Train LPI flow 2700 (2600 to 2800) gpm on DH-1-FI1 4.9 _ Close all HPI recirc to sump _ MUV-543 valves.
_ MUV-544
_ MUV-545 MUV-546 EM-225E Rev. 6 Page 22 of 53
ENCLOSURE 5 Page 1 of 5 B LPI TRAIN CROSSTIE ACTIONS DETAILS STATUS
- ECCS suction transfer has been completed.
- DHP-1B Is operating.
- B Train ES selected MUP Is operating In piggyback.
- BSP-1A is shutdown.
- LPI crosstle NOT In progress.
- DHHE outlet TEMP is s 130 2F AND > 32 hours3.703704e-4 days <br />0.00889 hours <br />5.291005e-5 weeks <br />1.2176e-5 months <br /> have elapsed since Rx shutdown.
OR DHHE outlet TEMP is > 130 2F to < 1759 F AND > 81 hours9.375e-4 days <br />0.0225 hours <br />1.339286e-4 weeks <br />3.08205e-5 months <br /> have elapsed since Rx shutdown.
NOTE Tincore should be closely monitored while changing ECCS alignments.
5.1 Ensure A ES selected HPI MUP-1A pump is stopped.
_ MLIP-1 Bl EM-225E Rev. 6 Page 23 of 53
ENCLOSURE 5
-Page 2 of 5 B LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS 5.2 _ IF both LPI pumps are running, THEN stop DHP-1 A 5.3 - Isolate A LPI Train.
- Ensure the following are closed:
DHV-34
_ DHV-39
_ DHV-42 DHV-210 DHV-1 1
- _ Select BSV-3 to MAN" and closed.
- Select DHV-1 10 t o *MAN" and closed.
EM-225E Rev. 6 Page 24 of 53
ENCLOSURE5 Page 3 of 5 B LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS 5.4 - Adjust DHV-1 11 setpoint to 1600 gpm.
NOTE During crosstie DHV-11O must remain in manual.
5.5 - Establish LPI crosstie. 1_ Ensure DHV-5 is open.
2 Open LPI crosstie valves:
DHV-8 DHV-7 3 -Throttle DHV-1 10 to achieve LPI crosstie flow of 900 (800 to 1000) gpm on DH-38-FI1 4 Adjust DHV-1 11 setpoint to achieve B Train LPI flow of 2100 (2000 to 2200) gpm on DH-1 -FI2 EM-225E Rev. 6 Page 25 of 53
ENCLOSURE 5 Page 4 of 5 B LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS 5.6 Stop HPI flow. 1 IF HPI flow is > 300 gpm, THEN throttle HPI flow to 300 (200 to 400) gpm.
2 Open all HPI recirc to sump valves:
MUV-543 MUV-544 MUV-545 MUV-546 3 Close all HPI valves:
MUV-23 MUV-24 MUV-25 MUV-26 EM-225E Rev. 6 Page 26 of 53
ENCLOSURE 5 Page 5 of 5 B LPI TRAIN CROSSTIE (CONT'D)
ACTIONS DETAILS 5.7 - WHEN the TSC directs 1 Stop the B ES selected MUP:
termination of the MUP, THEN stop the operating MUP-1 B MUP.
MUP-1C 2 -Close DHV-12 NOTE During crosstie DHV-11O must remain in manual.
5.8 _ Increase LPI flow. 1 _ Throttle DHV-1 10 to achieve LPI crosstie flow of 1250 (1150 to 1350) gpm on DH-38-FI1 2 _ Adjust DHV-1 11 setpoint to achieve B Train LPI flow of 2700 (2600 to 2800) gpm on DH-1-F12 5.9 Close all HPI recirc to sump MUV-543 valves.
MUV-544 MUV-545
_ MUV-546 EM-225E Rev. 6 Page 27 of 53
ENCLOSURE 6 Page 1 of 3 STARTING A TRAIN LPI PUMP ACTIONS DETAILS STATUS
- ECCS suction transfer has been completed.
- DHP-1 B is operating.
- B Train ES selected MUP Is operating In piggyback.
NOTE Tincore should be closely monitored while changing ECCS alignments.
6.1 ___ Ensure proper alignment for 1 Ensure the following valves are closed:
the A Train LPI system.
DHV-34 DHV-39 DHV-11 2 IF LPI crosstie is NOT in progress, THEN close DHV-110 3 Ensure DHV-42 is open.
