ML18078A354
| ML18078A354 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 11/06/1978 |
| From: | Mittl R Public Service Enterprise Group |
| To: | Parr O Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 7811080102 | |
| Download: ML18078A354 (49) | |
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- Public Ser1ice Electric and Gas Company 80 Park Place Newark, N.J. 07101 Phone 201/430-7000 November 6, 1978 Director of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D. c.
20555 Attention:
Gentlemen:
Mr. Olan D. Parr, Chief Light Water Reactors Branch 3 Division of Project Management RESPONSE TO REQUESTS FOR ADDITIONAL INFORMATION NO. 2 UNIT
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SALEM NUCLEAR GENERATING STATION DOCKET NO.
50-311
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,7 Pursuant to our meeting of October 24 & 25, 1978 regarding electric power systems, Public Service Electric and Gas Company hereby submits.4 0 copies of our responses to your request for additional information.
The enclosed information pertains to the open items 040.1(1), 040.5, 040.8, 040.9, 040.13, 040.17 and 040.18.
Should you have any questions, please do not hesitate to con-tact us.
- w R. L. Mittl General Manager -
Licensing and Environment Engineering and Construction Department Enclosure The Energy People c2_
781.108 010 95-2001 ( 400M I g. 77
~:
ITEMS 040.l (1) AND 040.5 The following documents.are provided in support of PSE&G's position with regard to the above items:
I.
Mid-Atlantic Area Council (MAAC)
Reliability Criteria II.
Salem Nuclear Generating Units 1 and 2 Stability Analysis, containing swing curve plots for critical fault conditions which demonstrate that Salem No. 1 and No. 2 nuclear generating units have an ade-quate transient stability margin and conform to the MAAC Reliability Criteria.
III. Salem Generating Station Minimum Expected Steady-Slate Voltage Conditions, containing a set of AC power flow transciptions showing condi-tions on the PJM 500-kV system in the vicinity of Salem Nuclear Generating Station both before and after a contingency which produced the minimum expected steady state voltage at Salem, including an impedance diagram.
IV.
PSE&G Policy with Regard to Intentional Disconnection of Transmission and Inter-connection Facilities During System Disturbances V.
Reserve Definitions and Applications P78 126 63/67 i:'*
'I.
MA~C RELl~BILITV C!'!ITEe Pnncioles Th* bulk elrcmic supply SVsten shall be ola.,ned..ind construct*
wd.in sucn mann!f' tnat it c.Jn be ooent~ 50 t:ie mor-e probable con*
tinqenc:1es c:in be s.:suined W'I tn no los:s of load. Ll!SHlrObal>I* COl'trn*
91"Cres will be e:um1ned to de~1ne meir eHect on system perlor*
mance. Thee s:unoa~s apoly only to tiiose facilities wtiic.'1 affect ~
- liabiliry of tne M~A.C system.ind not to facilities.iHectil'9 the rulia-*
biliVof of suooly only.:o loc;il S°'f'rn!m loadi. Auromaric load relief snail be oroviced to min1m1z~ !tie prccao1lity of t:'le total s.'lutC:own of Jn atH wnicn.t::ecomes 1sol.itl!'d by mu1t1ole cont1nc;el'c1es, tller-eoy fac:lli*
Ut1t1CJ noid restorauon of t:ie interconnected systems.
Reliabilitv Sunda~s
- l.
lnsulled c;enentin9 uoacitv ret:uiremena: Sufficient me-;>
wan c;enentin9 ccac1rv s.'lall be installed to insure that in tach year for tne,1,1~~C S'(stem me probaoilicy of oa:ur*
rtncl! of load exc~ing ttle availacle c;enen.t1n9 cacacity shall not be gre.ater. *on me aYerage. than one day in ten.
yun. Among the facto!'l to be eons1c:ered in :he calculation of tl'le orooaoiliCV are t/'le characterin:c:.s of the loads. :he probaoilirv of error in lead forecan. the sc!ied1.1led main*
- tenance reQuiremen::s for ;enerating units. t."le fon:ed outage rates of ;eneraring units. limited ener;y eacacirv. t..,e eH~:s of connections to oi::er pools. 3nd network transfer capabil*
ities witl'lin the MA.AC syn.ems.
- n.
Transmis:;iori requirements:
7.-.~ ::ullc tran:nis:sion system shall t:e Ce"teloc~ so that it ~~ :ie operated ;n all load lev*
els to m~
t.~e following un!:Cn!!':lulett c:ontin;l!'!"lcies with*
Out inr.3Cili:y, c::i=cing or interr.Jption of load:
A.
The los:s of any single generating unit. transmission line, transformer. or bus in addition to normal sc:.'1e-duled ouuc;e:s of bulk electric S1Jpply system fac:ilities wit.~out exc:~ing t.~e acplieable emer;!nC"( rating of 1nv facilit'f. ).f'ter the outa~. t..,e syr.em. must be* ca-paole of r!3Cju~ent so C':at all" eQui;:iment (on the MA~C and *ne1;nooring systems) will be loaded wit.'1in normal rat1ni;:i..
B.
A~er oa:urrel'1':e of ~e outac;e and *cie r!llC:jus:ment of tne svr.:m s:ecified in( Al. the subsecl.lent outai;e of
_any remaining ;enentor or line without e:xc~ing trie short time emer-;ency rating of 3ny facility. Atter this ouuqe, me fVS':em mu.st be ca::iable of readjustment so itlat all remaining eQuipment will be *1oa~ee within ao-plic;iole emenienc:y ntini;s for tne prob.Joie dur.ition of Ule ouui;e.
