ML19257C642

Forwards Position on Recommendations Contained in B&W Rept 1564, Integrated Control Sys Reliability Analysis. Supporting Documentation Encl

ML19257C642
Person / Time
Site:	Rancho Seco
Issue date:	01/21/1980
From:	Mattimoe J SACRAMENTO MUNICIPAL UTILITY DISTRICT
To:	Reid R Office of Nuclear Reactor Regulation
References
NUDOCS 8001290532
Download: ML19257C642 (75)

Text

{{#Wiki_filter:SMUD fg^ SACRAMENTO MUNICIPAL UTILITY DISTRICT C 6201 s street, 95a13; (916) 452-3211 January 21, 1980 Mr. Robert W. Reid, Chief Operating, Reactor Branch No. 4 Division of Operating Reactor U.S. Nuclear Regulatory Commission Wasnington, D.C. Docket No. 50-312 Rancho Seco Nuclear Generating Station, Unit No.1

Dear Mr. Reid:

Your letter of November 7,1979 requested that the Sacramento Municipal Utility District provide its position on recommendations contained within Babcock and Wilcox Report 1564, " Integrated Control System Reliability Analysis." Af ter careful review the District forwards its position on each of the recommendations in attachment I to this letter. Attachments 2 through 6 provide supporting information. S inc erely, ff to T-A John b. Mattimoe Assistant General Manager and Chief Engineer Att achment s h( t 1827 042 80019.o0 b b S AN ELECTRIC SYSTEM SERVING MORE TH AN 600,000 IN THE HEART OF C A LIFO R NI A

1. a NNI/ICS Power Supply Reliability.

District Response During Rancho Seco startup testing, many trips were experienced due to 120 volt inverter problems. These inverters were the sole power sources f or NNI-X and NNI-Y and for the ICS. The District recognized that inverter power supplies needed improvement. Through improved maintenance eff orts and some minor equipment changes we improved inverter reliability. To minimize the consequences of loss of an invarter, we installed automatic bus transf er ( ABT) devices on NNI-X, NNI-Y anu the ICS power sou rc e s. Now, if the primary power source f ails, the ABT shifts to a backup inverter power soume. In addition, as a result of the review of the Rancho Seco transient of March 20, 1978, the District intends to modify the NNI-X and NNI-Y internal power supplies. Attachments 2 and 3 to this letter describe the changes. shows power supply configuration before the change and attachrnent 3 shows power supply configuration af ter the change. 1.b Reliability of input signal from the NI/RPS system to the ICS - specifically, the RC flow signal. District Response Rancho Seco has tripped because of problems with the jack which connects the buffered RPS flow signal with the ICS. The District is considering two improvements to this connection. First, we are considering changes in the jack or hard wiring the ' low signal to the ICS. Second, we are considering use of an auctioneered RCS flow input signal to the ICS. This alteration would require much additional evaluation. Current engineering work loads make near term analysis of these potential improvements unlikely. l.c. ICS/ BOP system tuning, particularly feedwater condensate systems and the ICS controls. NOTE: Although this concern is related to tuning, it appears that more basic design and/or operational problems in the feedwater (and related) system may exist. Therefore, include a discussion of the following items: (1) Any particular operational (startup, etc.) problems experienced at your plant with respect to the ICS. Reference to previously submitted inf ormation is acceptable. (2) Bases for operator intervention in place of automatic ICS action (including start-up, power operation and shutdown activities). (3) Procedures used by the operator to perform the operation described in Ic(2) above. 1821 043 (4) Additional training provioed to the operator. District Response The Operating Experience Section of the Integrated Control System Failure Modes and Effects Analysis (B&W Report 1564) provides the most comprehensive summary of ICS problem experience now available. Three operating procedures provide the majority of ICS operating g uidanc e. They are system operating procedure A.71, Integrated Control and plant operating procedures B.2, Plant Heatup and Startup and B.4, Plant Shutdown and Cooldown. The:;e proceduras provide basic ICS operating guidance to control room operators. A.71, Integrated Control is attachment I to this letter. B.2, Pl ant Heatup and Startup, and B.4, Plant Shutdown and Cooldown are attachments 5 and 6, respectively. The Integrated Control System for Rancho Seco is taught to all operators as part of the license preparation training program. ICS Training typically consists of several days of fonnal classroom lecture and audio-visual training. The course content includes: 1.

== Introduction:== The introduction provides the trainee with a broad view of the Integrated Control System. Simplified schematic diagrams enhance understanding of basic system flow paths. It covers reactor control, feedwater control, turbine control, advantages of turbine following versus steam generator / reactor following operations anc advantages of an integrated cnntrol concept. II. System

Description:

Each major subsystem is discussed in detail for purpose, functions and limits and interactions with other subsystems and plant equipment. A. Unit Load Demand Subsystem The Unit Load Demand Subsystem is discussed using simplified diagrams and detailed analog and digital diagrams. Operational limits discussed are: 1. Load Limits and conditions that cause them ( a) Loss of one or two RCP ( b) Loss of either feed pump (c) Asymmetric control rod cnndition (d) Reduction of RC flow 2. Rate of Change Control - advantages and capabilities of control and automatic rate of change conditions for plant limiting conditions because of: ( a) Loss of RCP ( b) Loss of MFW pump (c) Unit in track {f) 2"*TE fi"'" ' " ' " "' " l82f 044 3. Frequency Control - how f requency is used and its effect on unit load demand. 4 Tracking - what conditions bring on "tr acking" and the effect of subsystem control unit behavior tr',ause of tracking. B. Integrated Master Subsystem The Integrated Master Subsystem is discussed using the same analog and digital diagrams utilized to explain the modes of operation. Major control f unctions covered are: 1. Steam system pressure control and conditions under which the turbine accepts responsibility for pressure control. 2. Effect of megawatt error on steam system pressure control and unit load demand. 3. Steam system pressure control set points during normal operation, reactor trip, and loss of condenser vacuum. C. Feedwater Control Subsystem Feedwater control topics are: 1. Sharing flow between steam generators. 2. BTU availability. 3. Level conditions of steam generators including how feedwater controls these functions by: ( a) Pump control using set points, pressure drops across valves and error signals. ( b) Flow control of feedwater to each steam generatcr with: ( 1) Demand versus flow. (2) Startup and regulating valve operation. (c) Level Control (1) Limitations for low and high level limit. (2) Parameters monitored. (d) Tc Control (e) BTU limits - reasons for limits, parameters monitored and effect on ICS control. (f) Cross Limits - action that ICS takes and indications observed by operators during cross limits. jg}j Q43 6 0. Reactor Control Subsystem 1. Rod Control system topics are: ( a) Parameters meastr ;d ( b) Demand versus actual signals (c) Cross limits and effects (d) T average control 2. Discussion of rate limits and maximum and minimum power control limits. 3. The relationship between steam generator / reactor demand and reactor demand and development of neutron demand signals to error signals f or rod movement. E. General - ~As all subsystems are discussed, the electronic cin uitry is described to explain functionally the various components. 1. Summers 2. Comparators (Difference) 3. Limit selectors 4 Calibrating Integrals 5. Modifiers 6. Rate of change amplifiers 7. Transf er switches F. B&W simulator training provides extensive an1 worthwhile operational experience on the ICS. 2.a Main f eedwater pump turbine drive minimum speed control - to prevent loss of main feedwater or indication of main feedwater. District Response The District is currently considering purchase of a new main feed pump control system. The system would have dual control oil systems. Either of the control oil systems would oe able to control the main feed pumps at minimum speed. If the system is purchased, it may be installed during the 1981 ref ueling outage. 2.0 A means to prevent or mitigate the consequence of a stuck-open main feedwater startup valve. District Response The main feedwater startup valves are f ully open during operation above 15 percent reactor power. As such, a stuck open startup valve is not a problem during nomial operation at power nor would it be recognized. At low power levels (less than 15 percent reactor power) a stuck open startup valve would be recognized. The operator has multiple opportunities to recognize the situation. Some of the opportunities include OTSG level not on the low level limit, decreasing main steam pressure, decreasing reactor coolant system pressure, and decreasing reactor coolant system temperature. 1829 046' _4

Once the operator recognizes the f ailed open startup valve he has several opportunities to control the situation f rom the control room. First, he can shif t the startup valve centroller to HAND f rom AUT0. If the startup valve f ails to respond in HAND, the operator can then shif t main feed pump controls to HAND f rom AUTO. In HAND, main feed pump soeed can be decreased to reduce feedwater flow to an acceptable rate. In the extremely unlikely situation that main feed pumps did not respond properly, the main f eed pumps could be tripped and the auxiliary f eedwater system could be used to provide flow. 2.c A means to prevent or mitigate the consequence of a stuck-open turbine bypass valve. District Response If the operator discovers an open bypass valve he can shif t control of the valve f rom AUTO to HAND and then try to close it f rom the control room. Upstream of the turbine bypass valves are manual isolation valves. These manual valves can be closed if a turbine bypass valve sticks open. On at least one occasion during Rancho Seco startup testing a turbine bypass valve did stick open and it was isolated using the manual isolation valve. The isolation was completed without excessive cooldown. 1821 047 ATTACHMENT 2 Q TO 6 16 i TO 8RC pat 4EL /b $ 5-11 5-0 n CUSE FUSE PANEL PANEL ll8 VAC IWAO p s f mvE:.Th a l ' INVERTER D aaEAxEs JCG 8 3 - -- BREAKER DCl AU~CV AT IC

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ULM: LS:Iml:Jj 8/20/75 ATTACHMENT 4 A.71 INTEGRATED CONTROL 1.0 PURPOSE .1 To provide procedures for starting up, normal operation and shutdown of the Integrated Control System (ICS). .2 To provide procedures for selector station manual / auto trans-fers during unit startup, normal operation, and unit shutdown. .3 To describe the abnormal operation of the integrated control system (ICS) during periods when the unit master control station is in track as a result of a control station, other than the reactor / steam generator demand or the turbine control stations, being in the manual operating mode as a result of an existing abnormal plant operating condition.

2.0 REFERENCES

.1 NNI Instruction Manual Volume 3. .2 Rancho Seco Unit 1 ICS/NNI Instruction Manuals Volumes lA,1B, and 1C. .3 Rancho Seco Unit 1 ICS Instruction anual Volume 3. .4 Rancho Seco Unit 1 Process Stanadards. .5 Rancho Seco Unit 1 Technical Specifications. .6 Rancho Seco Unit 1 Plant Operations Manual Procedures B.2, B.3, and R.4, Plant Starttp, Normal Operation, and Shutdown. 3.0 LIMITS AND PREC/JTIONS .1 When transferring a control station from HAND (MANUAL) to AUTO depress the auto pushbutton and verify that the auto light comes on. .2 When transferring from AUTO to HAND, depress the hand pushbutton and verify that the hand light comes on. .3 Prior to placing the Diamond Rod Control Station in

AUTO, the following conditions must be met.

.1 The ICS must be energized. .2 No large neutron error may exist (error >+/-1 percent inhibits transfer to auto control). 182Sj! O50

3.0 LIMITS AND PRECAUTIONS (Continued) .4 If, while controlling the reactor from either the Reactor Demand Control Station or the Diamond Rod Control Station, a feedwater cross-limit occurs, adjust the reactor power to be compatible with the total feedwate - flow. .5 If while operating with both Feedwater Det,nd Stations in HAND, a neutron cross-limit occurs, adjust the to'.a1 feedwater flow to be compatible with reactor power. .6 lbtch demand and measured values for any givea control para-meter, as closely as possible, before switching any ICS control module from HAND to AUTO. This is done to facilitate bumpless transfer to AUTO control. .7 When operating with one or more ICS control stations in HAND, care must be exercised to avoid introducing transients or other conditions which would exceed built in limits and cause a reactor trip. .8 While in HAND control of the unit, care must be exercised to not exceed the unit load limits and load rate of change limit. .9 If a control station is in HAND, it is the operator's responsi-bility to provide the necessary control station anputs for unit runback should plant 'imits be exceeded. NOTE: In effect, the operator must perform those functions that would otherwise be performed automatically. .10 The ICS does not necessarily go into the TRACKING code with feedwater pump (s) or feedwater valvc(s) (main and/or startup F.W. valves) in FAND. With the remaineder of the ICS in AUTO, feedwater control may become difficult during load changes. Except for plant startup, do not put more thau one feedwater pump or feedwater valve in HAND at the same time unless absolutely necessary. .11 While in HAND control at either the Reactor Demand Control Station or the Diamond Rod Control Station, do not exceed 100 percent indicated neutron power. The ICS 103 percent power limit is bypassed when in HAND. .12 If a BTU limit occurs while in HAND control of feedwater demand, reduce the feedwater demand until the BTU limiting condition just clears and investigate the reason for the limiting condition. 1821! 051 A.71/2

3.0 LIMITS AND PRECAUTIONS (Continued) .13 The normal ICS power supply is Vital Bus C; automatic transfer from normal to standby power (J Bus) occurs on loss of Vital Eus C. The automatic transfer breaker (H8DICS) must be reset to return to the nornal, Vital Bus C, power supply. 4.0 SYSTEM STARTUP .1 Energizing the ICS Initial Conditions .1 The ICS is de-energized. .2 120 Volt AC Vital System Inservice per OP A.62. .3 No maintenance is being performed on the ICS which would preclude system operation. .4 ICS disconnect breakers to fan bus are open. .5 ICS disconnect breakers to vital busses C and J are open. .6 Switches S1 and S2 on the ICS power autioneer panel are open. c Procedure .7 Close the ICS disconnect switches to the fan bus. .8 Close vital bus C breaker C07. .9 Close inverter J breaker J04. .10 Reset the auto transfer breaker (H8DICS); this lines up power to the ICS from vital Bus C. Power is provided from the J Bus when the auto transfer breaker is tripped. .11 Close the disconnect switches S1 and S2 on the ICS power auctioneer Ianel. CAUTION: Do not close the disconnect switches to the ICS, NNI and RPS, and SFAS cabinets prior to closing the main vital bus disconnect breakers. The combined inrush current for all three of these loads may damage the vital bus inverter. Any two of these loads may be started simultaneously with no concern due to inrush effects. A.71/3

4.0 SYSTEM STAR 10P (Continued) .12 Verify that all power sup,>ly monitor (PSM) lamps are on, thus indicating that all DC supplies and DC busses are operating normall:. If any of the PSM lamps are not on, determine the cause of difficulty and rectify it before proceeding. .13 Check fure panel for blown fuse indications. If any fuses are blown, proceed only after correcting fault or determining that plant operation is permissible with existing conditions. .14 Allow ICS to warm-up and stablize for one hour before proceeding with unit startup in order to assure accurate unit control. .2 ICS Unit Startup, O to 20% Power Initial Conditions .1 Reactor coolant average temperature equal to or greater than 525*F and in Hot Standby Condition per OP B.2. .2 1CS is energized per Section 4.1 this procedure. .3 Turbine bypass valves are in AUTO and the turbine header pressure is set to control RCS Tave. .4 Atmospheric exhaust valves in AUTC. .5 Startup feedwater valves in AUTO. .6 Main feedwater valves in HAND and closed. .7 Auxiliary feedwater Bailey Control valves in AUTO and the auxiliary feedwater air dump solenoid valves are in AUTO. .8 Auxiliary feedwater pumps in AUTO and the bypass key in 0FF. .9 Remaining control stations in HAND. Procedure .10 Set Steam Generator / Reactor control station and Unit Master control station to 0% demand. .11 Verify the "A" Feedwater Pucp control station is in AUTO (B in HAND). .12 Set loop A & B Feedwater Demands at 0% in HAND. A.71/4

