ML19269E398
| ML19269E398 | |
| Person / Time | |
|---|---|
| Site: | Crystal River  |
| Issue date: | 06/22/1979 |
| From: | Stewart W FLORIDA POWER CORP. |
| To: | Reid R Office of Nuclear Reactor Regulation |
| References | |
| 3--3-A-3, 3-0-3-A-3, NUDOCS 7906280120 | |
| Download: ML19269E398 (30) | |
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Florida Power C 0 R PO R A T sO N June 22, 1979 File:
3-0-3-a-3 Mr. Robert W. Reid Chief Operating Reactors Branch #4 Division of Operating Reactors U.S. Nuclear Regulatory Commission Washington, DC 20555
Subject:
Crystal River Unit 3 Docket No. 50-302 Operating License No. DPR-72
Dear Mr. Reid:
In our letter of May 1,1979, Florida Power Corporation committed to imple-ment several design changes at CR #3 prior to startup in order to satisfy items a. through e. on page 1-7 of the ONRR Status Report to the Commission of April 28, 1979.
On May 16, 1979, we submitted additional information, including drawings, describing these proposed modifications for CR #3.
Since that time we have met with the NRC review team assigned to CR #3 on May 20, 1979 and June 11, 1979 to discuss these design changes in more detail. As a result of these meetings it was necessary for Florida Power Corporation to make some revision to its proposed design changes.
Enclosed for your staff's review are copies of the design modification that have been revised to reflect the decisions reached at the above mentioned meetirgs.
Five (5) copies of the drawings referenced in the attached design descrip-tion were given to both Mr. Chris Nelson of your staff and to the NRC review team at the June 11, 1979 meeting.
If you require additional cop.es of these drawings, please contact us as soon as possible.
The enclosed design des otions specifically address Item (C) on page 1, Item (7) of Enclosure (1j. and Item (8) of Enclosure (1). contained in our letter of May 1, 1979 to Mr. Denton. The design changes described in Item 6 of Enclosure (1) and Item (C) on page 2 of our May 1,1979 letter were not changed as a result of our meetings with the review team and therefore are being implemented prior to startup as described in our sub-mittal of May 16, 1979.
2170 117 General Office 3201 inirty-fourin street soutn. P O Box 14042. St Petersburg. Florida 33733 813 - 866-5151 7906280120'
Mr. Robert W. Reid Page Two June 22, 1979 Also enclosed is additional information requested by the NRC review team discussing (1) the control rod drive breaker scheme, (2) the position indication available in the control room for the PORV valve, and (3) the design change providing readout of incore thermocouples in the control room.
As of this submittal, Florida Power Corporation has responded to all concerns raised by your staff or the NRC review team concerning the design changes proposed in our letter of May 1, 1979.
Should you or members of the review team have any additional questions concerning this submittal, please contact us as soon as possible in order that they can be resolved prior to our planned startup of CR #3.
Very truly yours, FLORIDA POWER CORPORA ION M
W. P. Stewart Manager, Nuclear Operations ECShewW01(D6)
Enclosures cc: Mr. J. P. O'Reilly U.S. Nuclear Regulatory Commission Office of Inspection and Enforcement Suite 3100 101 Marietta Street Atlanta, GA 30303 2170 118
STATE OF FLORIDA COUNTY OF PINELLAS W. P. Stewart states that he is the Manager, Nuclear Operations, of Florida Power Corporation; that he is authorized on the part of said company to sign and file with the Nuclear Regulatory Commission the information attached hereto; and that all such statements made and matters set forth therein are true and correct to the best of his knowledge, information and belief.
,d.n D (na>L/
Y W. P. Stewart Subscribed and sworn to before me, a Notary Public in and for the State and County above named, this 22nd day of June,1979.
add L
Notary Publid Notary Public, State of Florida at Large, My Commission Expires:
July 25, 1980 2\\10 \\\\9 (CRPNotary 1 D12)
k 4
ITEM (C) - MODIFICATIONS TO REACTOR TRIP ON LOSS OF FEEDWATER FLOli OR TURBINE TRIP B&W has amended their field change authorization package to include automatic pypasses for turbine trip below 20% load or for loss of both feedwater pumps below 10% load. The attached B&W amendment describes these changes.
Low-low steam generator level (18 inches) in both steam generators will also provide a trip signal to the reactor trip breakers via the ICS system (See Figure 10A).
The normal minimum operating level in the steam generators is 30 inches.
When the level drops to 24 inches a low level alarm annunciates indicating a problem.
