ML18088A856

Response to 3/10/1978 Letter. Submits Affidavit of Messrs. Kent, Bivans and Flugger, and 12/14/1977 FPLs Response to NRCs Questions Concerning 5/16/1977 Outage Enclosed

ML18088A856
Person / Time
Site:	Saint Lucie
Issue date:	03/31/1978
From:	Coll N Florida Power & Light Co, Steel Hector & Davis
To:	Mike Farrar, Johnson W, Salzman R Atomic Safety and Licensing Board Panel
References
Download: ML18088A856 (107)

Text

{{#Wiki_filter:SvzEw H @cfog &. D~vis-SGUTIICAST FIRST PIATIGTJAL SATIK SUILDING MIAMI. FLORIDA 33I3I WILDAH 0. STtCL UIS J. >COTOR OARRCY A, OAVIS OWIONT SULLIVAN WILIJAII 4, ULLAH CRNCST J, NCWCTT JtRRY 4, CROCK~ WILSON SHITV fALSOT O'ALCIISCRTC JAHCS, >>. SWCIHY, JOHN COWARO CHITH NORHAH A OLI OS. C. CARPS SHCPARO KINO AROCH 004$, JR HATTHCW ll, OHILOS CARRY R, OAVIOSOH NOCL V, NAfION TRUCt, S RUSSCLL ALVIN d. OAVIS JOSCPN A. ILOCIL JR ~ICHAAO 0 JHITV TVONAS ~. NCOUIOAN PATRICIA A, jtlft OCNNIS A, LARUSS* ~ AUI,.J SONAVIA JUOI'TV v, KOROHIN JOHN V SAAKC ~OSCRT J. IAVIH J CRPRCY I, HUI'HS VANCC C. SALTCR'OHALO H, HIOOLCSROOKS NCNRY J, WNCLOHCL JOSC LUIS CASTRO March 31, 1978 WILL M, RRCSTOH Of COUNSCL TCLCRHONC I305I 577 2500 TCLCK 5I-5r55 OIRCCT OIAL HUIKSCR Michael C. Parrar, Esquire Chairman Atomic Safety a Licensing Appeal Board Nuclear Reg Tlatory Commiss'on fl<ashington, D. C. 20555 Dr. N. Reed Johnson Atom'c Sa ety 6 Licensing Appeal Board Nuclear Regulatory 'Commission Washington, D. C. 20555. Richard S'.

SaZzman, Esquire Atomic Safety

& Licensing Appeal

Board, Nuclear Regulatory Comm'ssion Washington, D.

C. 20555 Re: In the Hatter of rlorida Power ana Light Company (St. Lucie Nuclear Powe Plant, Unit 2.) - Docket No. 50-389

Dear members of the Appeal Board:

':n response to the Board's Order of Ha ch 10,

1978, we subm't the ollowing:

(1) Afficavit o= Cl'fforc S. Kent (Questions Al through A7 concern'ng steam gene a or tube integrity); (2) Affidavit o" E"nest L. Bivans (Quest'ons Bl(a) and. B2 concerning electrical gria reliabili y); (3) Affidavit of: frederick G. :lugger (Quest'on Bl(b) concerning coincident. loss of offsit and onsite power); and catec 19I7 reply (4) A copv of "-1o 'ca Power 0 Ligit Com any's "esponse December 4, 1977, to NRC s-aff cuejiior s posea Octobe= (Question B3 (b) concern'ng = lorica Power 0 Licht Company' o NRC staff quest'ons conce..'g May 10, '977 outage). l Resp c ul'y submit-'AC/sm NORYD A. COLL cc: See attached service list.

~ZilZTZD STA ZS OF MMZRiCA NUCLZAR REGULATORY COMMESS:ON Before the Atomic Safet and Licensina Appeal. Board ln the Matter. of FLORIDA POWER & L1GHT COPmANy ) (St. Lucie Nuclear Powe Plant, Un't No. 2) Docket Vo. 50-389 CERTIFICATE. OF SERVICE E hereby certifv that a true and correct copy of the foregoing response of:lor'a P owe & Light Company to cues ions contained in the Appeal Board Order of March 10, 1978 have been served this 31st'. day'f iMarch,

1978, on the persons snown. on the attached service list by deposit. in the 'nited States mail, pro-perly stamped and addressed.

NORI.'MV S ee 1400 S Nat'on A. COLL Hec or & Davis outheast Fi st al BaiLc Bu2.1G3.- g iMiami, Flor'da 33131 Telephone: (305)577-2863

(7iilZTED STATES OF'~~RICA NUCLEAR REGULATORY COa>2'iZSS ION Before the Atomic Safety and Licensin Anneal Board ln the Rnatter of FLORIDA POWER & LiGHT COMPANY ) Docket No. 50-389 (St. Lucie Nuclear Power 'Plant. ) Unit 2) ) SERVlCE LZST Hr. C. R. Stephens Supervisor, Dockeiing and Serv'c Sec"'on Office of the Seer tary of the Commission Nuclear Regulatory Commission Washington, D. C. 20555 Michael C. Farrar, Esquire Cha'rman Atomic Safety & Licensing Appeal Board Nuclear Regulatory Commiss'on Washing on., D. C. 20555 Dr. W. Reec Johnson Atom'c Safetv & Licensing Appeal Boa"d Nuclear Regula 0 p Comm ssion Washi..gton, D. C. 20555 R'cha "'. Salzman, Escu're Atom'c Sa etv & L'ensing Appeal Board Nuclear Regulatory Commiss'on Washington, D. C. 20555 Alan S. Rosen Cha 'an Atom' Safety Nuciea. Regu'ash'.kgion ~ D

thai, Escuzre icens'..c Appeal Panel tory Corrm"ss'on 20555 Edward Lu -on I Chairman Atomic Safety Nuclear Regul Was<'nc oi:,

D Escu're & Licensing Board Panel atory Commission C. 20555

P g~o Michael Glaser, Escu'r A'ternate Chairman Atomic Sa=e v and L'censing Board 1150 Litn St=eet, N. W. Washington, D. C., 20036 Dr. Marin N. Mann Technical Advisor Atomic Sa=ety & Licensing 3oard Nuclear Regulatory Commission Washington, D. C. 20555 Dr. David L., Hetrick Professor of Nuclear E. ginee ing Un'ersity o Ar'ona

Tucson, Arizona 85I21 Dr. Fran'( F. Hoooer

Chairman, Resource Ecology Program School of Natu al Resou=ces Universi,ty of Michigan A~ Arbor, Michigan 48204 Hr.,Angelo Giambusso Deputy Director for Reactor Projects Nuclear: Regulatory Commission Washington, D.

C. 20555 William D. Paton, Esauire Counsel for NRC Regulatory Staf. Nuclear Regulatory Commission Washngton, D. C'. 20555 Marian.".arolc.".odder, 1130 N. =". 86 St ee'iami, Flor 'a 3 313 8 Esm i"e Harold ":. Reis, scu' Lowenstein,

Newman, Re 1025 Connect'cut Avenu Washington, D.

C. 2003 's ~ Lxelrad eI ocal Public: Document Room Lydian River Junior College Library 3209 Vircrinia Avenue 'Dias a 1 r.r 0) 0 c, F o ~ ~a ~ -'50 U. S. Nuclear Regu'ato Wash'ng on, D. C. 2055 sou 1 Y'O CoÃa~zi1's ~ on

UNITED STATES OF AFRICA NUCLZAR REGULATOR COi+~1ISSION BEFORE ~HZ'TQ'41IC SAF TY AVD LICEVSIVG APPEAL BOARD In the Natter o ) ) "LORIDA POWER AND LIGHT COMPANY ) ) (S t. Lucie Nuclear Power ) Plant, Unit Vo. 2) ) DOCKZT NO. iO-389 /'n / "'4C AFFIDAVIT OF'LIF."ORD S. KZNT tg, ~-. '"' "VS> j L am Clifford S'. Kent, Project Nanacer fo 2 the St. Luc' nuclea oroject for Florida Power 6 3. Light Compa y. My educat'onal and p ofessional quali ications appear in the Nuclear Regulatory Commission' record of this proceeding, following 6 Tr. 5184. The purpose of. this affidav' is to espond S to the cuest'ons concerning steam generator tube integrity 9 set forth in "he Appeal Board's Order of March 10, 1978'0 in this proceeding. 13 QUESTION 1 Data from Maine Yankee and Millstore 2 (hotn, li!<e St. Lucie 2, are facilities of Comhus tion Eng'eer ing " cons'cer hl -'ucge hac =orme 16 on th tuoe sheet, indica ive of inacecuate b owdown performance. How has the St..Lucie 2 steam generator

blowdown sys" m been mocif'ad to provide o= mor 2 affective removal o= solia. materials from th steam 3 generator than has been achieved at "~ase-other 4 facili ies? RZSPONSF There has been no charge in the -'ntarna1 8 blowcown piping of the St. Lucia 2 steam generators 9 in comparison wth ear1'er C-E steam generator designs. Florida Power G Lici.t. expec s to minimize anc control the fo~atior of. slucga 'n the St. ucie 12 steam generators hy both using a h'gh capacity b owcown 13 rate arc. hv control QC'econcary system cor=osQn pro-14 duct forma 'on. Data =rom the Maine Yankee plant ind'ates the e ~ factiveness of contir uous '"'wcown.. Where only int rm',ttant hlowdown was employed =rom initia1 operat'on in 1972 unt

1975, sludge acc ~mu-tions

=eac.'".ac 3-1/2" on the tubashaet. con i uious hlowdown was amp 'yad:Q r tiazimum Qn Q 1 21 Qf suspended sol'ds. During the~= 1977 LilSpact-'0 n I 22 sludge dap"hs had increase hv or. v 1/2" to =- I o>> 1 23 depth o= 4". he. St. Lucia 2 h1owcown system will he 2 41 Coni Lnuous1 y h 1 Qwdolv~ a.c increase max m'>>ILi gpm cn

(c olant start-u~ or when steam generator chem'tl r 2 parameters show n inc ease above, no~rmal levels. The effect'veness of preventing. solids 4 entering the= st am g nerator 'n minimizing. sludge 5'ccumulai 'ns 'ndicatec hy the Calvert Cliffs 6 plant,, whici nas a steam generator des'gn essent'ally 7 identical to Millstone Z'Z: and St. ~ucie 2 witn respect 8 to Slowdown and tDesheet =low pat"erns. After wo 9 vears of ope ation,.the Calvert Cli=fs ~ stews gener-10 ators. were verv clear. and the sludce dep~~ cenerally. ll was less'han l/4" on the tuhesheet. As described in the ~tovevwer 4, l977, Kent a=f'davit, operationa'easures to restrict the fornation and accumu'ation o sludge in the st ~m genera.tors incluce the minimization of'o..denser in-leaicage,. st=ict chemistry control o= the seconda"y system,, and h'ch steam cenerato" Slowdown. 7n order to limit the amou.t o = cor=oson p"oduc s =ormed 19 u"'g an out ce "eriod, wet lay-p a..- ni <<ocen 20 capping ~v oc>>deq =ol owec. Deaerated condensate is used =or fill ~ ng of corn"one..ts tha.t have been 22 c<<a~ ned fo ma'nte..ance. Additiona y, ~e 'feedwa e 23 <<ecx cula 3.on c'e>>n-up system '" designe to minimize anspo t o: 25 ou ace ~

1 QUESTION 2 Shat'is the latest assessment of the ability 3 of the AVT method to minimize tube degradation resulting 4 from the bu'ldup of scale and, the'nset of stress.- 5 assisted corrosion or crac!<ing'? 7

RESPONSE

The pe" ormance of Inconel 600 'n AV' 9 chemistrv conditions'both of which are to be used 10 in St. Zucie

2) continues to be exc llent.