4.0 SYSTEM STARTUP (Continued) .13 Place loop A & B Feedwater Demand control stations in AUTO. .14 Increase Reactor power to 5% with the Diamond Rod Control in RAND. .15 Verify that the Reactor Demand is 0%, then transfer the Diamond Rod Control to AUTO. .16 Increase reactor power to 10% with the Reactor Demand station. .17 When the startup feedwater valves reach 80% open and the main feedwater block valves are open, and if the intent is to increase power, place the main feedwater valves in AUTO. .18 Place turbine control in OPERATOR AUTO at the turbine control station. NOTE: The maximum load limit should be set per Procedure B.2, Section 6.8.1 or at some limit above 20% (194 MWe load). .19 Initially load the turbine to 5% load per A.l:6, Section 4.3 or 4.4 as specified by B.2, Section 6.0. .20 Increase reactor power to 15% and Tave to 582*F with the Reactor Demand station. Increase Steam Generator-Reactor demand to 145 Ele (11.6% scale indication = 145 MWe = 15% full power). .21 Place the Reactor Demand station in AUTO when the demand deviation is zero. Verify the Unit Master is in TRACKING. Verify the Steam Generator-Reactor Demand is zero then place it in AUTO. .22 Raise the turbine load until the turbine bypass valves are shut. NOTE: Aa the turbine load increases the feedwater control system will switch from OTSG level control to feedwater flow control. This can be observed by an increase in OTSG level (low level alarms will clear). A.71/5 1821 054

4.0 SYSTEM STARTUP (Continued) .23 Place the Turbine Control station in AUTO and verify that the TRACKING. node is cleared. NOTE: The NSS and turbine c.e now being con-trolled frotn the Unit Master in MAND. .24 Using the Unit Master, increase the Unit Load Demand (Megawatt Demand) to 193 MWe (20% power). NOTE: The Unit !bster station indicating scale is 0 to 100%, which corresponds to O to 1250 BEJc; i.e., 193 htic is approximately 15.5% full scale (100% full power would be approximately 77.4% full scale, 967 1"?e). .25 When both OTSG's are off low level limit set the "ATc" setpoint equal to " unit ATc" and place the load ratio control in AUTO, then slowly adjust the "ATc" setpoint to zero. .26 The "B" feedwater pump may now be placed in operation as follows: c .1 Increase "B" feedwater pump speed slightly witn the raise-lower switch, and check the operating feedwater pump for a slight decrease in speed, and match feedwater pump suction flows. .2 Place feedwater pump "B" in AUTO. .3 Adjust the bias on feedwater pump "B" to equalize flow between the A and B pumps. .4 During operation adjust the B pump bias as necessary to belance A and B loop flows. .27 The Unit Load Demand, High Load Limit, and Low Load Limit may be adjusted to the desired values. NOTE: The system is set up for the integrated control mode. in this mode of control the operator has the responsibility of establishing the amount of generation (Continued next page) ^ i 82'l 055

4.0 SYSTEM STARTLP (Continued) NOTE: (Continued) produced by the unit. The Integrated Control System has the responsibility of maintaining all parameters within prescribed limita. 5.0 NORMAL CPERATIOh NOTE: Other forms of ICS operation may be used at infrequent intervals. These forms of operation are described in Section 7.0, Abnormal Operation. .1 Integrated Control Mode .1 When all ICS control stations are in AUTO, the ICS will automatically control the plant to deliver the power input into the Unit Master station. The operator is responsible for inserting the Unit Load Demand into the Unit Master. .2 In this mode of control, the steam generator and reactor, as well as the turbine vill respond simultaneously to changes in the Unit Load Demar.d. .2 Stear Generator / Reactor Following Control Mode .1 With the Stera Generator / Reactor control station in AUTO and the turbine control station not in ICS AUTO the mode of control is Steam Generator / Reactor following (TRACKING). This cor. trol mode is characterized by rapid unit response tr load enanges, but relatively inaccurate and slow turbine header pressure control. .2 The operator is responsible for setting the generated megawatts at the turbine control panel. .3 The Steam Gennrator/ Reactor will maintain Turbine Header Pressure control and Tave. .4 If a system upset occurs while the turbine control L in HAND, match the turbine valve position with the existiag generated megawatts until a steady state condition exists. A.71/7 182()056

5.0 NORMAL OPERATION (Continued) .3 Turbine Following Ebde .1 With the turbine control station in ICS AUTO and the Steam Generator / Reactor control station in HAND, the mode of control is Turbine Following (TRACKING). This control mode is characterized oy relatively slow unit response, but very accurate and rapid Turbine Header Pressure control. .2 The operator establishes the generation manually by changing the steam generator / reactor control station. .4 ICS Boron Controller .1 The Boron Controller provides cutomatie termination of continuous feed and bleed operation at regulating CRA group nominal position. .5 Rate of Chance .1 The rate of load change is adjustable f rom 1 INe to 99 MWe (0.25-10%) per minute, for all loads between 193 and 870 MWe (between 20 and 90% load; basis is, 10u% load equals 967 MWe). .2 Above 870 MWe and below 193 MWe the rate of change is automatically fixed at a rate of < 48 !Ne per minute (<5% per minute). .3 EXAMPLE: A 20% (193}Me) load to 30% (290 FMe) load increase is as follows: .1 Time desired for the increase to be completed is 5 minutes. .2 The load change is 97 Mbe, the rate of change is: 19 FMe/ min. Rate = = 5 min. .3 Set rate of change to 19 MWe/ min., and High Load Limit to 290 MWe. .4 Increase Unit Load Demand at the Unit Master Station to desired value. The load will increase from 193 MWe to 290 MWe at a rate of 19 MWe per minute, and will stop at the set target load. .5 The Unit Load Demand and High Load Limit may be adjusted as desired. ^ 7 '8 182'l 057

5.0 NORMAL OPERATION (Continued) .6 Unit bbster Station .1 There are two modes of control for the Un c Master control d station: .1 HAND mode; in this mode of operation the operator is responsible for establishing the load at which the unit is to operate. .2 TRACKING mode; in this mode of operation the operator has no control of this station. TRACKING is indicated to the operator by both the HAND and the AUTO lights being "0N". Further discussion of this mode will be covered under abnormal conditions. NOTE: At the termination of any TRACKING con-dition, control is returned to the operator and is indicated by the AUTO light going "0FF" and the HAND light remaining "ON". Also the cause of the TRACKING condition is annunciated by light indication so the operator will know what coriition placed the sytem to TRACKING. .7 Load Limits .1 There are two ranually adjustable load limits available to the operator: .1 High Load Limit (FMe) ; this limit is dialed in by the operator and will not allow the unit load to increase beyond the set value. CAUTION: The operator should be very careful when adjusting this limit. If the dialed in number is inadvertantly decreased below the generated unit load, the load will run back to the new value if the system is in the integrated contral mode. .2 Low Load Limit (MWe); this limit is dialed in by the operator and should not be set below 145 MWe when operating in the integrated control mode (with design conditions this corresponds to approximately 15% Teactor power). 1829 058 A.71/9

5.0 NORMAL OPERATION (Continued) .2 lbny conditions exist in the plant that can impose a limit on the total amount of generation produced by the unit. Those conditions will be discussed in abnormal operations. .8 11AND-AUTO Stations .1 A HAND-AUTO station consists of: .1 A setpoint, or bias circuit, if neither are required they are omitted for that function. .2 A RAISE -LOWER toggle switch for HAND operation of the control element which follows the selector station. .3 Two pushbuttons, one marked "AUT0" the other marked " HAND". .4 Two indicating lights, which indicate; .1 The station is in AUTO control when the red indicating light is "0N". .2 The station is in IL\\ND (MANUAL) control when the white indicating light is "0N". .3 In some cases both,the " AUTO-HAND" indicating lights may be "0N". This indicates that the operator has no control icom that station; the ICC is controlling. .5 An indicating eeter with a two position switch so that the meter may be read: .1 Measured Variable (up position). .2 POS or Following Element (down position). .2 Control Station .1 The following is a list of the functional control stations, on the console, and what the measured variable indicates and position (POS) indicates. Routinely all stations are left in the POS position. NOTE: All Control Station indicating sceles are 0 to 100%; the ranges / units listed below for each station correspond to 0 to 100% scale indication. A.71/10

5.0 NORMAL OPERATION (Continued) .1 Unit Fbster - Meas. Var - Actual Unit Load Demand (0-1250 FNe) POS - - - - Unit Load Demand Setting (0-1250 MWe) .2 Steam Generator / Reactor Meas. Var - Unit Load Demand input to the integrated master subsystem (0-1250 FMe). POS - - - - Difference between AUTO and RAND Steam Generator / Reactor Demand (HAND mode only). Unlimited Steam Reactor Demand (AUTO mode only, 0 to 1250 FNe). .3 Reactor Demand Meas. Var - Reactor Average Temper-ature (520*F to 620 F). POS - - - - Neutron power demand ( 0 to 125% Power). .4 Turbine Bypass Valves Loop A & B Meas. Var - Loop turbine header pressure error (-300 to + 300 psi error). POS - - - - Loop bypass demand (not limited, 0 to 100% open). .5 Atmospheric Exhaust Valves, Loop A & B Meas. Var - Difference between tur-bine header pressure and atmcspheric exhaust valve bias setpoint (-300 to +300 psi error). POS - - - - Atmospheric exhaust valve demand (0 to 100% open). .6 Startup Feedwater Valve Loop A & B Meas. Var - Error between HMD and AUTO valve position demand (-50% to +50% demand error). i82 060 POS - - - - Startug feeuwater va1ve demand (0 to 100% open). A.71/ll

5.0 NORMAL OPERATION (Continued) .7 lbin Feedwater Valve A and B Meas. Var - Error between AUTO and HAND main feedwater valve position demand (-50% to +50% demand error). POS - - - - Main feedwater valve demand (0 to 100% open). .8 Feedwater Demand Loop A and B Meas. Var - Error between RAND and AUTO demand (HMD mode only, -50% to +50% demand error). Loop feedwater demand (AUTO mode only, 0 to 100% demand). POS - - - - Feedwater demand (0 to 100% Feedwater demand). .9 Feedwater Pump A and E Meas. Var - Error betwc;n HAND and AUTO pump demand (HAND mode). Difference across analog memory (AUTO mode, -50 to +50 psi feed valve delta P error). POS - - - - Main feedwater pump speed demand (0 to 100% demand). .10 Auxiliary Feedwater Valve A and B Meas. Var - Feedwater level setpoint in steam generator (0 to 100% of setpoint (transmitter) range). POS - - - - Emergency feedwater valve position demand (0 to 100% demand). .11 Steam Generator Load Ratio (Delta Tc) Meas. Var - Reactor Delta Tc error (-10 to +10 F error). POS - - - - Steam generator load ratio (-10 to +10 F). i 827 061 A.71/12

6.0 SYSTDi SHUTDOWN .1 De-energizine the ICS Initial Conditions .1 Reactor cooled down and on decay heat (i.e., no feedwater is required to the steam generators). Procedure .2 Open disconnect switches S1 and S2 on the ICS power auctioneer panel. This turns of f all ICS AC power. .3 __Open disconnect breakers to fan bus af ter allowing the ICS to cool for five minutes. 7.0 ABNORMAL OPERATIONS .1 Load Limits .1 A maximum load limit is automatically established for the following conditions: .1 Three reactor coolant pumps operating - Unit Load Demand it limited to 75% full power (%725 hJe). .2 Two reactor coolant pumps operating - Unit Load Demand is limited to 45% full power (s435 MWe). .3 One feedwater pump operating - Unit Load Demand is limited to 55% full power (s532 MWe). .4 Asymeteric control rod condition-Unit Load Demand is limited to 60% full power (%580 MWe). .2 If the Unit Load Demand is above a limiting value, then a runback will occur and terminate at or slightly less than the limiting value as follows: NOTE: The following runbacks do not, in all cases, protect against exceeding Tech. Spec. limits. It is the operator's responsibility to insure that applicable Tech. Spec. limits are not exceeded. .1 One of four reactor coolant pumps trip - runback and limit' Unit Load Demand to %725 MWe at a rate of 50% per minute. A.71/13

7.0 ABNORMAL OPERATIONS (Continued) .2 Two ef four (1 RCP/ loop) reactor coolant pumps crip - runback and limit Unit Load Demand to N433 MWe at a rate of 50% per minute. .3 Loss of one feedwater purn - runback and limit Unit Load Demand to $532 MWe at a rate of 50% pur minute. Load .4 Asymeteric rod fault - runback and limit Unit Demand to N580 MWe at a rate of 30% per minute. .2 TRACKING TRACKING is defined as the mode of operation, when due to .1 some abnormal condition, the unit is being limited in its production of megawatts. In order to maintain coordination of all control variables, the unit must track, or follow, the limited condition. .2 In the TRACKING mode, the acutal generated megawatts is used as an indication of the limited condition. The unit demand will follow the generated megawatts in order to maintain the proper relationship between those stations for in automatic and any one station in manual, except reactor trip, cross-limit or load rejection. Any one or more of the following abnormal conditions will .3 cause the ICS to go into the TRACKIN, mode: .1 Unit under cross-limits. (The difference between reactor power and reactor demand exceeds plus or minus 5 percent of 100 percent reactor power, or the difference between feedwater demand and feedwater flow exceeds plus 5 percent of 100 percent feedwater flow. .2 Transfer of both Feedvater Demand control stations to HAND. .3 Transfer of either the Diamond Rod Control station or the Reactor Demand control station to HAND. .4 Reactor tripped. .5 Tripping of both generator breakers. .6 Steam-Generator / Reactor Control station in HAND. .7 Turbine Control station not in "ICS AUT0". A.71/14 18297 063