If the low level is not corrected and it drops to 18 inches the low-low level signal will trip the reactor.
In addition to the trip functions described above, the FPC will implement a
design to open crossover valve FWV-28 upon receipt of a low flow signal f rom either main feedwater pump (see. attached partial elementary B-208-032 FW19 and FD-302-081).
This design modification will insure the availability of feedwater to both steam generators under loss of one main feedwater pump.
Florida Power Corporation has also prepared a design change to add low-low steam generator level signals to relays 86/AFWPT and 86/BFWPT (See attached Fig.7B).
The purpose of this addition was to permit the ICS system to reposition valves FWV 33, 34, 35 and 36 to divert the flow from the normal steam generation of emergency feedwater from low-low steam generator level.
This action is designed to reduce the thermal shock to the normal steam denerator feedwater nozzles.
2170 120 Simpson (ChkProc) D67
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DOCUMENT SU3MITTAL FORM Babcock &Wilcox Powar Generat cn Grcuo P o Box 1250. Lynchburg, Va. 245C5 Tele::ncne: (804)384 5111 5-16-79 Florida Power Corocration DATE rn P. O.
Gox 14042 Ban CONTRACT NO. 620-0007 FEC
't. Petersburo. FL CUST.
PR3-1000 33733 CUST. ORDER No 1
SHEET I oF
.'4r. D. A. Shook TYPE CoC Field Change
' I" 'Is - OuNcER sEP cover 5 ENctoseo O roR ccouENr5 s secsovAt.3v O ENCtoSEo O FoR I N Fo RM A TI ON CNt y OUNCER SEP cover HAS BEEN Reil SED A3 PER 'rouR PRE'.80b<
6 sh w CCMMEN TS OF D foR FINAL DI STRI BU T i oN FURTHER E X P t AN A T I CN RECUlRED S E E 9 EL O'.V CR A T r a D.'.'E'. T s 00CtvENT DESCRI P Tion
. ENCOR 9 4.v COMP GRP COC i.'.
CCC.No Do c NC.
No.
No.
ri tt E This Field Change Package has been revised to include an Automatic Bypass.of Turbine Trip below 20" and Automatic Eypass of FWP Trip below 10'; pcwer.
This is the same
'fesign as ANO-1 which has been aporoved by NRC.
'.W 04-1110-01 21 01 Peactor Trip on Loss of FMPS Turbine Trip J. T. Janis c:
G.
P. Beatty w/ attach.
Service Panacer W. P. Ellsberry (B&',1, RE) w/2 attach.
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By:
M. G. Chance P00R ORGIN:1 217o i21
P 3 5 - 210 4 4 5 ( ; - /,' )
e FIELD CHANGE AUTHCRIZATICN BA8CCCK & WILCCX
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Daci4 Cu:r0% a fj'jj/. 3,44[ 5/,r/7 7 620-0007 3 '4 - 3110-01 Florida Power Corp.
3 U P P t. l E a P.A.
NO.
PART NO..
OR.
TASX NO.
OROUP 10.
SEQ.No.
jMtdE*fr}0 05'N[sbEh FWP ?. Tt.rbine Trip 21 001 001 di DESC4tP(10N AND JUSTIF IC A TION OF CHANGE:
Implement reactor trip upon loss of both main feedwater pumps or upon turbine trip.
(FC 04-3110-01 supersedes 04-3110-00) e
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'O' R E A T,04 FOR CHANGE:
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React.or Trip on Loss of FWP & Turbine Trip SHEET
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OF 7 DESCRIPTION OF CHANGE:
u 1.0 Purpose Prod' uce a reacter trip in response to a trip of the main turbine or a trip of both main feedwater pumps.
2.0 Philosophy The philosophy is that the main feedwater pumps A and B trip signals may be ANDED to yield a signal indicating loss of both main feedwater pumps.
This signal may be ORed with the main turbine trip signal fanned out, and utilized to trip both CRD trip breakers.
This will result in a trip of the reactor control rods.
3.0 Theory of Ooeration 3.1 Existina TCS Hardware Relays 86TT, 86 AFWPT, and 86 BR[PT including the field contacts associated with them already reside in the ICS.
Note that the field contacts close to convey the respective trip., states.
3.2 Conveyina Main Feedwater Puma Trios The trip of both main feedwater pumps energizes relays 86 AFWPT ar.d 26 BFWPT.
Upon loss of both main feedwater pumps relays K3 & K4 de-energizes due to the opening of parallel contacts from 86 AFWPT and 86 BFWPT.