C.
The le!S of any double c:in:1.1it. line or tne combination of fac:liitie"S resulting from 1 line ~*ult and a m.sc:k bru*
ker in llOdition to normal 2:.'1eduled generator ouuc;"
wirtlout exc~inq the snort time emeri;enC"/ rating of l~V facility, Aft!!' the outage. the svnem must !:le c:a.
paot1 of rudjust7nent so mat all ecu1oment will be loaal!"d within i:iclioole l!'merc;enC"f ratinc;:s for the pro-l:li!lle duration of the outac;e.
In ce::ermin1ng UH! bulk tranvn1ss1on ~uiremena. recoc;ni*
tion :nall be given to rne oc:urrence of similar c:ontingenc;es in neic;nooring synemi and their effl!!:t on tJie MA.l.C SV1-tem.
111.
General ~1.1i"mena: Sufficie 0nt m~avar c:acacitV with 1decuat1 c:ontrots Viall be inna1led in eisc:n svr.em to suo*
ply :!It ruc:1ve lo.id and los:s rec:u1remena 1n orc:er to main*
aun ac::eouc1e emer-;el'CV tran11n1ss1on v0Ua9e ;iro tiles au r-ing all !_he *OOv* cont:nc;enc1"-
lnmllrtion of ~ner2tion ~
tr:insmiS:sion facilities s..,.all be coordina-ted to insure Uln in each year for eJll:tl memoer 1'(1tem tt'l1 proca01lirv of oo::urr~ of'lc~ exceeding t.'11 av11l1bl1 C3C<<:1ty ~~
snall not be c;r-eiltef'. on m~ rvl!'f'*
1199. tl'lln one d.ay in ten vun. Available =.x:*tV ~urc:!"5 consist of the ~er.n:ing caoac1lity a11a1l.able 1ntem1I to the membeor ~
o1nd tne. cao.x:itV tTlat Coln b1 tran$Tl1nl!'d into U'l1 memoer*rvn*em. ISee ~etworw. tranl'fer c:.1010.tityl rv.
- v.
Vl.
VII.
e Stal:liliry ~ui~ents: The mt11litv of !tie svnem sl'lall e.
m11nained without los:s of lo~ during.and.atur the folio-ing rvoes of faula OCC1.1mnc; " th* mon c:r1t1c:.I loc.3t1on n 111 load l~ls..
A.
A tti~n~ '3ult witt& norm.al c:learinq time.
B.
Sinc;I" pna:se-to-<;rt1und fault* w1tn
- Jt'.Jck brnicer or other cause for delayed cleu1n~
- Test:s for ab1litV of MAAC system to withrwsnd abnormal distn.ib.ances: The MAAC grouo rect>qn1z~ aiar ot is *~oos iibl* to ant1c1pate or test for.ill !tie c:ont1ngenc1es tt:at c;in occur on tne e>~t and future MAA.C svnem. TM~ t~.
- itierefQre. serve onm.ar1ly u.a mean*s to measure the aodi!'f.
of tne system to witrinand I~ procaoie contin;e!"c:~.
some of ~ic.n may not be rudily aocare:-it. The-...e :er..l are preic:ribed not on me basis of.i hign le"lel of ;ircca:::1i1tV.
- but rather u.a Practical muns to st"Jdy the svs-::m for i-:s ability to witlinand dirn.i~anc:n beyond ~ose.,..,.,,c.., Q..,
re.11SOnably be exoecte-:l. Thi MAAC syst?m. therefore...... u be tested to detel'T:"line -:tie eHect of vanoui rvces of cent:n-gencies on system pe~ormanc:. Examples of less ::ircba::ile continc;encies to ::ie m.icied are:
A. Sudd!n loss of the entire c;eneratin; cacability of any station for any. reason.
B.
The outage of the man critical tranSTliUion line on any one of the interconne'.:t!d sys-:ems as me rl!Sl.llt of 1 three-phase fault immediately !0110.... ing (i.e., before readjunme!'lt) the tripging of a~ct.'ieo critical line en the same or on an adjacent syS':~.
C.
The sudden los,s of all lines of one voltac;e emana:ir:g from a substation.
- 0. The sudden los::s of all lines on a single rigM-of-way.
E.
- The sucden dropping of a lar;e loac or a maier le~
c:znter.
F. The oc:C"Urrence of a multi*phue fault wi:h delaved c:l"earing.
Relaying and o*ote<::ive devices: lnde::iencent C!'YiC:l!'S s."lall be installed to cne extent necessary to ;ircvide back:.::: fer tile primary prot!!':tive devic~ and c:m;::oriena so as to limit equipment damac;e. to: limit U'le s.'ioc:k to tne svr.em and to s;lei!O restoration of service.
Relaying instJlled shall not restrict the normal or !tie n~~
-s;ary realizable network transfer cacabilities of trie sym~m.
UnderlreQ1.1ency ~layi sl--~11.be instJlled to provide !dC:i*
tional insurance against* widi:soread syr.em cir..Jr.:al"c~
They shall not ~e used to satisty tl".e :ontinc;enc:es lis:!":l under the Installed generatlng c:.:1pac:itY r~uiremen-:s and ttie Transmission r~uirements -sect;cns.
Netwerk transfer C:loability: The amounts of power planned to be interchanged between areas w*t!'lin M~~C ind ~e t\\'wftn MA~C and neignooring pools shall be SIJCh that acoli*
c:aOle ratinc;s and stability, voltac;e and relay limitations are noiex~ed.