7.0 ABNORR\\L OPERATIONS (Continued) .3 Cross Limits .1 Reactor control - if feedwater flow drops more than 5% below feedwater demand, reactor power will be reduced slightly more than 5% to return to the i 3% control band. .2 Feedwater control - If reactor power changes more than 15% of reactor demand, feedwater demand will be changed accordingly to keep the system within the control band of i 5%. .4 Transferring both Feedwater Demand control stations to RAND. .1 With these control stations in HAND, the Unit Load Derand has no effect on feedwater flow. Therefore-. the Unit Load Demand follows the actual megawatts generated to maintain the proper relationship between feedwater flow, Unit Load Demand, and reactor power, if these stations are in AUTO. .2 The Unit Load Demand will respond to changes at either Feed-water Demand control station. The steam generator load ratio (Delta Tc) control will be ir. HAND and will remain in HAND until one or both Feedwater Demand control stations are placed in AUTO.and transfer of Delta Tc control to AUTO is initiated. Inlile Delta Tc control is in HAND Delta Tc should be monitored. .3 If a system upset occurs while both Feedwater Demand control stations are on HAND, match the loop feedwater flows with the existing generated megawatts until a steady state condition exists. NOTE: Generated megawatts versus loop feed-water flow for balanced loop flow and steady state operating conditions is shown in Enclosure 2. .5 Transferrin 2 either the Diamond Rod Control or Reacter Demand Stations to HAND .1 When either station is in HAND, RCS Tave is controlled by feedwater. A.71/15 i BL2'l 064

7.0 ABNORMAL OPERATIONS (Continued) .2 With either of these control stations in HAND, the Un'.t Load Demand does not a f fect the reactor power. Therefore, the Unit Load Demand follows the actual megawatts generated to maintain the proper relationship between reactor power, Unit Load Demand, and feedwater flow. .3 If the Diamond Rod Centrol station is in AUTO, the reactor power may be controlled from the Reactor De=and station. .4 The reactor power may be controlled from the Diamond Rod Control station with the Reactor Demand station in any mode. .5 The reactor power must be maintained consistent with feedwater flow. The operator must adjust reactor pow 2r as necessary to correspond with feedwater flow. NOTE: Neutron power versus loop feedwater flow for balanced loop flow and steady state operating conditions is shown in. .6 Neutron power versus total feedwater flow for steady state operating conditions is shown in Enclosure 1. m .7 The Diamond Rod Control station, if in HAND, cannot be transferred to AUTO if a neutron error greater than plus or minus 1.0 percent of 100 percent neutron power exists. If the Diamond Rod Control station is in AUTO, the neutron error should be maintained less than 1.0 percent of 100 per-cent neutron power by the ICS. .8 The Diamond Rod Control station should not be switched to AUTO unless Tave error is reduced to near zero. while the Reactor Demand control .9 If a system upset occurs station or the Diamond Rod Control station is in HAND, match the neutron power with the existing generated mega-watts until a steady state condition exists. Neutron power versus generated megawatts for steady state operating conditions is shown in Enclosure 3. .6 Trippine of Both Main Generator Breakers .1 ICS goes into TRACKING mode. A.71/16

9 7.0 ABNORMAL OPERATIONS (Continued) .2 When both main generator breakers open, the unit is separated from all offsite loads. A runback at a rate of 20% per minute to 15% ( 145 MWe) power will be initiated to reduce steam production and avoid a reactor trip. When Unit Load Demand is reduced to 15% power, the turbine bypass valve bias is removed; the valves will operate at the Turbine IIcader Pressure Setpoint. .7 Reactor Trip .1 ICS goes into TRACKING mode. .2 When a reactor tripped condition occurs the Unit Load Demand tracks the actual generated megauatts at a rate of 20% per minute. .8 The Followine Limiting or TRACKING Conditions Are Linht Annun-ciated, on the Control Console, for the Operators Information: .1 Reactor coolant pump .2 Reactor coolant flow .3 Asymeteric rod .4 Feedwater pump .5 Reactor trip .6 Generator breaker. tripped .7 Turbine trip .8 Reactor manual .9 Turbine manual .10 Both feedwater loads manual .11 Increasing load .12 Decreasing load .13 Tracking .14 Limited by reactor .15 Limited by feedwater flow A.71/17 i82 066

7.0 ABNORR\\L OPERATIONS (Continued) .16 On low limit .17 On high limit 8.0 ENCLOSURES .1, Neutron Power Versus Loop Feedwater Flou for Balanced Loop Flow and Steady State Operating Conditions. .2, Generated Megawatts Versus Loop Feedwater For Balanced Loop Flow and Steady State Operating Conditions. .3, Neutron Power Versus Generated Megawatts for Steady State Operating Conditions. A.71/18 1829 067

OF A.71 p 1 "" ' J u NEUTP.0U FOUER VERSUS 100? FRED'4ATFR FID!! .h y.. h_..l.. .__ j. l .p. q-i -j -_ L .I i. i i i i.. .-l l i i + l .__.__-__.{...._ i ...i.....i. ___7.___..__.___... .7 o i i i i i _k _..__.__ h _l__ _ I L l l i-0 t _.. _l !-l i __,_ __ j __. -.. _. -. + -, l-- - -, - - .:..l i l- ? _ __ q _ -..4._,._ _ 7, _ 3 ~ i j. j -{- T 100 g q __.H . i

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t 2 oo i ' + .l [T - l ; ~ . T~ i i j i E0 .j _ p. _ ; _ _ i__. 70 .. ;e i. _z.__.- - l-- - __..(__. 60 x n ~ I___I__[ ' I s [ l-l '. l. o m g c ___ i . ~ -l .} s l ..l ~~ 1 f', k 3 l l l t i: 40 f) I l. i l' 4 1 F 1_____. m l,i i: i: l i h -l l ..--~i__, - '-l .i-p l .i1 nl- _ __ _ [__!_ j_ [_._.. _ o I i ' .z_ f__y__h_'._ l___ _ r! __d _... a 30 / __ _ l' i i p i i - e p i i 'O i: i i. i 't j i l I 7 T - -~i 1 Fi ~ 0 l 0 10 20 30 40 50 60 70 80 90 100 Percent Design Loop Feedwater Flc l l l l i e i I I i l i 0 .6 1.2 1.8 2.3 2.9 3.5 4.1 4.7 5.3 5.9 Loop Feedwater Flow (x106 #/hr) a { 3. r--- - - - - - - r -* - r ' r' I .i' 'l.. j- .L n u___.

n m _..

[.. 't' t~i 8" d.__. x; ii' ~' ) 100% Ucutren Power = 27721fde T i 6 E 100% Icop Feedwater F1cv = 5.874 x 10 lb/hr

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k&> gl%, '^" [j gj Enclonure 2 GENERATED MEG A'.#TTS VERSUS IDOP EED'1ATFR FLO'.1 ~ h l \\ i i .i. .t. ...p l. l l-i f l ? l t i ..u. .s.. -l g t I ' -r ! -l j i j i I l i o ... f.. _. .. _ p. _ L._ _.. g. l } i l i i j -l ! l i L I-l __L_}i - {. i l. [~~ j -l = l 100 _' ! ' : } _.l___. .. j _ ._. 7.. _1_ _.1_. l. _.. _ i __., __ _.i .i t r l _l._.__ ...j.. s n, o i I { l { l _ 3...,_...__._. l _.) I I I '.{ i 60 l l, } l l-1 l _l l l i-1 3 ! ~ i ? 70 l 1 r ._,.-. {.. _ l _. -.._...._.__..__{_.._ = _.!_ - l... ;._ : o -_a-.. . - a__ I 0 60 - l 1-u j l - _.. _. p - } __. ...... _ u_. _j l _q y 50 I j l 1 _ _i ._.,_J.__.____..__ e i L__: _1_ s t r . i a 40 l. i l g . _... _.. __..j__. q._ ___j_ _ _ l_._ __.._u.._ ._l__.._,.._ a i .__2_ 'I I '0 I O. 3 c l l l. .j . j .._i_.... _ i 1 1__.. i s

i l !

l ~l i L. . I l. l---- b 20 e l i i a .1... 3 e 1 -l l-i i 1 A l } l 10 j i. i l 1 _.1 l i l l 1< .. _...u.. s = 0 i s 9 10 20 30 40 50 60 70 EO 00 100 Percent Design Loop Feedwater o Flow I l l l l l l l l l 5l.9 6 #/hr) Loop Feedwater Flovi (x10 0 .6 1.2 1.8 2.3 2.9 3.5 4.1'4.7 5.3 i .t

u..

? A 10C% Generated Gross Megnur'tts = 967!T..'e (Norinni Turbine Reting) 6 100% Loop Feedveter Flov = 5.874 x 10 lb/hr g . p. ..9...... .7.q... n. .p ,q.. _,.9

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.i J A.71/ 20 1829 069

0? A.71 Enclocura 3 D (W T NEUTEON PO'.EH VEESU3 GENERATED ICGAVI.TTS I p ?- .' ;.l. . I: l- .I I I I ..1 n i ._i __. i. f l.. ) ?_._ h._ l. [_ ._4. _. _. l.._ ..j._. i c r ' I '. b... _ _ i__ .. _ !. l__._.] - E .r r i .l I - n .._.. [.._ h._ ..L. .__ h.. i. +. _ _w !_. - [-. - _.g ! l I o i j - l - .i ~ j ~ ..-_ _ _ b : !.. - _....j _..j._. [._. _ __.-}...._-. L_ j f f..._.i _.l___.l_.l_ '__b _.i _.}_.! _ 1.._L-._ k ii _ _ _.,_. l [ 96% of Design Conditions at 4.5 in. l [ ~ _.1 _ i_ .. _... _. __ j_l _.L. l t j.j l g . j.,. ;. 100 Hg; Worst Case Summer Conditions - t +i Design Conditions i.e., - e 2.,5 in. Hg.,Av. Vacuum. j No effect for small Main Steam 90 ~ Temperature changes. -.. l..,., ; . f.. l.....h f..... - r-- -- i- ~~~---}-"----- l i i EO } l ll_ U .__f _.._ I __I_-_..-_--- _._ __) _. _~ l i l i l 70 j, l j. i j 60 1/. l ._. j g_- {. _.. i 4--.__ j. I o b 50 g l - [ i._-.__ _ _.. p. i t ~ I l-- o 40 .i. i - l- / l l i co ..__.__p__ _ j __ i + -l l - l-i l i id - ! - - M__J. ' ' l.._.h__. .. _.. l_ J_ _..]__ -. e b I l i i i 2 a c 20 _ _ _ '. . + i i i + i 5 10 .__ j j. i 1 d_ .l j = 1 I _v. 2 _7, 1 0 i i i 4 o 0 10 20 30 40 50 60 70 EO 90 '00 Percent Design Megawatts O 9'7 143290 337 404 500 677 774 070 967 Cenerated Megawatts b '8 15 23 3 '. 39 46 54 62 70 77 Percent of 1250 MWe Full Scale i Indication s ...,. i. i i f. 1- _ _. _ ! _. j__ I l i bul.ui.d d- . ih..li: ui.: {

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} 100% Neutron Pcwer = 2772:Gt [ 100% Generrted Gross Megrvetts = 9671Ne (Nominal Turbine Rating) o _g q.. . _p_._ p. : - xp. .t

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Rev. 13 ATTACHMENT 5 B.2 PLANT HEATUP AND STARTUP 1.0 PURPOSE .1 Provides major steps for operations listed below to take the plant from cold shutdown conditions to 15 percent power. OPERATION SECTION Reactor Coolant System Heatup 4.0 Initial Conditions 4.1 Preparation for Reactor Coolant System Heatup 4.2 Heatup to Hot Shutdown with Reactor Coolant Pumps 4.3 Approach to Criticality 5.0 Zero to 15 Percent Power Operation 6.0 Method to Determine Neutron Multiplication 7.0 NOTE: This procedure may be used for start-ups from other than cold conditions providing all prerequisite steps and conditions of this pr,ocedure are met at the commencement of startup.

2.0 REFERENCES

s .1 SMUD Rancho Seco Unit 1 FSAR, Section 15, Technical Specifications. .2 SMUD Rancho Seco Unit 1 Process Standards. .3 SMUD Rancho Seco Unit 1, Chemistry and Radiochemistry Manual, AP-306. .4 SMUD Rancho Seco Unit 1, PJ ant Operations Manual. 3.0 LIMITATIONS AND PRECAUTIONS .1 If the OTSG is drained, or the water level is below the feedwater heating steam aspirating ports in the tube bundle (383 inches above the top of the lower tube sheet or 96 percent on the operating B.2-1 Rev. 10

3.0 LIMITATIONS AND PRECAUTIONS (Continued) .1 rmage) it should be filled to this level prior to filling the RC System. NOTE: (a) This provides a means of heating the OTSG shell and assures al, low-able tube-to-shell temperature differentinis when the RC System is filled and vented. (b) For RC System temperature chove 230*F, the OTSG level can decrease below minimum startup level. Shell heating is accomplished by flow induced by condensation of steam above the' water level. .2 Minimum allowable feed water temperature to the main feed nozzles is 350*F below OTSG. downcomer outlet temperature. .3 Maximum allowable AT between RCS and OTSG average shell temperature 3 is 60*F (See OF A.6, Enclosure 8.6). .4 Do not feed steam generators via auxiliary feed nozzles except during emergency conditions or unless feedwater te=perature is within 50*F of both RC System and 0TSG shell. .5 The auxiliary feed nozzles must be used for filling an empty OTSG, <8 inches startup level, when RC temperature >200*F. .6 With a filled and vented RC System, do not fill, drain, or blow an OTSG dry without flow in the RC System. Flow may be through Decay Heat or RC Pumps. Rate of fill, drain, or blowdown shall not decrease RC System temperature (T-cold) or OTSG downcomer temperature by more than 50*F below initial temperature. .7 Maximum allowable OTSG fill rate is 500 gpm. .8 When cocked rods and the shutdown bypass position are desired, reset all four power range channel trips to 5%. blanket in the pressurizer to maintain plant pressure .9 Use of a N2 shall only be used when at pressures of 0-50 psig. When RCS pressure is raised above 50 psig, a steam bubble shall be formed in the pressurizer and the N2 vented. in the .10 The pressurizer spray valve must not be open sd with N2 pressurizer, however, minimum bypass flow must be maintained. )b B.2-2 Rev. 3

3.0 LIMITATIONS AND PRECAUTIONSJ(Continued) .11 "Do not actuate the pressurizer spray valve during plant heatup unless the AT between the pressurizer and the RCS is < 250*F unless required for plant safety." .12 Before reactor coolant temperature >280*F: .1 Feedwater temperature must be at least 40*F to at least one OTSG with: .1 at least one main condensate pump and one main feed-water pump or one auxiliary feed pump operable with its associated system. .2 two or more safety valves operable /0TSG. .3 one or more turbine bypass valves or 1 of 3 atmospheric vents operable /0TSG. .4 greater than 250,000 gal. in the condensate storage tank. .5 at least one pressurizer code safety valve operable. .13 Prior to criticality: .1 At least 17 OTSG code safety valves operable. .2 Both auxiliary feedwater pumps operable with their associated systems. .3 Both pressurizer code safety valves operable. .14 Observe RCS Heatup and Cooldown Limits per Rancho Seco Unit 1, Process Standards Curve 101.lA. 10 .15 Prior to any RCS temperature change, verify per OPOP B.6, a 1% Ak/k Reactor shutdown margin will exist at new RCS temperature. .16 Do not add positive reactivity to the core (e.g. Heatup or Debora-tion) without first performing a shutdown margin calculation and fully withdrawing at least two groups of safety rods. .17 If boron concentration is to be changed while a Decay Heat Pump is in service, insure that the calculation of change in concentration uses only the Reactor Vessel - Decay Heat System volume, not the total RCS volume. The RCS total volume will not be circulated, or mixed when on Decay Heat. .18 Do not heatup and deborate at the same time. Likewise, do not de-borate and withdraw CRA's at the same time. B.2-3 Rev. 10 1821f 073