When relays K3 and K4 de-engerizes 2 output contacts cause a reactor trip by means of the CRD trip breakers.
3.3 Conveyina Main Turbine Trio A trip of the main turbine causes closure of the contact in series with relay 86TT.
Relay 86TT energizes.
Thi's opens a contact in series with relays K3 & K4 de-energizing relay :'3 & K4.
K3 & K4 propagates a reactor trip as described in paragraph 3.2 above.
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OF 9 DESCRIPTION OF CHANGE:
3.4 Turbine Trio Cycass In order to allow for power esca'llation to provide for starting the main turbine and to allow for normal shutdown of the main turbine, a bypass
~
arrangement is provided.
The bypass can be placed in effect only by automatic action when reactor power is equal to or less than 205.
When reactor power increases above 20% the bypass is automatically removed.
~
Assume reactor power is >205.
When power is decreased to 5205 relay 59/NP-3 closes a contact energizing relay K2.
Relay K2 closes contacts K2A and K28.
Contact K2A implements the turbine trip bypass.
Contact K2B annunciates on control room annunciator that the turbine trip is bypassed.
When reactor power is increased above 20% the turbine trip b.ypass is automatically removed.
3.5 Main Feedwater Pumo Bypass
~
In order to allow for normal startup of the main feedwater pumps and control rod drive testing during reactor shutdov.n a bypass arrangement is provided.
The bypass can be placed in ef fect only by automatic action when reactor power is equal to or'less than 105.
When reactor power increases above 10% the bypass is automatically removed.
Assume reactor power is >10",.
When power is decreased to sl0% relay 27/NP-4 closes a contact energi:ing relay Kl.
Relay K1 closes contacts KI A and Kl B.
Contact Kl A implements the main feedwater pump bypass.
Contact KlB annunciates on the control room annunciator that the main feedwater pump trip is bypassed.
When reactor power is increased above 10% the main feed-water pump trip bypass is automatically removed.
//. o Installation Instruction Turn off power to the ICS cabinets.
Install the two relay modules in ICS cabinet 2 rou 7 positions 3 and 4.
Install the signal monitor module in ICS cabinet 3 row 6 position 8 Utilizing a wire wrap tool and 22 AUG solid strand wire, connect the relays, signal monitor (do not connect signal wiring to Pin 1 until checkout pro-cedure is ccmpleted)and power per the attached two sketches.
Power
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RLVISED REQUIREMFHTS 8
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Reactor Trip on Lost of FWP & Turbine Trip SHEET 3
0F 4 DESCRIPTION OF CHANGE:
i connection to be the +24Vdc bus within the cabinet.
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'ReactorTriponLossofFWPor[urbineTrip SHEET 4
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DESCRIPTION OF C il A N G E :
CHECK 0UT PROCEDURE NOTE:
READ AND STUDY THIS PROCEDURE COMPLETELY BEFORE 1.0 Purpose The purpose of this procedure is to checkout the ICS trip logic once installation has been completed.
2.0 Initial Condition A.
The NSS is in shutdown B.
The control rod drive system is in a tripped state C.
The ICS is operational and the plant status is so that power to the ICS can be interrupted.
D.
SHUNT trip power is present in the control rod drive breaker cabinets.
3.0 Required Eouipment A.
A.C. voltmeter capable of heading 125 VAC B.
Hand Tools C.
Jumper Leads 0.
Variable Power Source to simulate Il0VDC signal.
4.0 Checkout Procedure (gae..New thecko4 PeoceCurt 4+'i1 4 first remove power from the ICS.In all steps where wiring is remov Remove the module containing relays 59/MP-3 a power to the ICS.
(location 3-6-8) do not install until directed.
A.
Remove Power - Disconnect field contact wiring For turbine trip input 1-6-1-15 and 16, main feedwater A trip input 1-8-1-13 and 14, and main feedwater B input 1-8-1-15 and 16.
nEvisEo atoui d Wsis suPetlER Revisions
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0F DE5cRlPTION OF CHANGE:
6 4.0 Cont'd B.
Power Up - Verify that the ICS trip logic is in an untripped state.
Measure for the presence of line voltage across both K3 & K4 tr")
contacts.
(If this voltage is not present check for the presence of shunt trip power at the CRD breakers.)
C.
Remove Power - Install jumpers across the terminals for turbine trip input.
(See A above).
D.
Power Up - Verify that the ICS trip logic is in a tripped state.
~ Measure for the absence of line voltage across both K3 & K4 trip contacts E.