To our 11 knowledge, there have been no instances of scale 12 build.-up or leakage in'tiated =rom the secondary sde 13 in any alloy 600 tubed steam gene ators wh'ch operated 14 solely with volatile. chem'st"y. In fac-, there has 15 not even been an Eddy Curr nt Test indication of 16 secondarv side tube corros'on in an alloy 600 "U" 17 tube steam generator solely utilizing AVT.. 18 Based on the informat'on to date, there is '9 lit"le likelihood that stress-assisted tube cor"osion 20 or crac!<inc will be a problem in the St. Iucie 2 21 generato s which will be operated solely witn AV 22 cnemistry control. 23 24 QUEST:ON 3 25 Ca on sic 1 . as be n =c nec as a pa teal

1, cause of the denting phenomenon, as it mav undergo 2 runaway megnetite or@ation under certain environ-3 mental conditions. Although steps have been taken to 4 eliminate these conditions, would it not be prudent 5 also to build the eggcrate tube support of something 6 other than carbon steel? [See Table 1, EPRZ*, which 7 lists tne use of more corrosion-resistant suppor" 8 plant materials as one of a number of a "steam gene 9 ator, des'gn improvements"j. 10 ll

• "EPRZ" rerers to

a. paper presented a

the American 12 Power. Conf rence, held. at. Chicago, illinois on April 13 18-20, 1977, ent'tied EPRZ Steam Genera or Programs, 14 by L. J. Nartel, et al. 15 16

RESPONSE

17 The use o a more corrosion-resistant supoort 18 plate mate ial is a possible steam gene ator desicn 19 improvement. ~r/hile such an approach may perhaps be 20 more directly applicable to designs employing rigid 21 support =lates, PPL concurs that the use o" corros'on-22 resistant egg c a e tube suppor" structures would not 23 be an imprope choice in futur steam generator des'.ns. 24 Nevertheless, for the reasons statec., Florida Power 25 E, gh" Company (=-PL) bel'es "ha-the St. Lucie

. 2 carlton 26 2/

steel egg c a e tube s" p ort st uctures ago oo atel v address the concern =or dent'ng of ste m generator -t bes

Based on operating experi nc nd, laboratorv 2, test'g, the denting phenomena is 'assoc'ted, with mag-3 netite formation caused. by the concent ation" of steam generator water impurities in the tube/tube support plate annulus of a rigid carbon steel support plate. The local secondary chemistry environment 7'hich leads to the denting phenomena can be precluded 8 bv either eliminating the annular crevice region, 9 removing the rigid, carbon steel interface, or elim'- 10 ating the source. of the. steam. generator contaminat'on. ll As described in. the November 4, 1977 Kent a fidavit, 12 the. S . Cucie Uni" .2: design is. sucn to el'minate all 13 three. 14 The design of the St.. Lucie Un't,,'2 steam 15 generators has been improved to include, the exclusive 16 use of non-rigid (eggcrate design) tube support struc-17 tures which eliminates both the narrow annular gap and 18 the rigid carbon steel 'nterfac "-liminaiion of the narrow annular cap '.. the 20 design of the eggc ace tube supports provides for almost 21 complete washing of the tube surface wth unconcent ated 22 steam generator wate , since the support may contact 23 the tube at. only four lines on the tube circumference. 24 Assuming the situat'on o nezplained magneti 25

growth, he eggcr

e des'".". pr vents dent-ng as coes

not provide. a ri id support o ce - ra" su;r-'c-'ent 2. in-olane 1 oac~ ncs to cause. tube. dero,, on ~ C-=- has demons t-ated ". mode st am generato= 4 tests that ex ensive magnet'e norma ion and. tube denting 5 do not occur in carbon steel eggcrate supports in¹ 6 same. operating'nvironment that does produce denting, .7 in ca bon steel drilled, support pla es. Fur he 8 prelim'ary visual examination o= carbon steel support st"'-s 9 removec zrom the Millstone Ti steam cene ato s, whe e: 10 significant tube dent'g occur-ed the dr'ied support 3.1

plates, showed no evidence or non-prot ct'e macnetite 1 Z formati on, at the tube to carbon.

s ee ', strip i;tersections* ~ 13 it may be concluded hat extens 'e macneti' ~omation recuires mechanical arrangements and local hvcraulic 15 conditions, which are not present-in the St. Lucie 2 16 steam cenerators where al 1 eggcrate tube support con-17 struction is used. 19 QUEST:GH 4 20 Attachment B to tne >jovember 4, 1977 Kent 21 af"idavi . ind'ates that a navLber ox =eedwate train 22 components that operate in contact w'h feedwater at 23 relativelv high temperature w'l contain copper bear'g 24 allovs. Does sing copper a '. s, titanium, "ncone 2 ~ ~ I ~ ~ ~~~v 5 any a +on st"ei n <<ne Same ~vsrem cause

1 materials compatability problems or conflicting 2 water chemistry (pH) requirements? [EPR1, TABLE 1 3 suggests that copper be eliminated as

a. potential 4

source of corrosion products in. steam generators.] 6

RESPONSE

The utility industry has for several decades 8 been aware of the impact of condensate and feedwater 9 system corrosion. products on steam generator (fossil 10 &. nuclear) tubing integrity. Corrosion control of 11 secondary syst: em materials. of construction is accom-12'lished by material choice and operating chemistry, 13 specifically condensate and feedwater system chemistry 14 control, during shutdown and operation. 15 Due to the identification of copper as an 16 agent in the electrochemical attack of fossil boiler 17

tubes, the industry has been sensitive to the presence 18 of copper in secondary systems.

The wide use of copper 19 alloys in heat exchanger tubing is due to the alloy's 20 many proven qualities including excellent heat transfer 21 conductivity, excellent workability (manufacture 22 fabrication), good reliability, and low total cost. 23 lt was based on these qualities that the St. Lucie 2 24 feedwater syst: em incorporated copper alloys. 25 The presence of copper alloys is compensated

1 for by chemical treatment of the condensate and 2 feedwater systems. As-described in the November 4, 3 1977', Kent af idavit,. St. Zucie 52 chemistry control 4. includes minimizing condenser in-leakage, minimizing 5 ingress of oxygen, chemical scavenging of oxygen, a 6 comprenensive lay-up program when offline, and a 7'eedwater recirculation cleanup system to provide 8 removal of feedwat r "ra'n corrosion products and 9 other-impurities prior to start-up. 10 The corrosion rate of cond nsate and ll feedwater system materials of construct'on is most 12 a fected by oxygen levels. in the secondary train,. 13 To limit corrosion during secondary system operat'on, 14 oxygen is norma13.y ma'nta'ned at less than 10 ppb at the 15 condensate heater. Oxygen levels are otherwise 16 cont oiled by wet lay-up and nitrogen capping pro-17'edures and by utilizing a source of deaerated water 18 for system filland on loss of normal feedwate". The pE at which the feedwater is controlled 20 's dictated by the materials of construction in the 21 condensate and eedwater systems. Zn a mixec ferrous 22 and copper alloy system, a pH control range is selected 23 to minimize the corrosion of all materials witnin the 24 svs em. En p ac 'e a H cont ol point is se lee Bd 25 which minimiz s cor oson of ":" syst m's cop"e 'ys.

The change to titanium condense tubing is 2 benezicial to the St. Lucie 52 secondary svstem corro-3. sion cont. ol in a number of ways. Fi st,. the excellent 4. reliability of t'anium will. prevent circulating water 5 in-leakage. This results in more stable chemistry 6 con rol and reduced. system corrosion. The titanium 7's essentially inert under condenser conditions and 8 does not have to, be factored into tne secondary system 9 chemistry control scheme. Lastly, adopt'n oz titanium 10 condenser tubing removes 75$ of the-total. copper alloy 11 surface area in the condensate/feedwater system. 12, 13 QUESTlON 5 Precisely how will the eggcrate conc'ept be 15 utilized in the bend region oz the steam generator 16 tube bundle where the part'al tube support plates are 17 being replaced? Provide drawings or other materials 18 to illustrate this. 20

RESPONSE

21 The design of a partial eggcrat tube support 22 is identical to the full disk eggcrate support, with 23 the addit'on of' s izfening bar along the chord. 24 forming the inner boundary of the partial support. 25 The sti. fening bar, 1" x 5/8" in crossec

ion, has na l.

holes to accept the rows of tubes just inside and 2 just outside the partial support. Tube wall denting 3 is, not= oz concern at this location because the thin 4 strips. of the eggcrate design adjacent to the" tube 5 inside the support, and the. lack of restraint 6 adjacent to the tube outside the suppor, do not 7'rovide the required rigidity for constriction of, 8 those tubes and denting.. The basic eggcrate design 9 is snown in the attached sketch and..accompanying 10 photographs. 12 Attacnments: 13 14 1) Sketch: Eggcrate Assembly (does not show chord 15 16 2) Photo: 17 3) .Photo: 18 19 ~ stiffening bar) Close-up 'of Eggcrate Assembly (NP-C-74-10) View of Steam Generator Unde Cons ruction Showing he L~stalled Partial Tube Support P'ate Assemblies (NP-C-74-22) 20 21 QUZSTiON 6 22 The Kent afzidavit, Attachment A, p. 2, 23 notes that the "tube support plate des'gn provides 24 protect'on "rom tube carnage due to meci anical and 25 low incucec vibrat'n". Assumina that he support

plates refer=ed to here are of eggc ate design, what 2 -is the'basis for. this determination concerning pro-3 tection from tube damage? ls there experimental evidence? Do the eggcrate strips remain flexible in 5 this. region or. can thev become rigid as the tubes. 6

change shape during operation? 8

RESPONSE

C'-E'as per=ormed.ull scale laboratory 1'0 tests to demonstrate that the tube suppor" design ade-11. cuately protects the tubes from damage due to both mechan-12 ical and flow induced vibrations,. These tests include 13 mechanical shaker tests in air and 'n water to determine 14-the response oz the tube and tube support system to v' 15 bration'ver a;- wide range of freauencies, and single and 16 two-phase flow vibration tests under simulated operating 17. conditions to determine the forcing functions anc frecuen-I'8 c'es imposed on the tubes during operat'on. The results 19 oz these tests show that the eggcrate suppor design will 20 'ndeed provide the necessary protection under all ooer-21 ating cond'tions with a good margin of sazety. 22 Although there is no reason to expect tnat 23 tubes will signizicantly change shape during operation 24 (s ince the c uses of the tube denting. phenome..a have 25 been removec), a dest"uct've test has been =erfo"med on -1 2-

1 a production eggcrate assembly. With tubes in each 2 tube space in the eggcrate, except the normally 3 unoccupied tube lane, the assembly was radially 4 loaded from the periphery of the eggcrate.assembly. 5 Even at extremely large deflect'ons of the overall. 6

assembly, the tubes still remained free in tne 7

individual tube spaces. Deformation of the egg-8 crate assemblv was at the intersection of inter-9 locking support strips, indicating that loads would 10 be-transmit"ed within the strip assemblies,, not on 11, individual tubes. Tube deformation occurred only at. 12 the peripneral tubes of the eggcrate assembly at gross 13 deflection levels ar exceeding any loads that would 14 be expected during steam generator operation. 15 16 QUESTION 7 17 1nsofar as't bears on tube leaks or failures, 18 what powe" plan operating experience or laboratory data 19 exist involving tne use of titanium concense tubes 'n 20 a sea wate environment and what does that experi nce 21 or data reveal? 22 23

RESPONSE

2-. Florida Power a 'i ht chose "'anium 25 =or.St. Lucie ~2 based on an ana ysis of tubing alta 1 natives which included 90-10 Copper-Nickel,

titanium, and the orig'nal'ly specified alum'num-brass.

3 Our: study concluded. that. as a material choice, \\ 4 titanium offered outstanding resistance to identified 5 corrosion mechanisms (i.e., pitting, erosion,

wastage, 6

ammonia attack, etc.. ) encountered in seawater condenser 7 service. While titanium had not been in commercial use 8 foz' long time, the exis ing data base indicated an 9 outstanding service record 1 10

Recently,

a. comprehensive EPRI s.tudy 'as, 2.