A.
Extended period tranl'fer:
T°l'e muimum amQ\\o:nt of c:.aoacitY planned to be ce!iver?C t~:m one area :o.in*
Othl!r for economy interc:nange in no=al dav*tG<ay ogerarions shall be limi1ee as foilcws:
- 1.
With 111 tnnsmis:s;on fac:llit1es in servoc:e and nor*
mal generator ma1ntenanc:r sc:!'l~ul&ng. all S°'f',_
iem componenu s.~all be w1:nin norm.al lc.icif"g
- 2.
limin.
'WitP\\ t:l'le outac;e ol any iingle ~ac:litV. rr-e Pre>
visioni of the* Tr3n~ia1on r!Qu1rtmenu ;,-\\)
s.ection snall aoclv.
- 8.
C.:icacity emer;ency transfer: The m3:x1mum Jl""l..,,.nf of c:.acac1rv planned to :ie tnnsflr~~ 'rom one aru :::i another for cao.c*tV sl'lor:ac;" S."1111 *::e t.motec: as ~01*
lows:
- 2.
- 1.
Wittl all trins...,,1s:sion fK1li1i" in 5o1rvice and "Or*
mat ~era-tor m1intenance :ir::hedul"* tr11 lo.-=!*
inCJS of all rynem c:ompcnena sl'lall be w1min ap.
pliable emer;:eric:v ratini;s.ind ~11iry lim10.utd no ncrs3i~ voltq drocs sl'ltU occur *.
Thi int~onn~ed syn!f'ns sn.ail cnen t>. lbl1 tc IC9orO 'tlie initial co_, twinq *~nine; from the
~dden IOU of ariy 0
0DC tnnSTHISIOn lin* "or gener.
l'Ul'ICJ unit."
Aftv tli* initi1I swing l:!f'iod. t!'ll lo.dint;3 of 111 1Y1tem c:omponl!na
- stlall be..,,min snort tim~
eme~l"CY rat1t>c;s Uld.ar:ugu.Q11 YOIU~ lim1a.
./
II.
SALEM.NUCLEAR GENERATING UNITs #1 AND #2 STABILITY ANALYSIS A review of existirig transient st~bility analysis done for the Salem #1 and #2 units as part of the Lower Delaware Valley (LDV)
Area Transmission Study dated February, 1970 indicates that the results are still valid.
The portion of that study which dealt with 1973 was in fact the service date for the Salem #2 unit at that time.
In reviewing the system representation si~ulating 1973, it was determined that the system conditions re~arkably resembled those presently projected for 1979.
In terms of system conditions, the following comparison.can be made of the representations:
PS
' Total Installed Generation-MW Installed Generation Outside PS Territory-MW System Peak Load-MW 1970 LDV Study
-1973 Conditions-8,952 2,738 7, 390 -
Present Projection
-1979 Conditions-9,502 2,770 7,190 Further, the 500-kV system configuration in New Jersey and neighboring Pennsylvania and -Delaware is identical in both representations (See Exhibit la and lb) while the underlying 230-kV and 138-kV systems have only minor variations.
It is therefore concluded that the stability analysis and results presented in the 1970 LDV report for-Salem #1 and #2 units are still valid.
The transient stability analysis was conducted for light load conditions because past studies indicated that such condi-tions represent a more pessimistic state for testing stability.
Detailed represen*tation of machine characteristics including exciters and governors was used.
Tests were conducted to determine whe-ther the system would re-main stable for critical three-phase faults cleared by primary protection and for critical single-line-to-giound faults cleared by backup protection as required by the MAAC-Reliability Standards.
Although the MAAC Reliability Standards do not require that system stability be maintained for a critical three-phase fault cleared by backup protection because such a combination of events is considered extremely unlikely, that contingency was also evalu~ted *
- The test results concluded that Salem #1 and #2 units at full output*would be stable for the most critical three-phase fault cleared by primary protection and single-phase-to-ground fault cleared by backup pr.otection.
Iri addition, Salem #1 and #2* uni ts would be stable for the most critical three-phase fault with two phases cleared by primary protection and the third phase cleared by backup protection.
Of the various types of faults considered, a three-phase fault cleared by primary relaying represents the least critical.
Exhibits 2 and 3 show swing-curve plots of both Salem units for the two most severe contingencies:
(a) a three-phase fault at Salem on the Keeney line with two phases cleared at Salem by primary protection in 3.3 cycles and the remaining phase cleared at Salem by backup protection in 8.25 cycles; and (b) a single-phase-to-ground fault at Salem on the Keeney line with clearing by backup protection at Salem in 12 cycles.
These cases indicate an adequate transient stability margin for the Salem units.
ALBURTIS 000 KY BRANCHBURG HARMONY IUD ~ION MONROE PEACH BOTTOM NEW FREEDOM llQO 1(11 ____
KEENEY SALEM llOHUfllO DEANS 500 llV REVISED LOWER DELAWARE VALLEY PROPOSED 197l roO-KV SYSTEM SHOWING ~001230- KV SUBSTATION BUS ARRANGEMENTS
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RllMllPO ALBURTIS 500 KV BRANCHBURG MONROE PEACH BOTTOM CONASTONE NEW FREEDOM 500 KV '----~
KEENEY SALEM ROSELAND DEANS cox's CORNER 230 KV 500 l<V LOWER DELAWARE VALLEY PROPOSED 1979 500-KV SYSTEM SHOWll<G 500/230- KV SUBST."ITION BUS ARRANGEMENTS 500 KV 230 KV Exhibit lb 10-10-7R r
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.Jo Reaatntng Phase Cleared at Salea at 8.25 Cycle*
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Peacb Bottoa 12 Brunner 13 Salea ll & #2 MuddJ Run Exhibit 2
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'"° Time-Seconds Single Phaee Fault at Salem on Keeney Line Delayed Clearing at Salem
..90 Mudd7 Run Exhibit 3 r :.