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN .1 Initial Conditions NOTE: If the intent is to go critical after heatup, start B.1, Plant Pre-startup checks, in conjunction with this pro-cedure. B.2-3a 1827 074

s DATE 4.0 REACTOR COOLANT SYSTEM HEATUP TO EDT SHUTDOWN (Continued) INITIAL _ .1 Component cooling and turbine plant cooling water systems are in service according to Plant Operations Manual, Procedure A.26, Section 5.0. .2 Plant cooling water and reservoir system are in service according to Plant Operations Manual, Procedure A.36, Section 5.0. .3 Plant air system is in service according to Plant Operations Manual, Procedure A.40, Section 5.0. .4 Nuclear service raw w 'er system A and/or B in service according to Piant Operations Manual, Procedure A.25, Section 5.0. .5 Nuclear service cooling water system A and/or B in service according t.o Plant Operations Manual, Procedure A.24, Section 5.0. .6 Deca:- Heat Removal Systen A and/or B in service 7 according to Plant Operat ions Manual, Procedure A. 8, Section 4. 3. .7 Reactor Coolant System filldd and vented (or in progress), in accordance with OP A.l. .8 _If the OTSG's have been in wet lay-up above the minimum startup level, draising to a level between 96 and 100 percent on the operating range should be in progress, in accordance OP A 6, Section 4.3. .9 An auxiliary boiler is operating and capable of supplying auxiliary steam for FW heating, clean-up, air ejectors, sealing steam, etc., or startup is in progress, in accordance with Plant Operations Manual, Procedure A.39. .10 Boron concentration in reactor coolant system is as required for reactor shutdown margin in accordance with Plant Operations Manual, Procedure B.9. .11 Concentrated boric acid system available for service in accordance with Plant Operations Manual, Procedure A.12. .12 The steam and mo't'or driven auxiliary feedwater pumps automatic start signals are bypassed. .13 Reactor Building HVAC operating per OP A.14. B.2-4 Rev. 7 1821t 075

s 4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN (Continued) INITIAL .14 Extraction Steam and Reheater Drains System lined up per OP A.53. .15 Review Work Permit status to insure that exceptions will not impede plant heatup (per OPOP B.1, Section

5. 3).

.16 Reactor Protection System energized per OP A.69. .17 Safety Features Actuation System energized per OP A.70. .18 Integrated Control System energized per OP A.71. .19 Reactor Non-Nucleat Instrumentation System energized per OP A.73. .20 Control Rod Drive System energized per OP A.74. .21 Reactor Building Presaure Equalizing System is 3 isolated in accordance with OPOP A.14 Section 4.1.9 .2 Preparation for Reactor Coolant System Heatup Procedure .1 The following prestart/ precritical checks, test and calibrations have been completed or are in progress in accordance with OPOP B.1. .1 Nuclear instrumentation .2 Control rod drive system .3 Safety Features Actuation System .4 Radiation Monitoring System .5 Reactor Protection System .6 Non-nuclear instrumentation for nuclear steam supply system and supporting auxiliary systems. .2 Cycle the following valves to verify operability: VALVE NO. DESCRIPTION INITIAL HV-20570 Main Steam Line Trap Isolation.................... HV-20571 Main Steam Line Trap Isolation.................... HV-35069 Main Steam Line Trap Isolation.................... HV-35070 Main Steam Line Trap Isolation.................... B.2-5 Rev. 13 1829f 076

a 4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTD0'JN (Continued) .2 Preparation for Reactor Coolant System Heatup Procedure (Continued) VALVE NO. DESCRIPTION INITIAL HV-20560 Main S team to Aux. S team Header.................. HV-20565 Main S t eam to Aux. S team Header.................. HV-20596 Main Steam to Aux. Feed Pump..................... HV-20569 Main Steam to Aux. Feed Pump..................... HV-3224 3 Main S team to Pe gging S te am...................... B.2-Sa Rev. 10 18222 077

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN (Continued) VALVE NO. DESCRIPTION INITIAL HV-20598 Main S t e am t o Reh eat e rs.......................... HV-20597 M ain S t e am t o Rehe a t e rs.......................... PV-20562A Main S t e am Atmos ph e ric Ducp...................... PV-20562B Main S team Atmospheric Ducp...... PV-20562C Main S t e am Atmospheric Dump...................... PV-20571A Main S t e am Atmos phe ric Du=p...................... PV-205 71B Main S t e am At mo s phe ri c Dump...................... PV-20571C Main Steam Atmospheric Dump...................... PV-20561 Loop A Turbine Byp as s Valve...................... PV-20563 Loop A Turbine Bypass Valve...................... PV-20564 L o op B Turb in e Byp as s Valve...................... PV-20566 Loop B Turb ine Byp as s Valve...................... NOTE: Verification of operability must be by visual observation of the valves, not by Control Room indication. .3 Place circulating cooling water system in service acco_rding to Plant Operations Manual, Procedure A.38, Section,4.0. .4 Perform feedwater pu=p turbine startup checks according to Pla tt Operations Manual, Procedure A.50, Sections 4.1 and 4.2 and place feedwater pu=p-turbines on turning gear. .5 Establish condensate -and feedwater system operation (condensate pump operating on mini-flow to condenser) per OP A.47, Section 4.3. NOTE: System may be in operation with flow through heater train to condenser. However, prior to establishing con-denser vacuum, condensate pump op-eration on mini-flow is preferred to prevent excessive red iron oxide formation through heater train. 1824! 078 B.2-6 Rev. 2

4.0 REACIOR COOLANT SYSTEM HEATUP TO HOI SHUTDOWN (Continued) INITIAL .6 Place the turbine lube oil system in operation and place turbine on turning gear, per 0F A 46, 2 Section 4.1 and 4.2. .7 Establish sealing steam to feedwater pump turuines and main turbine-generator seals according to Plant Operations Manual, Procedure A.49, Section 4.1. .8 Establish a minimum of 25 inches Hg vacuum in each L.P. condenser according to Plant Operatioas Manual, Procedure A.49, Section 4.2. .9 Establish condensate and feedwater system cleanup and heatup per OP A.47, Section 4.4, and place the turbine plant chemical addition system in operation per OP A.43. .10 Place reactor sampling system in service according to Plant Operations Ebnual, Procedure A.11, Section 4.0. .11 Verify levels and boron doncentrations of the core flooding tanks, borated water storage tank, and con-centrated boric acid storage tank are within Jimits. (Minimum limits are specified by SMUD Rancho Seco Unit 1 Process Standards.) .12 Verify that the coolant radwaste system is lined up per OP A.16, Section 4.1. Verify that the coolant waste receiver tanks, T-607A and B, have sufficient capacity for reactor coolant expansion and deborating volume. .13 Place reactor chemical addition systen in service according to Plant Operations Manual, Prceedure A.12, Section 4.0. .14 When turbine plant feedwater chemistry has been established within limits, per the Rancho Seco Unit 1 Water Chemistry Manual, establish OTSG 2 level between 96 and 100 percent as indicated by the operating range level instrumentation, in accordance with 0F A.6, Section 4.1. . 15 Complete reactor coolant system initial filling and venting according to Plant Operations Manual, Procedure A.1, Section 4.1. B.2-7 Rev. 2 18211 07

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUIDOWN (Continued) INITIAL .16 Form a steam bubble in the pressurizer according to Plant Operatiouc 2bnuel., Procedure A.3, Section

4.3. CAUTION

Do not exceed Decay Heat System pres-2 sure/ temperature limits (see Process Standards curve 100-4). NOTE: RCS Heatup and Cooldown Limits, En-closure 7.5, must be observed. .17 Place the letdown and purification makeup system in 2 service in accordance with OP A.15, Section 4.2. .18 Increase reactor coolaat system pressure to approxi-mately 230 psig, as & cad on low range RCS pressure transmitter (that pressure required for RC pump operation), per OP A.2. NOTE: Observe curves in 0F A.1 for simulta-neous operation of DH and RC pumps. .19 Start control rod drive cooling water system ac-cording to Plant Operations Manual, Procedure A.9, prior to reaching 150*F RCS temperature. .20 Verify OTSG valve lineup is per 0F A.6, Section 4.1.7; then pull a vacuum, minimum of 20 inches Hg, in the OTSG by opening the turbine bypass v alves. This produces steam at low OTSG water 2 temperature which will condense on the OTSG shell and warm it. The vacuum source (condenser) will remove non-condensible gasses f rom the OTSG. NOTE: (a) A minimum vacuum of 20 inches Hg is required for OTSG shell heatup to prevent exceecing the tube to shell dif ferential tem-perature limit (60*F during heat-up). R.2-8 Rev. 2 iB 080

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN (Continued) INITIAL NOTE: (Cont'd) (b) Greater than 20 inches Hg is re-required to satisfy turbine bypass valve interlock and allow valves to open. .21 Adj ust decay heat system cooler outlet and bypass throttle valves as desired to increase reactor coolant system te=perature for startup, (i.e., via reactor decay heat). .22 During heatup to 220*F, keep the turbine bypass valves partially open. .23 Before reactor coolant system temperature exceeds 150*F, reactor coolant pump seal injection should be started as per Plant Operations Manual, Pro-cedure A.15, Section 4.0. Verify reactor coolant pump seal flow. NOTE : The recirculation line on the operat-ing makeup pump must be open. .24 Establish letdown flow at a rate equal to reactor coolant pump seal in leakage. If adequate letdown is not possible, reduce the RC pump seal flow control valve setpoint accordingly. (Do nct raduce flow to less than 3 gpm seal flow per RC pump). ~ 25 Place pressurizer level controller in automatic and set to control pressurizer level at approxi-mately 100 inches. .26 Run each RC pump for 5 minutes minimum, in acccrdance with OP A.2. NOTE: Do not run 'A' or 'C' Reactor Coolant Pumps by themselves. .27 Complete RCS venting per OF A.1, Section 4.2. 7 B.2-9 Rev.- 7 1821& u81

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTD0 TIN (Continued) INITIAL .28 Verify RCS chemistry is in accordance with Rancho Seco Unit 1, Chemistry Manual. NOTE: Cl, F1 and 02 in the pressurizer must 7 be within RCS specifications prior to exceeding that pressure which allows simultaneous operation of RCP's and a decay heat system. NOTE: During heatup with an irradiated core (greater than four full power days), establish operational hydrogen concentra-tion in the system prior to exceeding 200*F. Refer to Plant Operations Manual, Procedure A.12, Section 4.4, Reactor Cool-ant Chemical and Hydrogen Addition System. .29 Perform the following operations prior to heating up to hot shutdown conditions: .1 Complete nuclear instrumentation precritical checks per OPOP B.1, Secticn 5.1 or 5.4. .2 Adjust over power flux trip to 5% full power. .3 Initiate shutdown bypass on each channel of the Reactor Protection System. NOTE: This will remove the following trip protection: .1 Power - imbalance - flow .2 Power - pump .3 Low reactor pressure .4 Reactor pressure - temperature .4 Verify that che teactor will be >l percent sub-critical during heatup with safety rod groups 1 and 2 fully withdrawn, in accordance with OPOP B.6, Section 5.3 - Shutdown margin determination. .5 Calculate the source multiplication that should occur due to the safety group withdrawal. Re-fer to Enclosure..1, anel Enclosure 7 11 worksheet in OPOP B.6. .30 Prior to reaching 200*F/300 psig RCS Temperature / Pressure 7 lineup place the Reactor Building Spray System in standby per OF A. 7, Section 4.0. B.2-10 Rev. 7 18 082'

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOW'N (Continued) _I_NITI/4 .31 Complete the reactar containment building iso-lation requirements of OPOP B.1, Enclosure 5.3, Item 5, prior to reaching 200*F RCS Temperature and 300 psig RCS pressure (with the exception of the OTSG drains to

• ae HP condenser), prior to being subcritical by less than 1% Ak/k.

.32 Line up the Auxiliary Feedwater System per OP A.51, Section 4.2. CAUTION: Do not place controls in auto until the RCS is at Hot Shutdown. .3 RCS Heatup to Hot Shutdown Conditions with Reactor Coolant Pumps .1 Increase letdown flow to the maximum obtainable. Adj us t pressurizer level setpoint to control at approximately 100 inches. NOTE: Place both letdown coolers and filters in service. Observe maximum letdown flow limits during heatup. .2 Increase reactor coolant system pressure to satisfy reactor coolant pu=p NPSH require.nents per OP A.2. CAUTION: a) Do not exceed RCS or DH System Pressure Limits. b) Do no t Feed and Bleed without flow in the Reactor Coolant System. CAUTION: Before proceeding to the next step verify that 3 OCB-220 and OCB-230 are OPEN and that they are restored to the condition fot normal operation in accordance with EH.174. .3 As RCS pressure approaches the maximum for decay heat system oepration (255 psig) stop the decay heat pumps and isolate the DH system from the RCS. Place clearan:e on HV-20001 and HV-20002. Continue pressurization to >400 psig then with-draw control rod safety groups 1 and 2. Verify predicted neutron multiplication during control rod withdrawal. NOTE: The minimum RCS pressure for energizing control rod drives is 400 psig unless the conditions of limit and precaution

3. 3 o f OP A. 74 a re me t.

