ML20054J618

Forwards Matl in Accordance W/Commitment to Provide NRC W/Results of Studies Performed to Demonstrate That Addl Undervoltage Protection Is Not Required on Class IE Buses When Powered from Unit Auxiliary Transformer

ML20054J618
Person / Time
Site:	Pilgrim
Issue date:	06/17/1982
From:	Morisi A BOSTON EDISON CO.
To:	Vassallo D Office of Nuclear Reactor Regulation
References
NUDOCS 8206290354
Download: ML20054J618 (90)

Text

BOSTON EDISON COMPANY Os= =as Orrices aOO moneto= meerav 90efow, MassacMue stre 0219 9 A. V. M O Rl59 MANAGER NUCLEAR OPERATIONS SUPPORT DEPARTMENT June 17, 1982 BECo. Ltr. #82 Mr. Domenic B. Vassallo, Chief Operating Reactors Branch #2 Division of Licensing Office of fluclear Reactor Regulation U.S. fluclear Regulatory Commission Washington, D. C.

20555 License fio. DPR-35

/

Docket tio. 50-293 Second Level Degraded Voltage Protection Study

Dear Sir:

The attached material is submitted in accordance with Boston Edison Company's (BECo) commitment to provide the f4RC with results of studies performed to dem-onstrate that additional undervoltage protection is not required on Class IE buses when powered from the unit auxiliary transfonner. This commitment request was reiterated in the Safety Evaluation Report accompanying the recently approved

" Degraded Voltage Tech. Specs." (Amendment 61 issued May 29,1982).

This submittal provides the bases for Boston Edison's belief that safety is best served concerni g the adequacy of station electric distribution system voltage by the steps we have taken and which are described below:

a) Safety related voltage relays that are in service monitoring the 4160 volt safety buses, alarm to signal an undervoltage condition.

This alarm indicates a voltage that is below nonnal, but above a voltage which is considered degraded.

It alerts the operator so that he may respond with appropriate actions, predefined by procedure, to restore the safety bus voltage level while the unit remains on-line.

l b) The installation of safety related voltage monitoring relays on the 4160 volt windings of the station start-up transformer (the preferred off-site supply) trip the start-up transformer breakers, when they are supplying the safety 4160 volt buses, at the onset of a degraded voltage co ndi tion.

During this condition the operator has no means to correct or control the voltage, therefore rapid automatic tripping is desirable (a short time delay is included for transients and motor starting).

E holS 1206290354 820617 DR ADOCK 05000

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BusTON EDISON COMPANY Mr. Domenic B. Vassallo, Chief June 15, 1982 Page 2 c) A modification, which was recently installed, will immediately trio the Unit Auxiliary transformer breakers (the nomal supply to the safety buses when the unit is on-line) for any reactor scram. After a scram, the supply to the safety-related buses will automatically

" fast transfer" to the start-up transformer (off-site power) which has complete first and second level under-voltage protection. This feature has been tested several times by scrams occurring since its installation, d)

The approved changes to PNPS Technical Specifications concerning degraded voltage situations and protection, and the related, em-placed procedure, guide the Operator in recognizing and correcting under voltage on the safety-related buses.

The study consists of five sections provided as Attachments A, B, C, D & E.

I.

Attachment A consists of the results of a voltage studv concerned with voltage at the Pilgrim's 345 kV switchyard under conditions of varying loss of generation, an explanatory text, and a transmission map.

II.

Attachment B consists of the results of a voltage study of the safety-relatid buses with the Pilgrim Unit on-line and feeding an arbitrarily adjusted grid system, an explanatory text, the machine's capability curve, and the voltage schedule memorandum which has been in effect for several years.

This schedule directs the operators on control of the voltage.

III.

Attachment C consists of the results of a voltage study of the safety-related buses with the Pilgrim Unit on-line, under normal conditions, and at various f1 VAR loads; and an explanatory text.

IV. Attachment D consists of a New York Power Pool study of Transmission System Low-Voltage conditions and recommended responses, and an explanatory text.

V.

Attachment E consists of a REMVEC (Rhode Island, Eastern Massachusetts, and Vermont Energy Control) Report of the System Disturbance of July 30, 1979, and explanatory text, and a copy of the PNPS voltage recording chart of the disturbance.

Should you require any additional infomation concerning this issue, please do nnt hesitate to contact us.

Very truly yours, OM Attachments

C, ATTACHMENT A TEXT The result of this study was submitted on October 26, 1981 and was originally conducted for Pilgrim Unit #2 consideration of added load (feeding Pilgrim #2). This study observed voltage at the 345KV switch-yard with selected, nearby large generating units both on-line and off-line. This study was New England wide, and removed, in turn, selected generation from the grid system, the greater impact being those large units close to Pilgrim such as Canal Units 1 and 2, and Brayton Point #3 located in Southeastern New England (560MW for Canal 1 and 2, and 640MW for Brayton #3) and which feed the 345KV grid directly; refer to attached transmission map. This study is conservative in the sense that pro-posed station load requirements are high -- 40-70MVA vs. the actual Pilgrim #1 load of 20-25 MVA. Also considered was summer peak con-ditions which would produce the most vulnerable voltage -- the 1981 projected summer peak was chosen as the test basis. At the time of the study the station service load of Pilgrim Unit #2 was not firm, thus the range of loading tested.

Again, conservatism is noted in the 70MVA loading and loss of Pilgrim, Canal 1 and 2, and Brayton Point 3 leading to a per unit voltage of 0.972 (335.3KV) existing at the Pilgrim 345KV switchyard -- it is obvious that with Pilgrim Unit #1 on-line (and with more realistic station service loads with the absence of Pilgrim #2) the voltage would be comfortably above this, still adequate, switchyard voltage.

The projections for the 1987 system were somewhat ambitious; more realistic assessments show a system essentially similar to that existing now.

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'.e ATTACHMENT B TEXT This submitted study is basically a stochastic analysis concen-trating on the PNPS unit, at various excitation levels, on-line feeding an arbitrarily voltage adjusted system (L e. selected or varied low levels of system grid voltage). The effect of a chosen low grid voltage and a chosen point of the generator excitation is then reflected (by use of the existing load flow program) on to the safety-related 4160 volt and 480 volt buses within the station. The following points should be emphasized:

1.

At full MW output, with the generator's automatic voltage reg-ulating (AVR) systems in operation and functioning to allow the machine to attain its maximum 350 MVAR lag capability, the safety-related 4KV buses will not deteriorate to the 90% voltage level until the transmission grid voltage is reduced to below 310KV.

2.

With redaced MW, such as 500MW and the machine regulating to its maximum MVAR capability of 480 MVAR, the safety-related 4KV buses will not deteriorate to the 90% voltage level until the transmission grid voltage is reduced to 305KV.

It is to be noted that during the near system collapse of July 30, 1979 (with Pilgrim off-line) the switchyard voltage at Pilgrim did not go below 321KV as recorded at REMVEC but may have had an instantaneous reading of 319KV as read by the Pilgrim control room digital voltmeter.

3.

The 90% voltage level on the safety-related buses could occur at higher grid voltage (v328KV)if the AVR is not in operation and manual misoperation allows the reactive output to drop to zero or to go into the lead. Operators have been instructed, over the years, to maintain a strict voltage schedule in regard to both the 345KV switchyard and the 4160/480 volt buses. See attached memorandum for 345KV schedule; during all times the lower voltage buses are maintained as follows:

4160 volt buses 3850 to 4400 volts 480 volt buses 445 to 506 volts Gross excursions of the machine's excitation into the lead direction would be prevented by the " loss-of-field" relay, type KLF-1.

The operation of both impedance and directional elements of this relay sounds an alarm to alert the Operator to low excitation (or high MVAR lead flow). Additional operation of the undervoltage element of the relay trips the machine. The undervoltage element is set at 90% of normal voltage or 21.6KV. Inherent time delay in the KLF-1

e

• e 2

(attachment B cont'd.)

relay trip is 15 cycles, to assure positive contact coordination under all possible operating conditions.

Because of the stochastic nature of the study only a discrete number of points could be analyzed -- artificially setting grid voltage and machine excitation. Of course, both the grid system and the machine control are dynamic systems subject to infinite variations. The study l

does not deal with the probability of such values or conditions occurring simultaneously, nor does it factor in dynamic swings associated with system transients or an imminent collapse.