11 consolidated. much oz the utility experience. wi th 1?'itanium tubing. The ZPRZ study concluded: "Titanium, 13 the newest condenser tube material,,- is the only material 14 n this survey that'an be expected to last the plant 15. lifetime in the condensing section oz saltwater cooled 16 condensers". This survey included saltwater cooled '7 genera" ing units and compared: condenser tube mate ials 18 such s admiralty, 304 SS, 316 SS, 90-10 Cu-Hi, aluminum-. 19

brass, a'minum-bronze and titanium.

courteen un's in 20 the survey nad titanium tubes 'n service. 21 The oldest titanium tubes rezerenced in the 22 study we e seven. tubes installed in a, condenser as 23 part of a test. in 195'9. After 91,000 hours of oper-24 ation in polluted brackish wa"er, 25 corros'on 'has been observed. Of no ev2.cence oz the 31 i an um tube

sets surveyed (total of 164,000 tubes), 22 tubesets 2 reported. a total of 48 failed tubes. All oz the failed 3 tubes reported were associated with mechanical.

causes, 4

predominantly vibration. Zn the EPRI study, not one 5 instance oz corrosion or erosion failu e was reported. The major difficulty encountered w'h backzitting 7 titanium in condenser tube applications has been vi-8 bration. The. major. cause for this situation is that 9 titani~~ 'ubes usually have a thinner wall than the 10 copper, alloy tubes'hey replace. As described in At achment B to. tne November 12 14-,. 1977 cCent azfidav't, Florida Power & Light has taken 13 measures to assure that tube vibration will not occur 14 at St. Lucie ".'2. FPL incorporated additiona3., partial 15 tube support. plates 'nto the condenser design to assure 16 adeauate tube suppor would be available. 17 l. ."Installation List: Timet 50A Condenser Tube", Titanium 18 Metals Corporation of America, June 1974 19 2 "Steam Plant Surf ce Condenser Leakage Study", Electr'c 20 Power Research Institute, EPRI 'AP-481, March 1977

C ~7ORO S. KENT STATE OF FLORIDA COUNTY OF DADE ) ) ss. .) Subscribed and sworn to berore me this dcLQ oic cL~ i%v commission. expires: 1978. NOTARY fUBUC STATE QP flan.UA i'NY CQt<$<!SS(QN EXPIRES AUGUST 24. lM> SOEESED THRV MAYNARD BCNQENQ AGENCY. VOTARY PUBL1C

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'lt .l.;. i CLOSE-UP OP EGGCRATE ASSEMBLY a ~ a'~ r,J$ ~i ~)gl5gkh tpt r '~At 4P;d (NP-C 10)

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,B I ~' By ~~~+TVTP~W~ 4 44 f '44', I)..PiVf ( .; r T ,'~I Location of stiffening bar (typical) 4 ~ P isa'P.," ~P ' )+o'lP ~l 1~ s. N Ai i' o VIEW OP STEAN GENERATOR UNDER CONSTRUCTION SHOWING THE i '.. i%/ ~ ' INSTALLED PARTIAL TUBE SUPPORT PLATE ASSEBLIES (NP-C-74-22) \\ ')Q ~ A) I ('h%P Al ~ 4's ~I 2 ~r '4 h ~ 1

UNi?TED STATES OF Ai4KRiCA NUCLEAR REGULATORY COMMiSSiON BEFORE THE ATOMTC'AFETY AND LiCENSiNG APPEAL'OARD in the Natter of: ) ) FLORiDA POWER AND LiGHT COMPANY ) ) (St. Lucie Nuclear Power ) P lant, Unit No. 2) ) DOCc(ET NO. 50-389 t I 'u-.-" t AFR g ~gee ~ Otttt~ < tie Sees t~ tto6Nttt g ftrtttt Secttott /J AFFiDAVTT OF EPJVEST L. BiVANS Z am Ernest L. Bivans, Vice President in + 2. charge of Sys em Planning fo" Florida. Pawer & Lign 3 Company. Ny educat'on and professional cual'cations apoear in the Nuclear Regu1atory Commission's record oz. the'St. Luc'e 2 oroceed'ng following Tr. 4896. The ourpose of this affidavit is to accress 7'uestions B.i(a) and B.2 'n the Apoeai Boazd's Ozder 0 E Narch l0, l9 78 toge tner witnin tne ' common context. 10 Gr' FPL serves aporox'matelv 200 municipa1it'es and over 30 count'es in the State az-Florida. The Company's exis 'ng gene ation faci1tties cons'st oz eleven generating oiants distributed geographical1y around 's se v ce er 'ry ~ w..ese p1 ants are 'c 16 'to a sys-m-wide " nsmission ne"t~ork, somet'mes referrec to a s a gz'ic the pu"oose of wh'ch is to

1 transport energy from the generat'ng plants to the 2 load. areas and to assure svstem reliabilitv. "lorida 3 Power @ Light Company operates approximately 4,165 4 circuit miles of transmission lines., A map showing 5'ne FPL system and interconnections is at ached to 6 this affidavit. Florida Power & Ligh Company 's d'rectly 8 interconnected witn n'ne other Florida utilities, 9 both public and prvate, which have significant 10 gene ating capacity., FPL maintains fourteen. normally 11 closed and. two normally open interconnections. Included 12 in the normally closed 'nterconnections a.e one 115 kV 13 and two 240 kV interconnections with Florida Power 14 Corporation, whicn in turn has interconnections outside 15'f Florida: one 230 kV and four 115 kV ties to Georg' 16 Power Company, and one 230 kV tie to'ulf Power Company. 17 Peninsular Florida possesses special geograpnic 18 and electrical featu es. Surrounded by water on three 19

sides, opportunit'es for interconnections with major 20 ut'lities outside of Florida are res ricted. to the north.

21 Zn addi"ion, Florida has 'been subject to hurricanes and 22 is. one of the most severe-lightning storm areas in the 23 United States. 24 Consecuent'y, Florida Power ~ 'ght Company, 25 and the other uties in F'orida, have had to take

1 these factors into considerat'on in designing and 2 building a r liable stat wide. system and the eby 3 lessening the need fo-strong interconnections 4 outside of Florida. 6 The 'St. E,ucie Plant: The Florida Power & Eight Company grid 8 and connections to nuclear power plants on it are 9

designed, and operated so as o comply with applicable 10 NRC recuirements En particular, GDC-17'eauires a.

ll. svstem of sufficient: capacity and capability "'to 12 assu"e that (1) specified acceptable fuel design 13. limits and design conditions of the reactor coolant 14 oressure boundary are not exceeded as a result of 15 anticipated operational occur ences and (2) the core 16 is cooled and. containment. integrity and other vital 17'unctions are maintained-in the ev nt of pos ulated 18 accidents".. Nith respect to of site "ower, GOC-17 19 also recuires that there must be "two physic lly 20 independent circu's... designed anc located so 21 as to minimize to the extent practical the likelihood 22 of their simultaneous failure under operating and 23 postulated accident and environmental condt'ons".

n add'on, there must be provis'ons

""o minimize 23 the probab'lity of losing e ectr'c "ower f"om

1 any of the remaining suppl'es, as a result. of, or 2 coincident with, the loss of power-generated bv tne 3 nuclear power unit, the loss of power from the trans-4 mission.network, or the loss of power from the onsite 5 electric power supplies". At this time, offs ite power is available 7 to St. Cucie Plant from not two bu" three separate 8 240 kV transmission circuits fron "-lorida Power 9 Light's Midway substation ten. miles to,.the west. 10 The transm'ssion system cons'sts of three separate 11 circuits,. placed. parallel. o each other, which are, 12

designed, nd constructed, to assure tnat each cannot 13 physically interfere with the othe".

Over the Indian 14 River, the towers supporting the separate lines are 15 spaced 200 feet apart. They rise 173 feet-, holding 16 the conductors 153 feet above the river.. Tower 17 spacing ke ps the conductors at least 90 feet above 18 tne ntracoastal Waterway and Gl feet above water 19 elsewhere. Each circu't conductor over water consis s 20 of one 3400 kcmil ACSR/AN wi e. Over land, the tr ns-21 mission structures for the separate lines are spaced 22 126 feet. apart'nd rise 60 to 80 feet above grade. 23 Tower structu es on each line are spaced at 660 foot 24 intervals, except where road o" "a cross'ngs ecu're 25 greater clearance. R'-ht-of-way easements are 1200 feet'

1 Each circuit conductor over lani consists or two 1691 2 kcmil. w'res. Each, circuit is sized "or 100,percent 3. of one unit. output, or 1000 MVA, which is. 'n excess of 4'00 times. the emergency shutdow~ load oz the.unit. 5 Electrostatic shield wires and other lightning protection 6 equipment are provided at each tower as recuired. The design oz St. Lucie Plant also provides 8 for the independence o powe supplies so as "to 9 minimize the probability of losing electric power from 10. any of the remaining, supplies. as a result of, or coin-11 cident widow, the Loss. of" one.. Each un'~ is prov'ded 12. with two start-up transformers. Dur'ng normal plan" 13 operation, AC. power is provided. =rom the main generator 14 through the unit's two auxiliary transforme s. Normal I 15 transfer of. power between the auxiliary and sta t-up 16 trans ormers would be initiated. by the operator from 17 the control room. Zf a ma'n generator should trip 18 unexpectedly, the auxiliary AC load t=ansfer from the 19 aux'liary trans ormers to the start-up trans=ormers 20 would be initiated automatical'y by orotective re y 21

action, thereby providing su ficient ofzsite power to 22 safely. shutdown or mitigate the consecuences of a 23 design. basis accident.

Of site power, in such case, 24 would be suppl'ei from the t nsm'ss'on sys em o" the 25 other operati. g.St. Lucie uni". houli oz-s ) te Dower

1 not be available from either o tnese

sources, suff'.

2 cient power to accomplish-a shutdown-would, automatically 3 be. provided by the onsite: diesel generators. Physical separation,. of transformers and trans-5 mission lines and flexible,'utomatic switching arrange-6 ments are utilized to orotect against the simultaneous 7 loss of any two sources or powe (unit main generator, 8

offsite, and onsite) to safetv related 1oads.

in 9 addition,- the onsite sa ety related electric power. 10 system. for each. unit. is. separated into two redundant 11 and. independent trains, each with a diesel generator. 12 E'ther train is capable of assuring a, safe unit shutdown. 14 The Yidwa Substation The Midway 240 kV substation is presently con-16 nected to the north by two 240 kV circuits. to ~<alabar '7 Substa"ion and from there by two 240 kV circuits to 18 Brevard Substation which provides ccess to gene at'on 19 at Cape Canaveral

Plant, Sanford Plant, anc also 'nter-20 connections with Florida Power Corporation, Orlando 21 Utilities Commission, and Jacksonville Electric Authority.

22 Two 240 kV circuits connect Midway Substation to 23 the south with one c'rcuit. going di ectly to Ranch Sub-24 staon and the o he= go'ng to 'Ranch Substation via 25 Endiantown and P=at 5, Nhitney Subst tions. Ranch

1 Substation provides access to generation at Riviera 2 Plant,. Lauderdale Plant, Port. Everglades Plant,. Turkey Point. Plant, all of which are on the east coast, and Fort. Myers and Manatee Plants on the west coast. Also included are interconnections to the Lake North municipal 6 system and Tampa Electric Company '(which is also interconnected with Florida. Power Corporation).. 8 In. addition, the 240 kV Midway Substation 9 is connected by two 112 YVA autotransformers to a 10 138 kV substation, also at Midway, which is in turn ll supplied by one 138 kV line to Plumosus Substation 12 to the, south and from there to. the Riviera Plant," another 13: 138 kV'ine, temporarily operated at

69. kV,, ties 14 the Midway 138 kV substation to the Malabar 1'38 kV 15 substation to the north.

This last line. serves as 16 an interconnection with.the municipal generating 17 systems of. the Cities of Fort, Pierce and Vero 18 Beach. In the unlikely event of separation of all 19 the four 240 kV and the two 138 kV lines feeding into 20 Midway Substation at present, the restoration. of any 21 one of these lines would allow energization of the 22 Midway bus and restoration of offsite power to the 23 St Lucie Switchyard. 24 25 S stem Improvements and Modifications

The. growth of any dynam'c system recuires 2 addi"ions and changes. hese changes involve trans-3 mission construction, relaying practices and. operatng 4 procedures ant are designed to minimize. the likelihood 5 of an outage. As a result. of outages wh'ch occurred on April 7 3 and 4,

1973, FPC contracted with Stone.

& Nebster 8 Engineering Corpor t'on to review the Flor'a Powe 9 & Light. Company bulk power system reliability and to 10 provide recommendations

designed, to,improve it..

Out 11 or such recommendations and other 'nternal studies, 12 Florida Power Light Company has implemented nume ous 13 changes to its system since 1973, includ'ng transmission 14 additions wh'ch have strengthened the ties between the 15 southern area (south of Ranch Substation) and the rest 16 of Florida; a second tie to Tampa Elect"'c Company; 17 new transmission lines down the west coast to Ft. ayers; 18 and the new 500 kV circuit across the Everglades from 19

t. Nyers to laude ca e.

Tn addition,'the east coas 20 transmission was strengthenec by re'n orcing old 21

lines, adding new, lines, and rearranging-circuits 22 from the Midway Substation southerly through Lauderdale 23 and into the Miami area.

Two major'dditional inter-connecl 'ns 4 ad30 t I es we e so est b 25 1'shed at San=or" (Florida Powe Corporation) nd a'

1 Bradford (Jacksonville Electric Authority). During this 2 same time frameadditional generation was. added at Manatee, 3 Ft. Myers,

Putnam, and. St. Lucie Plants.

5 Scheduled Im rovements 1978 to 1981 During the period from 1978 to 1981, new lines 7 are scheduled to be. installed which will increase reliabil. 8 ity and therefore benefit the St. Lucie units. 9 In 1978, a new 240 kV circuit from Midway Sub-10 station to Martin Plant,. which is under construction, will, be 11 energized In 1980,. a 500 kV circuit. from. Midway Sub-12 station to Martin Plant. will be energized. and two 500 kV 13 circuits from Martin Plant to Andytown Substation will be I 14'uilt and energized to coincide with the operation of the 15 first unit at Martin (775 MW). By 1980, there will be. one 16 500 kV,. five 240'V, and two 138 kV feeds into Midway Sub-17

station, In addition, at Martin Plant, a second unit (775 MW) 18 is scheduled to go into service in 1981.