)h B.2-11 Rev. 13

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN (Continued) INITIAL CAUTION: Before primcry system temperature ex-ceeds 280*F and decay heat pumps are stopped at least one OTSG must be available for RCS heat removal. .4 Start RCP 'D', per OP A.2. NOTE: The recommended sequence for starting RCP's during heatup is: 'D', then 'B', then 'A', then 'C'. .5 Stop nuclear service cooling water system and place on standby, per Operating Procedure A.24, Section 4.2. .6 Stop nuclear service raw water system pumps and place on standby, per Optrating Procedure A.25, Section 4.3. .7 Place the Decay Heat System in the SFAS stanaby 7 mode, per Operating Procedure A.8, Section 5.1 8 Monitor and plot reactor coolant system temper-ature and pressure and RCS heatup rate. Use pressurizer heaters and/or spray valve to main-tain reactor coolant system pressure within the heatup limits of Enclosure 7.5; and observe maximum pressurizer heatup rate of 100*F/ hour. 9 Start second reactor coolant pump, when the RCS heatup rate permits, in accordance with Operating Procedure A.2 (preferably RCP 'B'); and when the RCS heatup limits permit, start the third reactor coolant pump (preferably RCP 'A'). NOTE: During heatup, maintain pressurizer level at 90 to 115 inches; maintain MU Tank between 60 and 80 inches. f8{f B.2-12 Rev. 7

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN (Continued) INITIAL NOTE: Should the OTSG tube (RCS Tc) to shell tem-perature differential approach lhe ---- limit of AT >60*F, the turbine by-pass valves should be cracked open or opened further to increase OTSG shell warming. 10 Prior to reaching 180*F RCS temperature, complete the condensate and feedwater system cleanup-re-circulation and place the system in the startup-recirculation mode for feeding the OTSG's, per OP A.47, Section 4.4. NOTE: Feedwater and condensate system water chemistry must meet startup chemistry specifications for feeding the OTSG's. OTSG chemistry must meet specifications prior to exceeding 200*F. .11 Sample and establish RCS water chemistry per Rancho Seco Unit I, Water Chemistry Manual (See note of Section 4.2, Step.28 of this procedure). .12 When the RCS temperature reaches 180*F, initiate OP A.6, Section 4.2, OTSG Heatup and Startuo, i.e., establishing OTSG feed, then, draining and steaming down the OTSG 1evels to the startup opcrating, level of 30". NOTE: OP A.6, Section 4.2, will~ be per-formed concurrently with OPOP B.2 during RCS heatup. 13. " Prior to exceeding 200 F RCS temperature, return ~ 0 pressurizer HPI spray lineup to normal and remove shutdown RCS over-pressure protection as follows: 1. Close HV-23802. 2. If the MU pump is not being used 'or B HPI and the B HPI pump is not supplying RCP seals 9 and normal makeup, lock closed SIM-068 3. Remove Caution tag from HV-21505. 1829!085 B.2-13 Rev. 9

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN (Continued) Initial .4 In NNI cabinet 3, place key lock for pressurizer electromatic relief in 9 Normal position and remove key. .5 Remove clearance and open HV-23801 (and place a clearance on ACB 2B179) and re-sto re power to SFV-23809, SFV-23811 and SFV-23812. .6 Remove clearance and rack in breakers 9 for HPI pumps P-238A and P-238B. .7 Place the HPI system in SFAS standby per OP A.15, Section 4.3. .14 When reactor coolant system pressure reaches 500 psig, adjust the RCP seal flow to 32 gpm and check each seal flow input at 8 gpm. .15 When the RCS pressure is approximately 700 psig and increasing, place Core Flood System in stand-by service per OP A.4, Section 4.2. .16 Perform the following when reactor coolant pres-sure approaches the high pressure trip point, 1820 psig. (This is automatically reduced below the low pressure trip by initiation of the shut-down bypass.) .1 Stop heatup using the Turbine Bypass Valve and startup feedwater valves to balance reactor coolant pump heat irput. .2 Drive all control rod groups into the core and trip the reactor utilizing the manual trip button on the reactor control console. .3 Reset reactor protection system bypasses (all four keys to the Shif t Supe rviso r). .4 Reset power range channels overpower trips to 105.5%. .5 Raise reactor coolant system pressure above the low pressure trip of 1900 psig and reset each RPS channel. .6 Withdraw control rad groups 1 and 2 fully, per OP A.74. .7 Resume heatup. .17 Verify that all SFAS Channels are reset at 1850 psig RCS pressure. .18 Place pressurizer heaters and spray valve in automatic control when reactor coolant pressure reaches 1950 psig, and RCS temperature 1380*F. ) bl2 h(lh B.2-14 Rev. 9

4.0 REACTOR COOLANT SYSTEM HEATUP TO HOT SHUTDOWN (Continued) INITIAL .19 When main steam pressure reaches 350 psig (%430 F), place a feedwater pump in operatio.1, per OP A.50, Section 4.3. NOTE: A feedwater pump must be in operation prior to reaching 500 psig main steam pressure. .20 When each OTSG steam pressure is greater that 500 psig and stable, enable each main steam line failure logic circuit. .21 When reactor coolant system temperature reaches 520 F (T-cold) and the reactor coolant pump interlock clears, start the fourth reactor coolant pump, in accordance with OP A.2. NOTE: When reactor coolant system Tave is >525 F, steam generator steam may be used for feed train heating and turbine gland steam. This may be accomplished by gradually reducing the auxiliary boiler output and allowing main steam to supply the auxiliary steam header (See OP A.39, Section 4.7). 9 .22 Start the second main feedwater pump and place it ia manual at minimum speed, per OP A.50. .23 Place the auxiliary feedwater pumps and valves in automatic in accordance with A.51, Auxiliary Feedwater System. .24 The RCS is now at hot shutdown condition: .1 The reactor has 3,1% Ak/k shutdown margin. .2 RCS Tave 2.525 F. .3 RCS pressure is being controlled at 2155 psig. .4 Turbine bypass valves in automatic and con-trolling OTSG pressure at 885 psig. .5 OTSG levels being controlled at the startup operating level. 1827 087 B. 2-15 Rev. 9

50 APPROACH TO CRITICALITY .1 Limits and Precautions .1 The reactor coolant system will never be deborated and/oc maintained at a boron concentration that; would cause the reactor to be critical on safety groups with Group _5 <20% withdrawn due to xenon burnout; or, during an increase in power with high xenon concentration. .2 Axial power shap. ods may not be used for any purpose except axial power control. .3 The reactor shall not be 315% power with the pressurizer level greater than 290 inches or less than 160 inches. .4 The normal startup rate will be 1 dpm or less. The prompt change associated with attaining this SUR will be less than 1.5 dpm. .5 The minimum count rate prior to rod withdrawal to go critical is 2 cps on one source range channel. .6 A minimum of 1 decade of overlap between one source and one intermediate range instrument is required. .7 The reactor shall not be critical unless safety groups are fully withdrawn and Group 5 is 3,20% withdrawn. .8 Recommended critical rod positions are: .1 Critical on CRA's with sufficient reactivity _ to over-ride total deficit from 0% to desired operating power level. .2 Group 8 at the same position as previous shutdown. .9 Reactor power shal1 not be 3,15% full power unless CRA Rod Index is > 90% RI. 10 .10 Methods of reactivity concrol: a) Safety groups: Reactivity control for maintaining reactor shutdown capability. b) Regulating groups: Reactivity control for compensating temperature feedback from 0 to 100% power. 1827088~ B.2-16 Rev. 10

5.0 APPROACH TO CRITICALITY (Continued) INITIAL c) Axial power shaping rod assemblies (APST): Reactivity control for maintaining power balances in the reactor core. d) Soluble boron: Reactivity control for com-pensating equilibrium xenon and fuel burn-up. .11 The following maneuvering restrictions should be observed: .1 ZERO TO 20% REACTOR POWER - The maximum rate of reactor power increase shall be 10% per hour. .2 LESS THAN 48 HOURS BELOW 20% REACTOR POWER - Normal reactor maneuvering rates apply for power operation above 20% reactor power, with a 2 hr. Tech. Spec. hold at the power level cut off (92%). .3 MORE THAN 48 HOURS BELOW 20% REACTOR POWER - The maximum rate of power increase above 20% reactor power shall be 30% per hour with a five (5) hour hold at 20% power below the power level cut off (92%). .4 FOR STARTUP IMHEDIATELY FOLLOWING A REFUELING OR A CONTROL ROD INTERCRANGE - The initial escalation above 75% reactor power shall be limited to 3% per hour, with a 5 hour hold at the power level cut off (92%); this is in addition to Steps.1 and.3 above. .2 Initial Conditions ~ .1 Plant is in a hot shutdown condition. .2 Estimated critical rod position calculated in accord-ance with B.6, Reactivity Balance Calculation. .3 Plant Pre-startup checks, B.1, completed. .4 At least one source range NI reading >2 cps. .5 At least one RCP running in each loop. .3 Procedure 18217 085 13 B.2-17 Rev. 13

5.0 APPROACH TO CRITICALITY (Continued) INITIAL .1 Place the Reactor Trip From Turbine-Main Feed Pumps in service as follows: .1 At Panel #2 of Protective Relay Generator Panel H3PRG, reset the target drop on 30FPT, Both Main Feed Pumps Tripped. CAUTION : If 30FPT target drop cannot be reset, DO NOT PROCEED until the problem has been corrected. .2 At ilIRI check the ReaEtor/f2P TrifR5 fit is not ON. Place Reactor /FUP Trip cutout key in NORMAL. CAUTION: 12_ If trip light is ON, DO NOT move the switch from the CUTOUT position. .3 Verify Annunciator " Reactor-Gen Prot./FPT or Cdt6ut* clears at il2TSA. .2 Calculate the source multiplication that should occur due to safety group withdrawal. Refer to Enclosure 7.1 or Enclosure 11 worksheet in OPOP B.6. .3 Announce " Reactor Startup in Progress" over the plant intercom system. .4 Withdraw safety groups in sequence to their upper limits in accordance with A.74, Control Rod Drive System, if not done during heatup. Observe source multiplication. .5 If criticality cannot be achieved with recom-mended rod confirguration, perform the following: .1 Calculate boron concentration required per B.6. .2 Calculate the Feed and Bleed volume required in accordance with B.9, Soluble Poison Concentration Control. iEL2f D90 B.2-17a Rev.12

5.0 APPROACH TO CRITICALITY (Continued) INITIAL .1 If criticality was achieved at more than 0.5% ok/k below the ECP, resolve the dif ference in estimated vs. actual critical configuration; then proceed with Step .8. .2 If criticality was not achieved within 0.5% ok/k above the ECP, perform the following: .1 Insert all regulating groups. .2 Verify boron concentration, time, Tave. .3 Recalculate the ECP. .4 Repeat Steps 3.4 through 3.7 above. .9 If the reactor is critical within +0.5% ok/k of the ECP, raise the power to 10-8 amps on the intermediate range and record the following on the ECP form. .1 Rod position. .2 Boron concentration. .3 RC average temperature. .4 Time. NOTE: Observe intermediate range channel is on scale and indicating before the l7 5 source range is at 10 cps. If not, 4 reduce power to 10 cps and check intermediate range. Observe that source range high voltage de-energizes at about 10-9 amps on the intermediate range channel. .10 The plant is now at hot standby: .1 Reactor critical at <2% power. .2 RCS pressure being controlled at %2155 psig. B.2-19 Rev. 7

5.0 APPROACH TO CRITICALI1Y (Continued) INITIAL .3 RCS Tave 2.525'F. .4 Startup feedwater valves in auto. .5 Main steam pressure being centrolled at %885 psig. .6 Two condensate pumps and two main feedwater pumps in operation (one main feed pump in auto and one in manual at minimum speed). 6.0 ZERO TO 15 PERCENT POWER OPERATION Initial Conditions .1 Reactor Coolant system at hot standby. .2 Reactor coolant system pressure being controlled at s2155 psig. .3 At least one reactor coolant pump per loop running. .4 Condensate and feedwater system in service. .5 Auxiliary feedwater system in automatic. .6 Main turbine in manual control. Procedure .7 Verify the ICS/ hand auta stations are lined up as follows: Station POSITION INITIAL .1 Turbine bypass atmospheric exhaust valves A & B. Auto .2 Turbine bypass condenser dump valves A & B. Auto .3 Auxiliary feedwater valves A & B. Auto .4 Startup feedwater valves A & B. Auto .5 Main feedwater valves A & B. Manual (Closed) l3 1 BJ21) 09?_ B.2-20 Rev. 3

6.0 ZERO TO 15 PERCENT POWER OPERATION (Continued) Station POSITION INITIAL .6 Main Feedwater pump A (B). Manual Main Feedwater pump B (A). Auto .7 Loop feedwater demand A & B (Set at zero) Manual .8 Reactor Deman (Set at 0) with Tave setpoint at 582*F (s62%). Manual .9 Diamond ' Rod Drive Controls'. Manual .10 Steam generator-reactor master (Set at zero). Manual .11 Unit load master (Set at zero). Manual .12 Steam Generator Ratio - ATC 7 (Set at 50% ). Manual .8 Verify the unit load demand setpoints as follows: .1 High load limit at 145 MW (%15% power). .2 Low limit at 96 MW. (%10% power). .3 Load Rate at 1 MW/ minute. .4 Unit load demand at N12% (%15% power), .9 Verify the Loop A and B feedwater demands are zero, then, place both in automatic, then place the steam generator ratio-ATC in automatic. NOTE: Verify the startup feedwater bypass valves (FWS-129 and FWS-130) are closed when feedwater demand is placed in automatic. B.2-21 Rev. 7 i8217093 1 s

( 6.0 ZERO TO 15 PERCENT POWER OPERATION (Continued) INITIAL NOTE: Check the relationship between reactor power and reactor coolant system temperature (T ave) as shown on Enclosures 7.2, 7.3, or 7.4. If the plot falls below the desired relationship, lower steam generator water level. If the plot falls above the desired relationship, raise steam generator level. NOTE: Recalibrntion of the ICS may be required to achieve the desired steam generator level control with the startup valve in automatic. .10 Increase reactor power, using the rod drive controls in manual. NOTE: Observe that the power range channel comes on scale at about 10-6 amps on the intermediate range channel. Observe RCS Tave is increasing commensurate with Enclosure 7.2. " Allow pressurizer level to gradually increase from %100" to 20.0" l 14 during power escalation to 15% FP". .11 When reactor power is %5%, verify zero neutron error and place the diamond rod control in automatic. Continue reactor power increase to %10% power with reactor demand in hand. .1 "When the startup feedwater valves reach 80% open and main feedwater blocks valves are open, and if the intent is to increase power place the main feedwater valves in AUT0". ~ .12 When reactor is >10 percent power, steam pressure %885 psig bring turbine up to speed, per OP A.46, Section 4.3, for operator auto startup; or, Section 4.4, for computer auto startup. Lineup the 220KV system, syncronize, and load the generator to 5% load per OP A.54 and OP A.46. Hold initial turbine load for minimum warmo; period as required by OP A.46. .13 While main turbine is going through warmup period witl. initial minimum load, continue increasing reactor power to %15%. NOTE: Prior to exceeding 15% reactor power, secure OTSG blowdown per OP A.6. .14 Increase steam generator-reactor demand to N15% and complete the following: .1 Verify reactor demand deviation at zero and place in auto. 1829 094 B.2-22 Rev. 14

6.0 ZERO TO 15 PERCENT POWER OPERATION (Continued) INITIAL (2) Verify steam generater-reactor deviation at zero and place in auto. .15 Observe that feedwater pump speed responds to feedwater valve dp error, i.e., to maintain 35 + 5 - O psid across feed valve. .16 When main turbine warmup with initial load is completed raise turbine-generator load to nuclear steam supply load in accordance with A.46 and observe that the tur-bine bypass valves close. .17 Place turbine-generator governing valves in ICS AUTO control. 3 .18 Enable main steam to second point headers by placing PV-32244 and PV-32245 in AUTO. .19 The plant is at 15 percent power and reactor coolant system is being controlled at 2155 psig and 582*F T-Turbine bypass valves are closed. ave .20 The nuclear steam supply and the turbine are being controlled with the ICS Unit Load Master in hand. .21 The plant is ready for power operations in manual by the operator. See Overall Plant Operating Procedure B.3, Section 4.0. 7.0 ENCLOSURES .1 Method to determine neutron multiplication. Multiplication =R (100 - R ) 2 R (100 - R ) 2 Where P = how far subcritical prior to reactivity 7 change (%Ak/k). Where R = how far subcritical after reactivity 2 change (%Ak/k). CR = M(CR ) where CR = New count rate. 2 2 CR = Init.lal count rate. y B.2-23 Rev. 3

7.0 ENCLOSURES (Continued) .1 Examples Example 1 Condition: The reactor is 10% subcritical 5.3% reactivity is added by withdrawing safety rods. The initial count rate iis 10 codnts. The reactor is 4.7% suberitical. Calettlation: R = 10% R = 4.7% y 2 M = 10 (100 - (-4. 7)) = 10 (104. 7) = 2.03 4.7 (100 - (-10)) 4.7 (110) CR = 2.03 (10) =20.3 cps 2 r Example 2 Condition: Safety rods are withdrawn the reactor is 5% suberitical. Deborate 100 ppm Ck = 500 cps. boron worth hot is 0.bl%k/k/ ppm. P = (100 ppo).01 = 1% b The reactor is nov 4% subcritical. R = 5% R = 4% y 2 m = 5 (166-(~4)) _[=__5(14f=~1.2'4 4 (100-(-5)) _4 (105) CR = MCR = (1. 24) (500) = 620 cps 2 y B.2-24 TRev. T 1827 096

ENCLOSURE 7.2 ~ g-D l3 C'" ^ OP B.2 un

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.... {=.. .. t....l...,. =. =. [n:r=... j.. _.m.. : ....... f....p.. .. r

m. - p., g.

r.. :.-..} _n. :: :. :....