In reviewing the.results of this study it must be remembered that the safety-related buses-degraded voltage alarms, set at 3850 volts, would operate and alert the Operator to take corrective action. If any SCRAM signal was to occur during such a low voltage period, the safety-related buses are automatically tripped from the unit-auxiliary transformer immediately and would be transferred to the on-site diesel-generators.

This feature was described in our letter of October 26, 1981, and was installed during the last refueling outage. As detailed in the above letter, this modification was installed for the reason that it is difficult to factor in all contingencies which may lead to a grid systen voltage degradation, especially at a major generating station, while on-line. As part of this modification the voltmeters in the Main Control Room which monitor the safety buses were calibrated and marked at appropriate action levels of voltage.

It is easier to predict values of safety-related bus voltage for the situation of the plant off-line (station load being supplied from the grid system through the start-up transformer, the preferred off-site source) than the dynamic situation of the plant on-line and supplying power. The setting of protection levels is more clear cut in the off-line mode, using relatively unsophisticated undervoltage relays which operate at discrete, predetermined voltage levels and do not factor in those complicated chain of events taking place in the grid system. The determination of whether the grid is undergoing a short term or long term degradation, whether the System Dispatcher is taking corrective steps, and whether disconnection from the stressed grid will cause a cascading outage and segmentation cannot be made by an analog pro-tective relay alone.

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PILGRIM #1 STATION SERVICE SUPPLIED FROM AUXILIARY TRANSFORMER STATION SERVICE BUS VOLTAGES AS A Fl!NCTION e

OF VARYING 345 KV GRID VOLTAGE AND GENERATOR OtTTPUT (STATION LOAD - 20.02 + J 9.53)

CRID GEN.

A5 A6 B1-86 B2 INST.

CEM.

OUTPUT KV KV KV KV VOLTS VOLTS VOLTS MW MVAR I

328 22.9 3.98 3.98 456 478 116 690 350 328 22.5 3.88 3.88 444 458 112 690 200 l

328 22.1 3.82 3.82 436 451 110 690 100 s

328 21.8 3.76 3.76 428 443 108 690 0

328 23.3 4.05 4.05 465 479 118 500 480

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328 22.9 3.98 3.98 456 478 116 500 350

• 328 21.4 3.69 3.69 419 434 105 690

-105 323 22.6 3.91 3.91 448 462 113 690 350 3

d 323 22.1 3.82 3.82 436 451 110 690 200 323 21.8 3.76 3.76 428 443 108 690 100 9

323 21.5 3.69 3.69 426 434 105 690 0

323 23.0 3.98 3.98 457 471 116 500 480 a

323 22.6 3.91 3.91 447 461 113 500 350 310 21.0 3.76 3.76 428 443 108 690 350 j

J-l GENERATOR REACTIVE CAPABILITY ALLOWABLE VOLTAGE RANCE OI NOMINAL MIN.

MAX.

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9 690 MW 350 MVAR LAG

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105 MVAR LEAD 4.16 kV 3.74 4.58 500 MW 480 MVAR LAG 480 V 432 528 120 MVAR LEAD Inst. Bus 108 132

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',pestSu Eoison COMPANY OFFICE MEMORANDUM n...mm FILE v.

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s, PI14 RIM STATION #650 345 kV vol.TAGE SCHEDULE The REMVEC Ad Hoc Voltage Comittee has completed Phase 1 of It otudy.

In its initial phasa, a very detailed representation of the REMVs high volt was put together and tested using various voltage schedules for light EC area loads.

These tests were conducted to determine an optimum voltage sch d l and heavy fcr each of the RD4VEC units to alleviate high voltage conditioeue loads, and to provide good voltage with minimum VAR flow at he ns at light avy loads.

Phase II involves the ireplementation and evaluation of thes Therefore, the attached voltage schedule will be in effect for Pil e voltage schedules.

ccarcencing April 1,1976 grim Station units under REMVEC control are being issued and will be in effectLi with Pilgrim's.

light load voltage schedules be accomplished as follows:We recomm coincident and a)

Cae-half of the desired voltage transition before the hou stated.

r b)

One-half after the stated hour.

C nal Station will be operating on a similar voltage schedul Unit is carrying its share of the MVAR, leading or lag icor:su e.

However, close sure that each g ng requirements.

In cddition, station operators at Pilgrim Station should b REMVEC:

e instructed to notify j

1)

If the unit has reached a VAR limit, i

2)

If and why you are unable to hold the assigned voltage sched l u e.

3)

If an automatic voltage regulator is removed from or retur to service. Do no_t, operate unit icading with voltage re ned gulator out of service.

4) the voltage schedule.If your unit has to go into the leading MVAR mode to v:rictions from the. voltage schedule. Unusual loading conditions may perator to request IB Se#5

6M CDF Arr4mam OFFICE MEMORANDUM

.[./ A sesoN c:MPANY FILE NI%UU

.a Go Ca And98nini FRoM._Mr...h..Q 8eR o ATc.N.ar.ch 11.

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mal' PHONr f

Also attached is a copy of the " Reactive Capability Curves" for Pilgrim Unit #1.

We have superimposed on these curves the following:

1) The steady-state stability limit - this reflects the most critical element, Line #342, out of service.

2) The KLF-1 or loss-of field relay.

3) The URAL (under reactive ampere limit) - this setting is based on transient stability limitations while operating in the leading mode.

4) The generator terminal voltage limits - assuming + 57. nominal 3

voltage with the 345 kV schedule in eff4c't';'# '"

5) The gross output capability of the unit - net'NEPEX audit capability (670 MWS) plus normal station load 25 MWS =

gross output capability (695 MWS).

By using the limiting boundaries, we have shaded in an area which we define as the units operating region. Hydrogen pressure wes assumed to be 60 Psig.

This is to be used solely as an aid to the cperation of Pilgrim Unit #1.

It is not intended to supersede any more salient restriction on the units operation which has not been considered in our review. We would appreciate being made cware of any more limiting restrictions, if one should exist.

LW

^

CWF/ a xc: Messrs. J. L. Barker R. C. O'Connell D. Hayward (REMVEC)

Station #650 File g'r C. E. File #341 Division File j

Mr. R. V. Atkins (Pilgrim Station) V CWF Check File

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6AR.T OF ArrAoirseer G PILCRIM 345 kV VOLTAGE SCHEDULE Effective: April 1, 1976 Eastern Standard Time Weekdays Saturday Sunday and Holidays Time (kV)

(kV)

(kV) 0700 - 2300 358 358 0000 - 0700 355 355 2300 - 2400 1600 - 2200 358 0000 - 1600

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2200 - 2400

.,.--- 355 Day Light Saving Time Weekday:

Saturdcy Sunday and Holid.ys Time (kV)

(kV)

(kV) 0700 - 2300 358 358 0000 - 0700 355 355 2300 - 2400 0000 - 2400

+

355 Unusual 160 ding conditions may prompt the REMVEC system operator to request variations frcm this schedule.

l Station operators should notify REMVEC:

l

1) If unit has reached a VAR limit 2)

If, and why, unable to hold assigned voltage schedule 3)

If an automatic voltage regulator is removed from or restored to j

service. Do not operate unit leading with voltage regulator out of service.

l 4)

If unit must go into leading MVAR mode to hold assigned voltage schedule 1

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4 ATTACHMENT C TEXT The result of a third study is submitted which shows safety-related bus voltages during normal operation and system conditions with varying excitation levels imposed on the machine. As shown, there is no problem of degraded voltage on the safety-related buses for any operating point within the machine's capability.