19 In 1980, a 240 kV tie between Georgia Power Company 20 (Kingsland) and Florida Power & Light Company (Yulee) is 21 scheduled for completion A new System Control Center is 22 scheduled to become operational by December 1978. 23 0 eratin Histor 24 The Midway Substation, originally named St. Lucie 25 Substation, went into service in November 1965.

1 The. =.lorida Power & Ligh" Company operat'ng "ecord reflects that until the. even s of Nay 16,

1977, no 3.

outage or. any system disturbance had ever caused a loss J 4 of'ower at the midway Substation. 5 Two days prior to the events. of Hay 16-,

1977, 6'he: Florida Powe"

& Light Company Andytown Orange 7 River transmission line had been converted from 240 8 kV to 500 !cV operation, as part or the continuing 9 program to strengthen the system. This line was out 10 'r. service on May 16, 19.7T, in order to complete the 11 fina3 tests of'ts protective-relays. Had this >00 kV 12 line: been in service, the loss of the Turkey Point, Unit 13 No. 3 at. 10:08 a.m. and. the outage of the Ft. iNyers 14 Ranch 240 kV line at 10:24 a.m. would not have resulted 15 in the loss of any system load. 16 A number of independent contingencies caused 17 pari of the system to come down. The principal reasons 18 =or the outage were the loss of Turkey Point Unit 19 No. 3 due to a defective auxiliary relay and 16 minutes 20

later, the r t. ayers

-- Ranch 240 kV line "rom an 21 unrelated phase-to-ground fault. The loss of the Ft. 22 ayers. Ranch 240 kV line caused the system to split 23 south ofHidway, leaving Midway Substation and St. Lucie 24 'Plant s"itchvard energ'zed =rom the svstem to the north 25 of Midway. The sp'it of ":". svstem caused he St. Luc'e

1 Unit, No. 1 to reject load and it was tripped manually 2 at 10:-24 a.m.. The Plant continued to receive offsite 3 power from Midway until 10:38am,, when. the system 4'- voltage decayed to

a. level which caused the diesels; to.

5 'tart automatically.. The Plant continued on onsite 6 power for a. period of. time after the grid stabilized, 7 and at ll:00am, offsite power was reconnected, and. 8 the use of diesels was terminated. Immediately'following, the system outage south 10 of Midway,, the Orange River Andytown 500 kV line ll was'ut. back into service to f'acilitate the restoration 12. of service. At 12:03pm, an incorrect relay operation 13 at Andytown caused the 500 kV'ine to trip. The 14 resulting power surges resulted in the interruption 15 of service from Midway south, this time inclusive of 16'idway Substation, causing a loss of., offsite power to 17 St. Lucie. Emergency diesels were again started auto-18 matically.

However, 17 minutes later, Midway was re-19 energized from the northern part of the system, offsite 20 power was restored to the St. Lucie switchyard and 21 the use of diesels was terminated.

The unit was 22 returned to service in a normal manner, and synchronized -23 to the system at 9:58pm, without incident. 24 Following the May 16 events, the grid status 25 was reexamined, previous studies

reviewed, new studies

1 initiated, and a number of actions taken to further 2.'mprove reliability.. Gas turbine controls. were 3 modified,to permit automatic synchronizing at lower 4-. bus voltages; restoration plans were reviewed and 5 updated; maintenance priorities were set and in-, 6 spection increased for transmission lines; a 7 "dispatcher training simulator"', has been pur-8 chased and is. being used to improve dispatcher 9 or power coordinator training; a new type of fault 10 locating, equipment was purchased for installation on ll key transmission lines; the iMartin.- Midway, 500 kV 12 . circuit. was also reschedul'ed. for completion in 1980 13 instead of 1983 as originally planned. 14 The new System Control Center will allow 15 power'oordinators to monitor relevant parameters 16 such as megawatts, megavars., volts, amperes, and hertz 17'or transmission lines,, generators. and substations. The 18 status of all positional devices such as circuit breakers 19 and switches in the transmission system will also be 20 monitored. All information received from the field 21. will be checked against limits and alarms produced if 22 these limits are exceeded. The power coordinator will 23 be capable of assessing system security under 1 both. single-and double contincency cond't'ons by 2 use of a computer program which is capable or 3 simulating automatically up. to 500 contingency con-4 ditions every 30 minutes. The System Control Center will also provide 6 the capability to analyze ne r term (presen through 7 up to seven days) network conditions, allowing the 8 power coordinators to improve their operating stratecy. All these actions, taken since 61ay 16,

1977, 10 will, make. major improvements to the reliability or: the 11 system 13 Assurance of Electric Power at St. Lucie 14 Nith specific 'reference to Appeal Board Question 15 B.,l.(a), r lorida Power.

s Light Company does not possess 16 the data to compare the assurance of power at St. Lucie 17 with other plants. Nevertheless, based upon the fore-18

going, the e is overall assurance that-there will be 19 electric power at St.

Lucie under both acc'dent and 20 normal conditions: A.. The r lorida Power 6 Light Company 22 svstem, is designed and. operated to 23 take into account the unique nature 2! of Peninsular = lorica and i"s 1 c-r'c grid and to conform to all

2'pplicable. NRC." requirements B'. Offsite power to. St. Lucie is available from-, three. separat 10 240 kV transmission circuits. Each circuit has-. conductors which:, are sized. to. carry the entire output o== one unit.. C. There are at present six sources of power to the. 51idway Substation 240 kV bus. connecting the tnree circuits to St. Lucie. Plant. 12 Bv 1983, there will, be eight. 13 sources of power to the Midway 14 Substation. This assures that 1.7 18 20 Florida Power & Light Company's ability to supply of site power to St. Lucie Plant will not be impaired.

0. There are no c=itca'ly shared sys ems between the

~o St. ucie units. 22 E'. Finally, a variety of significant measures have been and, continue 23 to be taken to improve the reliability of the " ansmission sys em. 25 With r = rence "o Appeal Boa=d Question B.2,

1 and the need, to minimize the probability of the co-2 incident loss of power sources, as demonstrated

above, 3-(1)

GDC-17 will be met, (2) the likelihood of the trip 4 of one of the St. Lucie units'ausing the other to trip 5 is'inimal., and (3) the possibility of a reoccurrence. 6 of an outage similar to that on May 16, 1977 has 7'een, substantially reduced. 8

Further, FPL's evaluation of the system as 9

projected for 1983 and thereafter indicates that in 10 the event the two St. Lucie units were to trip 11 simultaneously,. offsite power will. not become un-. 12 available due to system stability. I ~ r ERNEST L. BIVANS Vice. President STATE OF FLORIDA COUNTY OF DADE ) ss. ) Subscribed and sworn to before me this ~!-~7 Ny commission expires: 1978.. NOTARY RUSUC STATS OR FLORIOA Ct TAROS h1Y COMMtSSION SKPIRSS AUGUST ZQ 1M1 NOTARY PUBLIC P I

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~ae CO Te GEORGIA ~eeeoeovkkc ovacv hler rr era IIECLLO JJtrotae>>4e4 NIECNvkkI 4 4 HOOKON SOS r. FCNNANOCEA 2 THOOC ICTO I EASSLNC NNCOf ~ Sf ~ttiehC ~o eooo 5 HSOC'4( eetf Lk>>4 ~ aLa JJ4>>net (Err INC(SO Io I ve>>L erac I ~ /rlkla ecgoLE 'MIEIS 4 KC(LY ~Ikelaw ~I arel Kevaarl Iaiaaa lave sr rei OLK~ Craeht >>J JIEV lt NMNTNC ~OT44154 Eaar ekwao rkaeaI Ira, MvNM State loafe 44UICOJ T OJJME Ia ~OLAINA IOT COL%clef 'Ori ~ Oeaw J( JJC Ee I UOUNal 0 trl 0 45 (II (2) IS) (~ ) (5( ( ~ 1 (1( CW SNTANA OCACH If.l loNeavla CINSTkL NIVCH (OIS TLINNCN550 Il~ IJrf FLORIDA POWER 8 LIGHT COMPANY PLANNED TRANSMISSION ADDITIONS. THRU 198K AN(LOTS SOIl, Lrarlke'RAN 55( (ON IN loof(NO25( EJIT DCMealtt N~t -<<et~/ IioewN4 Oerroh '44 MIJOEM SEILSI 500KY ~~ RITURE 500kV 240 Kv ~ FUTURE 240kV

rrillrl 135 rr llikv UIK44LLr Eeervto Ieltrr Jt KV ON L25$ w4vei4 vo wrteEoewcf UITcel ~e caela rraaehk IAEICNOAOVNO CASLC TNJIENNSSKNI SCNvCC LOKXN CENISTTKICTKN Ethnaa r(TE ~AVO(NLO I00 OkNTOW COO Eall>>UIEO Ilier OOIUNKN reUV SILO ~Marti4 evot raw ILkaa Oaretv KIKC NNVN OCINAkflNO SLANT Eareoarn w INT NEOJMTTO CILIATTTO t(ANT WMH TAANSICNHJKTION Od TNANSNKSOON YOLTAOC'NANONS SON SWOTATON THAN5IKSSION CWSTNTHSN WITH TNANSFONNATTON CN'NANSNNSKIN VOLTAOC (NS1NSLIT(lON OIOSTATION Ipaflto Nerih td aaKH IUMleltel ~N LNKTCO Of NANSFFONNCN CkdkaTY 240 KV CONSTIKICTION, ISS KV OOCKATION 240 KV CttlSITIVCTION, II5 KV OFCAATION 240 KV CONSTCIICTION, ft KV OOCAATION 354 KV CCNTNRUCTICN. 45 KV CFCNATION HSKV CONSTNOCTVSN. OO KV OFCKACKSN 500 KV CONSTVCTIOJI. 240 KV OFCOATION 441 4 Ork Ek>>red lrvieUA avlk ~WVIMS I 04 04aeo MVTIUL124. a JUI Cae Itear ~leer ooloa IEIEe UMMIVLa Mvala Mae haeeov 4NLN eolkwo real I I lear Mr Nerf>> eteerekf 0004ILLC \\ tact TJONANO NT ~e ea enrrtlIrrrENI 2e are~ / 'I an ~ 0tCO Cktaa LJJ coala ahakllHE ,allaa vasDN MIJNJ I ar io Ialhak dfEtrtJ Nattt LkrC MLES I ~ utrree r rtlTlket eaatl tesoEMT lt5 OM'Uktv 00 04 NO (240 ISSO ~ rl etaec Jrrrtf akkr>> Jete ... L I~ VCAO OCAEM I54 CAE! Itt AVON Okkt ~ 4 re OMEre Entfrdtft N v fr writ Drr ee It>>aloe SL (2(OC 111 ten/4 IEME>> ~alelo>> ~ CC NUITIN 5UO I4Jr detttedttC I ~ ~>>\\JIVE 4 rrrrl 4 ~wflICV eahll Jekvle ralrhoka kea OCWIIrr war NIVICNA454 Kltraah OEIC 4 WOITN III IN erie Car vrJf/t ~a>>oat t ~DIC rkara ff HICKS II'if La IL VHC (thea Cree I 2 CTS. T tl evlat ~aloe Elliao Narra I ale ttk",4 ALABAMAJ ~ ak t CO II~ Ir tlerI0 ~ ~Lk.eto il~ eve ~eattvaac a llah ahlk Eef d rifi'tk frri de ,'/ Ni IO kLaei fakrr rtir hero>> gWhnek 4040 NECKS ~E rlaat Irk>>4k IOCllvl areLEr rri>>.*tr.la oeaeo ~ Dhkrlr4a>>0 Eaevoh Lhl (HIST KISS ealvke Lvtaae ILJrro I srtat e ~ 4 I refteter iv War akae aka rhkk J40 ~llawa ~ Vrerev~ ehhraev~ Ll eeaeaa CHUENJWHATEHEC, ~aroe raeaa ke(an 'vv 4 rv 'htk ekakvw n 3 It ruNe 4<<r Decit ollfW ol UILLhel tarot aea4 I GULF OF arr Laaa ~ weal ~ ~0KOIIU 4(ppMvhew~eooo IO eloeooo ~eIAI CJI ede>> LANSINO SMITH Jkkrea. SEC ~ ~I'M 4040 r E4 Ire 5CHOLC OO NJV vl'oeh 4JIIEI I Jedek(A NIJC IrlJOE IIV EVIH raklka ~ 00040 aavN IIV>>0~ 0 I edlka I k rv I vvrIrr00 HONCSTCAO 5554k rkraoa avv COC 5 CUTLCN 244 ( ~ ~ rer ~ TakeCT eONT 2014 S . 4JNNNV0t . FOIT CVCAOLAOCt ISO(.S I I hoaaeee IEJce ~ove svn v IILC aria vaW ~eovC 1 SC JOC Ia~ ~@>> 4$>> O QOS CITY OF KCY NCST lit STATE OF FLORIDA ~~lsf~ ELECTR(C SYSTEM'AP PREPARED BY FLORIDA POWER 8 UGHT OQ 'I Io lo lo 00 lo 12 ~ SI 11 IIJIAw hatt ~1 ENff(TH 44000'OISOTCO