...E. i'. n u. r

r......

- =. - :: u. 4 t // s.._..... ? O 0.5 1.0 1.5 2.0 2.5 3.0 + %i L' W n:.u]m. =_

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M IE 5E"

• 5 d

'~

Eib rdlMiii"l~Eis"~"~I+i=1'=t.-" tab"F='=r!=!=ilr P T *ili # ) E a-5

!l.

j::'

.pn:

..i.. 0 20 40 60 80 100 E y:,:r.:T p l..

t.

g IM 5.P "Il5E NSS Power, %FP NE Mik N M ~i N E ilik ~"i"" E n}iijif- ;t r;.-{-~~~ TiiT=r -

ii i dil ~

.. O :- "+ i c I i "-l ..:. t :: .. ::17 :. 1: xpectet.

l,

..l = n

a..

o .i.i.. e... 8.. .:I :

1 :

r. M !rt: ! n.,. .i.. ~~i-- '~~~I --- d. 1 y,..n - it ~ !:E . N i e. t:! !!!E. !:ln" Tit!f ~ 5 - - - - A11oveble ..p !=., Deviation } g] }g/ B.2-25 Rev. 3

ENCLOSURE 7.3 m -c c,.. b l3 ~ OP B.2 .m_....... .._..__.........m... y l RCS A11cunble Tc=perature Deviation vs Power With Three i ., [Q RC Pumps Operating - Average Te=pereture of 582 F end ji. ~ ~ ~ ~ 92,000gpn. 1. . u...q g. m. e 9 9 p. g i g....%u m, .m. o..y np. e b. g.. ,on.m....... hl1 { hi .. l... .a. ::

4:.

..l.: ch: n h.o ..p .. ::l:; : - {.. 'll _:l: .. l '. .l: .l 'I~ -l-i .z. X -d q.. ]- ~ ~ j~ el " l .: P. 9 i.l : .:P a.l: - n!4

• fir Tiii

~li . 1..2c .u l.:

4...-

. l _.. .in- . -j-_.

- [

4.,

atu .._.a .g.. _. In. niem. mE Reactor Outlet - 2 Pumps j

.,n :c. _= ail l.:

= = h_.- . -'{.4 =! ;mE. :Ff % o t:: ST-

a..

... - s .,,,, ~,, .ml.. _ ..i...- .. t.:

m. r 610

=-}=:: lu=il=,.:- Maximu= - 2 Pu=ps 2.;;;.

up::. u:h = 1 c aIn-u _ c :_. J .-h,

u..r

=- a :- _i;: il_ n r.r ---d = = u:.r ' = l= f = - !Ef::.T=r::jf 9.i.p-{- } n l:s'N{p e pr nl:: na c_ n ' ].: R r .i 8 sc= r. =:r.- =_ g". ; .~,;;.4

4

.:G ; 4;;.?Z%";;4%*.

.i; {j [;g; _=Q. ((: , g. t;i ;, -{ ,g

l~

!!}ii-

/

g Maximum - 1 Pump JEi Miij~#iN 'I I 6 h:il.. Pi!1IE =E Fi' 5 3- "I^1"'- l L i i 600_ .q.-1..t.. -. r.=h,=x. usu. t. u..cg_,;,,. .;...y ._u e. "~ Reactor Outlet - 1 Pu=p .. r= c m. = .=:h. :, i.j=]:, 9-- q-A"... .. M. :. 6... j.,. n..

a..

-- =

i

r

--e-se = mte m nemt ni. r mn -- = e

- =. - . e r_. i t .. ;r m.1:.. r mE. ] rue; :.x

c:

..[ : =- /l m n:n !.. n t = l:: ..l:: :. l:: :

::: p g -

_. -. a Minimum 1 Pump , '(,.,.#g: l:en = +# r~7-i .,v. 4.: .... :: rl.:.r 7 m pc .==- o -t 2 ...t q. r 590 - - - _ v}. " . l- - r-. ' u -

- t

a"-

u t.:. . ::tn an: i t/. W :r P :> r-

:::tM.

M"'... p - - - - - ~ma ..;L.._.,. =..l. {. -.. 4.,. =J r.. _. t.. g -/j... 2 j =. Mini =um - 2 Pu:Es =.... I. c. a.

=.

.._g.... .. C a._ 2_: ; a _'.. - -- - - - ". u u--. t _. t. l :. - -.. _. - _R ini: _

y...

.:r_ ...;l.:2.- t _. : ..I _ ;- pn - : 1: - N-hS4 -}" bEli9d -fl-i 4:' { ml.: i : : f". ".-. '.;n: i - ' } r hil*:i la verege i

w. 580 n,.=...l.=-..=...-.

.b...T.. !. .....".t.c ~ ,~,..n,-,.e.,,..

n..-. [=.... [=..j i... g.r.:.2. b....1 n...t =.. f..d....

O. o r.

t. a.. _..m _

Minitum ..e..- j .c:t =t = p... Y". }N m:= t :: r: -

r.::

md= ah:

h:

.[:

-4a .:an :t=7.:

nyn c

rl e rtrnt:u:.

. N i - -

P tr

-~ r n

n* M:C -- hr-'-- :

r.; -

.n 7 : "j... p.. ~ -2 ~ -'" . :f 2::h. nam. 3":r :* _", u =:. t m'+li M*f = h' h .. } u:. =- :' I* k.3 T2 \\ .4-4;;j:= r-a c n 7-e. r

nt:: :

Efir = 5tilist=E a-i!# i.ii: b.i - 1-Eh" R T -li!r M. =hinCx.J NiG *i~- =i=E: m -U 570 -- n =h =e= *r =:t: 1 Meximum

t -I-== -

..I::': ,_t _ .el.ud=m = =d" ..=l=au 3 _ -tu a.. m= -- r-g n 7__ .r g _._ pr.. y {_ y '.t' -~ ~~

=

= -r p. =7 u. 2_ 4. ;.=...ts_-. =.:m. -. = r:...n..: '_ { ;, ;:;_. l J-T :}.]. r nu .: u 5 E -} s o 6 i ~E" ~7 OTSG Outlet 9 b. '*;. N.7 'r.

• g2.

w .m i u =..c.. a i :- "j' 3 <i..- cut ..t =. }.n.. %. h:.. . K;,, = @..r . :j... .i. ~ Ml:' -.j r .!~~ 5:'? f '. N h: m.l- -.j l... s g 960 u-j..=.. c.y;. . }.:. a.. s. u..a.z z.n

n. 94\\

,u [.7.y a 7 ._ m _ h i m pr-

.l= auj.u.

ub: ...-, _ r r ; i:. pn. ' Nr... g:": iy. ah; - nt.

.t..

.s

n. -

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li i

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e. p. : a =.. p. :.

... h-

n_.4.. j....,..2...=....,n..

w n iiPiEF,':ii!!E :,'!MMId,ifi35fsiMllI!ili:ElisisiEN5ihi;, a ,i!& Til# ' !@!sIMIU Ei!E .. I ". E O 20 40 60 80 100 lh. .l:

u.

oa NSS Power, %FP ,h 3

;a u;e :q..

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7 i:!!H jiphilj@r#j.i. i'j.L El:'- Sp; li!L

jf s j Expected

---

A11ownble Deviation B.2-26 Rev. 3 c-

/ D I )y' F h ENCLOSURE 7.4 m: _ c f.i f ~ gg,, a[ f, l 3 l U 0F B.2 4:t lil Allowable Temperature Deviation vs Power With Two (2) RC Pumps - 3 One (1) Per Icop; Average Temperature of 582 F and 92,000gpm. v..i im.

j..

t shliii w yr -- pp:p;" w pp yp nn w g gr up

p g i". 7 "gp p.

~~ ,...{. ..._s. g.. 'l F!L

ii in:

L . d.. -- -.l. fi k.. '

.a uml=..

.uau i.: .. p..

4....

J. 610 .. h p.i Maximum _ L, _-1El.! .t i 4! Fli! .i h .!;jg

p: 7-f:: ' ;j:j.:.

..U hr :,pM ]ij ,g.. .:pny-",,;, f'p.:l3 'l' s EIE Nd Ur !I' "i 'I Ihi - eactu: Outlet .a.

, w C

l: * -

!-f* *.

• t ! -*

,,.at.

. : P 3 1 '

n* :. P ::f:: u n v -.-e. - =,:' t : '_. : -t t : .=t= t ~1'

t m:

600 g4.i_. u;) :g ::jg ;-l.; gjt;...:,9 4

p. ' Mas, w

pj +;.j:= .}r pp1

lly 15 ~ J Pdnimum

!~ ' II~ "I' fjui-F 7.;jjjj ; tMM " ?!M ,!!i+j#iils'"- rp 4' llE

!lii 4:

t:-

-i'il-9P T',1,P"@.-d'W #isi i-T(!!~ iE@=ili#=h-F ": a!: li!!

li

?!E 590 =ggg g;c; p,gj, agi, ;,,g. =gqspa.a_ c a = :=ngi;up; g w. _jg

g. y 25ffiit El5" Nd!E Ni -

Eh! -tiit ~ 3f~2: fil!'I#i - -':1 - :21 5 i=i===FisMaximum ~~ "'"~' ~ "l:!- T_""_3j' T ;i.Q[T ' i] ~-' $.--M!-- Q ":-~~- T.-- '-f--I ii ! i i everere l'ib-g_g. g.i;..p. _i

q =.p: py :.i :.p :p; e.g._ :; _ 3 i _ ;. i.

.r ; - 9

.;p.

ni =. @2i. :ad Milii 1;ngii

iii[ji!!i!llE i;j!!

'li?i; e 580 d:= f. !/.i = Minimum .. gg. 3 g.g Ej=jl3f.% G ;l.-E!!-" 'i@! [ Epi"li@ilis g. J t..-.Ma* ;i. p.i_..:.J.:

iph ap.r.

_ij.. f. ^4' E _ 4..js. L,E.. p:Tlii: .-fil_s_ __ 1..=.=.=_ i:..E_:s_ jm_.r._:.=E _ 7_ N.E. _ {.. M...i.ir E..EE 5 ' ?.:. l=...". O_..m,i[.:ih.. H.. i. >..! l.- :T..l5. 85p.: L"i! f gi-G F,,jF ' i.5:: .:E.l _.-:, f 570 o. _tg;._ j.. r,- 3 7. __w..py......, ; 3g.. ;_q___. =. _.,.__p.._.;g,.,;s; g.:_;;; a _qg E..

q.,

3.!. ug,., N -t ; - - - 2 'k -"I l-- "t .r ..g.. _%. t r b N"t ~3 I N*ikz-W~-9 N8ximum

• ---f

~ 'i ' _.:g " l [ N 5. -- " -' t ;.. i -'.. N 2 i C4 I 1 I.i ) / - /{_ "G-E;}!Eti=-=iil:-Jr =J-9 N '-D5QiiW.E- :!P=li E!E" 4

-in.- rs i--

N i . =..{ =..in =:= n ;= a, n 4,en,3.x.w. :m t A.1x -R +sp.c... _ a

j:.,

l .-l # [.:/,.. - - ~1 u. _..p ,m wm-n m. r o }l/ I =~ OTSG Outlet ElSiM@Ni ib +!:

l-

E!f / / :.t uE e. - t --.

L _.. -- ..i. _.; EdF= EliiE%_fiM:i i 5 trii'- =hi i + ti-- ~ m. p, f : "' 1. :,. =...t._. _t.r. -._. _.... _.. ~:r r.. =... t. a n..

._... : ; = -. =..

r..n.-

. a.T'.'~::

I::.. M, c:

i i

:t E3l nf!:.

MIDI *N O r: = +l:u=r .. :l. : :

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-l n..

p;

. t.r. E4 or{=.

.:rnr

,t. - +. - r :: 550 gii3.gg 3. gg . yyia gg gj y .gg =g. igjg m:;.-; r- =. l.. --d:.- -- 1. : ..= ta z - ha +: ~~

r.

_a=n u, L :.afa .n. . " v. :. ---t=-- -u = t. .. v.-- JPiii Nilii . li - nidi!: "i17 5EI^:i: 'S

10 il L- :iEbih $

'it! F jfi-d= ~ "-l :i

i:i iibr

-ii" " 2:l!:..:i:lE" *-iJ' -!.!E SDl !!!!fi !.li! r" ij/f" 540 g 3;. _ _ ;.g;_ __7 j;;;c g};;

yi;,

gijg; g,3;

gs n

.}

m_. ; 3yp =g};j (/.ir i; !!iE-filN~.tER ;:finc *li"

.F el- =Ht i:!.:+

WHi! R!iH-1 4g. ;j j:=

ir i-i. -

l.: di .:.liif --M.! 4!!stidg H;)

[i :

4p'- H i '* Mi# 4 ~* IF W 530 4_.M M' #

p

.

iiii iui : !!li!. Di!E 5 NSS Power, MWt x 10-3 diL iib:i i.N $:L -$: i:il.. il 1=T ri-~1P"Frmne ,T"I!: n

• .... -Hl. iE

;IE-W h.-

.. i!