4 Ensure DHV-5 is open.
EM-225E Rev. 6 Page 28 of 53
ENCLOSURE 6 Page 2 of 3 STARTING A TRAIN LPI PUMP (CONT'D)
ACTIONS DETAILS 6.2 Start A Train LPI. 1 Ensure required cooling pumps are operating:
[Rule 5, EDG Control]
DCP-1A
_ RWP-3A 2 Start DHP-1A 3 -Ensure DHV-210 is open.
6.3 _ IF LPI crosstie operations
- Close LPI crosstie valves:
are in progress, THEN stop crosstie flow. DHV-8 DHV-7 6.4 Ensure LPI flow is properly
- Ensure LPI control valves are in AUTO" controlled. and set for 2000 gpm:
DHV-110 DHV-111 EM-225E Rev. 6 Page 29 of 53
ENCLOSURE 6 Page 3 of 3 STARTING A TRAIN LPI PUMP (CONT'D)
ACTIONS DETAILS 6.5 - WHEN all the following exist: 1 Stop B ES selected MUP:
A Train LPI flow > 1400 MUP-1B gpm MUP-1C B Train LPI flow > 1400 gpm 2 _ Close DHV-12 THEN stop HPI.
6.6 Increase LPI flow.
- Adjust LPI control valve setpoints to 2700 gpm:
(2600 to 2800) gpm on DH-1 -FI1 and DH-1-FI2 DHV-1 10 DHV-1 1 EM-225E Rev. 6- Page 30 of 53
ENCLOSURE 7 Page 1 of 3 STARTING B TRAIN LPI PUMP ACTIONS DETAILS STATUS
- ECCS suction transfer has been completed.
- DHP-1A is operating.
- A Train ES selected MUP is operating in piggyback.
- IPI crosstie in progress.
NOTE Tincore should be closely monitored while changing ECCS alignments.
7.1 Ensure proper alignment for 1 Ensure the following valves are closed:
the B Train LPI system.
DHV-35 DHV-40 DHV-1 2 2 IF LPI crosstie is NOT in progress, THEN close DHV-1 11 3 Ensure DHV-43 is open.
4 - Ensure DHV-6 is open.
EM-225E Rev. 6 Page 31 of 53
ENCLOSURE 7 Page 2 of 3 STARTING B TRAIN LPI PUMP (CONT'D)
ACTIONS DETAILS 7.2 _ Start B Train LPI. 1 Ensure required cooling pumps are operating:
[Rule 5, EDG Control]
DCP-1 B
_RWP-3B 2 Start DHP-1 B 3 _ Ensure DHV-21 1 is open.
7.3 - IF LPI- crosstie operations
- Close LPI crosstie valves:
are in progress, THEN stop crosstie flow. DHV-8 DHV-7 7.4 - Ensure LPI flow is properly
- Ensure LPI control valves in AUTO' controlled. and set for 2000 gpm:
DHV-1 10 DHV-111 EM-225E Rev. 6 Page 32 of 53
ENCLOSURE 7 Page 3 of 3 STARTING B TRAIN LPI PUMP (CONT'D)
ACTIONS DETAILS 7.5 _ WHEN all the following exist: 1 Stop A ES selected MUP:
A Train LPI flow > 1400 MUP-1A gpm MUP-1 B
_ B Train LPI flow > 1400 gpm 2 -Close DHV-1 1 THEN stop HPI.
7.6 ___ Increase LPI flow.
- Adjust LPI control valve setpoints to 2700 gpm:
(2600 to 2800) gpm on DH-1 -Fi 1 and DH-1-FI2
- DHV-1 10 DHV-1 11 EM-225E Rev. 6 Page 33 of 53
ENCLOSURE 8 Page 1 of 3 ESTABLISHING A TRAIN PIGGYBACK ACTIONS DETAILS STATUS
- ECCS suction transfer has been completed.
- Both LPI trains are operating and providing flow.
- LPI crosstle NOT in progress.
NOTE Tincore should be closely monitored while changing ECCS alignments.
8.1 ___ Ensure proper HPI 1 MUP recirc to MUT valves closed:
alignment.
MUV-53 MUV-257 2 HPI recirc to sump valves closed:
MUV-543 MUV-544 MUV-545 MUV-546 3 HPI valves are open or throttled as directed by the TSC:
MUV-23 MUV-24 MUV-25 MUV-26 EM-225E Rev. 6 Page 34 of 53
ENCLOSURE 8 Page 2 of 3 ESTABLISHING A TRAIN PIGGYBACK (CONT'D)
ACTIONS DETAILS 8.2 - Align DHP-1A discharge to
- Open DHV-11 MUP suction.