- e.
.IJ1 SALEM GENERATING STATION MINIMUM EXPECTED STEADY.-STATE VOLTAGE CONDITIONS Salem unit #2, scheduled for service in May, 1979, will be connected to the 500-kV transmission system as shown in Exhibit 4, including transmission line impedance data.
Of concern in this section is the minimum steady-state voltage condition at Salem for the most critical yet extremely unlikely combination scheduled and sudden outage situation.
Exhibit 5 is a power f.low transcrip-tion of an all in peak load condition simulating a PSE&G capacity emergency power import level.
Exhibit 6 is a condition which simulates the maintenance outage of Salem unit #1 along with the New Freedom-Deans 500-kV line.
In Exhibit 7, in addition to the previously described maintenance outages a sudden loss of the Salem-Keeney 500-kV line complicated with a stuck breaker.at Salem, causes Salem unit *2 to trip leaving the auxiliary load of 44 MW at Salem to be fed radiaLly from the New Freedom 230-kV bus.
The resulting voltage shows a total re-duction by 5.8% from the initial 103:6~ on the 500-kV at Salem.
I 1
THREE MILE PEACH BOTTOM CONASTONE
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KEENEY ROSELAND RAMAPO
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LOWER DELAWARE VALLEY PROPOSED 1979 500-KV SYSTEM SHOWllJG 500/230* KV SUBSTATION OUS ARRANGEMENTS 500 KV 230 KV Exhibit 4
MUDDY RUN Hllfl~dONY RED LION CON A STONE 500 KV PEACH BOTTOM
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500 KV BRANCHBURG MONROE ROSELllND cox's CORNER 230 KV i' 4-26(100) 230 KV NEW FREEDOM 411-~-'H-(l:OOCij
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LOWER DELAWARE VALLEY PROPOSED 1979 500-KV SYSTEM SHOWlliG 500/230- KV SUBSTATION BUS ARR,\\NGEMEtHS 500 KV 230 KV Exhibit 5
Ii RAMAPO ALOURTIS 500 KV THREE MILE ISLAllD BRANCHBURG HAR,WNY RE 0 LION PEACH BOTTOM CONASTONE cC!!_+/-_?:_)
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~. PSE&G POLICY WITH REGARD TO INTENTIONAL.DISCONNECTION OF TRANSMISSION AND INTERCONNECTION FACILITIES DURING SYSTEM DISTURBANCES As a general practice, PS E&G does not in tend to automatically trip its interconnection ties during a system emergency.
Automatic tripping devices are *inherently undesirable and should not be applied to protect against extremely severe contin-gencies because of:
- a.
The difficulties in selecting optimum tripping settings due to system complexities and. random nature of such disturbances.
- b.
Th.e potential of causing unnecessary system separation due to relay malfunction.
- c.
The preclusion of possible human intervention by system operators *to reduce *the impact of system disturbances.
Manual tripping of interconnections by system ~perators to relieve an overload situation is likewise undesirable unless clearly required to prevent the imminent destruction of a costly trans~
mission facility or to alleviate adverse impact on maintaining supply to a large service area.
The availability of transmission interconnection facilities generally enhances the ability of a power system to withstand severe disturbances and it is that improvement in system reliability that frequently provides the justification for reinforcement of the interconnected systems.
It goes without say1ng that a system's chance of surviving a disturbance is dependent upon maintaining the transmission system intact and would be substantially impaired by the intentional opening of a life sustaining link to the "outside world."
The Public Service Electric and Gas Company philosophy is that given the inability to relieve an overloaded interconnection or related internal transmission facility as by means of genera-tion shift, switching operations or phase angle regulator (PAR) adjustment, there still exists another action short of opening the overloaded facility, to wit, manual load shedding.
To that end, rather than relying on the intentional opening of an inter-connection facility* to alleviate overload~, it is the practice of Public Service Electric and Gas Company to provide its system operations personnel with detailed guidelines for executing a
- strat*gic plan fo~ manual load shedding giving due regard to the specific character~ of the overloaded.facilities and the associated risk of permanent, costly damage thereto.
.. e Those guidelines are as f~llows:
The PS Dispatcher shall manually shed load to alleviate overloaded facilities:
a)
Overhead Transmission - If line loading exceeds the current emergency rating, but is lower than 115% of such emergency rating, a period of 15 minutes may be used to verify readings and to adjust generation and PAR'S.
If the loading exceeds the emergency rating after 15 minutes, shed load immediately to reduce circuit loading to or below the emergency rating.
If line loading exceeds 115% of the emergency rating, a period of 5 minutes may be used to verify readings.
Then commence shedding load immediately to reduce circuit 16ading to or below the emergency rating.
b)
Cables and Tanked F.quipment - If loading ~xceeds the shortest time published rating (30 minute or 15 minute), a period of 5 minutes may be used to verify readings.
Then commence shedding load immediately to reduce circuit loading to or below the 24-hour rating.