,+,m Ru 0

20 40 60 80 100 ldd U7i NSS Pouer, FI? B.2-27 Rev. 3 f.'

t ENCLOSUkE 7.6 !fb._, I i j Allowable Deviation In T-Ave For Power Up To 15% F !!1"" ":l"" : ' d"!H 'M"" M 1" 1" U"Mi ' !jj.:p::' L S; hlj i:lE f: Lli- .4: L!" ~ ~ ":. i n 'l- ..li:

.i :

ali: l-E..

t; r!.--

.t: . l. [ !.. .l --l-in;t.:

t 4;

q ' l< . in .i l. Ji : Lif cil-i j-: alb i? .. ].. .{. l -l-q 7 -l. ..l:-. .4 pl.: p- ..g. l- }

l..

Lil ei.; . 1. El ni r =-

{..4

..l : j.... c.g..ig . l.;. - lx.

{...

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Eli Ll!!

i 2i~- ?! ~5 l L t .i; =!!

.h.=i *::t:

K LI:i

+

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ini; 11.r i~iu. ;n}J:-

i.!.. jp}.~31 p:1 F:}j.l. jjit Rid!-- -4

l!

f 590 ="l.p.L" i:ii-3=-.Ei= - -i- ' 18 tii4=: +-iiiE5 E=ii.% 'E! i- :=!!E :!!it: !!!!? :+ji: =.1:i :

• J E. t.F..:;u,i. l..ty

1,.

i

ti-.. t. ! =.

zi..'l.i. - O Y..l.J.i.ir :t 4 {i.i I r;L: ".ii.M E_4ii.... Ei..:.._ ::.ii.4=_.:. E. ,l., _...t.. ,..t.. .t .t. o i t. I i. l f- ----}-- LE.T~~n f"E~. l-I"_

f*

~1 [

"f-

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+

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1. !!E ~EPs!s!!E EEElmyiE : s r4 M F= D M:: F MsiiE F

-Eil=" r 12 E s 5E ! yf, yin,. l~! i.:I[ri-I j f :- in i!IIR ff! bi - "l; f - iiii '15: [ 0 .. _..)rE!Eh/i "M I lisl .L+.'f5tiin!EE -El!!-

!!i?.'

,#: r-Till:I eel b r - 570 7 j;;jigjjgq;j, G c.;. qj;t. _in:.;i.i:;jgr_. 5 __;;;= 3g.1__;g ja 4 . g:, / _i:: /j:-, /- !. E. [...I.c.V.e.-........._....- TW. 15 ..._:- -,:{: E. "ji_aFije -i, k - c -. :e]ii;.. i. :,-l. : .--i.E. 7.g'. -. _i~...E._nfg l[.1.h..p.:-ii. : E.. j.i _ _i. -f ii- :h }ii.n :. i.:. E..: !:li. =: vi $g ' t e a_ fg; -41 V.-l; _ l.e j,/ li::;}l- . 3 4_.. ll[ jig l iEl%ip:. q- ~ ~ j 8-

n: _ !{

.,i r "- g 560 y

_gm; q ggg g,_ g _. g gg a

g 33- : i-- C " ~ I"5 illii j 4ii N i;y nifi'Ii" " EU3iir2}%: M -.'Elif MI:.!Eil!- lH-EP i!P I c:b r2 EE _ '! f ~-[ !M!M Mini::um phf; ti +ii 5!if ui-li: !!}i! Elf rf!-: W:: i!hir - # /f /i Ei? : ill!! ~~i1~ t piri = F : n!!lil G }} Expeeted 550 } g 4g gl:gg q. g.g g gg.s g q. .lg c ;/ : ran-

t..

ai-

, a:

en: A11cueble 4 _ .: n-gy /.. -. t.. ..}: - an: s

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r.

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l.l'-.q d::.

d- :: :;}n..

3 7 x pr pm eg;-

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r

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jji: i:;i. 5 530___U Cih lii" "4 "Ei lin l!! f.* 2ll" ti!! != T j 0 100 200 300 400 500 600 m. a NSS Power, MVt . :i.p.t . i. 4. m i:iE. - -..j : 5 ..a.. g;. .i. .. u j.: . j.: ... - 9,. p.r..,] r. *1," ;: t t..... ls...,.,.f - t!",, n. t !:::{:", :l n : :} :. g,, g }. j ,,9 ..g.

{,3).(..

l 0 5 10 1S 2'o NSS Power, %FP 18 100 B.2-29 Rev. 3 i l

Rev. 12 ATTACHMENT 6 B.4 PLANT SHUTDOWN AND C00LDOWN 1.0 PURPOSE .1 To outline the steps by which the nuclear steam system is shutdown from 15% power and cooled to the cold shutdown condition. .1 Plant Shutdown, Section 4.0 .2 Plant Cooldown, Section 5.0 .3 Natural Circulation Coeldown, Section 6.0

2.0 REFERENCES

.1 SMUD Rancho Seco Unit 1, FSAR, Section 15, Technical Specifications .2 SMUD Ranche Seco Unit 1, Plant Process Standards .3 SMUD Rancho Seco Unit 1, Water Chemistry Manual, AP-306 .4 SMUD Rancho Seco Unit 1, Plant Operations Manual 3.0 LIMITATIONS AND PRECAUTIONS .1 Maintain RCS Pressure, temperature, and cooldown rate within the limits of Process Standards Curve 101-2a. l6 .2 The pressurizer cooldown rate shall not exceed 100*F/hr. .3 Maximum allowable AT between the RCS cold leg temperature and pressurizer temperature is 410*F. .4 The secondary side of the OTSG's shall not be pressurized >200 psig if secondary side temperature is below 100*F. .5 The feedwater temperature to the OTSG shall be no more than 350*F below OTSG downcomer outlet temperature. .6 Do not open valves connecting the decay heat removal system to the reactor coolant system until reactor coolant pressure is less than or equal to the maximum pressure shown in process standards curves 100-3D thru 100-3K, and/or 100-4, and until RCS temperature is less than 290*F. B.4-1 Rev. 6 182it 101

3. 0 LIMITATIONS AND PRECAUTIONS (Continued)

.7 At all times during cooldown, the reactor shall be maintained at least 1% suberitical. If source range count rate increases 1 abnormally, discontinue cooldown until cause is identified and corrected. .8 Maintain makeup and purification system and decay heat removal system boron concentrations equal to or greater than tha boron concentration of the reactor coolant system such that the reactor coolant system is not diluted during cooldown. .9 Observe allowable RCS pressure-temperature curves for simultaneous 1 operation of RC pumps and Decay Heat System see OP A.2. .10 Continue seal injection and component cooling water to RCS pumps until RCS temperature is <l50*F. .11 Before RCS temperature decreases to 520*F, at least one RCS pump must be taken out of service. .12 Close core flood tank isolation valves when RCS pressure decreases to <700 but >600 psig. .13 All subcritical boron changes shall be verified every estimated 30 ppm change or hourly, whichever is more frequent. .14 Between 0 and 15% reactor power, maintain pressurizer level commensurate with, but not less than, process standards curve 100-16. .15 Maximum allowable AT between OTSG downcomer inlet temperature and RCS T cold is 25*F. .16 Maximum allowable RCS temperature change rate between 0 and 15% power is 150*F/hr. .17 Maximum allowable 6T between OTSG average shell temperature 1 and RCS temperature is 60*F (see OP A.6, Enclosure 8.6 for calculating OTSG Average Shell Temperature). .18 To prevent inadvertent actuation of the auxiliary feedwater system during cooldown, the automatic start controls for the pumps and valves should be placed in manual prior to cooldown. .19 The auxiliary feedwater system shall be used for filling an empty (< 8 inches level) OTSG when RCS temperature is >200*F. .20 If all RC pumps are lost during cooldown, continue RCS cool-down via natural circulation per Section 6.0. " '-2 Rev. 18252 102L

3.0 LIMITATIONS AND PRECAUTIONS (Continued) .21 The minimum natural circulation cooldown rate is 20*F/ hour. .22 The maximum allowable AT between RCS T and T is 100*F. g .23 When cooling the RCS with one OTSG in a dry condition, that OTSG's Average Shell Temperature must be within 100*F of the RCS temperature and maximum T to T across that OTSG is 10*F. hot cold .24 For loss of OTSG feed or decay heat. removal system see Emergency Procedure D.14 or D.16, respectively. .25 Control rod safety groups 1 and 2 shall be fully withdrawn when-ever positive reactivity is being added to the reactor by either xenon, boron, temperature, or motion of part length control rods. The following exceptions may be applied. .1 The reactor coolant,ystem has been borated to at least the hot, xenon free boron concentration and is being maintained at hot shutdown. .2 The reactor coolant system has been borated to the cold shutdown boron concentration and the plant is being cooled down. 4.0 PLANT SHUTDOWN Initial Conditions .1 Unit is *15% power. s .2 Unit T is controlling at 582*F and Reactor Coolant Pressure ave is controlling at N2155 psig. .3 Two main feedwater pumps and on, condensate pump operating (Preferably one main feedwater pump in auto and the other in manual at minimum speed). .4 At least two circulating water pumps in operation. .5 An auxiliary boiler is hot and pressurized,per OP A.39, Section 4.0. ~ .6 RCS shutdown boron concentration has been determined for hot shutdown and/or cold shutdown per GP B.6 and calculations made per B.9 to insure > 1% shutdown margin during all l stages of plant shutdown and/orceooldown. 1829 103 .7 Pressurizer level control in " Auto" and controlling at 200 inches. l7 B.4-3 Rev. 7-

4.0 PLANT SHUTDOWN (Continued) .8 Plant loads transferred from unit auxiliary transformers

1. 1 and #2 to startup transformers, per OP A.58.

.9 If the RCS is to be cooled down, RCS degassification is in progress per OP A.15 and/or OP A.3. Procedure NOTE: Communicate with SMUD dispatcher prior to switching power supplies, large equipment such as RC pumps or anything that would effect power transmissions. .10 Place reactor steam generator, feedwater loops A and B and reactor demand in hand and decrease feedwater demand to zero. Establish OTSC blowdown per OP A.6. NOTE: This insures that OTSG is being controlled at minimum level. Verify letdown flow is reduced to block orifice flow only. .11 Place the EHC in " Operator Auto". .12 Set speed-load reference setter at 50 MW. .13 Set load rate setter to 5% per minute or less. .14 Depress EHC "Go" pushbutton. As load decreases, observe turbine by-pass valve maintains steam header pressure at set point (885 psig). s .15 At N10% turbine generator load take the :: reheaters out, of service in accordance with OP A.46. -- r. .16 When load decreases to N50 MW, trip the OCB's and remove main generator excitation per OP A.64, Section 6,1. Observe turbine bypass valves are controlling header pressure at 855 psig. CAUTION: Prior to accomplishing the next step, verify that OCB-220, OCB-230 and the Main Generator Field 9 Breaker (41) are OPEN. Failure to have all three (.3) open will result in a reactor trip when the turbine is tripped. CAUTION: The Turbine Trip pushbutton MUST be used in the next step. Use of the Generator Trip pushbutton will result in a REACTOR TRIP. .17 Trip the turbine and observe that AC bearing oil pump starts on decreasing oil pressure. Start the bearing 10^4 104 lift pump, iUdL i .18 Follow OP A.46, Section 6.0, for steps to completely place the unit on turning gear. B.4-4 Rev. 9

4.0 PLANT SHUTDOWN (Continued) .19 Gradually reduce reactor power to 8% while monitoring and plotting cooldown rate (maximum of 150*F per hour between 0 and 15% power). N,0,T,E : E Between 0 and 15% reactor power adjust pressurizer level setpoint to decrease pressurizer level to 90-115 inches. Maintain pressurizer level decrease commensurate with but not less than process standards curve 100-16. 4 .20 Between 8 and 5% reactor power, place the CRD panel in manual and gradually reduce power to <2%, by inserting the regulating group. NOTE: Makeup to the makeup tank, as re-quired to maintain makeup tank level between 60 and 80 inches. If going to cold shutdown add concentrated boric acid as calculated per B.9 for boration during cooldown. .21 The plant is now at hot standby: .1 Reactor is critical at <2% power. .2 RCSpressureisbeingcontrolledat%2155psig. .3 RCS T >525*F. l3 ave .4 Startup feedwater valves in auto. .5 Mainsteampressurebeingcontrolledat2885psigby the turbine bypass valves. .6 One (1) condensate pump r.nd 2 main feedwater pumps l3 in operation (one main feed pump in auto, and the other in manual at minimum speed). .22 To take the plant to hot shutdown c.amplete the following: .1 With the CRD panel in manual, insert the regulating groups to reduce reactor power to 10-8 amps, while monitoring and plotting RCS cooldown rate. .2 At 10-8 amps and steady record reactivity balance 1821 105 information as required below: B.4-5 Rev. 3

4.0 PLANT SHUTDOWN (Continued) .1 Rod Configuration .2 RCS Boron Concentration .3 RCS Pressure Temperature .4 Date/ Time. .3 Further reduce reactor power to %5 x 10-11 amps by inserting the regulating group. NOTE: Observe that source range instrumenta-tion is energized at approximately 5 x 10-10 amps. __ _ 4 At25x10-11 amps, verify source range instrumenta-5 tion is on scale and indicatig no greater than 5 x 10 CPS. CAUTION: If the source range itatrumentation does not indicate <5 x 105 CPS when the intermediate ra'nge is at 5 x 10-11 amps, the required one decade overlap 8 does not exist. Reactor power shall be maintained >5 x 10-11 amps until at least 1 source range channel is operable. .5 Fully insert the regulating groups. NOTE: If the plant is to be cooled down for refueling, group 8 may be inserted at this time, if reactivity addition due to inserting group 8 will not decrease shutdown margin to <1% shutdown. .6 Disable the Reactor Trip From Turbine - Main Feed Pumps as follows: .1 ' At HlRI place Reactor /FPT Trip CUTOUT Itey in CUTOUT. 10 .7 When ft has been confirmed that >l G hdtdown margin will exist, per B.6 calculations all safety groups may be inserted. NOTE: For cooldown safety groups 1 and 2 shall be withdrawn. P 06 B.4-6 Rev. 10

4.0 PLANT SilUTDOWN (Continued) NOTE: If desired, for cooldown, the RCS may be barated at this time to the cold shut down boron concentration. Since it is desirable to batch borate for cooldown, the pressurizer level may be increased to 290 inches during batch boration. See B.9 for baration during cooldown. .8 Open MCM-165 and MCM-166, feedwater loop A/B startup recir-culation valves to the condenser, to establish condensate recirculation flow. Throttle open FWS-129 and FWS-130 to provide continuous ninimum feedwater flow to each OTSG. .9 The plant is now at hot shutdown. .1 Reactor >1% shutdown. .2 RCS T >525"F. ave -- .3 RCS pressure being controlled at approximately 2155 psig. .4 Main steam pressure being controlled at approximately 885 psig with the turbine bypass valves in automatic. .5 OTSG's on low level control (30 inches). .6 One (1) condensate pump and two (2) main feedwater l _ pumps running (one main feed pump in auto and the other in manual). 5.0 PIAiT C00LDOWN Initial Conditions .1 Reactor is in a hot shutdown condition. .2 Safety Rod Groups 1 and 2 100% withdrawn. .3 RC Makeup aligned per OP A.15, for feed to makeup tank from demin. RC Storage Tank and from concentrated boric acid tank. .4 Boron concentration / addition requirements determined per B.6 and calculated per OPOP B.9 for cold shutdown or for refueling concen-tration. .5 RCS degassing completed per OP A.15 and/or OF A.3. 1829 107 B.4-7 Rev. 3'