UNZTED STATES OF Ai<KRZCA NUCLEAR REG~TGRY COY~ZSSZON Office ol le ~crt, ~tiny 5 ~c BEFORE THE ATONZC'AFETv AND LZCENS'Z fG APPEAL (St. Lucie Nuclear Power Plant, Unit No. 2) in the Hatt r of: ) ) FLORZDA POWER AND LiGHT COK?34NY. ) ) ) ) DOCKET NO. 50-389 AFFZDAVZT OF FREDERZCZ G. FLUGGER i am Frederic!c G. Flugger, Superv'or, Plant 2 Licensing, Power Plant Engineering Department fo Florida 3 Power and Light Company. Yy education and professional qualifications apoear in the'uclear Regulatorv 5 Commission's record of the St. Lucie 2 oroceeding 6 following. Tr. 1310 The purpose of this afficavit is. to respond 8 to auestion B.l(b) conce n'ng loss of all AC powe f=om 9 the Appeal Boarc's Orcer of March 10, 1978 in this 10 proceeding. 12 Question B.l(b) As a function of the cela y time invo 1ved, wnat 14 are the consecuences of a 'oss of offsite power at St. Lucie 2 combined with fai1ure of onsite power sources to sta . on cemanc (i.e, delaved start) No other 17 failure of the svstem (e.p., LOCA) need be considered

in this analys's. 3

RESPONSE

Loss of all AC power is not a design basis, 5 for St. Lucie. Like all other plants, St. Lucie has 6 been des'gned to the single failure criterion, in 7 accordance wi h applicable NRC regulations.. in order =or a loss o all AC power to occur 9 a ter a loss of offsite power, a double failure, i.e., 10 the failure of two independent diesels to start and. 11 supply onsite power, is recuired.. Consecuently, a. 12 detailed analysis of such an event nas not been, 13 performed.

However, assuming the hypothesis in the 15 Board's. cuestion, there are two predominant safety 16 functions to be performed following loss of offsit 17 power'nd failure of onsite power to star (1)

removal, of decay heat

=rom the'eactor coolant system and; (2) removal of decay heat.f"om the spent fuel 20 storace pool. 21 (1) Heat from the reactor core will be 22 transferred to the steam genera or by natural circu 23 lation of reactor coolant. Heat removal can then be 24 accompi ished by the feed wa er provi ded bv the auzil i a 25 fe cwater sys tern

a. c ezhaus ted to the atmosphere bv

1 the atmospheric steam dump 'valves. This process is totally 2, independent of AC powered equipment and components. 3 The feedwater will be supplied by a steam. turbine 4 driven auxiliary feedwater pump, operated with steam 5: from the steam generators. The auxiliary feedwater 6 pump takes suction from the condensate storage tank 7 (CST). The CST. contains a sufficient volume of conden-8 sate. so that as so operated it would allow the unit to 9 remain at hot standby for at least 16 hours EO (2) The loss. of offsite power and the. failure 13 of'nsite power to-start will cause the spent, fueE pooE 12 cooling system to stop operation. The decay heat from 13 the stored spent fuel will cause the water temperature 14 to rise and eventually boil. '5 The water level in the pool will not require 16 make-up for at least. 36 hours.. 17'n view of the foregoing, FPL believes that 18 either offsite power would be restored,, o onsite power 19

supplied, before any safety-related consequences would 20 occur.

/z FREDERICK G. FLUGGER STATE OF FLORIDA ) )'OUNTY. OF DADE ) ss. Suhscrihed and svorn to before-me this day of Ny commission expires: 197'8. MOTAAY PUBUC STATS CP FLORA st LARClf MY'OMMiSSiCil eXPIASS AUGUST 24r SSJ RQNOB) THR'J MAYHAR lG AMLCY NOTARY PUBLIC

FLQRIOA PQV4~a 5 'GHT "QiVPAPZY Dec~@her l!, l977 L-77-380 Off'c o= Hucl >> Reactor Requlation 3, tention: 2 . Gaorqe Lear, Ch'o Oaerat'nq'Reactors Branch..=3 Division of Ogeratinq Reactors O'. S. Hucl a" Raqulatory Comm'ss'on Washinqton, D. C. 20555 Dear >~. ea Re:: 2'lorida Powe>> G, Liqht. Company Doc.'cet Hos. 50'-250, 50-251, ance, >0-3'35 Racuas~ for Tnformation The glori a Power S L'qnt Company response to you= latter of October 5, l977's at ached.. Cl~~ifyinq info~ation obtained at, a Hovember 8, '977 meet nq w th me+wars o the HRC staff has bee.. used in pr parinq this response. At the meetinq, a revised dua data o= DeceMi er l5, l977 was astabl'sh d.

n the cont~at. of the attached mater"'

we da 'ne Power Systmt Stability as that ai -'.ibuta of a svs om or "a of a system wn'ch enables it to cavaloa restorinq forces acual to or q=aatar thaw c s urbigq forces so as to restore a s ta of acuilibrit m. Very t= ly you=s, Ro = - =. Uhri Vice President ttachmant ~ l/>> J pgs 0 O cia 1 1 v Sar 1Qp'obert owanst 'n, =s-ui=

ATTACR~iVT'LORIDA POWER &'IGHT'OHPAiPl DOCKET HOS. 5'0-250, 50-251,, & 50-335 iVRC'EQUEST'OR ZHFOB~TZ'ON SYSTEM DZSTURBAiVCZ (5/16/77)

QUZSTlON So that we may better understand the causal relationships between the events that occurred on. Nay 16,, 1977', please p ovide ihe following in ormation: A time trace of.the real power loading on the rt.. iMyers-Ranch 240kV line for tne time oeriod 10:08-10:24 am;. 1.2 The. normal rating of this, line (i', KTA); 1.3 The long time and. short t'me emergency raiings; 1.4 Zf the ratings are given in Sl, indicaie the oower actor to which they apply; 1.5 The. PiA load, (or the power: factor) on the line when it relayed open; l.6'f the information in. Items l. 4 and. l. 5 is not available,. provide power factor or eauivalen< information at ooints as. close. to tnis lire as available; and 1.7 The line loading information (power, power actor, etc.) on this line for eacn occasion in ihe pas-when i" re-. layed ooen.

RESPONSE

1 This 1'ine, is not equipped with instrumentat'on from which to obiain a time trace of real power load'ng. 1.2 The normal raiing is 1010 amperes continuous, or 420 bGTA at 240kV. The conductor is 954iMC~ ACSR. 1.3 The continuous rating of the 1'ne is 1010 amper s, based on a conduc or tempe ature of 75'C with an amient of 25'C and, l. 3mph wind. The. emergency rating is 1260 amper s (524 HVA 9 240kV) based on a, conductor temperature of 100'C with an ambient of 35'C and 2mph wind;. The. time limit is 10,000 hours over the life of the conductor to restrict the, loss of tensile st=ength io '%. Yiith a impi wind nd 35'C ambient, ihe conduc"or can carry 2000 amps wi-hout exceeding the 100'C conductor 'mitation. The sag for a 650'ypical. span is 10.5 feei with a conductor temperature of 60'r, 16.5 feet w'th a conducto-temperature oi 1,85'P. 1,4 Ratings were given in ampe es.

1.5 This in ormation is not ava'lable. l.o The combined. NW load. on the Ft. ayers-Ranch. 138kV and 240kV'ircui s can be determined with re sonable accuracy by adding the- ""instantaneous" cnange in t'e line flow on tne TEC ties-, the. change 'n generation on tne west coast plants,

FNl, FN2. and NTl, and the change in load.

The. change in transmission losses is included with the. load. From these. changes-, tne flow west to eas on the Ranch-Ft. ayers cir-cuits is: found to be 595 NW. "rom, past history of the division of load, the NW. load, on the 240kV line is estimai ed at 420 i~PÃ.. The automatic logger of the West. Palm Beach Supervisory recorded the following events: 10:08:29 10:08:39 Frecuencv decl'nes Ranch-Ft.. Myers 240kV line exceeds amp limit of 959 amps 10:09:24 Ranch-Ft.. Hyers 240kV line exceeds MN limit of 418 NH 10:09:39 Ranch-Ft. Ayers 240kV line exceeds Var 1'mit of 147 10 09 54 Ranch-Ft. Ayers 240kV line watts normal (less than 418 NN) 10:0'9:54 Ranch-Ft. ayers. 240kV line Va s normal (less than 147 MVAR) 10:10:09 '0:10:39 10:10:49 10:16:24 10:24:01 Ranch-Ft. ayers 240kV Frecuency normal leone exceeds Var liimi" Ranch-Ft. Nyers 240kV 1'ne Vars normal Ranch-Ft. Ayers 240kV line opens Ranch-Ft. ayers 240kV 'ine exceeds wat limi'he oscillatory nature of the alarms tend to indicat that the loading was near the alarm se+ points. it can be con-cluded f oil the above that, at the time of ipp'ng, "he line 1 oad was in excess of '8 ~~W a~~d less c'"az 1<7 qVgq. The =or" ayers-Ranch line ripoed at both ends wi"h a ground pilot target at Ranch and a Zone ', and ground. 'nstantaneous targets at Fort Ayers.

Broward, iÃidwav and Ringling oscillo-grapns-recorded a phase-to-ground fau' a

this time. The R'ngling oscillogram ind'ca ed a "B" phase-to-ground f'ault. The attached oscillogram rom Ringling sho~s a discrete step

change in curren+, indicating a fault rather than an over-current.. The oscillograph is

a. 32 channel

machine, but due, to p'ay hack 'imitations, the output is printed on tnree separate'ages.

The following attachments, are included to document the data and conclusions: Cha,ts of tie flows Char s of generation of FNl, FN2', NTl Char s of frequency at Ft. Nyers (to show high frequency ollow'ng the tripp'ng and explain the load rejection o the pla. ts). Oscillogram fr'om Ringling which shows that the system was not swinging wildly but relat'vely stable following the fault. A simplif'led, schematic. of the central portion of the FPL system to facilitate following the events. 1..T iVot available.

T ~ /

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~ ~ << ~ qr Q( > ~ .: J<>>>( 'ilQ'IAY> OKE:CHOBEE= '" '~li LCHEST" AO. '1ILr C? EST 10. ATL<<t fTIC. BELLE GLAD'2'BfS-.:f 'iOH"T "'OP. t. "IOO'3 P AHOK+~ ? LrJ!I':)8US RIVIERA . L()2IDA ST:-EI'()UTH RAY'<<.'i'.) ='R I3 > t r-EL YI '. '~. t;i YAI'IATO YA>A>() YA."ATO YA.'rAT() 'r I~ ', IBl.i t W>> L()q r QA ST,-=r r P t I I ~g r Lr '<>. g:.I:) IOY f) ~ r -ri/ cff ';) i h.) 0</I ~"-:iV ') =) t )'i "Ii '-'I'~SS 69/138KV !)CR LO'ff'IR PRESS a"-Ia)10 4661'f65'16 "CHARf0 tTc. I ST<<.TI:)i-S:- i VI'=. STATION Scsv I.C-I g832+3 92 ) 2/S~.')I 138ri32c41'- (:-'Of UX(,'/3'.:.: SRO .t.~D f Lt:-:;=.;-;iT T.4 Tr '.)': S='-'V i C-. " STATIO<<f ScRVICE ST<<TI')I'>> 2F.+ ~t.C = 138iff3>434 BROc< /SPOf< BP.()'IIARD I Ll~tt~ P()T STATIOH SERVICE 138'i'f32441 HYP()LUXO/3N)if I TRIP C[RCUlt , ~ *' I TJTIQl'I 5 g / IC L ~ I

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QUESTION 2 Please", provide: the-following; information: 2'.,1 If, the likelihood" of a" causal relation between the F". Nyers-- Ranch line relaying and'he Turkey Point, Unit 3. scram. were

conceded, would'. FPL,'continue to represent; that the two.

events constituted a double rather than a, single contingency? 2.2. Provide a discussion of the bases or your response to Item 2. l. BZS?ONSZ 2 If. a hypothetical causal relation between the Ft ~4iyers-Ranch line relaying and the Turkey Point. Unit 3 trip were assumed, it would. appear,. by definition, that this would constitute. a singl~ contingency under. Classification Type: 1, of AiNSi N41. 2, Section

5. 1..