I
... Jl.RESERVE DEFINITIONS AND APPLICATIONS No. OI - 4.8
Subject:
F..ESE~V!: DEFI~!TICNS.A_'\\D AP?L!CA TI CNS DEFINITIONS Gra~hical Re~resentation of Reserve
( t ::::;; 30 min.)
Operating Reserve (t~lO min.)
Pri::iary Reserve
-* e No. OI - 4.8 Sheet 1 of 6 April, 19i8 (10 min *...c:t :=30 min.)
Secondary Resei-..re (synchronized)
Spinning Re.serve Cnot synchronized)
Quick-Start Res~rve where t
~ time interval following ID request.
Ooerating Reserve is reserve capability (generating capability and/or equivalent. generating capability scheduled to operate in excess of the forecast hourly integrated PJM system load) whicn can be converted fully into energy within 30 mi~utes from the request of the Interconnection Dispatcher (ID).
Based on the time required to effect the reserve energy incremental contri-bution, Operating Reserve is subdivided into Primary Reserve and Secondary Reserve.
- . ~-
A.
Primarv Reserve is reserve capability which can be converted fully lnt.o energy within 10 minutes from the request of the ID.
Based on *the operating statu* of the facility providing the reserve capability, Primary Reserve is subdivided into Spinning Reserve and Quick-Start Reserve.
- 1.
Soinnin2 Reserv~ is reserve capability ~hich can be converted fully into energy *"'1 thin 10 minutes from the request of the ID and must be
- ;:irovided by equipment electrically synchronized to the system.
Included as Spinning Reserve are Cl) the inc~eas~ in the output energy level of
OI - t...8 Sheet 2 of 6 a synchronized ge~erator which can be attai~ed within 10 ~inutes, (2) t~e lo&d of a p\\l.':iped hydro unit currently synchronized in the pu~ping ~ode a~d ca~able of beir.g shut do~n within 10 minutes (provided that the ID had det=r~ined t~at the loss of the generating capability which the F'.J:7.ping ;.;ould pro'lide *,.,ould not seriously af!ect future P.I'o:i system reliability), and (3) the rnaxi~u."ll output e~ergy level that could be attai~~d within 10 minutes on a unit operating as a synchro:'lous co~denser (provided that (a) it has been deter~ined that the less of voltage control that would occur by reversing the synchr~nous condenser
~ould not seriously affect future PJM system reliability, and (b) the unit's synchronization is not required to be interrupted during transfer to the generating mode).
- 2.
Quick-Start Reserve is reserve capability which can be converted fully into energy within 10 minutes from the request of the ID and is t:r:>vided ~y equi?ment not electrically synchrnozed to the system.
Included as Quick-Start Reserve is the ~aximu."!l output energy level of a unit ~hich in the opinion of the systems operators can be attained
~i!hin 10 minutes from the ID's request to initiate the starting seq-..:c:'lce.
The units which generally qualify in.this cate£ory a:-e c-..:r:-e!".t ly shut-do*..m t"'.ln-of-r:. ver hydro, pu.-:'iped hydro, i:'ldus t.ri al co~bus:ion turbines, jet engine/expander turbines, c:o~bi~ed cycle, and d:!.e:sels.
!3.
Secor.d.:r1 Reserve is reserve capability "W"hich can be converted fully into e:.ergy within a 10 to 30 minute interval following the request of the !D.
~~ui?~ent providing Secondary Reserve need not be electrically s:-rnc!':.ronized :o the system.
- U:SE~VE OB~!:CTIV~S In the daily opera~ion of the PJM system, the objective is to operate generating capability and/or equivalent generating capability as required to carry the load reliably and economically by providing.reasonable protection asainst instantaneous load variations in excess of the hourly integrated value, lead forecasting error, and loss of system capability due to generation equip~ent f ai 1 ure or ::ial!'unction and by providing reasonable capability for frequency regulaticn and area protection.
The amount of reserve capability necessary to obtain this objective is established periodically by the Operating Co1TC1ittee.
'nle ~est recent reserve objectives are tabulated in Appendix A of this Operating Inst:-'Uc':ion.
Reser~e objecti~es are lower limit reliability objectives.
Spinning, quick-s:a:-t, a:!d secor.dary reserve have a priority:sequ.ence based on the level of reliabilit:1 which each provides.* Spi::1ning reserve, being the most reliable, can also q".Jalify for an* objective which requires quick-start or secondary reserve.
Like*,.,ise, quick-start reserve can also qualify for an objective vhich requires sec:~ndary reserve.
Sin.Ce.the system is to. be operated in the most economical
=a~~er ~hi!e satisfying each reserve objective, economics will dictate the
~x:ent :o *.rh1ch :nore reliabl~ reserve excesses can be applied to subordinAte
~~s~rve ca:egori~s.
. t.
OI - 4.8 Sheet. 3 of 6 R~sd:-ve obj~~tives can only be satisfied ~ith generation a~d/or eGuivalent
- ,*.
- -..
- -~t :'.*:>n *,;J-.ol :y or jointly o*.med. by P.D1 ::-:e:::-:ber syste-~s.
Short ter:it r:urchases f~:~ ~j~~c~nt syste~s do not qualify specifically as P~"X reserve but may permit t!-.~
a:t~:.:-.5.:-:g of rese::'ve on PJM o~-ncd equip=nent.