5.0 PLANT C00LDOWN (Cemein.ued) Procedure .6 Stop 1 main feedwater pump in accordance with 0F A.50. Verify the remaining feedwater pump is in automatic and verify MCM-165 and MCM-166 are open with condensate flow to condenser. .7 Place the automatic start signals for the emergency feedwater system in manual (pumps and valves). .8 Close the letdown isolation valve SFV-22009. Monitor MU tank level and feed at the required boron concentration as necessary during cooldown to maintain the MU tank between 60 and 80 inches. NOTE: Verify the RCS boron concentration every estimated 30 ppm change. Sample the pressurizer water space for boron concentration and periodically increase spray flow as required to keep the pressurizer boron concentration within 18 ppmb of the RCS. .9 Establish a drain path f rom the OTSG's to the HP condenser la accordance with OP A.6, Section 6.0. Follow OP A.6 for steps to control OTSG levels during cooldown. .10 Establish one RC pump running in each loop (preferably B & D). NOTE: Sequence for stopping RCP's dur-ing cooldown is: C,A,B,6D. l .11 Initiate and control RCS cooldown with the turbine bypass valves. Monitor and plot RCS cooldown rate. Turn pressurizer heaters OFF and spray the pressurizer as required to stay within the pressure-temperature envelope of Enclosure 7.1. .12 Vent the pressurizer to the PRT in accordance with OP A.3. Follow OP A.3, Section 6.0 for pressurizer cooldown. Vent the MU tank as necessary. .13 When RC System pressure decreases to between 1950 psig and 2000 psig, terminate depressurization and cooldown. .14 Drive all safety rod groups to the full "In" position as per OP A.74. B.4-8 Rev. 2 18292 108

5.0 PLANT C00LDOWN (Continued) NOTE: If cooldown is for refueling and group 8 has not been inserted it may be fully inserted at this time (prior to insert-ing safety groups). Insertion of group 8 will add positive reactivity, there-fore, monitor neutron count rate closely and verify >l% shutdown margin. .15 Trip the reactor and continue to depressurize to 1750 psig, terminate depressurization. NOTE: Adjust turbine bypass valve setpoint as required to maintain RCS temperature steady. .16 Initiate Reactor protection system shutdown bypass and reset the high flux trip to <5% as per OP A.69, Section 5.2. .17 Withdraw safety rod groups 1 & 2 to the full out position. .18 Initiate safety features RC System low pressure bypass between 1750 psig and 1650 psig. CAUTION: TRIP is at 1600 psig. .19 Continue with depressurization ar.d cooldown. Monitor and plot temperature-pressure to stay with in limits in.1. NOTE: Establish letdown and purification for RC System as necessary. .20 When main steam pressure falls to approximately 500 psig, bypass the main steam line failure logic. Place the main feedwater control and block valves in manual and closed. Leave the startup feedwater valves in auto. .21 At approximately 500 psig main steam pressure, bypass the running main feedwater pump by opening MCM-154. With the main feedwater pump at minimum speed, place it in manual }g}{ }]9 and secure it in accordance with OP A.50. B.4-9 Rev. 2

5.0 PLANT C00LDOWN (Continued) .22 When the RCS temperature reaches 400*F initiate Section 6.0 of 0F A.47, to establish condensate and feedwater system chemistry for layup. NOTE: Layap chemistry is not required if shutdown is for short duration <48 hours and condenser vacuum is not to he broken. . 23' When the RCS pressure is below 400 psig verify the low range RCS pressure transmitter is in service. 14 __At 675-700 psig RC System pressure, close the core flood isolation valves (HV-26513 and 26514). Open AC supply switches at MCC-S2D2 and tag, in accordance with OP A.4 .25 When the RCS temperature decreases to approximately 350*F, adjust pressurizer level controller setpoint to 90-115 inches, per OP A.3, Section 6.0. .26 When main steam pressure has decreased to N200 psig verify that the auxiliary boiler has picked up the auxiliary steam load. .27 When RC System temperature is N310*k, stop the RC Pump in loop A and establish 1 or 2 RC Pumps running in loop 'B'. .28 Before the RCS pressure / temperature relationship falls below the minimum, per process standards curve 100-14; verify RCS boron concentration is > the cold shutdown boron concentration; and, that >1% shutdown margin exists; then, insert all safety groups and makeup at RCS boron concentration. NOTE: s Rack out and clearCRD breakers A & B. 3 Assistant Superintendent, Operations permission required prior to re-energizing CRD's. .29 When the RCS temperature decreases to 300*F, begin in-creasing the OTSG levels to 96-100% on the operating range in accordance with OP A.6, Section 6.0, or Section 4.3 if for wet layup. NOTE: Sample the RCS and verify chemistry is within specification prior to reach-182jf110 ing 200*F RCS temperature. 3.4-10 Rev. 3

5.0 PLANT C00LDOWN (Continued) .30 When RCS temperature approaches 300*F, place the NSRW system in service as per OP A.25 and the NSCW system in service as per OP A.24. .31 When RCS temperature / pressure is s 200*F/300 psig, rack out breakers for both Reactor Building Spray pumps and both SFA C valves SFV-29107 and SFV 29108. NOTE: Breakers may be racked in as required for scheduled Surveillance Testing. .32 Establish RCS pressure and tcmperature for simultaneous oper-ation of RC pumps and decay heat system, then, place the decay heat removal system in service per 0F A.8, Section 4.3. .33 Close HV-23801;open HV-23802 and SIM-068 to provide HPI spray to the pressurizar. Observe OP A.3, Section 6.0, for pressurizer 5 cooldowr.. .34 When the decay heat system is in service, rackout and tag the auxiliary feedwater system in accordance with OP A.51, Section 6.0. .35 Follow OP A.8, Section 4.3 for cooldown with the decay heat system. NOTE: Continued cooldown with simultaneous operation of RCP's and decay heat system is preferable as long as the RCS operating pressure curves are observed. (This will reduce RCS hot / cold leg temp. stratification.) .36 Follow OP A.3, Section 6.0 to control RCS pressure and press-urizer cooldown. .37 When the RCS temperature decreases to :230*F, the OTSG's should be at 96-100% on the operate range. Follow OP A.6, Section 6.0 to secure OTSG feed, maintain wet layup, and place a nitrogen blanket on the OTSG/ main steam lines. .38 When RCS temperature is s200*F, establish RCS overpressure pro-tection as follows: .1 Close and place clearance on HV-23801, SFV-23809, SFV-23811 5 and SFV-23812. .2 Caution tag the electromatic relief block valve, HV-21505 to remain open when RCS <200*F. .3 In NNI cabinet 3, place key lock for pressurizer electro-5 matic relief in the SHUTDOWN position. B.4-ll Rev. 3

5.0 PLANT C00LDOWN (Continued) .38 (Con:inued) .4 Place clearance on breakers for HPI pumps l'-238A and P-238B. l5 NOTE: HV-23801, SFV-23809, SFV-23811 and/or SFV 23812 may be opened as required for maintenance or Surveillance Testing if an in series valve in their respective HPI line is closed and placed under clearance or the RV head is removed. High pressure injection lines may be 5 lined up as required for the performance of SP 203.01A or B, SFAS Digital Chann21 1A or 1B Refueling Test, without in line valves tagged or the PV head being removed. .39 When OTSG feed is terminated close MCM-165 and MCM-166, and place the condensate and feedwater system in cleanup recirculation to the condenser, per OP A.47, Section 6.0. 40 When the RCS is less than 200*F, verify RCS boron concentration and chemistry. 41 If condenser vacuum is to be broken, shutdown the condensate and feedwater system per OP A.47, Section 6.0. NOTE: If condenser vacuum is to be broken for longer than 48 hours, place the feedwater heaters and reheaters in layup, per OP A.53, Section 6.0. .42 Uhen the RCS is cooled down to approximately 150*F, initiate fur-ther cooldown of the pressurizer in accordance with OP A.3, Section 6.0. .43 When the RCS temperature is 140* to 150*F, the pressurizer cool-down is completed, and a nitrogen blanket has been established in the pressurizer; the makeup system may be secured in accordance with OP A.15, Section 6.0. 44 When the decay heat cooler outlet temperature is <135'F and the MU pump stopped, the decay heat purification mode may be placed in service per OP A.8, Section 4.5. .45 At 140*F the cooldown is considered complete; however, it is recommended to further reduce coolant temperature for personnel comfort and safety if RC systems are to be opered. 1821! 112 B.4-12 Rev. 5

5.0 PLANT C00LDOWN (Continued) NOTE: If the RCS is to be opened for main-tenance or refueling, vent the RCS loop high points and the CRD's in accordance with OP A.1, in preparation for draining. 6.0 NATURAL CIRCULATION C00LDOWN .1 Reactor Coolant Pumps (RCP's) Tripped (Operator or Automatic l12 Function). Initial Conditions .1 Reactor tripped. .2 RCS being maintained 1,50*F subcooled by: .1 Pressurizer control, OR .2 HPI flow, OR .3 Control of RCP seal flow /RCS makeup or letdown flow. .3 Auxiliary Feedwater System (Aux FWS) in service. l12 Procedure .4 Verify Aux FWS auto start on loss of RCP's. If Aux FWS does not start, core cooling must be provided by HPI flow in accordance with Emergency Procedure D.2 Reactor / Turbine 12 trip and Aux. FUS is restored IAW Emergency Procedure D.14, loss of Steam Gen. Feed. .5 Verify both OTSG levels approaching 50% on the Operate Range recorders (%135" Startup Range). .6 Verify RCS temperature / pressure relation >50*F but <l50*F subcooled. Take manual control of feedwater. flow rate and/or RCS pressure control as required to maintain pressurizer level at 150 1 50 inches. CAUTION: If RCS AT approaches 100*F or subcooling is <50F, increase flow through the core by: 1) increasing Aux FWS flow, 2) raise OTSG 1evel to 95% (slowly) 3) increase steam flow (TBV's or ADV's) l12 Monitor RCS subcooled >50*F closely. Maintain pressurizer level 150 1 50" while raising OTSG 1evels. 182jl i13 B.4-13 Rev. 12 .--m-e ese - w=- -. - = e mumm==*- e e e

6.0 NATURAL CIRCULATION C00LDOWN (Continued) .7 Verify natural circulation by: rises about 35'F and stabilizes in 15 to 30 l12 .1 Thminutes (also incore TC's). .2 RCS AT increases and stabilizes in 15 to 30 minutes. .3 Tc remains steady or decreases slightly and is at 12 saturate temperature for secondary pressure. .8 With all RCP's stopped, if RCS pressure increases to >2300 psig OR indicated Th/Tc implies Technical Specif-12 ication pressure / temperature limits may be exceeded and natural circulation can not be confirmed: .1 Open the EMOV by placing in Shutdown position in NNI Cabinet #3. .2 When RCS Pressure decreases to within 100 psig greater than secondary pressure, close the EMOV by placing in Normal position in NNI Cabinet #3. .3 Continue this cycle until 1) the RCP can be started or 2) natural convection flow is established. Isolate the EMOV when it is no longer required. .9 Verify RCS cooldown rate is at least 20*F/ hour but less than 100*F/ hour. (Maximum cooldown rate with Tc 1 280*F is 50*F/ hour). .10 Adjust RCS cooldown rate using the TBV's (condenser vacuum) or the ADV's (no vacuum). NOTE: Maintaining the RCS between 50*F and 150*F subcooled will ensore RCS pressure / temperature limits are not exceeded until RCS pressure is reduced to 800 psig. Below 800 psig refer to Process Standards, Figure 101-2a. Below 1525 psig minimum desired sub-cooling is bl50*F to maintain the fuel under compression. .11 Monitor RCS AT by comparing Th (520-620*F) with T ~ c (50-650*F) until Th goes off scale low. With Th ff scale use the highest indicated incore thermocouple and compare with T to determine reactor AT. c 182i!114 B.4-14 Rev. 12

,\\.. 6.0 NATURAL CIRCULATION C00LDOWN (Continued) .12 Restart of RCP's (requires feed tc-at least one OTSG): .1 Uith RCS subcooling verified stable at >50*F, and natural circulation flow established, start 1 RCP LAW normal pump start procedures OP A.2, RCP system. Do not operata more than 1 RCP/ loop. .2 If natural circulation flow can not be verified and RCS pressure exceeds secondary pressure by 600 psig, or RCS > 1600 and not decreasing, run 1 RCP for 10 seconds (perferred RCP in operable OTSG loop). Allow RCS pressure / temperature to stabilize. 12 NOTE: When an RCP is started be prepared f or RCS pressure swing due to mixing of hot and less hot water. .3 Subsequent 10 seconds RCP runs may be repeated at 15 minute intervals until nctural circulation flow is established OR until each RCP has been run once. .4 If subcooling can be verified start original RCP (first 10 second run) and maintain forced circulation. .5 If subcooling can not be verified, maintain core cooling IAW Emerg. Pro. D.2 until subcooling of the RCS can be established. NOTE:

1) An RC Pump restart is allowed only if feedwater is available to at least one steam generator.

2) Standard precautions to be observed prior to pump restart.

.1 CCW hus been maintained or will be reinstated prior to starting the RC pumps. 12 .2 Seal inj ectio.. flow has been maintained to all RC pumps. .3 Seal return is maintained or is reinstated prior to starting pumps. }g} }}{ .4 Pressure j>250 psig.

3) Emergency operating limits for continued pump operation.

.1 Shaft runout (vibration) shall not exceed 30 mils. .2 Irame vibration as measured on the lower motor mounting flange shall not exceed 5 mils. B.4-14a Rev. 12

I .. k I 6.0 NATURAL CIRCULATION COOLDOWN (Continued) .2 .6 When RCS pressure / temperature and pressurizer level are stable, trip the RCP's in accordance with OP A.2. Verify T and/or incore T 's indicate a steady rise of h about 35 F, then stabiEize. T should remain steady or decrease slightly. .7 Verify RCS subcooling does net decrease below 50 F. Restart at least one RCP (preferably one/ loop) if at least this amount of subcooling is not maintained, or provide core cooling with HPI flow. .8 Refer to section 6.1.7 through 6.1.17 for continued l12 RCS cooldown. Cooldown shall be in accordance with Process Standards, Figure 101-2a. B.4-16 Rev. 12 )b .}}