8.3 _ Ensure DHP-1A flow is within
- Ensure DHV-1 10 in AUTO" and set limits. for 2000 gpm.
8.4 Start A Train HPI.
- Start the A ES selected MUP and required cooling pumps:
[Rule 5, EDG Control]
MUP-1 A MUP-1 B 8.5 ___ Stop B Train ECCS pumps. 1 Ensure the B ES selected MUP stopped:
_MUP-1B MUP-1 C 2 - Ensure DHP-1B is stopped.
3 Close DHV-12 4 _ Close DHV-6 EM-225E Rev. 6 Page 35 of 53
ENCLOSURE 8 Page 3 of 3 ESTABLISHING A TRAIN PIGGYBACK (CONT'D)
ACTIONS DETAILS 8.6 IF 2 72 hrs post accident,
- IF adequate SCM does NOT exist, TiHEN ensure HPI flow is THEN throttle HPI flow to 470 gpm within limits (440 to 500 gpm).
(use digital low range).
- - IF adequate SCM exists, THEN throttle HPI flow to
< 500 gpm.
8.7 - IF < 72 hrs post accident, * - IF adequate SCM does NOT exist, THEN ensure HPI flow is THEN establish full HPI.
within limits (use digital low range).
- IF adequate SCM exists, THEN throttle HPI to maintain minimum adequate SCM.
EM-225E Rev. 6 Page 36 of 53
ENCLOSURE 9 Page 1 of 3 ESTABLISHING B TRAIN PIGGYBACK ACTIONS DETAILS STATUS
- ECCS suction transfer has been completed.
- Both LPI trains are operating and providing flow.
- LPI crosstie NOT in progress.
NOTE Tincore should be closely monitored while changing ECCS alignments.
9.1 Ensure proper HPI 1 MUP recirc to MUT valves closed:
alignment.
MUV-53 MUV-257 2 HPI recirc to sump valves closed:
MUV-543 MUV-544 MUV-545 MUV-546 3 HPI valves are open or throttled as directed by the TSC:
MUV-23 MUV-24 MUV-25 MUV-26 EM-225E Rev. 6 Page 37 of 53
ENCLOSURE 9 Page 2 of 3 ESTABLISHING B TRAIN PIGGYBACK (CONT'D)
ACTIONS DETAILS 9.2 - Align DHP-1 B discharge to 0 - Open DHV-12 MUP suction.
9.3 - Ensure DHP-1B flow is within
- Ensure DHV-1 11 in "AUTO" and set limits. for 2000 gpm.
9.4 _ Start B Train HPI.
- Start the B ES selected MUP and required cooling pumps:
[Rule 5, EDG Control]
MUP-1 B MUP-1 C 9,5 - Stop A Train ECCS pumps. 1 Ensure the A ES selected MUP is stopped:
MUP-1A MUP-11B 2 - Ensure DHP-1A is stopped.
3 _-Close DHV-1 1 4 -Close DHV-5 EM-225E Rev. 6 Page 38 of 53
ENCLOSURE 9 Page 3 of 3 ESTABLISHING B TRAIN PIGGYBACK (CONT'D)
ACTIONS DETAILS 9.6 - IF 2 72 hrs post accident,
- _ IF adequate SCM does NOT exist, THEN ensure HPI flow is THEN throttle HPI flow to 470 gpm within limits (440 to 500 gpm).
(use digital low range).
- IF adequate SCM exists, THEN throttle HPI flow to
< 500 gpm.
- 9.7 IF < 72 hrs post accident,
within limits
.(use digital low range).
- IF adequate SCM exists, THEN throttle HPI to maintain minimum adequate SCM.
EM-225E Rev. 6 Page 39 of 53
ENCLOSURE 10 Page 1 of 2 EMERGENCY LPI CROSSTIE AND PIGGYBACK OPERATIONS ACTIONS DETAILS STATUS
- At least 1 LPI pump Is operating.
- Multiple failures have resulted In the Inability to establish Piggyback.