7~e ::;*::-~t:::g a:id pr'!.:::-.ary reserve objectives c.re calculated probabilistically.
r.~~: ~i:=~=-
c~e to :~eir sc~e~~at different treat~ent of the followir.g factors:.
&~~~=a:or ~~x. lc~d le~el, ti:e of cay, day of week, season of year, load forecast
- .;::ic*;rta:.:-.t.y,
- ro~abi li ty of c-qu ir;
- :-.ent f creed out.age, probability of equir;rnent re:::..rn, t*:*c,:..:;bili ty of ei;,uir:::-.-:nt failure to start, and the eX?osure time interval ov~r w~ich t~e interaction of these various factors is eval~ated.
The S?!~::iing reserve objective is ceter~ined at the discretion of the C~erat"!.~g Co=::iit:ee after careful review to insure appropriate'system reliability.
In ad.:l.:. tion, the C?erating Com:ni t"tee periodically reviews the assigr.r.ent of an acijust.:7:ent factor to the quick-start reserve to insure agair-.st prcbability of
- !ail~~e of eq~i~u.ent to start.
For eac~ daily scheduling period s~fficient capability ~st be sc~eduled to
~:i::'t t.!':.~ !:::-:cast !oad plus the operating reserve* object:ive in the mose e~. :-:c~~ :~.:! l
~~~ner. It ~~st be recognized that, due to the reliability priorities of resd=ve cb3ec::.*:es as descri:ed earlier in the section entitled "Reserve Objectives",
~e~:i~g t~e c~erati~g reserve objec-cive further implies the obligation to schedule sui:icie~L s~i~~ing, quick~start, and.secondary reserve capability to co~ply in t~at or=er with each objective.
ft"hen there is insufficient capability within the PJM sys-cem to meet the above stated scheduling obligation, all adjacent systems must be contacted in an attempt to establish an interchange schedule which will provide sufficien~
inter.'\\al capability to eliminate the deficiency.
In scheduling to ~eet the obligation, consideration must be given to trans-
~i ssion li::"Jitations restricting the use of operating reserves.
For importing areas, sufficient internal reserve mus"t be scheduled to provide for the loss of the area's largest generator, or most critical transmission facility in the i~~ort path.
Ex?or"ting areas must be checked to assure that all expected reserve
- i:hin the lead area can be delivered assuming the loss of the :nost c:-ritical t~a~smissicn facility in the export path.
I: i.s ~
res;ionsi~ility of the ID to monitor PJM system reserve.
To aid in
~*o~i tori:lg Teser-1es. t!'le ID is to take periodic Instantaneous Reserve Checks ( IR.C) rsee A::::::enci.x 3) *
.An !RC is a "snapshot,. of the actual reserve available on the syste:::i.a~ *_*given poin~: in.time
- ITEM 040.8 See attached document, Calculation of Initial Rate of Frequency Decline for a Hypothetical New Jersey Electrical Island.
P78 126 64 CALCULATION OF INITIAL RATE OF FREQUENCY DECLINE FOR A HYPOTHETICAL NEW JERSEY ELECTRICAL ISLAND The initial rate of frequency decline for a hypothetical electrical island consisting of. the entire combined New Jersey electric sys-tem was computed in 1974 for the then-projected 1977 system condi-tions. In order to obtain the.maximum* initial rate of frequency decline, the calculation was. performed for a total New Jersey 1 ight load level *of 5, 750 MW *w.ti 0ich corresponded to 4 5% of the then-forecast 1977 summer peak load.
It was further assumed that only Salem 1,. Salem 2 and Ojster Creek nuclear units and Hudson 1 and Hudson 2 fossil units or their equivalent amount of capacity were operating in New Jersey. Then an electrical island was formed through an unexpected combination of events which*
resulted in the severing of all transmission circuits linking the combined New Jersey electric system to the outside world at a time when those circuits were delivering approximately 1950 MW to New Jersey. The calculation, which is reproduced on the attached sheets, and slightly modified to be consistent w+/-th present unit capability figures, irtdicated a maximum initial rate of frequency decline of 3.4 HZ/second.
A review of syst~m c6nditions currently projected for the revised 1979 service date of Salem #2 nuclear generating unit indicates that the maximum initial 3.4 HZjsecond rate of frequency decline is*still valid.
It should be emphasized that the above result is based on rather pessimistic operating conditions.
If such a system separation were to actually occur, the initial rate of frequency decline would be substantially lower.
The initial rate of frequency decline in an electrical island is determined largely by two factors: (1) the imbalance of electrical load and mechanical power input to the island's turbine-generators and (2) the inertia or rotational.
energy stored in.the island's generating units.
Thus a given amount of pre-contingency generation distributed among a greater number of generating units will result in a higher inertia and a L
lowe~ rate of frequency decline.
Public Service Electric and Gas Company is a member of the
- Pennsylvania-Jersey-Maryl and Interconnection (PJM) power pool.
Its generating units along with those of the other PJM member companies are dispatched on an economic basis as if all.
belonged to a single company.
As a result, the nominal 1003 MW of non-nuclear New Jersey generation, assumed for the purpose of the attached calculation to be concentrated in two fully-loaded units at Hudson Generating Station, would in reality be spread among a number of partially-loaded generating units within the boundaries of New Jersey.
. 4'l Several other factors would come into play shortly after forma-tion of the island that would tend to reduce the rate of fre-quency decline in time by reducing the imbalance between total electrical load and total mechanical input power to the island's turbine-generators.
One such effect is the "load damping factor" which reflects the inherent tendency of electrical load to decline with declining frequency.