Remove Power - Remove the jumoer installed in C above.
Install the jumper across terminals for feedwater pump A trip - Step A above.
F.
Check that a single feedwater pump trip does not produce a trip output.
Measure for the presence o line voltage across both K3 & K4 contacts.
G.
Remove Povier - Remove the jumper installed in step E.
Install the jumper across the terminals for feedwater pump B - step A above.
H.
Power Up - Repeat step F.
I.
Remove Power - Reinstall a jumper as in step E leave the jumper in-stalled in step G in place.
J.
Power Up - Check that with both main feedwater pumps tripped the ICS trip logic outputs a trip.
across both K3 and K4 trip contacts. Measure for the absence of line voltage K.
Remove Power - Remove all jumpers.,
L.
Power Up - Reset both CRD breakers.
M.
Check Trip Transmission - Use a test lead to momentarily short the main turbine trip input terminals - See A above.
Check the CRD breakers both should be tripped.
Reset the CRD breakers and momentarily short REVISED REQUIREMENIS q
SUPPLIER REVISIONS i
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( COM I t hU t T 10N SHEET)
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{ hbf UUCUMENI NE' Reactor Trip on loss of FWP or Turbine Trip snger 4
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DESCRIPil0M OF CHANGE:
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the main feedwater pump trip /RPS in shutdown bypass to co inout. terminal - See A above.
fl0TE: I t 'ma y ge,jnecessary to place the fif g
ete steps C 11.
This step prepares the equipment for the remaining steps.
1.
Remove Power - Insure jumpers used for contact trip inputs (refer to Step A) are removed.
I I
2.
Install the module containing 59/flP-3 & 27/NP-4 (location 3-6-8).
3.
Connect Il0VDC power source to "Iti-1" on module. in location 3-6-8.
e 4.
Set relay 59/NP-3 trip setpoint at 20% power.
S.
Set relay 27/flP-4 trip setpoint at 10% power.
6.
Adjust I l0VOC signal input to represent power 9,reater than 20",
O.
Power Up - Check that the ICS trip logic is untripped.
Presence of line voltage indication on voltmeter.
P.
Decrease Il0VCC signal input to <20" power.
Check that control rocm annunciator indicates turbine trip is bypassed.
Momentarily short turbine trip contact in Step A.
flote that no reactor trip is cenerated, Remove jumper.
Increase t Check that control room annunciator alarm clears.10VDC signal input to Q.
Decrease 10VDC signal input to <10% power.
Check that control room annunciator indicates main feedwater pump trip is bypassed.
short the main feedwater pumo trip contacts in Step A.
Momentarily flote tha t no reactor trip is generated.
Remove jumpers.
Increase i10VDC signal input to greater than 10" power.
Check that control room annunciator alarm clears.
R.
Remove power to ICS - Reinstall wiring for turbine and main feedwater pump trips t'ha t was removed in Step A.
Connect wiring to Pin 1 of module at location 3-6-8.
s.
This connletm fhn chr'ckou t nrcrmiore.
REVISE 0 R E Qis t 9 E 9E N 15 SUPPLIER REVISIONS (CONilNulil0M SHEER)
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P03 21048A-4(l2-76) FIELD CHANGE AUTHORIZATION-CONTINUATION ,g TE E REFERENCE DOCUMENT IlTLE REF 3OCUMENT NO. pefafu e TR;p o s Loss oF Fwf 02 Tu r b;oe Tx;p 3HEET 7 0F 9 DESCRIPTION OF CHANGE: j-(,-t-y q I-T-I-a q 1-g-g.;gg _L Clo5cd ad _L Clastd ad _L C La si<$ od run b;ue mpy (anpg 14 p y pa mp s I" V TRIf Taie g 3 2.