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s PILGRIM STATION f600 SAFETY-RELATED STATION SERVICE BUS VOLTAGES NORMAL STATION SERVICE RESULTS OF LOAD FLOW ANALYSIS Cenerator Voltage 24 kV 22.8 kV 22.8 kV 23.3 kV 25.2 kV Megawatts 690 MW 690 MW 690 MW 300 MW 690 MW

• Megavars

+131 MVAR

-105 MVAR

-240 MVAR

-130 MVAR

,478 MVAR Auxili::ry Transformer Tap 23.0/4.16 23.0/4.16 23.0/4.16 23.0/4.16 23.0/4.16 1

1 345 kV Bus Voltage 355 kV 355 kV 358 kV 358 kV 358 kV S;fety-Related 4.16 kV Bus Voltages A5 4.18 kV 4.03 kV 3.94 kV 4.05 kV 4.41 kV A6 4.18 kV 4.03 kV 3.94 kV 4.05 kV 4.41 kV S3fety-Related 4.80 V Bus Voltages d

Bus B1, B6 486.7 Volts 468.0 Volts 457.0 Volts 469.9 Volts 516.0 Volts Q

B2 493.9 Volts 475.7 Volts 464.6 Volts 477.6 Volts 522.7 Volts n

S fety-Related 120 V Instrumentation i

Bus Y1 121.2 Volts 116.5 volts 113.8 Volts 117.0 Volts 128.5 Volts

• + Lagging MVAR b

- Leading MVAR 1

Pilgrim Station Load - 22.46 MVA g

Station Service Power Factor (p.f.) =.87 q

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ATTACHMENT D TEXT As stated in our letter dated October 26, 1981, itisdifficuitto factor in all contingencies which may lead to a grid system degradation.

To our knowledge no system wide study has been performed by the New England Power Pool or its satellites dealing exclusively with the situa-tions leading to degraded voltage, the probability of such, extent, or effect on on-line generation.

Research of Power Pool experience with or study of extended low-voltage conditions has shown that this is a rarely experienced and little researched phenomenon. Power Pools such as New England (NEPEX) or its satellites (eg. REMVEC) concentrate their studies on Load Flow and Transient Stability studies, modeling of new plant expansions, and Planning studies using loss of load probability for important trans-mission lined and generating stations. However, some work has been done in this area. Attached is a New York Power Pool interim report on transmission system low voltage. The NYPP is located in Guilderland, New York, near Albany, and can be considered the ninth largest electric system in the world. The Pool controls 105 hydroelectric, 10 coal-fired, 21 oil fired, 173 diesel engine or gas combustion turbine, and 5 nuclear power generating stations.

Some items in this study to be noted are:

1.

The effect of removing major generation (such as Pilgrim) during this period of gr?.d system stress.

2.

The plans in place at a Pool for dealing with such a condition, and the System Dispatcher's " feel" for his system.

3.

The slowly declining voltage, down to 328KV, during the early periods of such an incident, allowing time for local and system wide corrective measures. This was borne out in records of the July 1979 disturbance in New England.

4.

The efficacy of load disconnection and voltage reduction (on the Distribution Level) measures controlled by the System Dispatcher--

in our system by Radio Tone Control.

5.

The potential for cascading outages and " islanding" below 323KV.

The New England Power Pool has similar low voltage operating procedures in effect. This study by the New York Power Pool has been submitted because it is a concise introduction to this problem and to the methods that a Pool has to deal with it.

pgy-

+,

me m:a= m= =

i

(

NYPP IV. TEPIM If%' CCAE D!IT PEP 6RP JUNE 1976 Pm5a.Md by 1

'&.e NYPP Int-Voltare Stut/ Gmun R. E. Anderscn, omd== 1 New Terk Pcwer Pool F. J. Delea Canao11 dated Ediscn Cc. of N.Y., Ir.c.

P. Ievins, Jr.

New Ycrk State nectric & Gas Cen.

R. H. Ivescm N+

New York P wer Pool D. J. laBlane tem New York Power Pool J. Vom Niagara Moha:4c ?cwer Concratien O

e e -

D G

4.,rAa.aseisvR 3 eess w rcAes 2yfJEPet p e PE K 4REPrEES Es.7WT-M ES) 3(Gues

• ~

FOF INTERIM IDW-VOL'"AE L"C.EDO*C_

5 027_TTIS

\\.

EcrIQ:

PA2 1

I.

DTDODUCTIOi.............

II.

EODMMENDATIONS.-...........

2 III.

02iDITIOS OF NERIM 3

IDW-VOLTAE LDETS 5

IV.

SEQUENT OF OFERATDiG SIEPS V.

PEEDUE FOR EVISIQi OF 5

IDW-VOLTAE 12MITS i.

5 VI.

IEscussIGi 14 VII.

EXHIBIIS APPEh".TX 28 A

SCOPE O

e i

a e

!.T : 2.TC'* 'Z/ *.T*_TATi ZC *EFO.:C

• b.

I1I?C'?.5 2:

he W Voltage Study Grcup (~T.33) was forted by 0"!AS in mspense to a request received frcm the C;eratirg Cc:2::ittee:

"To detezrdne the min *-

c;eratir4 vcitage or k., bef.v.

voltages for the NYFP buL: pcwer trans=ission g

system (230kV and hig.er), at which Icad alief M

measums, including Icad disecnnection, n:st be it:plemented to alieve the icw voltage conditicn."

As the Icw-Voltage Study G: cup (LYSG) gathend infer s.tien and ccrpiled data to determine a icw-voltage li=it for the NYFP trans=ission syster, it becam appamnt that them was no readily available answer

,to the assiped task. For study purpcses, the voltage criteda in the "NYFP Desip Standards for Long Range Planning and S:~.: dies of Shcrt Range Operating Limits" are applicable to voltage deviaticns at unng'.: lated 115 and 13BcV buses. Tn actual system cperatien, them am no NYF? low-voltage criteria for any voltage level, includir4 the 345kV systa=. %ere am low-voltage criteria papamd and used by each m:ter ccmpa./ in the operaticn of their syste=s; however, none specify the 345kV voltage level at which load should be discenrected. The n fcm,

the LVSG has developed this mport ecntaining Interi= Icw-Voltage Limits in order to provide operating guidance during the time mquired to cceplete the A:11 Icd-Yoltage Study.

he Interim low-Voltage Li=its in this mpcrt am based on histcMeal data and preser:t operating practices. ' Day are, as I;he i

title irdicates, interim limits, subject to revisien as mere irSco matice. beccnes available.

N 4e @ddd v-4 s,, wk J

= b A e6

s. ech q.um E O % L a k y. 4 L w q.

eh 3

)

4_..

II.

PECDftE:DATICN5 1.

She interi:s predistu:tance low-voltage li: nits a:w:

C M Declaration of Iow-Voltage I::ergency Ccndition.

j Take any additicr.a1 car.ictive action, shcr: of Ioad disconnecticn, which has not alnady teen imple:ented.

(See Secticn m)

~

32327 Icad Disecrrection - In the amounts and at the locations deered necessary.

(See Section 1)

Che sele,ctien of these limits [is dis. cussed in

~

Seckien'VI.,..

che aspectis_cp=panipsMve, indieated,that,,a: an e,sti=ated 327 xv at.tseten and 337kV at Bcwlira Point corzwetive acticn will have to be taken to allow these units to unintada rated output.

2.

These limits should be observed en the fbilewing 345k7 buses:

Niagara Rochester, Statien 80 Clay Edic New Scotlard Pleasant Valley North Millwood West Bamepo Sprain BroeWDL..Me Rainey Parragut I

l Goethals

3. she Lvsa sheuld prepa:= a proposal, to witch tw4s ar4 =a: pcmer l

could be a'1~ a+ed, to develop techniques for =4-"1stien of Icng,,,

Tine Power Syste:n Dyna =ics, including low voltage effects, w e. %e,% Q<.. ( >' u-uk k.

% a b

,, 4 %pa su t)(toms) t< p.~.

.i t 4t L

- % p. p g gt.h &. yde.

h

A.

(r.NDIT 23 CT O.~E:Z4 IC4 '.DLTAE I2C S It is assu:ed that actions hate been taken to ::adr.ta'n system voltage at nc=al le'vels prior to the icw-voltage c=-Zitiens disr.:ssed below:

1..

Ascertain if the icw-voltage cerdition is sclely a NYPF problem ar4 rot sycptccatic cf a prtblen in a neigter'ng pool; e.g., New Scotlard and Pleasant Valley vs IE; ?.ana;o, Farrag.:t and Geethals vs PJM; ard Niagara vs OH. Fafer to CP-3 2.