Another is the presence of underfrequency load shedding relays to automatically disconnect 10% of the system load at each of three underfrequency set points:
59.3 HZ, 58.9 HZ, 58.5 HZ.
Finally, the governors would respond to the declining frequency and call upon the area's spinning reserve by increasing the mechanical power input to the island's turbine-generators.
CALCULATION OF INITIAL RATE OF FREQUENCY DECLINE FOR A HYPOTHETICAL NEW,JERSEY ELECTRICAL ISLAND ASSUM PI' IONS:
- l. All-transmission lines linking New Jersey to outside world are suddenly disconnected
- 2.
At a New Jersey load level of 45% of the forecast 1977 summer peak load:
Total New Jersey Fo'recast 1977 Summer Peak Load = 12, 771 MW 12,771 MW x 45% = 5,750 MW,
- 3.
With only the following 5 generating units operating within the State of New Jersey out of a total of 132* units:*
Stored Kinetic Energy @
Net Rated Speed Unit
~
Output (MW)
(MJ)
Oyster Creek Nuclear 600 3385 Salem #1 Nuclear 1090 4615 Salem #2 Nuclear 1115 4615 Hudson #1 Fossil 383 1870 Hudson #2 Fossil 620 2792 Total 3808 MW 17277 MJ Note: * *'.MW = Megawatt
- '"i'J3*-*= Megajoule CALCULATION:
The formula relating the imbalance between area lqad and area generation and frequency decline is:
Ps -
Pe = M <X where Ps =
Pe*=
M =
0( =
total electrical power output (MW) of the generating units operating within the area prior to the the island forming total electrical power demand (MW) on the generators in operation = total area load.
total angular momentum (MJ -
second/electrical degree) of the turbine-generators operating within the area frequency decline (electrical degree) after island second2 forming Solving for the "frequency decline yields:
o:=
Ps -
Pe M
The formula relating M to the total stored kinetic energy (GH),
in megajoules, of the turbine -
generators operating within the area is as follows:
GH =
( M/2) ( 3 60 f) where here f = 60 Hz Solving for the total angular momentum, M, yields:
M
=
GH 180f MJ -
second electrical degree
.flZJ1'/. o~
.. a* -y
- . w
- Substit1.Sting the value GH = 17277 MJ, we obtain:
M
=
17277 MJ - second
= 1.6 MJ -
second (180)(60) electrical degree eiectr1cal degree Then, immediately following the separation of the combined New Jersey electrical system from the outside world, the initial rate of frequency decline is given by:
- Now, So,
<X
=
Ps -
Pe M
- electrical degree =
second2
-1214 electrical degree secona2 360 electrical degree = 1 Hz second 3808-5750 electrical degree =
1.6 second2 0( = -1214 Hz
=
-3.4 Hz/second Original
- .Revised 360. second 8/2 9/7 4 10/30/78
ITEM 040.9 The interconnections within the 125V and 28V DC systems which were discussed during the NRC electrical review for No. 2 Unit consist primarily of the backup supplies to various dis-tribution cabinets and higher voltage AC system switchgear control power (DC) buswork.
This equipment design is iden-tical to that provided on No. 1 Unit and had previously been found acceptable.
All of the equipment in question is enclosed within metal cabinets which minimize the exposure to events which might otherwise present a threat to exposed devices.
All of the DC circuits are provided with individ-ual Class lE circuit breakers to assure that failures are cleared and cannot be transferred to other circuits.
The 125V DC vital bus battery chargers are supplied with 230V, 3 phase, 60 Hz power from the 230V vital busses through a lE rated breaker with a 125 ampere rated OD-3 trip mechanism set at 125 ampere long time trip.
The charger is connected to the 125V DC vital bus at the 125V DC switchgear through a lE rated non-automatic 400 ampere breaker (mechanism does not operate on fault current).
This breaker acts as a full load rated manually operated disconnect switch.
Internal to the battery charger, the 230V AC ~upply is protected by a lE rated circuit breaker and the output is protected by a lE rated 250 ampere 2 pole circuit breaker equipped for tripping on either high current or high voltage.
The static electrical components within the charger are pro-tected from high voltage transients by surge suppressors, while the filter capacitors are fused to protect the filter in the event of the failure of an electrolytic capacitor.
The components of the chargers that are considered to effect isolation are the transformer, the rectifier bridge, the current limit control, and the high output voltage trip, the two IE circuit breakers in series in the AC input cir-cuit, and the series shunt operated DC output breaker.
The battery charger is considered to be an isolated device by virtue of the following:
- 1.
The AC input is protected by two lE rated circuit breakers n series.
- 2.
The internal power transformer acts as DC "filter" to attenuate the effect on the AC input of faults on the DC output circuit, due to the saturating effects on the core of the transformer by the DC circulator currents.
P78 126 65*
ITEM 040.9 (Continued)
- 3.
The 3 phase, full wave rectifier bridge is an isolation device for DC to AC transmission of faults.
It also is an isolation device for AC to DC transmission of faults.
- 4.
The current limiting circuitry of each charger (110% of full load rating or 220 amps) acts to isolate the AC input from DC faults.
- 5.
In the event of a current limit circuit failure, the DC output high voltage relay will be actuated (nominally set between 141 to 142V) and shunt trips the DC output breaker.
In the event of a short circuit on the DC bus coincident with a failure of the current limit circuit the high voltage relay would not operated.
However, the DC output breaker would trip on short circuit current.