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(_) N O Ei:Al REFE4ENCE 00Cunimi IIILL ~~ -a AEF 3 0 (. u n t.,1 ha. I Rm +o R we 0" "'s " r P"f T"" b '" " T"if ~ SHEET I 0F OESCRIPTION OF CHANGE: F x r STING EQu o'f. A~~ a 21 H/L f
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PDS-280484-4(l2-76) FIELD CHANGE AUTHORIZATION-CONTINU$ TION }E TE f 1EFERENCE DOCUMENT IlTLE REF 30CUNCNT M0. $idche Tx;p ox La.ss of FWP on M b;"e E)o SHEET 7 0F 7 DESCRIPil0N OF CHANGE: t a4 vb c gg 1 3 r,- 2 ,11 Q _3 7 9 () 2 '7-7 9 2 7 4Q 36 dG 1 _a 7 1 59 _4 3 u y-y up-3 -t-A F WPT EFwPr kIh .27 O soc O /2 .'taQ ,, 7, t ye _L TT ky -73b 13 /O 19() 1O O 19 . TRIPS L CRD y y yI 3-2-4 K 1) 3-1-4 k 3 3-2-5 K 4) 3.2 -5 4** ~ 21 9 J P 2 20 Ksa -p-C0 H R QI To PL os +s-l A rterv os e ; nio e gg_ P00RORGNIL 2 + y MFW Pu es t' Yl0 TRi3 By fps Sid ~ t b O r OG KaB - 7 .15Q O7 af L "Tu R D lrt a-TRlp k26 gy f,g,S,,g n Il % - MC 07 m O REVISE 0 REQUIREMENTS SUPPLIER REVISIONS TASK IASK T I T L E. (CONTINUATION SHEET) NO. FREPARED BY D A TE REVIEWED BY DATE y CJ REVIEWED SY DATE MO. 2170 131 3//o -o l 0,. APPROVED BY DATE ssfEi /0 3F
~.u [] notwat REFERENCE 00CUHimi ilILE REF 00CbHEMI 80. & [- A ( 7~Q R TAlh CA/ A OA A O ~7'A/d d, 7f( / /C $HEET / OF 3 DESCRIPTION OF CHAMGE: Installation Instructions 1. Remove all power from the AC breaker cabinet before starting. ~ 2. Locate TB1 on the source interruption device of AC breaker cabinet A and 3. 3. Add a new cable between the source interruption device A of AC treaker cabinet A and the ICS. 4. Add a new cable between the source interruption device 8 of AC breaker cabinet B and the ICS. 5. The termination of the cable on each source interruption device shall be as shown on sheets 2 and 3. 6. The termination of the cable on the ICS shall be as shown on the for Task 21 (ICS). 7. The cables should be two conductor; 14 ga AWG. N REylSED REQUIREMENTS SUPPLIER REVISIONS I IASE IASK IllLE (CONTINUAil0M SHEET) NO. PREPARED BY DATE REVIEWED BY DATE bot" v3 C8S 5/cf79 REylEwED BY, DATE FCA MO. ) l ' I. ", j
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O /~ FLJ P CP 78/40 7 418 SHEET M of 3 DESCRIPTION UF CHANGE: - t RIP 13 R E t31<& n /9 I s f P00R OlGIEL c ADD NEW CABLE i .l T G 1 4 7 EX 1 STING CUST EXISTING CA8LE 31 CABLE -Of g o- - SOU RC E l INTE R RUP T 10N DEVICE 1 REVISED *E0UIREMENTS SUPPLIER REvls10NS l TA5a TASK TITLE (COMilNeafl0N SHEET) MO. PREPIRED SY. DATE REYlEWED BY DATE 40 CRDCS REVIEWED BY DATE ou-31}o-01 APPROVED BY DATE l3 /1 0F \\ SHEET
N ~ REFEREhCE 00CUMEar TITLE l AEF DOCUNEsi =0. A /4 C 7*g/L ~7~/t / P O A) l 01 : Of S L4) f Ok TvAd. '7"et / B SHEET 3 0F 3 OESchiPTION OF CHANGE: 7d /F Od d-Al( E4 O e.. PLOR D'TtG>WI LL ADD NEW CABLE .l T 0 A l 4 7 EX I STING CUST E X I S TING CABLE 31 ^ GASLE of c o_ _ _ _ source l J NTE RRUP T ION j D E.V IC E I ^^ __ m REvlSED REQul4EME"T5
- SUPPLIER REvlSIONS
!] TA5r TA5r TITLE l ( CON T t Ne A T10M SHE[T) l NO. PREPA' RED SY DATE REVIEWED BY DATE g FCA MO. REviEwCD BY DATE .c On. 3//O-01 j]() 13k g ~ .-~.