10.1 IF ail the following exist: 1 Ensure DHP isolation valve on idle train is closed:
LPI flow exists DHV-21 0 (A Train)
- Only 1 LPI train is operating DHV-21 1 (B Train)
THEN crosstie LPI trains. 2 Ensure LPI block valve on idle train is open:
DHV-5 (A Train)
- DHV-6 (B Train) 3 Ensure LPI control valve on idle train is closed:
DHV-1 10 (A Train)
DHV-1 11 (B Train) 4 Open LPI crosstie valves:
DHV-8 DHV-7 5 Establish the following flows using DHV-110 and DHV-111:
LPI crosstie flow 1250 (1150 to 1350) gpm on DH-38-FI
- Operating LPI train flow 2700 (2600 to 2800) gpm EM-225E Rev.6 Page 40 of 53
ENCLOSURE 10 Page 2 of 2 EMERGENCY LPI CROSSTIE AND PIGGYBACK OPERATIONS (CONT'D)
ACTIONS DETAILS 10.2 IF RCS PRESS prevents
- Open the necessary valves:
LPI flow, THEN establish alternate DHV-1 1 piggyback alignment.
_ DHV-1 2
_ MUV-62 MUV-69 EM-225E Rev. 6 Page 41 of 53
ENCLOSURE 11 Page 1 of 4 BWST REFILL FROM SF POOL ACTIONS DETAILS STATUS BWST refill from SF Pool desired.
11.1 Establish SF cooling with SFP-1A and SFHE-1A per OP-406, Section 4.1.
[Rule 5, EDG Control]
11.2 - Verify SF pool boron concentration > 2270 ppm.
EM-225E Rev. 6 Page 42 of 53
ENCLOSURE 11 Page 2 of 4 BWST REFILL FROM SF POOL ACTIONS DETAILS 11.3 Align SFP-1 B for BWST refill. 1_ Ensure SFP-1 B stopped 2 Ensure the following valves are closed:
SFV-12 "SFP COMMON SUCTION ISOLATION" SFV-34 "SFP-1 AJ B DISCHARGE CROSSTIE" SFV-35 "SFP-1 A/1B DISCHARGE CONTROL TO FUEL TRANSFER CANAL" SFV-43 SFHE-1 A/1 B TO SFFL-1 A11 B ISOLATION" SFV-50 uSFHE OUTLET CROSSTIE"
.SFV-87 "DHP TO SFFL-1 A/1 B ISOLATION" SFV-89 "SPENT FUEL HEADER TO DHP SUCTION ISOLATION" 3 Ensure the following valves are open:
-SFV-7 "SFP-1 A/1 B SUCTION CROSSTIE" SFV-1 1 uSFP-1 B SUCTION ISOLATION" SFV-46
- "SFHE-1A/1B TO BWST ISOLATION" SFV-37 "SFHE-11B INLET ISOLATION" SFV-49 "SFHE-11B OUTLET ISOLATION" EM-225E Rev. 6 Page 43 of 53
ENCLOSURE 11 Page 3 of 4 BWST REFILL FROM SF POOL ACTIONS DETAILS NOTE If SFV-28 has been previously positioned per Detail 6 of this Enclosure, Detail 4 may be omitted.
11.4 - Start BWST refill. 1 _ Record SF Pool initial level
[Rule 5, EDG Control] SF Pool Level:
2 _ Record BWST initial level BWST Level:
3 _ Ensure SFV-46 OPEN 4 Throttle SFV-28 SFP-1B DISCHARGE ISOLATION" 3 turns open 5 _ Start SFP-1 B 6 _ Throttle SFV-28 as required, to maintain SFP-1 B differential pressure between 45 and 50 psig.
(SF-4-PI2 minus SF-16-P12)
[NOCS 040415]
11.5 WHEN SF Pool level 1 Stop SFP-1 B 156 feet, THEN Stop BWST refill. 2 -Close SFV-46 3 Record SF Pool final level SF Pool Level:
4 _ Record BWST final level BWST Level:
EM-225E Rev. 6 Page 44 of 53
ENCLOSURE 11 Page 4 of 4 BW§T REFILL FROM SF POOL ACTIONS DETAILS 11.6 - Restore SF Pool level.
- PERFORM Enclosure 12, SF Pool Refill, in this procedure.
11.7 WHEN SF Pool level restored per Enclosure 12, AND additional BWST inventory required, THEN GO TO step 11.4 in this enclosure.
11.8 _ EXIT this enclosure.