FPL', howeve , does not concede he= likelihood of such a relat'on. There have been Turkey Point. unit trips 'n the past and they have never led to the loss of a transmission line.. Similarlv, the available data. from the Hay 16, 1977 disturbance show that the Ft. Ayers-Ranch. line did not relay because of an overload condition caused. by tne Turkey Point Unit 3 t ip. The fact that these two.events occurred., approximately 16 minutes apart is additional indication of their independence.. We have concluded that the Turkey Point trip could not, by itself, have caused the line t'o relay. Numerous contingencies with respect to the condit'on of the power grid would have to be assumed in orde to "'create" the hypothetical "worst case" situation 'n which a causal relation between the events would become at most a remote possibilitv. The fact remains that during the i>ay 16 d'tur-

bance, there were two "'s 'nct mal unctions; (1) the loss o" Turkey Point Unit 3 caused by a defective auxiliary relay, and (2) the loss of the Ft. ayers-Ranch 240kV line caused by a ault to ground from an undetermined origin.

QUESTiON 3 Shat. stud'ies-were'ade to determine the condition. oz the. system; with the outage. of Turkey Point Unit 4 and the 500kV line: orior. to: the shutdown. or these. two . acilities? Specifically, 3'.1, Nhat information did. the studies-orovide relat've to stability limits. and other, system limitat'ions'? 3.2 Zf the studies, were not made, why not? 3-3 if they were made and did not snow the vulnerability o the system ta

a. failure, why did'hev not?

3.4 i they were mace and did show the system vulnerable o a failure, what precautionary measures were adooted? RESPONSElorida Power & Light Company conducts transient stability studies as par" of the: Floz'ida Electric. Power Coorc'nating. Grou" (FCG) in order to assess the ezzects of the various contingencies listed in SERC Guideline Number 3, "Criteria for Reliability in System Planning." System Operations maintains. and'ses a current load flow model., System Planning has also just implemented an in-house stability program..

However, these are batch programs run on corporate computer facilities and turn-around. times of 24-48 hours are not uncommon.

Therefore, while these are helpful for short-range cont'ngency

planning, they offer little or no benefit under emer'gency conditions.

Installation of the System Control Center in 1978 will provide capability Cor real.-t'me load,flows, contingency planning and security ana'ysis. A status report of the reze enced '973 report oz FPL's consul-tant to the Public Serv'ce Commission is attached and will be referenced again in tne response to oaragraph 6. The latest FCG study, "Off-Peak Transient Stability Stucv =or 1977," considered the loss oC Turkey Point Unit 4 w'th a frag-mented. sys em This fragmented transmission system simulated the s'multaneous removal oz th ee major circui s: the 500kV Aadytown Orange River circu'" (-;PL), the Midway Xndiantown 230kV circuit (FPL), and the Can ral Florida Cle~ont Eas 230kV c'rcui" (-PC). Svstem recoverv was nodal anc no 'oac sneccing or relay ac 'n was observec. There was no reason to believe that the system coulc not be ooerated satisfacto"ily uncer the Hay 16, 1977 conditions. in any such tests several key points-are examined. These include: did any generator pull out of syncnronism, d'c transmission lines relay, and was any customer load shed'?

indeed, from the events oz Nay 16,

1977, we know that at 10:08 a.m.

following the. sudden loss, of, Turkey Point Unit 3, no generator pulled out. oz synchronism,. no. transmission lines relayed, and. no: customer load.. was. shed.. The stabilitv t sts-made. did not. show the. system; vulnerable. to a failure. The-sense-of paragraph 3; appears to assume tha't long-term dynamic stability programs are available to allow; simulation of the probable status of. a system for 10,. 15, or 20 minutes oz eal-time, following a disturbance. The fact is that. no such program or programs are currently available. 2'PL,, with others, is cooperating with EPRZ and. General Electric in the-development of such

a. program.

REPORT A JY/T-1-77'of 4 STATUS OF RECOM+XNDATIONS OF STONE: &; WEBSTER ENGINEERING CORPORATION OK FPL, ELECTRIC. POWER SYST~~'ISTURBANCES.'PRIL. 3'ND 4,. l973* (FROK STONE' WEBSTZR REPORT.'O FPSC) As a result of'ur findings, we make the following recommendations,: 2. As. Long as the Florida. companies must trip. units auto-mat"'caLly on underjrequency, ZPL should revise.the relay schemes so tha each set oj relays trips only one uni un.less tne total amount. oj generation to be tripped by one. set oj relays is Less than-250 MV. Individual underfrecruency relay schemes. are.installed; on each generating. unit of 250 NN or more, except Putnam.. At, Putnam. one relay scheme encompasses; both Putnam Units. 3'nd. 2.. 2. Zach scheme. as a; minimum should have tvo re Lays. bot'h set to pick up at '$8 cycl'es, vi th their. contacts in series so that both must operate to trip, the unit.. FPL selected a scheme comprising parallel sets of two relays with their. contacts in series to provide both security and; reliability. All generators in peninsular Flo'rida (or tie lines on some neighboring systems) are set to trip at 58 hertz afte a, l2 second t'me delay except for FPL's area east. of Ft. Myers and south of Midway where settings ar 57 hertz (this includes St. Lucie Unit l). Consideration shoula be given to adding out oj st'ep re Lays to ZZS kY, 138 kY, and 240 kY circuits to block recLosing on trips aue to stability svings. As a resul" of studies by Stone &. Webster and. FPL engineers, it was. decided to add ecruipment to sense out of step cond'- t'ons and block recloslng ollowing trip due to stability swings. Approximately forty 240 kV and 138,'<V line t rminals con-sidered to be most 1.'!<ely to be affected: by stability swings have had this equipment added to them. As new terminals are

added, consideration is g'ven as to wnether they should. also have this type of protection included.

2,of 4 On the basis of. further studies by Stone & Webster: and'. FPC, the.. practice of blocking; high-speed reclosing following Zone

1. trip was-adopted for all. 240 kV'ines=

south. of Ranch. Substation, and the-138, kV lines;. at the. respective substations. with. 240, kV. This has been completed. A. decision was reached recently to, extend this blocking practice. to the remainder. of the trans-mission system. This would include all 240 kV line. terminals, 138 kV line. terminals at 240/138 kV substa-tions,. and. 115'V line, terminals at. 240/llS kV subs a-tions., PPT should thoroughly z eviev i s relaying phi losophy and protective schemes to ensuz'e that this impoz'tant pazt of its system design provides the highest possible degree of re liability and. securi ty. An extensive review-of'PL. current. practices was con-ducted. by Stone & Webster and. FPL, engineers. Results were. publisned February. 22, 1974 and adopted;. While there was no wholesale retrofit, except as mentioned. above, all new installations and the. old ones-rebuilt follow the new philosopny. S. Provisi'on should oe made to establish. and. maintain digital load floe. and. stability models of'he c"lorida. systems representing current conditions. These models voul'd provide day-to-day information, to the operators on, stability limits and other system Limitations imposed by construction delays or. equipment ou ages, System Operations maintains and uses a current load Liow model., System Planning has also ust implemented an in-house stabi,litv program.

However, these are batch programs run on corporate computer facilities and turn around times of 24-48 hours are not uncommon.

Therefore, while these are helpful for short range contingency

planning, they offer little or no benefit in, erne gency conditions.

installation of the System Control Center in 1978 will provide.capability for real t'me load flows, contingency planning and. security analysis.. 6. Stabi lity and load f lou " udies should oe conducted for 1974 and E97$ conditions to checic the e fectiveness of coz rective measuz'es such as additional load sneddino, blocking of reciosing, ana o 'hez aspects of l" ne relaying and. system design. Stone & Webs ez= was retained to conduct, studies of 1974 and 1975. Analysis of these studies together with studies conducted, by FPL provided operat'ng guidelines or 1974 and. 1975;

3 of 4 7. These stud"'es should include of, -peak as ve H as peak load condi "ions... (See. respon'se to number 6..) 8.. 'PL should continue to put a high priority. on transmission. addi tions to strengthen tie's between the southern area and the rest of the Florida systems-. Construction of'rans-mission iines in. southern Florida has been delayed by environmen al considerations and labor-prooblems. Any further" delays vill affect the. reliabi lity of the FPL sy stem. FPL has continued to place a high priority on the expansion of, its bulk transmiss'on., facilities with the major addi-tions from: 1973 to date as follows:. Placed Zn. S'ervice Durin 1973 Ft.. Myers Ringling ~2, 240 kV Ringling Tampa (TEC) ,,2, 240 kV'anford North Longwood (F?C) 240 kV Placed in Service Durin 1974 Midway -- St. Lucie 240 kV Broward Lauderdale 52, 240 kV Broward - Ranch -2, 240 kV Ft.. Myers Lauderdale 240 kV Bradford Normandy (JEA) 240 kV . Bradford - Palatka 240 kV Placed Zn Service Durin 1975 Ringling Tampa t2, 240 kV (thru Manatee) Plac d En Service During 1976 Dade Tu key Point 240 kV Dade Lauderdale 240 kV Davis - Flagami 240 kV Flagami - Lauderdale 240 kV Baldwin - Duval 240 kV Ringling - Manatee ',2, 240 kV Bradford Duval 240 kV Flagami - Miami ", 240 kV Circui"'ea" angement Placed ~ n Service Dur'ng 1977 to Date Ft. Mye s Orange River. =,".1 .-'.2, 240 kV Andytown Orarge. River 500 kV (Converted from 240 kV) Andytown. Broward 240 kV Andytown Lauderdale 240 kV (2 circuits) Rancn Pratt &. Whitney ~1. & 52, 240 kV (increase Capacity) Midway Prat &. Whitney "-,',1, -2, 240 kV (increase Capacity)

4 or 4 9., g strong SOO kV'ystem vi th. ies to Georgia, which is. no+. in. the;. pl'arming stages, should. be pu sued. with due. regard: o devel'opment. of'roper sys ems-. vi.thin'Zorida. and.. Georgia; in conjunction: vitn. interstate ties'.', A. strong. 500 kV system has; been.

a. part of FPL,'s; plans.

for 10'ears' S'00 kV system was reported in the 1968'. National Power. 'urvey (1968 through 1990) by FPL. This included 500 kV Crom Miami to Ft. Myers to Sarasota:, plus 500 kV from Miami to Midway to Brevard to Bunnell., A joint study was made in 1972 by the Planning Subcommittee of the Florida Operating Committee. which con irmed. a coordinated 500 kV statewide expansion program through 1990., The; statewide 500 kV system i.s being reported annually to the redera3: Power Commiss'on. unde Order 383-4 (SFRC-TAC). The 1973. filing indicated.,a 500 kV sys em from'urkey Point to the Georgia line, tentatively by 1980. Xn 197'5, an additional joint study by the FCG'lanning Committee through 199S was made to determine effec"s or changing. load 'conditions and altered generation expansion plans. The 500 kV system completion need to the Georgia - line from South Florida was shown to be 1986. 10. Di scussions between Southern Company. and the Florida companies concerning additional'40'.kV interstate ties shou d be gi uen urgent. priority vi n the objecti ve of increasing-the emergency interchange capabili y to Floriaa from Southern Compariy to at Least 800 iMV by 1978. This vould allot. Loss of 0he la gest unit vi hout causing isolation of Peninsular Florida. The addition of these 240 k Y Lines should be. considered an interim measure and should not affeet the longer range plans for 500 k Y ties. Negotiations with Georgia Power Company are continuing Cor. a 240 kV transm'ssion tie to be in service in the summer of 1980. Tentative agreement has been reached., FPL has authorized projects for the timely'ompletion of this interconnection.

QUESTION 4 Please provide. the: foll'owing information,: 4..1. The freauency versus. time. information at the-. Turkey Poinc. bus. and. at the-St.. K;ucie-bus at leash to tenth af. a: second. accuracy for'he ten second period ollowing, the scram: of each reactor; and: 4.2 The. same information, requested in (4 1) 'ncluding blN pro-duction. versus time and,iWIAR production versus time. at the Turkey Point bus and. the St. Lucie. bus for: the time period. 10:08 to 10:24, and shortly before 10:08. This information may be provided on a coarser. scale.

RESPONSE

4 The continuous high; speed. recorder installed at: Turkey. Point. records. bus frequency. Since other-parameters are related. to generator output, only bus; frequency can be provided.. No equivalent recording equipment is 'nstalled at the St. Lucie Plant. The following tabulation indicates frequency. on the Turkey Point. bus to which the nuclear units are connected. The, time is in seconds after the reactor trip. Frecuency is in, Hertz. Freauencv Frecuenc 0 ~1 2 3 4 5

60. 00.