FPC REACTOR TRIP CHECK 0UT PROCEDURE CHANGE AS INITIATED BY B&W B&W has recommended changes to the checkout procedure for the control grade reactor trip codification. A copy of the checkout procedure change is attached for your review. The purpose of this change was to aid and clarify the checkout requirements for the technicians performing this work. Low-low steam generator signal monitor SPlA-LS3 was relocated from location 5-2-3 to 5-2-10. 2170 135 Simpson (ChkProc) D67
CHECKOUT PROCEDURE NOTE: A " Trip" condition is indicated by the presence of approximately 125 VDC across the K3 and K4 contacts (location 1-4-4-7, 8 and 1-4-4-9, 10) and control room annunciator indication. An "Untripped" or " Reset" condition is indicated by the absence of the 125 VDC and control room annunciation. A. Disconnect the field contact wiring for turbine trip input 1-6-1-15 and 16, Main Feedwater A trip input 1-8-1-13 and 14, and Main Feedwater B input 1-8-1-15 and 16. / Initial Date
- B.
Disconnect the + 10 VDC signal wire from terminal 1 of SP1A-LS3 (location 5-2-10) and SPIB-LS3 (location 5-2-8). Remove the signal monitor in location 3-6-8 and do not install until directed. / Initial Date C. Install the input test box as shown in Attachment 1. / Initial Date D. Place all input test switches in the open position and verify an untripped condition. / Initial Date E. Place the turbine trip test switch to the short position and verify a tripped condition. Return switch to the open position and verify a reset condition. / Initial Date F. Place the Feedwater Pump A test switch to the short position and verify that no trip condition exists. Place the test switch in the open position. / Initial Date G. Place the Feedwater Pump A test switch in the short position and verify a tripped condition. Place Feedwater Pump A and B test switches in the open position and verify a reset condition. / Initial Date 2170 136 Simpson (ChkProc) D67
H. Reset both CRD breakers. / Initial Date I. Place the turbine trip test switch in the short position and check that both CRD breakers have tripped. Place the test switch to open. NOTE: It may be necessary to place the NI/RPS in shutdown bypass to complete Step J. / Initial Date J. This step prepares the equipment for the remaining steps: 1. Install the module containing 59/NP-3 and 27/NP-4 (location 3-6-8). / Initial Date 2. Connect a f; 10 VDC power source to the "IN-1" on module in location 3-6-8. / Initial Date 3. Set relay 59/NP-3 setpoint to 20% power. / Initial Date 4. Set relay 27/NP-4 setpoint to 10% power. / Initial Date 5. Adjust the f; 10 VDC signal to represent power greater than 20%. Verify an untripped condition. / Initial Date K. Decrease the j; 10 VDC signal input to < 20% power. Place the turbine trip test switch in the short position. Verify that no trip condition exists. Verify that the control room annunciator indicates turbine trip bypassed. / Initial Date L. Place the turbine trip test switch in the open position. Increase the + 10 VDC signal to greater than 20% power. Verify that the control room annunciator clears. / Initial Date 2170 137
M. Decrease the i 10 VDC signal input to < 10% power. Verify that the control room annunciator indicates main feedwater trip bypassed. Place the Main Feedwater Pump A and B test switches in the short position and check that no trip condition exists. / Initial Date N. Place the Main Feedwater Pump A & B test switches in the open position. Increase the i 10 VDC signal input to greater than 10% power. Check that the control room annunciator alarm clears. Remove the i 10 VDC power source from the "IN-1" on module 3-6-8. / Initial Date O. Test of Steam. Generator Low Level Trip: 1. Connect i 10 VDC power sources to the "IN-1" jacks on modules in locations 5-2-10 and 5-2-8. / Initial Date 2. Set relay 27/SP1A-3 and 27/SP18-3 trip setpoints at 18" steam generator levels (-8.56 VDC). Increase both i 10 VDC signals above the 18" setpoints. Verify no trip condition exists. / Initial Date 3. Adjust the i 10 VDC signal to module 5-2-10 below and above -8,56 VDC and observe that no trip condition exists. / Initial Date 4. Adjust the i 10 VDC signal to module 5-2-8 below and above -8.56 VDC and observe that no trip condition exists. / Initial Date 5. Adjust both i 10 VDC input signals slightly below -8.56 VDC. Check for a tripped condition. / Initial Date 6. Adjust both i 10 VDC input signals above -8.56 VDC and verify the trip circuitry resets. / Initial Date 7. Remove the i 10 VDC signals to modules 5-2-10 and 5-2-8. / Simpson (ChkProc) D67 2170 138
P. Connect wiring to Pin 1 on module 5-2-10 (from 5-2-2-4), Pin 1 on 5-2-8 (from 5-2-7-4) and Pin 1 on 3-6-8 (from 3-6-12). / Initial Date NOTE: Measure the voltage at Pin 1 of modules 5-2-10 and 5-2-8 and check r. at it agrees with indicators SPIA-L12 and SPIB-L12. The voltage should also be checked at different steam generator level to insure that the signal monitors are receiving the steam generator level signals. Q. Reinstall wiring for turbine and main feedwater pump trips on 1-6-1-15 & 16, 1-8-1-13 & 14, 1-8-1-15 & 16 leaving the test switches installed for future functional checks. / Initial Date R. This completes the Checkout Procedure.