EM-225E Rev. 6 Page 45 of 53
ENCLOSURE 12 Page 1 of 2 SF POOL REFILL ACTIONS DETAILS STATUS Spent Fuel Pool level restoration desired 12.1 Determine total SF pool
- Perform the following calculations:
volume addition required to restore level to 159 feet. Lw - Unibal = LA
- . Lfiw = final SF pool level = 159 (feet)
Laa'= initial SF pool level _ feet)
(LA) (11100 gal. per foot) = (gal.)
Total Volume Addition = (gal.)
12.2 _ Restore SF Pool level to 159 . PERFORM OP-406, Section 4.7, Filling feet per OP-406. Spent Fuel Pools (Alternate Method).
NOTE To expedite BWST refill consider using reduced SF pool recirculation times and preliminary sample results for boron concentration verification.
12.3 - WHEN SF Pool level restored to 159 feet, THEN verify SF pool boron concentration > 2270 ppm.
EM-225E Rev. 6 Page 46 of 53
ENCLOSURE 12 Page 2 of 2 SF POOL REFILL ACTIONS DETAILS NOTE OP-403BA requires 10.25 hour2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br /> SF pool recirculation time prior to obtaining final SF boron concentration. To expedite BWST refill consider using the results of the preliminary (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />) sample.
12.4 _ IF SF Pool boron
- PERFORM OP-403B, Section 4.7, Boric concentration < 2270 ppm, Acid Addition to the SF Pools.
THEN increase SF pool boron per OP-403B.
12.5 WHEN SF Pool boron concentration verified > 2270 ppm, THEN EXIT this enclosure.
EM-225E Rev. 6 Page 47 of 53
ENCLOSURE 13 Minimum ECCS Flows Required to Re-move DH Whip (Saturated Vapor Flow) is the flow rate of water (@ 100 F with 0 psig Reactor Building pressure; OR e 200
'IF with 15 psig Reactor Building pressure) that, when injected into the reactor vessel, will remove all the decay heat and exit as a saturated vapor. ECCS flow rates < Wvp may not keep up with vessel boil off rate and will potentially result in core damage.
Wvap (Saturated Vapor Flow) 300-280 260 -----
__X I - ,
E 240 - _
- 0) 220 = = __.
180 pigPM)M psigat0 Cr10 0T 200 1.100 r: 2 2 . -.- 0 0 1 1 - 4 4 1 1 18 0 0 2 2 4 4 2 2 8 8 33 CO80~ ~ Tm ftrRato htow Hus NOTES
- 2. Flow Rates > two times Wvap bound HPI instrument uncertainty.
- 3. Compare redundant HPI flow indications. If significant deviations exist consider using lowest indicated f low.
EM-225E Rev. 6 Page 48 of 53
ENCLOSURE 14 Page 1 of 3 HPI FROM BWST DURING RB SUMP SCREEN BLOCKAGE ACTIONS DETAILS STATUS
- TSC has verified BWST level sufficient to support HPI at reduced flow rate 14.1 Ensure all MUPs shutdown.
A Train B Train l-MUP-1A MUP-1C l IMUP-1B _- MUP-1 B 14.2 - . Align desired MUP suction to
- Close LPI discharge to MUP suction:
BWST.
A Train B Train DHV-1 1 _ DHV-12
- Open BWST to MUP suction:
A Train B Train MUV-73 _ MUV-58 EM-22sE Rev. 6 Page 49 of 53
ENCLOSURE 14 Page 2 of 3 HPI FROM BWST DURING RB SUMP SCREEN BLOCKAGE ACTIONS DETAILS 14.3 - Align desired MUP discharge
- Close MUP recirc to MUT valves:
flow path.
A Train B Train L MUV-53 - MUV-257
_ MUV-543 MUV-544 I MUV-545
_ MUV-546 S Close Makeup and seal injection isolation valves:
A Train B Train MUV-596 MUV-18
-MUV-27
. Open all available HPI valves:
A Train B Train
__ MUV-24 MUV-25 MUV-23 _ MUV-26 EM-225E Rev. 6 Page 50 of 53
ENCLOSURE 14 Page 3 of 3 HPI FROM BWST bURING RB SUMP SCREEN BLOCKAGE ACTIONS DETAILS 14.4 - Start desired MUP and required cooling pumps.
[Rule 5, EDG Control]
14.5 _ Adjust HPI flow rate per TSC
- Split flow between all available HPI guidance. nozzles
- Do not reduce HPI flow < 200 gpm.