59.78 59.72 59.78 59.66 59.60 6 7' 9 10

59. 60 59.54 59.70 59.72 59.72 The following tabulation ind'cates f equency on the Turkey Point bus to wh'ch the nuclear un's are connected.

The time is in minutes after the reactor trip. Frequency is 'n Her z., +ime Freauencv Time F eauenc 0 1 2 3 5. 6 7 60.00 59.94 59.76 59.82 59.81 59.83 60.00 59.98 8 9 10 11 12 13 14 15 59.96 60.00 59.99 59'-. 98 59.97 59.96 60.00 60.00

Charts oz. switchvarQ voltage vs. t~~~e for Tur!<ey Point ant St Z,ucie: are attached..

F - e ~ IIl ~ I 'I ~ ~ I I ~ I I I l ~ \\ '1 ~ I ~ ~ ~ I ~ ~ ~ 'I '1 I I I I I ~ 1 I ~ ~ I ~ ~ i I I" ~ I ~ ~ I ~ ~ I I I I ~ '1 1 'I I. i I. I I ~ I I I l I il I i I ~ i I ~ ~ I I I I I ~ I ~ ~ I I I I ~ I ~ ~ I I I I, I ~ I ~ I ~ ~ ~ ~ I I I ~ I ' I i I ~ ~ ~ I

I I I I / f I f l I I i ~ ~ I I I I I I ~ I i I ~ I ~ I I I I I I I I 'I I ~ I i I I I I 'II I .l / / I / ~ I / I I I I ~ I / i I i / / / I // / / / / ~ I' / ,~ 7. a 4

10,10 eP I '1 <e>> I e V ~ I 1 'I I O.i]lf f I i l'0 I ~

~I ~ I I <I 'l

---

.2 ill---~

II' e< ~ ~ Vf ~ '. ~ * .I I ~)J I TT 3001 0'a Ql 0> M2~i e l Vee ~ Q ~ er) ~ ~ 1 I U r'i-, r ~no I i'.I l) ~ I ~ ~ ~ I 'l

-L'asl I

.tYc"t 0 .-1 Q.l) 3<"= j~ 1 14 ~.f-v ~ ~ U f f - -I I-~ lib-'-.'-I Oa I 0-i gt GNM ~ ->>.9. II~

-50~ I '~l]. 1~0,< I l. I ~ I "1 ' PI<II r ,II IIII<. I"Q" F 0- "'" 3 ~0-f~ I '9 gt QUs'VO TS. TI i Self.ctnl'-'C.gn)t --Ph-Ph~- ffnf,at-f': "..I 'I'0"'i3 ".1. 0-p-< 4 7 LLL+++ h-t I r0 l 0;++ ~ I' ~ I ~ I ,L.. 4 r'IIAII'<I<

vi AC

~ ~ ~ J 6 IIAAPIIICfiONIIIOIS COI<POIIAIIOII'OuflAIO. NLSV Yf<f<K ere<<<<1u 1 y/ I

QUESTION 5 Provide: the. following, infornation: 5' A; clear definition of FPL.'s; system =equirements orx. spinning

reserves, distinguishing between tie-line: imports; and. spinning reserves;

and, 5.2 A copy of the guidelines established by the Operating Committee of the 'Florida Electric Power Coordinating Group relat'ng to practices and procedures.

on spinning reserves,, load shedding, and emergency operating procedures.

RESPONSE

5 FPL's'ystem requirements on spinning reserves are dezined by Section III of the FCG. Operating-Committee Handbook. The spinning reserve requirements established by this section are. conservative; with respec." to NAPSIC Operating. Guide No. 10 for Integrated Systems. One copy each of Section II and VII oz the FCG Operating Committee Handbook are attached. These sections cover spinning

reserves, load shedding and emergency operating procedures.

OPERATING. CONNLTTEF HANDBOOK

ZZI.-j 10/14/76 DAILY OP"BATING BZSZRVK 1 Dailv Operating Reserve; is that amount of generating capa-bility and/or; equivalent load relief in excess, of fore-casted daily peak load'hich. is availab3;e. to-provide. for. load variation and forecast. error, frequency =egulation, area protection and contingencies such as loss of genera. ting capability. It. consists of the following components: A Soinnin . Reserve* 'Zhe term. "Spinning. Reserve" when. used: herein. means the. reserve generating: capability connected. to. the.- bus; ready to pick. up load. immediately, and: capable: of becoming fu13;y appl'icable with a frequency decline to 59.5 Hz. (It is. recognized. that this def'nition. of Spinning Reserve di fers f om th t of the, I;.,Z.Z.E; ) (1), Steam Unit Due to special. operating cond't'ons 'n. Peninsular Florida, no more than 16.-2/3% of the Continuous, Capability of a steam unit msy 'be counted. in. comoutinb t~e system Spinning Reserv e. (2) Combus ion Tu bire Unit (a) A por ion, generally 30%, of the base rating of combus 'on turbine genera-t'ng units may be counted as Spinning

Reserve, provided, 1) the. units a

e operating in'-their automatic control

mode, 2) the units are equipped with solid-state underfrequency relays in their ramp rate control circuits to change thei-response rate to erne

gency,

3) tests have beer made to demonstrat that such amount counted wi2." respond, ard. become fully applicable with a frecuency decl'ne to 59. 5 Hz, and.

4) unit response is equal. to, or fas e

than., the same amount of steam unit; capacity as defined above.

(b) The capac ty between base and. peak 'oad: of combustion-turbine-units may. be: counted. as. Spinning Peserve. pro-vided., l) the units are; ecuipoed with, solid-state unde@frequency relays which wi3.l automatically change: the operating. mode from "base" to "peak"'hen the fze'quency declines to 59.9 Bz",, and

2) unit resoonse is equal to or faster than the same. amount oz steam capacity as dezined above Since contractually intezruptible load, when it is interrupted, releases generating, capacity that is instantly available,

a. paz ic'pant may place such load on under=recuency relav control and, count the amount of.this..load so placed as Soinning Reserve; up to 75% of, his allacation.

Solid-state'elays will'e employed. for this application in order to minimize time delay. They will. be set to disconnect the interrupt-ihle load at 59.7'z. Use of this provision: by a participant in no way ch nges h's zesponsi-b'lity to provide his share of Spinning Reserve in. an emergency. interruptible loads which aze utilized as part of the Operating Reserve cannot be counted as. part-of tne load shedding obliga-tion. Su olemental Reserve The term Supolemental Reserve w en used herein means any generating capability and/or. load relief measure which.'can be maae fully applicable within 30 minutes or less. lt includes', but is not limited to'iesel un'ts, combustion turbines, 'ntez-uptible

loads, oad relief measures, and, any increase in gen-e at'on that may be obtainea from a genezat'ng unLt 2.

Zn normal ooeration the Daily Ooezating Reserve should be main~ '"m by the combined systems at a value equal o, or great r tnan, the sum of the Peak Capability ratings of the. two. largest generating units in serv'ce. Spinning Reserve should be maintained ecual to, or great

than, the Peak Capability rating cf the largest gen zat'g un't 'n service o allo~ the combined systems to zecove= '". an ozcerly manner

= om the instantaneous loss of such la gest unit. The ba'nc'of "he Da'y

ZZT-3 l0/l4/76 Operating Reserve; will be Supplementa t Reserve-.. Follow-ing the;, loss of

a. generating. unit, Supplemental Reserve should be converted to Spinning Reserve, i= required. to.

res ore the. recommended level oz Spinn'=ng. R serve,. 3.: The Daily Operating Reserve: and the Sp'nnirg, R serve requirements-,.'the minimum values specified in Para-" graph 2), should. oe allocated among..the. par ic'pants in proportion to each participant's maximum demand. for the preceding. year and the Peak. Capability of his largest unit. =ifty percent should be allocated. on the basis-of demand. and 50$ on the basis o the Peak Capability af the largest urit.. (See curren calculation on

Page, 5 in this. section.)

The Daily Oper ting Reserve reauirement and an ecu'table allocat'on. among the. pa ticipants will be a continuing interest. af the-PCG Operating Committee. A, new, alloca. tion w'll be calculated and used when a par icipant's s'ngle largest unit. is ofr line.. 5. The effect an a'participant's ability to maintair h's Soinning Reserve al'oca ion should be f~>> ly considered before. ag eeing to sell po~er to another participant. 6. Protection. of,

a. new un'. during shakedown wil1,. be the responsibil'ity of tne owne Eacn participant Daily Operating Reserve allocation should be available to the other. participants-and. not be restricted by transformer, 'line, or othe limitations.

8. Each participant's Spinn'ng Reserve allocation must be distributec on; enough generating units witr proper governor character's"ics, so that it will. not take a, , fre.uency drop 'n excess of 0.5 H to realize the full bene" its of each participant ' Soinning Reserve. Assum-ing 5% governors, this mears that the Spinning Reserve assigned ta a"y one unit should be no more than l6-2/3'4 oz the Con inuous Capabili y of that unit 9. Reliabl operatior'f the combined. systems. requires tha each participant's d'spatcher know at all t'mes the Con-tinuous Capability rating of his gererat'ng units. Par-ticularly cu ~ag per'ods when forecas"s 'ndic te c ose operating. reserves, the Continuous Capab'ty zatirg az all question ble units should be ver'-'ed by hav these units demons't=ate this. capability befo". the t'me. o the ex ec"ed peak zor the d y.

Zii-4 10/14./7 6 it-shou'd. be: recogn'ed. that

a. deficit.ency in Spinn'zg Reserve:

on. the. combined systems subjects: al3 partici-pants-'ustomers, to

a. risk of interruptior due to under-f equency relay operat'ore Zn abnoxmal. situations where the. Daily Ooerating Reserve and/or Spinning: Reserve of a participant is less than his allocation, such participant will notify the others, giving full details of his operat ng condition, so that they may deter. in what assistance they can malice avai3=

able. to be util'zed. The deficient paxticipant should take such measures that are available to him, to st'eguard. the reliability of the combined systems. This. would include:

1) ourchase from other systems,

2) inte rup-t'ng some-of his own load, or 3) installation of under-frequency relays set to'trip at 59.7 Hz, an amount of, load equal. to the: participant's. shortage in his Spinning Reserve. allocation.

Measure 3), known. as, Step. 2'ero (Step 0), is; to. be used; only in" extreme emergencies'here" no" other. alternative is; available"and. solid-state relays wzl3'. be employed to maize time delav., ("f Step 0 is.

used, the oad. so assigned should not result in a: reduc-tion in a system's proper share of the 'automat' 3.oad.

shedding, obligat'on described in Sec"ion XZ, Paragraph 1.) Deficiencies in Supplemental Reserve should be covered, by purchase if feasible. Administration. of the Daily Qperat'ng Reserve" formula is tne responsibility Power Corporation. To caxry out. this certain infoxmation is necessary* from ticipating. systems. This information Reserve and Spinning of the Zlo ida. responsibility. each of the par-1s: A. By January 15th the previous year ' peak load. and the Peak Capability of the larges-unit. B. mediate notification of a cnange in rated capability o" a sys"em's largest un't. C. Vo "2.cation when-a syst m's. 1arges unit 's ou o" service. The Daily Qperating and Spinn'ng Reserve w'l be calcul-ated at least yearly and re-calculated as necessitated bv information received = om a participating svstem. When re-caZc~~ation 'is necessary, the new va,lues wil 'e olaced on the teletype "or the disoatchers 'mmediate-use and a copy of "he calculation vill be ma'led "o each o~'he svstems.. (See following page =or current ca'cul-ation wi h largest un'" i. e cn system 'n servic .)'

III-5 10/14/7 5 DAII Y OPEHATfNG AND Sl IN f'IG R'-S'=RYE 4LLUCATIUIS BO'iH TURKFY 'POINT, tIUCLEAR, UN ITS. GN LINE EFFECT.I.VE: AS. OF! 5-3.-76: CAPABI LITY QF'ARGEST PEAK LOAD UN IT. GHQSS. 'lH GROSS Mv<. PERCENT'ERCEHT ='ASED BASED QN ON PEAK. LARGcix LOAD UN I I'LOR I DA PQI'(ER 8 LIGHT i"-O'.IPANY FLOA I DA PGA'EH CQi/PORAT IQN T4>/PA ELECTR!(.'QWPAeIY J'AC.'<SUN V I LEE ELFCTh IC'UTI]OR r fY ORL 4NDO" UT I LET I ES CQ:l'> I SS'ION CITY tJF TALLA+ASbc~ CI EY. OF LAKEL.~<<'0 CITY OF GAINESVILLc C I'fY UF FURT P IFRCF CITY UF LAKE;'~Q~TII CITY iJF VERQ BEACH TOT.A{ I 7400.. 0 3370. 0 1660. 0 I 136. 0 41'3..0 22'3. 0'.18.0 155. 0 59.0 54..0 56.0 4 744.,0. 722 0 527.,0 350.. 0 2.75. 0 327 0 7~.,0 115.0 85.0 38 0-35.0 33.0 2582.0'

50. 19.