As the voltagg en any of the ateve specified buses deteriorates to 328kV. all voltage centrol steps avaable to s4W the prcbles area sbculd be identied ard a f

pricrity of iz:plementatien shculd be establ* =%i, aces. icing those actions that have alnady been taken. Re=aining cornetive acticn shculd he 1::plec:ented, as requi:vi, to maintain those bus voltages at a 2:dni:m:= of 328W.

It should be ncted that the system has never egerienced a meJcd centir.gency at predisturtance voltages below 32Bcv, so that the rate of dec3dne of the voltage fn:n this level fc11cv_'rg a r:ajcr ccntingency is not kncwn. Major incidents, such as the 1 css of a heavily Ioaded uschine, have zusulted in bulk pen.r system vcitage deviatiens of 10kV to 20kV. Eowever, these deviatiens wen all fn:o predistu:tance voltages hig-li ' than 345ky. Man eming at voltages of 328kV cr telew, the occu=wnce of a major incident cculd require that 1:: mediate lead direcn:wetien be 1::ple::ented. Icad shedd'r.g capab47'cy (up to SCO is

• provided for in item 4 of the Pequi:enents secticn cf OP 1-2.

It should also be noted that if the system wen in a lead voltage ::36actice a:-d a major incident cer. wd, icw rastecer Iced voltage oculd be egerienced, :ssulting in unintentic=al inte=.:;cien of

^b

a custccer 1 Cad.

3 If the voltage cn ene or ::ca of these buses falls belew 323k7, Icad disecrrecticn shculd be 12pleme. ed in the amounts a.d at the locatiens deemed races,sa./ to maintain a n:ini:2:s cf M censistent with cra or cca of the folicwing conditicns:

A.

h Icw-voltage conditicn i= pairs the ability 1

l of the bulk power systa= to raintain the existing power transfers.

B.

Da voltage has decifred slcwly, all ether ccractive' action has already been taken and Icad disecrrection is the cnly recaining m.medy.

C.

Da voltage is declining so rapidly thzt, although other ccractive actions may be availabit, load disecrrecticn is the cnly viable means of relief.

4.

Ized disecrrecticn need not te unde if:

A.

Only a single bus er s=all area suffers voltage below the stated limit, and the low-voltage ccnditicri is not sy::ptccatic of a laz1pr prcble=.

thder this ccrxiiticn it is left to the eccpany affected to take cermetiva action it des::s necessary.

B.

Voltage (s) belcx the stated limit (s) is e.xpected to be relieved in a ahert time without load diseccnection.

i.

EE2 2 : 2 C? :. C :G S 3 *S Se Iow Voltage Study Orcup has reviewed all e.xisti.g !.???

Operating Policle's and nlated infc=atien to ascertain *.ich cf the proced.:::1rs nlate to syshm cperatien duri~..g low voltage cer.ditiens'.

A nstf.: of this :1rview has been to bring together, in a legica'-

sequence, the existing procedures and guidelines. S.is serc.ence is outidr.ed in Exhibit A.

Een this m pcrt has been ap; roved, a visions to existing Operating Policies will be req.lind. R.e changes in Operating Policies should provide for the fbilowing cperating flexibility to Mspond to a low voltage cmditicn:

1.

Voltage mduction at the distribution level in the amas that will help alleviate the pmblem c' low voltay cn the bulk power trans=ission systel.

2.

Load disecr:nection in the a:: cunts and at the locaticns dee::md necessan.

V.

PKkmm. FOR 1EVISION OF 'DE NYPP DTEKD4 IfW10LTAE LECIS She LVSG will cortinue to collect actual system data and seek additizial technical infomation relative to the dete=:ination cf LV limits. Een the LVSG determines that sufficient additional infcmatien is available for avisien of these li::its, it will subnit suggested mvisimis for appmval.

VI.

DISC E W A.

Detere:ina. tion of the Interim Lv Limits At the pasent time the long-ti:ne, ibil, dpH c ;!rocess of a voltage collapse in the actual system is not oc=pletely widerstcod primarily because we do not have ca::plete kn:wledge about low voltage effects cn system load or the full respense with time of pneratcrs to low voltage conditiens. C=.ser.:ently, existing analytical tools am net capable cf :nodeli.g the precess 7

-E-9 5,

of su:h a voltage cellapse. "his is discuzzed ir. Se::i=.

C belcw.

As an interim measure, a review as made of 22 incidents Wiich have occurad in NYF? since 1965 to identify insta.:es of low ' voltage and to myiew bulk power sys em perfer:ar.:e during these instances. Tnis effort was hagered by the scarcity of data for many of the incidents.

Eme days wre found W.ere sustained sesten voltages below 330kV we m experienced. t ese w m se,.te..ter 22, 1970 and June 11, and 12, 1973 (See attached Piz. 2,3 & 4 for New Scotland 345kV bus voltage nr.m about 1400 t: 2100 on Septeter 22,1970, Ra::apo 345kV bus voltage trcm abcut 1300 to 1700 on June 11, 1973, and Pamapo 345kV tus voltage nem about 1300 to 1700 en June 12, 1973). n e arailable data for these thme days indicate that the lowes: sustained 1

voltage that the system has experienced is between 318kV and 323ky. 'ntice, on Septeser 22, 1970, when the voltage went below this level it collapsed until lead alief reasums wem 1:aplemented; i.e., load shedding by cusumer dis-ocnnection for the first incident at 1548 heu:s and voltage zweduction fbr the seccmd incident at 1905 het:rs.

t Analysis of these incidents leads to the fo11owir4 observations:

1.

2e system voltage ray masonably te expected to operate down to apprcximately 323cv and l

still not experience a rapid rate cf decline due to slowly, increasing power transfers or inemases of load.

l l

[

_.7_

\\

~

2.

Dr. these occasi:ns '#.e. the system *.:1: age v

fell slowly to a level below 328kV, the

~

rates of decline in these voltages still offend masenable ti:1e for implem.v.atit:n of cornetive reastres, before reach".r4 323kV.

3 On those occasicns hten the system v:ltage fell below 323kV, the rate of declire was so rapid as to cause pctential cascading outages.and segnentation of the entim system.

4.

At system voltage below 323kV, load alier masums produced sigiificant improwants in system voltage as follows:

e ACTICN TAKE:N CN W ORNE CN VOLT /<E CFJJiE Sept. 22, 1970 M EFIRAIrEAST CN N N SCOII m*D DE TDES INDICA 2ED

+LINEEN GET-IAIS 345tV BUS Ioad Sheddir4 41548 HRS.

150 N

+ 1'IM7 Voltage Reducticn a 1905 + HRS.

200 W

+ 11kV -

4 a

O e

.c B.

Present P m :tices Che of the,scurces cf infe=aticn reviewed by the L*.'53 was the m:ter companies' pnsent c;erating practices 2f ative,

to the 34Ftl buses sele'eted for =cr.itoring. Table 1 and Figure 1 are a cccpenditml cf' the data stpplied by the certers as to operating ranges for the monitored buses.

'Ibe NYPP normal low limit voltage alarrs for the 34Ft1 buses selected for nenitoring, kith the exception of Ra:J;o which was net available, wem set to alam at 32Fil and lower.

Since January 1,1976, none of these has alamed.

C.

'Ihe Use of Icad Flow and Transient Stability to Si=.tlate Irw Voltare Events

'Ihe largest effort to ccr:putaticnally deten::".ne the effect of low voltage was a series of load now and transient stability nr.s conducted in the period June 1973 to Dece::ter 1974. or.e

~

pu: pose of these tests was to a.'utlyze transient spem perto.~ance Mith depassed syster: voltage. A second purpose was an atte:pt to establish a' method of date.6.g transfer lits as a Pr.ction of system voltaps.

'Ibe preldsdnary results of that wozt: are contained in a draft report which was distributed en Eccec:ber 14, 1974. ':his l

wpL was to be a supplement to the NYPP Transient Stab 41*ty Study Report of March 1974. Che of the significant ccr.clusiens of the LV5G in 2tviewing the study was that the testing was '

ine:riciusive since the system tested was stable f:r ocnstant i

lewis of pcwer transfer with both ncc:inal and depassed voltages.

'Ibe change in the stability lindt cf the system wa.s net dete=ined l

as voltage was lowezvd.