- See MAR 79-05-71B Engineering Instructions for Installation, Section "D" (Testing) for additional tests to be performed during this step.
- Module containing SP1A-LS3 has been moved from location 5-2-3 to location 5-2-10.
2170 139 Simpson (ChkProc) D67
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e ITEM 7, ENCLOSURE 1 - AUTO START THE EHERGENCY FEEDWATER PUMPS AND FWP'S TRIP BYPASS Florida Power Corporation, Crystal River Unit #3, has p epared, and intends to implement prior to startup, automatic startup of the emergency feedwater pumps when required as described herein. Emergency feedwater required relays 2 EFPT-1, 2 EFPT-2 and 3 EFP-1 consist of coincident loss of both main feedwater pumps sensed by loss of control oil pressure, or coincident low-low steam generator level detected by signal monitors in the ICS cabinets. The emergency feedwater ;equired reiays becomes deenergized on loss of any of the above two coincident conditions which causes a contact to close in the open circuit of steam admission valve ASV-5 to the turbine driven emergency feedwater pump. (See elementary B-208-008 Sheet AS-01 and B-208-026 Sheet EF-01) The motor driven emergency feedwater pump is automatically started upon closure of the emergency feedwater required relay, inlet valve open contact, control switch not locked out conditon and the emergency diesel generator breaker open contact closed. (See elementary diagram B-208-026 Sheet EF-01) Florida Power Corporation has amended the design for the emergancy feedwater pump automatic start matrix to include u ?.2y lock bypass feature. The bypass circuit is designed to bypass the coincident main feedwater pump trip. This bypass does not include the coincident low-low steam generator level signal which remains in service at al: times. An alarm on the main control board is also provided to remind the operator that the emergency feedwater automatic start matrix is bypassed. Administratively through procedures, the operator will place the bypass into service just prior to removing the second main feedwater pump from se rvice. A partial drawing of Elementary Diagram B-208-026 Sheet EF-01 is marked to show the location of the bypass in the emerg;ocy feedwater pump automatic start matrix. Florida Power Corporation will implement this modification prior to startup of Crystal River Unit #3. Simpson (ChkProc)D67 2170 1II t
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ITEM 8, ENCLOSURE 1 - EMERGENCY FEEDWATER SYSTEM ALARMS The emergency feedwater system alarm designs for FPC's CR-3 are based on the concept of informing the operator that a pump started when required or failed to start when required. There are four alarms designed to provide the operator with information concerning the emergency conditions turbine driven emergency feedwater pump. One alarm informs the operator that the turbine driven emergency feedwater pump has autocatically started. This alarm is actuated when emergency feedwater is required, the emergency feedwater pump pressure is normal and the selector switch is in the automatic (AUT0) position. The second alarm informs the operator that the turbine driven emergency feedwater pump has failed to start. This alarm consists of the same logic as the auto start alarm except that the turbine driven emergency feedwater pump pressure is low. The emergency feedwater required signal consists of two sets of conditions any one of which activiates the emergency feedwater required signal auxiliary relay. Basically these two sets of conditions consist of coincident loss of both main feedwater pumps sensed through loss of control oil pressure or coincident low-low level in both steam generators from signal monitors in the ICS cabinet. Another alarm informs the operator that the steam supply to the turbine driven emergency pump turbine is not ready. This alarm consists of main steam supply valve closures or the inlet valve (ASV-5) closure to the turbine driven feedwater pump. In addition a separate alarm from the turbine driven emergency feedwater pump trip valve limit switch, alerts the operator when this valve is not open (ASV 50). The motor driven feedwater pump has several alarms designed to provide the operator with information pertinent to the operating conditon of this pump in relation to emergency feedwater requirements. One alarm made up of control switch contacts and breekee contacts provides a pump auto start ala rm. Similarly a pump failed to start alarm consists of control switch contacts, emergency diesel generator breaker open contact and an emergency feedwater required contact. Another alarm informs the operator that the motor driven emergency feedwater pump control switch is in the pull to 1c k position. Additional alarms to provide pump status to the operator includes breaker out alarm, loss of control power and breaker trip. Elementary diagram B-208-008, Sh AS01 and flow diagram FD-302-082 are attached to shew the electrical contact arrangement for these alarms and the location of the turbine driven emergency feedwater pump discharge pressure switch (PS18) location. Elementary disgram B-208-026, Sheet EF-01 shows the circuitry which makes up the emergency feedwater required signal shown as relay 3 EFPT-1, emergency diesel generator breaker open 86/27 BTA and the control switch contacts. Simpson (ChkProc)D67