In addition, the battery discharge current would be indicated and the low voltage would be alarmed in the control room.
A summation of the isolation capability of the charger is contained in illustrated cases 1 through 6, attached.
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ITEM 040.13 The review of the 28V DC system revealed two valves in the Safety Injection System (SJ67, SJ68) which receive control power from the same 28V battery (these valves receive mo-tive power from separate 230V vital AC busses).
At least one of these valv~s is required to be closed during a changeover to the cold leg post-accident recirculation phase of operation.
A specific failure within th~ 28V DC system would result in the inability to immediately initiate closure of the valves fom within the control room.
This system will be modified to provide an additional control switch (in the control room), for each valve which is in-dependent.of the 28V logic system.
This modification will include additional position indication which is also inde-pendent of the 28V DC system.
P78 126 63/67 Item 040.17 The design of the Salem Unit No. 2 diesel-generator protective trip circuitry is described in the response to NRC Question 8.8 which was reviewed and accepted on Unit No. 1.
This design was completed prior to the final issuance of Branch Technical Position EICSB-17 of Appendix 7A of the Standard Review Plan.
The Unit No. 1 review of the diesel-generator trip design included consideration of the items which are currently addressed in the Branch Technical Position; this design was ultimately considered to be acceptable after changes were made in the trip circuits to reflect the philosophy of the BTP.
The low lube oil trip is incorporated to avoid* damage to the diesel units as a result of operation without proper lube oil requirements.
The manufacturer of the diesel generator units has indicated that these units would operate for a period of 0-5 minutes without lube oil.
Any operation of these units in the above time frame without lube oil will cause extensive damage.
This time frame, 0-5 minutes, is insufficient for operator response to a loss of lube oil pressure condition.
The "breaker failure" trip is incorporated to insure that the diesel-generator is tripped if the normal protective devices fail to operate.
This is a backup trip to prevent damaging the diesel-generator which should not be subjected to the redundancy requirement in the BTP.
The concept of redundant breaker-failure circuits and coincidence logic requirements is incompatible with this type of design.
P78.L51 73
Item 040.18 The electric penetration assemblies were purchased on February 2, 1970.
With regard to IEEE-317-1972 conference, the electric pene-trations were considered Class B nuclear vessels and de-signed to conform to all applicable standards and codes in effect during the time of purchase including USASI, IEEE, ASME, NEPA, IPCEA, NEC.
The penetrations also conform to applicable contact design criteria, specifications and pro-cedures.
The penetrations meet ASME Boiler and Pressure Code Section II, III, III Appendix IX, VIII and IX.
The penetration has successfully passed all required prototype and production tests addressed in IEEE-317-1972 with the exception of overload.
Further requirements under IEEE-317-1972 are covered in site installation and field test procedures.
Due to our design and the above, we meet the intent of Regula-tory Guide 1.63, Rev. O, dated October, 1973.
Regulatory Guide 1.63, Rev. 1, dated May, 1977 endorses IEEE-317, 1976, and as such we conform to the extent stated herein.
Qualification will be addressed in question 7.30 and has been satisfactorily reviewed in an NRC Inspection and Enforcement Board Inspection, as covered by NRC report 50-311/78-15.
In addition, the raceway system within the containment is seismically designed.
This alleviates the concern for a detrimental fault at the penetration terminals during a seismic event.
Further, all non-vital and vital 4160V, 460V, 230V and 125V DC switchgear have been purchased to the same specifications; therefore these interrupting de-vices associated with non-vital penetrations circuits are identical to those associated with the vital penetration circuit.
Time-current coordination curves for typical electrical penetrations are attached, as requested in sub-section (4) of this item.
(1)
Each type of electrical circuit that penetrates the containment is identifiable from Public Service Drawing 233901-A-1419.
(2)
A separate primary and backup overcurrent protective.
device is associated with each type of circuit.
These protective devices are time-current coordiriated to allow the backup interrupting device to interrupt in the event that either the primary interrupting or protective device fails to actuate or open.
These protective devices protect the load, cable and pene-tration as shown in curves supplied in (4) below.
P78 147 54
In addition, the cable is in most cases, one size smaller than the penetration feedthrough cable.
This will allow the cabl& to fuse and open before the penetration thermal capability is exceeded.
We have taken credit for this where the thermal overloads have been jumped out on safety related motor operated valves.
(3)
Manufacturer's published curves serve as the basis for protective device current-time characteristics.
The cable fault versus time characteristics are based upon the temperature rise of the cable between its maximum continuous temperature rating and the melting point of copper.
This is conservative in that this current-temperature-time relationship assumes there is no heat transfer of any means.
(4)
See Figures 040.18-1 through 040.18-12.
These curves show the time-current characteristics of the cable, penetration applicable portion of the backup protective device characteristic and maximum fault current plotted together.
(5)
All 4 kV protective circuits are periodica1ly checked for settings and trip capability.
Within the Salem plant there are provisions for checking the settings for 600V air circuit breakers.
Maintenance procedures exist for inspection and test of 4. kV circuit breakers and 600V air circuit breakers.
ANSI and IEEE standards exist which require design and production tests to control the reliability and quality of these protective and interrupting devices.
The high degree of reliability and quality is compati-ble with our past experience in other facilities, that is, when these devices are called upon to operate, they do so successfully.
In addition, it is our practice to thoroughly check the integrity of the protective circuit, interrupting device and affected equipment after the occurrence of a fault to assure continued successful operation and/
or the need for repair or replacement.
P78 147 54
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