/0

,n

~

2e UEG mviewed the ability of present 1cai new a.d transient stability pztpa=s to cdel icw voltaEs phena ena

'Ihe INSG telieves that existing 1 cad flow aind trs.sient stability prog:'a::s are net adequate tcols to ana*yze icw

. voltage ccnditiens because they de net have the ability to nedel the time frame involved (up to minutes) in the process of a voltage collapse.

'Ihe following is a ccrqEndit=1 of the masons.dv the U43 ccnsidered the load flow and transient stability testing to be incenclusive:

A.

Icad Flew

1) Questiens re=ained reEarding the values of acceptable mismatch:

a) Per individual Bus b) for the entim case c) between m 1ated cases

2) Questions acained as to the reason for ncn-cenvergence of seural cases. At least three types of ncn-cenvergence t

have been observed:

i l

a) The system model was in a technically diverger.t state and the propas was depicting that cendition.

t b) System conditien was serious and the progra= was having mathenatical difficulties.

c) System condition was net serious but the pr 4 c l

was having matscatical difficulties.

3) A question also resnins as to the inter,.retation of " system medel.... divergent" as in 2a above.

2ree inter,xetations are pessible:

_3 a)

he system as analyzed is either steady 1

.st, ate, transiently er dira:::ically tr. stable.

b)

The system could possibly be converg;ed if all the 1er.ger te:c effects wen odelled.'

c)

The nodel is not adequate to rodel the icnger term perfort:ance of such a system.

4.

Questiens were raised ag.ing kncwn inicet:racies in nodel data. Anong these am:

a)

Response of Icad codel to low voltage.

'the zu,sperre of mal life N and MAR load to 1cw voltage is poorly t:xierstood. This has been the subjef.s of a ntater of field tests and techa.ical papera. The major achievement thus far has txen to illustrate the wide range of possible adswers dependent upcn season, thf-day, and type of custcmer; e.g., asidential vs. -acial vs.

n:ixed ard in eat prWien, etc.

Further, unless accurate knowledge exists of the a::ot:nt and status of installed shunt and switched l

l capacitors and their interacticn with voltage t

agulators, they car:not be nodeled.

b)

Generatcr MVAR Output Mcdel 5he present load flow program capability allows the user to enter udni:mn an:1==+

limits Wich }iave been calculated en the basis of an asstrned normal machine te.%.a1 voltage.

The variation of generater MVAR esc =3114ty with voltage cannot be represented in tre presec day load ficu pregne:s. This program capability is

/L

s, aquimd since the Eenerator outpu: is

. c}:rrent (a pen) 1* 'ted and as s;.7:em g

voltage declines in actual cperatic:., the M7AR and/or !G output cf the machi..e must be zuduced.

B.

T: a.sient Stability 1)

'Ibe working g: tup is awam of questi:ns raised aga:f.ing the mathe=atical s:1ution of the transient stability preg:a=, in so far as the above leid now questiens would alate to the load flew solutien used in the transient stability pr 4 w.

2)

With zwspect to loed mcdel data, al' of the ccncems capassed above zugarding the load ficw load nodel am nultiplied in the transient load model. Although considerable technical 31terature exists in this azia, it is incen-l l

clusive. 'Ihe transient zwaction of the lead i

to rapidly changing voltage initiated fn:s a ecodition in which voltage is al:tady dep:sssed is difficult to model.

3)

Since the tim duratien of a voltage co11=rse appears to be such ica.ger than presently available transient stability pres:sns can accurately simulate, the use of these pr4-

~

does not provide a method of deteddng Icw voltage lir:its.

Om LVSG has zuviewed several protetype pr::g:a=s

. /S.

being develeped to a.elyze icnger time syste:

, dyna =ic perfomance. It appears that at leis:

ene of these pregn=s, e.en devele;+d, could be used to analyze syste= Icw voltege. Additicr.a'.

effort will also be requ2. red to detemir.e data mquinrents and to cbtain data fcr.1uch prog ams.

C.

Literatum Search and Cem.:.ication With Exrerts 1he Stu@ Group ccnducted a search for literatum that might mlate to the Icw voltage cpe:aticn of an-s DN system. It included the sources of

', FFA, E??.I, ANSI, II2E, CIGFE and CALSPAN 00-Line Irforce.tien Se:.d.ces.

Another ama of activity 22ich' the' Study G: cup sursued was the ccntacting of experts in NYPP, NPCC, ot.ner NERC Councils and in industry, agartling thei:', experience in

-~

x dealing with the lo.< voltage problem. ',

T i

n y

Of the m.11titude of articles aviewed and contacts N

x.

niede cnly two gave any indicaticn that 1:w volt,igef operaticr1 of any power system has been c:.r.sidend p a viously. She infbmaticn was not in a fbm dinectly usable in detemining NYPP system' low veitsge lit:its.

[

Uhe two items am:

1.

EVALUATION N' PNER SYStiX C?EP. MON AT 0FF-NORMAL ?REQUENCY OF,4_0.2Hz, s

Westinghouse Repo:t 70 732, Jum 12,1970, for the Mid-Am.dca Interpool Net'.cric.

(The MAIN Report) 4 g T

)

l

//..

.N.. -

l

.y 2.

DE IGI.I'iDiG CF.2-2 EGLATIli3 ~?2;SFC.T.I?.c AND DE EXCITATIGi CF ALERNATC*.S CN 55.3 E:

ELTAES AND STABIL".TY, by Jer2 Csicy, CITE, Paris, Paper #323,1962.

A list of the literatum considend as well as the identi-ficaticn of the abbreviaticns appears in Exhibit 3.

G O

e 9

2 P

~

e

/s

EX5IBIT A

~

A sequence of cperating steps folicws. It has been prepared.

presta:ing a espa_ city deficiency ccrditien in ene portion of the EPP system which has the dual 1. pact of racessitating higher transfe:s while cenet..antly aducing the var suppcrt capabilities of the system. D.eintentistoiderbi.^j

. all pc5hible, ac_tiens eevered,by Ope.asityg_Polici_el_a_s~ of J.ril,1,,1976, which should be taken prior to any disecer.ection of Icad. Assceiated with each step is a aference, where applicable, to the appropriate MPP Operating ?:licy.

24 sequence is:

Activity Reference

1) Voltage Control

,CP-9 EXCERPT PFCM"C_P-9-1 s-h& bd

• h nomal sequince for voltage c:ntzol during ceak lead reF_eds is:

I.

Individual Meder System Ccetrol (Independent Acticns) a.

Switch out shunt reactors.

b.

Switch in capacitors c.

Adjust mchine VAR loadin5s ard LTC transforters.

II. NYPP Power Contml Center Centrol (initiated by individual me:ter syster:s

~asking for help or by PCC request)

Muest meter systers or other Pools to provide assistance

' a.

cn trablesere interfaces.

~b.

Request coo: Ur.ated centrol by adjustrant of =achine VAR loading and/or LTC transfon:er tap position.

Reschedule those ecencq transfers that will 1.apmve c.

voltage cenditions.

d.

Besche<htle pt:T.ed hyd.~a units to generate, over t.'.e critical period.

Motor pt= ped hydro units to pr= vide MVAR, over the e.

critical pe.%.

No

~

I "b

, DHIBIT A (centinued)

~

2) Identify a cahacity deficiency centributcry to Icw voltage.

OP-2 a.

Purchases, transfers, OP-2 reallecation E5Id%T FPCM OP-2-7 Oceratien

7. If the above action has been inplenented aa.d the Fool has insuf.'1cient "'en-Minute Faserve, the Senior Pool ?_spatcher will then evaluate the anticipated quick nspense voltage reducticn capabmty plus the available Ten-Minute Fase. te.

~

Should this ceabination be sufficient to cover Ten-Minute

~~

Reserm Faquirunent, no ftzrther acticn wi71 he recessar/.

• If this cccbination is not sufficient, the Senice Pool Dispatcher will ingle:ent Operatir.g Policy #3 entitled

" Voltage Peducticn Policy".

j,

3) Voltage P W tien Policy CP-3 a.

5% voltage Reduction - Deficient Me:2er(sJ ManualAluick Fespcnse OP-3 b.

55 Voita6e Reduction - Ncn-dencient Mater (s) Manual CP-3 c.

5% Voltage Peduction - Ncn-deficient Mec6er(s) Quick Respense OP-3 d.