K>y14.6 Monitor BWST level.
Minimum BWST Level
- Notify TSC if BWST within 3 feet of minimum level 14.7 IF at any time, indications of NMUP cavitation or vortexing exist, THEN immediately shutdown MUP and notify TSC.
14.8 _ Exit this enclosure when notified by the TSC.
EM-225E Rev. 6 Page 51 of 53
REVISION
SUMMARY
Section Change 4.2 Added Guidance to section 4.2 to refill BWST AW Enclosures 11 and 12 (new)
._________ Added Guidance to section 4.2 commence boric acid production IAW OP-403B 4.6 NRC Bulletin 2003-01, "Potential Impact of Debris Blockage On Emergency Sump Recirculation at Pressurized Water Reactors" identified a concern that a HELD within containment could loose sufficient transient material to effectively block the RB sump strainer during the recirculation (long term cooling) phase of event mitigation. The bulletin required PWRs to develop and implement compensatory actions to mitigate the effects of a sump blockage event. In response to that requirement EOP-1 4, Enclosure 19 has been revised to include initial response steps for mitigating a sump blockage event.
Section 4.6 (new) in this procedure provides additional compensatory measures, to be implemented by the TSC, following mitigate an RB sump blockage event. The actions in this section are progressively more extreme and may violate CR3 design basis. Use of section 4.6 guidance will be implemented in accordance with 10 CFR 50.54 X and Y criteria.
- Section 4.6, bullet one - this bullet directs the TSC staff to expedite BWST and BAST refill in response to an actual sump blockage event. BWST/BAST refill should be in progress per section 4.2 of this procedure.
- Section 4.6, bullet two - this bullet directs the AAT to begin monitoring RCS and ECCS parameters to ensure compensatory measures implemented by the control room have been effective. A note ahs been included to remind TSC personnel of the limitations of the RCITS reactor vessel level Indicting system.
- Section 4.6, bullet three - directs the TSC to evaluate alternate shutdown criteria for the BSP if the EOP-1 4, Enclosure 19 shutdown criteria was not met.
- Section 4.6, bullet four - directs additional compensatory measures to be implemented if indications of sump blockage return. The guidance directs progressively greater flow rate reductions based on curves derived from the CR3 SAG (Enclosure 13, Figures 1 and 2).
- Section 4.6, bullet five - provides additional compensatory measures to be implemented if RB sump recirculation capability is lost. Guidance directs that an HPI pump be realigned to the BWST and inject flow be established IAW Enclosure 13, Figure 2). Cautionary statements are provided to assist TSC responders.
. Section 4.6, bullet fix lists options to be considered for establishing alternate methods of core cooling.
Enclosure 5 Step 5.8, Detail 2 - corrected typographical error. DH-2-FI2 changed to DH-1 -F12 Enclosure 6 Step 6.6, Detail - added range of control (2600-2800 gpm) and reference to applicable flow instrumentation. (PRR# 91188)
Enclosure 7 Step 7.6, Detail - added range of control (2600-2800 gpm) and reference to applicable flow instrumentation. (PRR# 91188)
Added new Enclosure 11 which provides guidance for refilling the BWST from the SF pool. This method was selected due to it providing an immediately available source of 1 borated BWST makeup that can be quickly transferred using a main SF cooling pump.
Use of SF pool inventory eliminates the need to recirculate and sample the BWST inventory prior to use.
Added new Enclosure 12 which is to be used in conjunction with Enclosure 11 (BWST 2 refill). It provides guidance for restoring SF Pool level following a BWST addition.
EM-225E Rev. 6 Page 52 of 53
Added new Enclosure 13 to provide guidance for determining ECCS flow required to remove DH during a RB sump screen blockage event. Enclosure 13 is derived from the SAG Wvap curve. This curve shows the minimum ECCS flow rate required to cool the core and exit as saturated stream (Wvap curve). The curve will be used by TSC personnel, in conjunction with section 4.6 of this procedure, for developing 3 compensatory action recommendations for a sumptscreen blocking event. The ECCS flow rate directed by this curves is below design bases requirements and should only be used in response to a sump screen blockage event in conjunction with the requirements of 10 CFR 50.54 X and Y.
Added new Enclosure 14 which provide guidance to establishing HPI from the BWST. 4 This guidance should be used only if recirculation from the RB sump becomes impossible due to sump screen blockage.
EM-225E Rev. 6 Page 53 of 53