RESPONSE TO REQUEST FOR DESCRIPTION OF THE CONTROL R0D DRIVE BREAKER TRIP SCHEME The operation of the Control Rod Drive Breakers from both the Reactor Protection System and the reactor trip on loss of feedwater or turbine trip are described in this write-up and the attached reference drawings. The B&W Field Change Authorization sketches for trip breakers A and B (see attached) describe the incoming cables to the " Source Interruption Device". Details of these trip internals are shown on atta hed figures 10-29 and 11-56, taken from the Diamond Power instruction manuals. Essentially, the contacts from the ICS system parallel the existing functions of Relay Contacts K7, K6, and K1 matrix causing the shunt trip relay to become energized and trip the control rod drive breakers, which in turn trip the reactor. Figure 9-7 shows the reuitry which describes the tripping of the control rod drive breakers tL ugh the Under Voltage Devices (UVD). Since the control grade reactor crip from turbine trip or loss of feedwater is accom-plished by the shunt trip mechanism and the reactor protection system trip is accomplished through the undervoltage devices, these trips are performed independently. Therefore the safety related reactor protection trips are not affected. The new control grade trip testing requirements will be inserted into the present test procedures for the reactor protection system trips of the control rod drive breakers and included on the monthly schedule. 2170 144 EMGekcMa(D47)
KRC RESPONSE TO REQUEST FOR DESCRIPTION OF THE POSITION INDICATION FOR THE PORV VALVE (RCV-10) There are three (3) indicating lights (devices ADI, AD2, and AD3) on the ICS section of the control board which are energized by the positions of two selector switches located in the NNI cabinets. The green light (AD1) is lit when the "AUT0" "0 PEN" selector switch is in the "AUT0" position. The red light ( AD2) is lit when the "AUT0" "0 PEN" selector switch is in the "0 PEN" position. The amber light is lit when the " NORM" "LO" selector switch is in the "LO" position and the low pressure protection circuit is made. Attached control board ICS assembly drawing E-201-141 shows the locations of these lights and attached elementary wiring diagram B-208-047 shows the circuitry for energizing the indicator lights. Note that the elementary wiring diagram also shows a contact closure to alarm when power is supplied to the valve solenoid. 2i70 145 EMGekcMa(D47)
RESPONSE TO READOUT OF INCORE THERMOCOUPLES IN THE CONTROL ROOM The Florida Power Corporation, Crystal River Unit #3. package designated MAR 79-6-60 is designed to provide increased reliability in monitoring the in-core thermocouple elements. These thermocouple elements are now being hardwired to an Esterline Angus Model PD 2064 Key Programmable data system that is a dedicated device performing this function only. The system utilizes a solid-state integrated circuit microprocessor to monitor up to 62 distinct thermocouple inputs simultaneously. We have utilized 52 channels to monitor the chromel-alumel thermocouples. Each channel can be programmed to alarm on high temperature and this alarm contact is being used to drive our present annunciator / events recorder system. The operator then will become aware of a temperature excursion in the core via an annunciator window in the control room and he can then go to the data system panel and find out which point (s) are in alarm condition from the printout which will also have the exact time (to 1 second) that the temperature went high. He can also check the other input channels at this time and get a printout of the status of each thermocouple. The system automatically checks for open-circuit thermocouples and displays an overrange condition for any that 2re open. Thermocouples that are known to be bad can then be deleted from alarm check. This system is being located in the main control room in the meteor-ological monitoring panel, bottom section. The power to it is coming from a control circuit feed from an engineered safeguards panel. In addition the Bailey 855 has been programmed with a degrees sub-cooled program to indicate if reactor cooling water approaches the boiling point for any given pressure-temperature condition. The program first selects the highest narrow range temperature if either is in range (greater than 520 F, less than 620 F). If narrow range temperatures are not in range, it looks at the temperature as measured by the first ten incore detector string thermocouples and auctioneers them to obtain the highest or most conservative value. The highest temperature and lowest pressure reading are then compared to the standard fluid properties tables to see if the boiling point is about to be reached. 2i70 146}}