Voltage Peducticn - Other Pools OP-3

\\

e.

Peter to OP Icad Curtailments CP-3 EX R5T Ff04 OP- 0

1. It quick zus;cnse voltage reducticn capability plus available Ten-Miralte Paserie are not s&fficient to meet the Ten-Minute Resera Require.ent, the Senior Pcol Dispatcher shall proceed as follows (in the order indicated) to the extent transnissict 14+4tiens per::d.t:

Direct the deficient cocyany or cacpanies to :sduce a.

voltage up to 55, *. ether =anual er quick nsper.se a.d, if necessa:/, dirtet cther am:=:er cecpanies hreing IE:uall7 activated voltage reducticM Cacabilic"7 to Tv'uCE g

/;~/.. _......... -.....-.... -......

~,,,,,

Etu:IT A (centinued)

,b.

If the Peel resetn ces are less than the Pool 1 cad cr Pcol.

facilities are above ratings er limits, dinct ctrar me=ber cec:panies to activate quick respense voltage

~

aducticn previously withheld as aquimd te =atch 1 cad and geraratien or n11 eve facility overloads.

'c. If Pool rescurces an still less than Pool lead, request,

cther Pccis to go into voltage reduction and ebtain emergency energy ft::m them to avoid Icad disecrrectien..

d.

If ft:rther lead curtailment is aquind,' imp'.ecant Operating Policy #7 titled, "Icad Curta41m.t Policy".

If Fool rescurces still cannet ratch Pool lead, nier e.

to Cperating Poli.cy #1 titled, "Operatien Etring Majcr Emergencies".

2. She New Yode Pcwer Peel will nduce voltage to the extent trans=issien li=itatiens pen::it fer a neitloring pcol already in vcitage reducticn to assist in pmtnting the neigriering pool frem intern:pting rim custccer load.

1.

Curtail ca::pany.use OP-7 s

2.

Volur: tar / Curtailment CP-7 Large Industrial and Ceccercial 3.

P2 11c Appeal - Radio and CP-7 Televisicn

~fX RPI FROM OP 7-2 If the foncast of Icad and capability for sc::n pedod during the day indicates that a 5; voltage nduction will net provide a -

t sufficient capability margin to continue to supply the Pool 1 cad withect more extr6::e measures, the Senior Pool Dispatcher will dinct the N-her coc:panies to j:ake the following actien:

1.

Curtail ca:pany use whenver possible.

2.

Contact large industrial and ca:rercial custocen and ask for volunta."/ curt =" ant of Icad.

In the event that the load reduction nsulting fr=n Steps il and

1. 2 shove dces,not provide a sufficient capability margin to continue to supply the Pool load without further meast=ts, the Senic Pcci Oispatcher will dinct the cact:er cc~.pa:iies to take the fellcwing action:

1.

Make gereral radio and TV appeals to the pclic to astrict urracessary use.

/P

EXHIBIT A (centinued) f.

Refer to CP Operatiens durir.g =ajor OP-3 m ncies 1.

Identify deficiency, take cc.metive CP-1 acticn - Irw Volta 6e Ccnditiens -

EX R?r F=CM CP'l-2 This pmcedum outlines a plan of cperations to he folicwet*. in the event of a r.ajor erergency such as unusually low frequency, equipennt overload, or icw voltage, *dch mightraeriously affect the cperatien of c,onst=ars'.or electdcal utilities' equi;=ent.

P.-ir.cicles She p'an of operaticn dedves freci the folicwir.g basic principkes:

1.

te lines, including intemal trans=1ssien circuits, emu not be opened deliberately except to prevent sustained interruptien to custo ers' service er to prevent da= age either to such tie lines or Ac equip-ment due to overicads, extra voltages, dr extre::n tmquencies.

Icad Relief Precedure C.

Icw Voltare Ccr.ditic'n 1.

Establish ecc :unication with part of system causing the low voltage.

2.

Atte=pt to have voltage level raised at s.urce.

3 Assist is raising voltage if possible.

4. 'If, after a nasonable tire based on voltage level, i

inprovement is not c:ade, separate the affected porticn of the system to prevent damage to equip-Bunt-O W M W - 6 W W W M 1

• t-lf

EXHIBlT A (centi.ned)

~

• 2.

Lead Adjusta nt - OP-6 I.

Identifiable Deficiency CP-6 a.

Discorrect load in deficient OP-6 area up to 6% of affected med ers,1 cad

~

b.

Disconract load in ncn-deficient CP-6 anas. Deficient areas main' ain 6% greater 1 cad disecrrecticn.

EXCERFP FFCM OP 6-0 Icad disecreacticn d.en requimd by this policy shall be used enly.

after all ether effective lead Wucticn precedures have been -

implemnted and all reserve has been rade available to the de"cient meder or rechers.

Operator Acticn Urf.er Dincticn of Senior ? col Discatcher:

b' A.

1.

En Senior Pool Dispatcher shall direct thp* mNr er

• meders causing'the emergency cceditiens to reduce lead, by disecrrection if necessary, in a=ounts su"ficient to zuturn that area to an acceptable cperating c=nditien.

2.

If this acticn requins any such med'er or me2ers to discorrect 1 cad in aucunts exceeding 6% of their lead at.that time, the Senior Pqcl Dispatcher shall direct other neders to reduce 1 cad, by discennecticn if necessary, to aid the deficient neder or me=bers.

24 anount of load to be reduced by each r.echer w." thin the g; ;e,caphic area of its franchised territory it.ere 1 cad reducticn can contribute effective relief shall be in the ratio that its estimated peak Icad for the,ct.: tat Capability Period in such a;ta bears to the sun of the estimated peak loads fbr the et= Tent capability pericd fcr all re2ers in such arwa, as set forth in Appendix I.

Eowever, the Senior Pool Dispatcher shall dirset rv5cticn of loads so that at all times the pcwer deficient reder or me2ers shall have disecer.ected 6% nere of their

, respective loads than the pcwer sufficient re2ers.

Netwithstarf**.s the forti;oing, t= der the cir~

tances set forth in OP-1, each meter is free to open ties sten necessar/ to p:wvent darage to equipment.

w

EDEBIT A (centi ted) 3 If then is 2Iem reserve in the deficie'nt area and the lires to that ama am cperating at e:ergency limits, the Senior Po.o1 Dispatcher shall so notify all meders involwd and they shall be papand to

~

l reduce Icad equal to any centi.gency or Icss of erargy pur2ase which ray usult in a further shortage of power en their cwn system.

4.

Meters within the affected area which experience a contingency while they are supplying enew to ether reders shall first withdraw such energy sales prior to reducing load, tnless excepted. by centract te.T.s.

This may force the rwceiving meter to provide relief by reducing load. S.e Serder Pool Dispatcher shall direct the withdrawal cf energy sale or delivery and any requi:sd 1:ad reducticra by the meden expedencing the Icss of such persased erergy.

II. Ncn Identifiable teficiency CP-6 a.

Disconrmet lead in deficient CP-6 ama - Use Appendix I for mecters affected

/

D.

1.

The Senicr Pool Dispatcher sh*7' direct mede:s in the ana whers the prtblem exists to 1::::adiately :sduce Iced sufficient to retum the area to an acceptable cperating conditien. D.e arcunt of lead to be reduced by each rader within the gecg aphic arwa' of its franchised territory whers load zwduction can contribute effective relief shall be in the ratio that its estimated peak load for the current Capability Period in such ama bears to the sum of the esti:ated peak loads fer the current capability pericd for all maders in such area, as set forth in Appendix I.

III. C:ntinued Icw Voltage CP-1 Disconnect up to 50% of lead -

Manual cathods EX RPI FIC4 CP 1-2 Requirwerents

' 4. Each syster. -t provide a reans to M11 eve a minin.n of 255 cf its system load autcratically to cretect s:-=<.s: Icv fmuer.cy ccnditiens and a =ini _'=.' cf 50% or its system icad rz."*'y to eretect as-dr.se 1cw ve':are and everlead ccndi:icns.

The au:cca:ic percien, if also centmiled by =a..ual =ea.s, na;/

be inclded as part of the 50% manual relief.

3 4

e.

e EXHIBIT A (centir.ced)

One :2:st r.cte that the above steps relate 'A a m for providir.g a solution to the existir.g pmbleb. bable s Syste:s ccndi ions my dictate a different sequence.

e e

9 O

O y

e e

e O

e I

S g

9 e

e e

0 0

e e

We

/

e O

e 0

e e

6 e

e O

O

+

e e 8 e

o S

4

~ '

MMS e

LTIES.L"TIFE REVI?4ED IN SEA?CH CP INFOMAT N PEIEDiG TO IIW-VOLTAGE OLE?./CION CF EHV SYs_.A5 1.

Caicy, "Ihe Infitence Of 'Ihe Pegulatir.g Transfor:4 rs kei 2.e Excitation of Altemators Cn Systes Voltages k.d S: ability",

CIGEE, Paris, Paper #323,1962.

2.

Westi.@ouse, "Evaluatien of Power System Operaticr. At Off-Normi Fmquency of +0.2 Hz", Paport 70-732, June 2,1970,

... for the Mid-A= erica Interpool Networic.

3 Bobo, Ekoeglund and Wagner, Westin@ouse, "Perfez ::ar.ce of Excitation Systems under Abnomal Cenditions",1 -- Paper 31 PP 67-18.

4.

Ccncer *ia, et al., G.E., "Iceg Tem Pcwer System C,r.a=ics - A New Plannir.g Dizensicn", paper subcitted October,.975, for

)

1976 CIGEE.

5 Davids=2, CEr, and Ewart and Kirchne.yer, G.E., "Icng Tem Dynazio Besponse Of Power Systen:s: An k.alysis Of Major Distu:tances", IEEE, Vol. PAS-94, No. 3, May/ June 1975 6.

Dunlop, AEP, and Ewart ab.d Schulz, G.E., "Use of Digital Ccx:puter Si=Wons To Assess Ieng-Tem Power System Dyna ='. Respense",

IIZE, Vol. PAS-94, No. 3, MayNune 1975 7

El-Shibini and Dayeh, " Reactive Power Optimizatien -Sing Modified Linear Progra:r::ing Approach", IEEE Paper C 75 024-5 8.

Fam arzi Sen, Nova Scotia Technical College, "Ihe Operation of a

.Parametic Transfomer between Two Busban", IEEE, Vol. PAS-94, No. 3, Mayaune 1975 9

0.E., "Besearch In Ieng Tem Power Syste=s Dynamics", a proposal to EPHI to extend RP-907, Apzt11975 1' 0.

Heydt, Purdue U. and Grady, Texas P&L, "A Matrix Me.: hod fer Optimal VAR Siting", IEEE Paper T 75 028-6.

11.

Imini, PG&E, ar.d Schulz and Tuz.er, G.E., "A Digital Cocputer P2tgract For k.alyzing Ieng Tern Dyna =ic Pasponse Of Power Syste=s".

12..

Mackenzie, et al., "Icss-of-Field Pelay Cperatien During System Disturtances.

---

Working Gzzup Pm;cre - June 1971",.Lt.

Vol. PAS-94, No. 5 Septe2er/ October,1975 j,

O 23

a EXHIBr B (ccr.ti c:ed)

- 13.

Ott, Wa2er r.d 'a'c: 4, U. of Missouri-Celu:tia, "Irog Tem Syste:

Dynamics Nybrid Si=ulaticn", EPRI Research Pmject 9C3-1, Pay,1975 it.

PJM Capacity a.d Mssicn Plannin6 Subecer::ittee, "1974 PJM System Voltage Study Teperc", May,1974.

15.

Sachde't and Ibrahim, U. of Saskatchewan; "A SMMaticn Technique Ibr Studying Real a.d Reactive Power Flow Pattems", IEEZ Paper C 74 389-3 16.

Schenke, Westi-@cuse, "Ihe Setting of Steam Turbine Generator Over and th6erexcitaticn Protective Devices, Report Gai 73-025", Nove:ter, 1973 17.

Schulz, et al., G.E., "EPHI Research Pmject 90-7-0, hg4em Pcwer System Dynacies", June,1974 18.

Smith,.NMPC, " Principles of A-C Power System Voltage ContIr1 for Operati.g Perscr:nel", AIEZ Transacticns, April,1954.

19.

Smith, ?U?C, "Ccntrol of Voltage and the Supply and Absorpticn of Reactive Power en A.C. Power Systems",1964.

20.

Velghe and Peterscn, "Opti=al Control of Real and Reactive Pcwer Flow under Ccnstraints", Power System Cc::putaticn Ccnference, G:encble, Septeder,1972.

21.

Weedy and Cox, England, " Voltage Stability of PaMa1 Power Links",

P10C. IEE, Vol.115, No. 4, April 1%8.

22.

Westinghouse, "Westin@ouse Engineer" Magazine Articles, Neve2er, 1967, through July,1974.

ABBREVIATIONS ANSI

- American Naticnal Standards Institute CAISPAN - Cornell Aercnautical Iaboratories - Search Procedure and Notaticn CIGRE

- Ccnfizunce Intemationale des Grands Fleseaux Electrig.aes a Haute Tensicn (Internaticnal Ccnference en Iarge Electric Systems at Hi@ Voltage)

IEI

- Edisen Electrical Institute EPHI

- Electzdc Power Research Institute ERDA

- Ehergy Research and Development Ad=inistraticn IEE

- Institu:; ion of Electrical Engineers (Iaxhn, England)

IEEE

- Instit=e of E?.ectrical and Electztnic Engineers l

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(ESIRED)

CWNE3S WIIEST RANE 34SkV Bt'EES voL"3 (KV) volts (Ky)

Niagara (PA) 340-345 330-362 1bchester (80)

Note il Note i:

t (M) 345-360 330-362 Clay Note #2 Note i; (NM) 345-360 330-362 Edie Note #2 Note #2 (NM) 345-360 330-362 New Scotland Note #2 Note #2 (NM) 345-360 330-362 Pleasant Valley N (E) 345-355 330-362 Mr.11 wood W (2) 345-355 330-362 345-355 330-362 Spra$n Brock /Dumoodie j

(2) 345-355 33b362 i

Rainey (m) 345-355 330-362 Farragut (2) 345-355 330-362 Goethals (m) 345-355 330-362 l

Note il - M coc:Cnates with NM.

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SCOPE To deteWne the udnimum operatir.g voltage or vcitages for the NYPP bulk power transn:issicn system (230kV and hisher', at which load zulief measu:ws, including load disconnection, m.:st be 1::plemnted to tulieve the low volta'ge conditicn. If zwquired, specify additional netaring. To develop the necessary Operating Policies.

BACKGPfGD Operation of the NYPP bulk power system at reduced voltage can affect system perfwwce in a nucber of way.: innM g:

1.

zuducticn of system transfer e-eity due to themal and zulay consideraticns.

2.

potential fbr a cascading system failuzw fcr either transient, dynamic or steady state conditicns.

3 furt.ber adjustnant of bulk power system vol ase would zusult in unacceptable custmer voltaap.

4 potential equipment dacage or malfunction d:.ae to opersticn outside specificaticn or warranty limitations.

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e ATTACHMENT E TEXT Enclosed for your consideration is a REMVEC report of the July 30, 1979 System Disturbance, generally considered as the worst case of near system collapse and of an extended time degraded voltage condition in our operat-ing history. The unusual occurrences and the part played in the drama by the System Dispatchers should be noted as well as the voltage levels recorded and the time frame of degradation and correction.

The importance of the remaining generating plants staying on-line and preventing total collapse of the grid is obvious. The difference between this historic incident and the submitted study of Attachment A can be summarized as follows:

Unplanned outages of three units: Pilgrim, Brayton Point #1, and New Boston #2 (total of 1286MW).

Higher than predicted temperatures.

Loss of a major intertie transmission line (#347).

Failure of Supervisory Control Circuit for breaker control.

Trip of a major generating unit (Mystic #7 at 591MW).

Higher peak load than planned.

Little or no reserve generation available.

Failure of AVR on the Brayton Point #3 unit.

All of which took place in less than an hour's time.

Attachment A's study allowed maximum of three to four generation units out but other units operating correctly and system ties intact.

Calculations havts shown that the probability of the independent events of the E * "" *"* "* 7 is in the 10 8 co 10'10 range. Other utilities, responding to the degraded voltage probability, have estimated probabilities in the 10-7 to 10-15 range for system conditions causing degraded voltage levels which could damage safety-related equipment. With Pilgrim on-lin and ope {gtingtomaintainvoltagetheprobabilitywouldbeinthe10g1 to 10 range for low voltage at Pilgrim.

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3 REPORT OF THE SYSTEM DISTURBANCE OF l

JULY 30, 1979 l

l GART cm v ATTA G A.H ERT E a

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, s, 8/9/79

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Report of the System Disturbance of Monday, July 30, 1979 On Monday, July 30, 1979 operating conditions necessitated that REMVEC (Rhode Island-Eastern Massachusetts-Vermont Energy Control) direct that 15% of customer load (= 850 MW) be shed manually due to low voltage conditions in order to preserve the integrity of the balance of the system.

The Vermont portion of the REMVEC system did not experience the low voltage condition and was excluded from the load shedding.

Initial load shedding of 5% was directed at 1028 and was increased to 15% at 1042. All load was directed to be restored at 1233.

The REMVEC System REMVEC is a satellite of NEPEX (New England Power Exchange) and comprises about 51% of the NEPEX load.

Temperatures were forecast to be in the mid to.pper 80s with high humidity. The NEPEX load forecast for the hour ending 1400 was 13,350 MW or approximately 6800 MW within RENVEC. Actual temperatures reached the mid 90s and actual NEPEX load was 12,681 MWH for the hour ending 1000 or approximately 130 MW higher than forecast.

Generating equipment out of service or reduced in the REMVEC area totaled 3140 MW.

Included in this total were three units that were originally expected to be on the line in the morning. They were: l 3

8/9/79 S e s

Pilgrim No. 1 (670 MW) - Control rod problem.

1 Brayton Pt. No. 1 (249 MW) - Boiler cleaning.

(367 MW) - Came of f line at 0024 due to a boiler New Boston No. 2 leak.

New Boston No. 1 (380 MW) came on the line at 0553 after repair Bray-work was completed and was operating at 150 MW output by mid-morning.

1 ton Point No. 3 (641 MW) came en line at 0409 for tests following annuc It was connected only to the 115 kV bus.

overhaul.

It was expected that voltage levels would be lower than desir-RPiVEC able but above levels at which drastic action need be implemented.

system operators had requested all generating stations to go to their heavy load voltage schedule by 0600, one hour earlier than normal.

By mid-morning the REMVEC load was approximately 6900 MW with I

Approximately 1300 MW over 2000 MW being imported from adjacent systems.

of this total was coming from CONVEX.

System voltages and transmission line flows were being carefully All available genera-monitored and were close to the anticipated values.

tion in the area was committed to support the voltage.

The Transmission System Because of the heavy import of power from the southeastern por-tion of CONVEX it was necessary to protect the Whipple Jct.-Mstic, Conn.

l h! -.

8/9/79 s

portion of the CONVEX #1280 line from overload on loss of the 345 kV line

1. 347 (Card Street-Sherman Road). To provide this protection the 115 kV line

1. 1870 was oper.ed at W. Kingston, R. I. and the W. Kingston load was carried radially out of Kect County. The Wood River substation load (approximately 25 MW) was carried radially out of Mystic, Conn. This switching, which is an accepted procedure done to provide first contingency protection in accor-dance with NEPEX Criteria, Rules and Standards 19 (CRS 19), was completed at 0852.

The Disturbance At 0956 the #347 line tripped with approximately 650 MW flow-ing into REMVEC. The #347 line has summer ratings of 1260 MVA normal, LTE and STE. The line contacted a white pine tree in the CONVEX system. See voltage summary A.

These voltage summaries represent voltages from various Ic :ations on the system as telemetered to REMVEC. At this time the partici-pants in the affected area were advised of possible manual load shedding.

t l

I At 0958 CONVEX energized the #347 line at Card Street to Sherman Road, however, the air circuit breakers remained open at Sherman Road.

The air circuit breakers would not close by supervisory control and it was neces-sary to send a man to the station.

At 1014 it was reported that the switchman at Sherman Road would be able to close the circuit breakers on the #347 line in about 5 minutes. [

t l

8/9/79 I

g 1

portion of the CONVEX #1280 line from overload on loss of the 345 kV line

1. 347 (Card Street-Sherman Road). To provide this protection the 115 kV line

1. 1870 was opened at W. Kingston, R. I. and the W. Kingston load was carried radially out of Kent County. The Wood River substation load (approximately 25 MW) was carried radially out of Mystic, Conn. This switching, which is an accepted procedure done to provide first contingency protection in accor-dance with NEPEX Criteria, Rules and Standards 19 (CRS 19), was completed at 0852.

The Disturbance At 0956 the #347 line tripped with approximately 650 MW flow-ing into REMVEC. The #347 line has summer ratings of 1260 MVA normal, LTE and STE. The line contacted a white pine tree in the CONVEX system. See voltage summary A.

These voltage sunmaries represent voltages from various lo :ations on the system as telemetered to REMVEC. At this time the partici-pants in the affected area were advised of possible manual load shedding.

At 0958 CONVEX energized the #347 line at Card Street to Sherman Road, however, the air circuit breakers remained open at Sherman Road.

The air circuit breakers would not close by supervisory control and it was neces-sary to send a man to the station.

At 1014 it was reported that the switchman at Sherman Road would be able to close the circuit breakers on the #347 line in about 5 minutes.

_3_

[

s.

5 8/9/79 e

s Low gas pressure on the breakers was reported as the problem.

At 1027 the Mystic No. 7 generating unit (591 MW) tripped with an apparent thrust bearing problem while carrying 550 MW and 265 MVAR (lagg-ing). See voltage summary B.

At 1028 REMVEC directed that Operating Procedure No. 7 be imple-mented and to shed load manually through step No. 5.

VELCO was excluded.

See voltage summary C.

Voltage summary D indicates the improvement in system voltage levels due to the effect of 5% load shedding (= 310 MW) prior to reclosing the #347 line.

'At 1031 the #347 line was closed at Sherman Road. It was dis-covered that the synchronism check relay was not closed and required that a technician remove the cover and close the contacts manually. See voltage summary E.

At 1040 Brayton Point No. 4 dropped to 80 MW from 380 MW and reports from the station were that we would probably lose the unit. The Brayton Point No. 3 generator went from 180 MVAR lag to 110 MVAR lead. Vol-1 l

j tages in the affected area declined by a substantial amount at this time.

Subsequent investigation revealed that the voltage regulator on the No. 3 generater malfunctioned. (

a 8/9/79 O

- s k

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At 1042 REMVEC directed manual Jr ad, shodding through step 15 s

I

(= 850 MW). See voltage summary F.

s H

Voltage summaries G H, I, J and K reflect the effects of lo d shedding.

N*

At 1047 NEPEX ordered the output oi'Montville No. 6 reduced by (

100 MW to reduce the loading on the #347 line.

s At 1116 the Brayton Point No. 3 voltage regulator was placed

^

on manual control and MVARs were adjusted from 91 MVA} 1eading to 119 MVAR f

lagging. Mystic No. 6 generator (142 MW) came on the line. See voltage summary L.

At 1119 REMVEC directed restoration of customer load from step 15 to step 10.

See voltage summaries M, N and O.

s At 1153 Mystic No. 7 generator came on the line. Further load restoration vac planned as soon as the Mystic No.-7 operators informed kEMVEC.

that the unit was stable.

See voltage sivaary P.

At 1212 REMVEC directed restoration of customer load from step 10 to step 5.

See voltage summary Q.

System voltage levels were being moni-tored and were improving. Flows on the tie lines to REMVEC were also being carefully monitored.

. 7

8/9/79

• s e

At 1233 REMVEC directed all customer load be restored. See vol-J tage summaries R, S and T.

s Some low voltages persisted throughout the afternoon.

f Pilgrim No. I camE on the line at 1426. The 345 kV and 115 kV busses at Brayton Point were tied together at 1639. Brayton Point No. I case'on line at 1640. The system was considered secure at this time.

The #347 line was removed from service at 1647 to cut down the tree that had contacted the line.

The #347 line was returned to service at 1921.

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