22. 86~,

I I ~ 26~ 7'. 70~

2. 80.o I.5 I C.

1.48m I. 05=.. 0..40~

0. 37,

0. 38

~ I CO. 00~

27. 96 20 4.1.~

13 5o~, 10.65, 12 ~ oo~, 4')...2.9 -. I'.4-7. I. 36~ 1.28~ I G3..i%3,~ RESEHyE u~ERA r ING Af LOCAi IQ'< HESEHVE PERCENTAGE .L(h SP I N<<.f NG SUPPf hhlE,< fA{ RLSERVE. RESEHVc ,MA )'( I FLQR.I DA P&jER IGn f CQiIPANY FL'i3R IDA POr<EH CUR POTATION TA'(PA ELECTRIC CU'IPA>iY J AC <SJNV I LL ELECTR IC 4UT;:OI<ITY ain't 4NDQ UT I LE ) IFS Cu>'s I SS IQN Cf fY JF TALLAHASSEE C ITY dF LAKELAND CI'l.Y'F GA INESV ILIc C I rY QF Fi)RT t IERCE C ITY OF LA<" tQRTH C I fY QF VETO 8-ACH TOTAL I 3V.OR 21.63 12 ~.41

9. IR

7. 73 2.21 2.97'

~.11 0.94 O.ao 0.83 CO. CO

5o4, 312 I 79 I 33 112 32.

4'3 31 14 12 12, 282 15o VO 6o 56 16 21 16 7 6 722 232 '~6 90 6oi6 16. 2,1 lo 7 0 6 722 DATE CA{ CULATED> 5-2-7'6

VII.-1 10/14/76 EMZHGENCY PROCZDUP" S eration Durin Declinin " Svstem Freauenc The-reliability or bulk powe . supply within peninsula". Florida is a, matter of vital concern to the elec"ric utilities. serving the area.. Conditions of declining system frequency requir

a. coordinated prog am of emergency procedures..

This, section outlines a."coo~'~ated.. program to-which the: members or. the FCG Ooerating Committee: volun-tarily subscribe. The. individual utilities se ~in@ the peninsular. Florida area are committed: to the design and operation of an interc=w~ected network; within. peninsular Florida wh'ch will.not be subject. to widespread system outages as a consequence of a major disturbance and over the years have developed guidel'mes for its safe and reliable operation. Regardless of these objectives and practices, emergency procedures a e, requ'red to meet conditions such as system seoarat'on and operation at. subnormal frequency.. Coordination of emergency procedures, which include load shedding and power plan< isolation, is essential. Xn the .ev,. nt of a sudden serious emergency, load shedding is used. to: ~ ~ A. Restore the balance between load and gene ation in the affec"ed a ea in the sho est possibl tim and permit the subsequent ret rn to 60 Hz operation, so as to minimize acverse e" "ects on customer service. B..>~n~mize the risk of damage to company and customer facilities and: equipment. It is recocn'ed that the ability to reduce firm customer load in an eztreme erne cency is not a subst'ute for prope" design and good operation. T.t is a measure "o be aken only af er he system has. su fe ed an emergency condition which mav othe ~ise lead to widespread. system outaces.

VEE-2 10'/14/76'mercencv Procedures Durin Oeclinincr System Frecuencv-Zme gency procedures will be-implemented, as ollows: = ewgcp~e 1 From "60 0 "Hz: to 59.2 Hz, all, operating reserves. and. emergency measures; should: be uti1ized to. the fullest practicable extent. The" manner of utilization of these reserves, will depend. greatly on De behavior of tne-system during: the. emergency., In cases where frequency declines rapidly, only that capacity on 3.ine'and. automatically.,responsive to fzecruency (spinning eserve), and sucn items, as interconnection assistance, and, load reductions by automatic. means are oz assistance in ar esting the decl'ne in. frequency. Phase 2: IF the frequency 'decline 's gradual, the syst m dispatcher(s) oz: the system(s) in. tzouble should invoke non-automatic emergency procedu es. This-'ou3.d. include the star ing of gas turbines., interrupting" load., purchasing power, etc. These, ezf'orts should cont'nue unti3 ".e frequency decl'ne is arrested. Generally speak'ng, it: is the-responsibility of the system'(s) in trouble to take whatever 'action is necessary to restore the frequency to 60 Hz,.and the system dispatcher (s) of such system(s) should take the lead.'n taking positive action, describing the trouble, asking for assistance, etc. If his actions do not produce results as

enough, the other system dispatchers may have to apply their judgements in assessing a given situation, taking action, and/or rende ing assistanc w'thout being.

equested. l4o hard and fast.-rules can be made except that all possible cooperation and communications between system dispatchers will oe required. If interrupt'ble loads are counted as spinn'ng reserves they should be capable oz being disconnected from the system by underfrecuency relays to assure the r.removal prior to Phase 2. Betwee'9.2. and 59.0 Hz inclusive, shed with automatic load, shedding relays not less than 10 percent of system load No intentional time d~~ay should, be used bevond that absolutely re-qu'd to void improper e'av oper tion.

ViI-3 10/14/76 i \\ . Phase 3: Between 58.8 and: 58.7 Hz. inclus've, shed. additio~ load with automatic load shedding relavs in an amount. not less thw 10 pe cont of-. system load. existingprior to Pha.se 2. This amoun+ of load, ~: - ~- ':.,should'. be shed.'in two nearly eaual, s,teps a,t .59.8 and 58..7 Hz:. No intentional. time delag , sluuld oe used beyond, that'.absol.utsly-"required f 'to 'avoid imprope rel'ay operation. ', f Phase 4; Be~can 58..6.and'58 5 Hz inclusive,. shad additional p,'aad vie automatic. load she'dding'clays tn an "amount not. less'han 10 percent of the system "load existing prior to Phase 2. This amount of'oad should be shed in two nearly equal steps ~ at. 58.6 and 58.5 Hz. 'o intentional. t~e de'ay shou&~ be used; beyond that. absolutely required.: to-avoid. 4npropex" relay operation ~ 8 ~ 'IMPOR"ANT" NOTE i PHASE 2., 3 AND' HILL HKVE "BEEN ACCOMPEiISl'ED. AUTOMATICALLY A~'THIS POINT THE DISPATCH="RS MUST. RECOGNIZE TENT >I-iE IS RUNNING OUT AND T>~~ 7 MINUTES OR LESS TOTAL ELAPSED TIME ES ALLQYl D FOK OPERATION AT PREQUENCIZS BETWEEN 58 5 HZ AND 58,0 Hz. EV HY EFFORT

MUST, BE HADE TO (1)

ARREST THE PREQUEL-RCY DECLINE TO PREVENT THE GENERATORS PROii BEING. - AUTOMATICALLY ISOL %TED AT 58. 0 Hz, AND (2) TO RETURN THE PREQ~~CY TQ ABOVE 58. 5 Hz'O PREVENT'HE, GENERATORS PROM BEING T~~PPED AT. THE END gP 7 MINUTES ELAPSED TIME IP OPERATION CONTINUES M~ THE ~ RANGE 58. 5 Hz 58. 0 Hz. Phase 5: PlLB,se 6: At 58. 5 Hz, if frequency is declining, take any

action which can be t ken at this point to

.arrest frequency decline. This m~a include add'iona,l load snedd'g, manual or automatic, and coordin ted. network separation. This sec" ion shall be. completed before f eq'ncy declines 58.,0 Hz. i At 58. 0 Hz,, isolat generating units in accordance with Paragraph 2 of this Sec ion, "isola.tion of Powe Plants From System". In the event it becomes necessa=y for a system to isolate a genera. ting un' at a frequency higher than 58.0 Hz, or in a t'me period shor er than stipulated in the schedule of Pa agraph 2, page 5, of this

Section, such system shall also simultaneous1y disconnect an amoun of load. equal totha" pa-ti-

"cular. generating uni"'s output. This amoun" shal'

be an. additional. amoun over any 'oad previously shed.. Automatic. 'sola ion of gen 'ting. un's is. to be-prefa ad. ove= ma.ual isolation, and i= employed shoulL'rov'de.

12. seconds time: delay to. permi tampora,w f aauancy excursions.

below th's. isolation frequency of 58'.0 Hz. Phase. 7: If at, any point in the, above procedure, the decline in area frequency is arrested and it. levels out between. 58.0 Hz anL 59.0 Hz, the systems ir the low-frecuency area sh 11,. sheL an additional 10 percent of the'. rema'ning 1.oad and shall,' maintain or 'ncrease, if possible, thei generat- 'ng output to a, value-corresponding to the full opan.contro'alve posit'on until frequency is restor d to synch"onizing range o" the main network.. Phase. 8: E=: af, er three minutes the action t ken in Phase 7 above has not raturneL area. f aquency'to 59.0 Hz or. above, the systems in the low frecruency,'rea shall. sheL an add'iona:1 10 percent of: their ramai.wng-load., repeating on. two-minuta intervals, until 59. 0 Hz: is reached. This step must be compl'atad within the, t'me limits ou"lined in Paragraph Z of this Sec 'on, "I'solation. of Power Plants from. System". Phase. 9: -Vhen'rea frequency has'een-established at 59.0 Hz or above., the system or, sys'tems in-the low fraauency area shall take any action necessary to permit re-.synchronization of the isolated area to the main-ne,twork.. Phase i0: Z~ftar frequency has returned-to synchroni 'ng

range, the 'solat d

aa shall be synchroniz d with the 'nterconnectad. sys"ams. Phase= 11: System cispatchars sha.'1. di act load es orat'on a..d. the esumpt'on of normal interconnect:ad ope~c~ on. Xn taking "'" s eps outlined the ">>CG'perating Committee. members wiLL utilize all, reserves.- "o the best of the'b'i,ties. The applicat'on of a3.1 emergency measures dur'ng decline~:g svstam free ancy within pennsular .=1orda should be re-viewed on agu'ar'.bas's and updated. as reaui ed to meet changing svs m conditions.

V'ZZ'-5" l0/l4/7 6 2.. Isolation of Power' lan ts = rom Svs tern Serious. damage to= turb'res can oe: caused. by loaded opera-tion at subnormal speed'.. Tt is highly desirable: to maintain service continuity, but it would: be. mast imprudent, to allow. equ'pment. to suf=er major damace which would impede the restoration of service after a major: disturbance. To m'nimize the possibility of damag to equipment, and still. maintain reliable operat'on of generatinc plants., coordination, or emergency. orocedu es, dur'ng low fxequency operat'on, is essent'al. Proc am or 1sol'at'on of Generatin Units Ourin Low System Zrecu encv Generating units shall be isolated from the system when all of-the procedu es performed. by the system dispatcne s in accordance. with Paragraph l o= this, Section-, "Operation. During; Declin'ng* System Frequency", have been unsuccessful in returning system frecuency to 59 Hz or above. Isolation, will be accomplished au omatically or manually within the ollowirg time limits. The twe pex'ods. and frequencies allowed are des'gned to assure that all possible oppor. u..'ty is given for the system to recover and yet protec" the genexating units from damage. . Adjust-. ments of ihe times and frequencies stated may be necessary for speci ic units due to the cumulative effect of:blade faimgue over the li e of the turbine, or to conxorm wi~%. manuf act~ er ' limitations. 60.0 -to 59.0 Hz No isolat on Below 59. 0 Hz 30.0 minutes maximum time before unit. isolation Belo~ 58. 5 Hz 7.0 minutes max'mum time befox'nit .isolat'on Below 58. 0 Hz Automat"c isolation by underfre-quency. relay with 12. seconds tmie delay <<This 7 minutes is pa.i. of the total, time of 30 minutes allowed. below 59. 0 Ez. "-very ef=o=t should be mad oy,the ooerator to maintain unit a ~'-ci 1 i~~i es and, if ooss 'le ~ a local load. This is to al'ow p'd e-synch-oniz'ng o the unit to the main network to a'd in restoration o~ the system.

VXI'-6 10/14/76 3. Procedures =or Ord r' Recovery Afte System Dis urbance Condition. Z. Loss'f Unit or Plant. W'hout Sepa ating.. Prom. The-Interconnected Systems (Ho Frequency Drop) S stem Zn Trouble After emergency is recognized. and immediate generation change has. been

made, raques" necessa~

power ree:ire-meats from othe svstams.. P&e frequent checks to assure that requests aqua~ net cowe on al3., t'es with. ot?:er systems. S stems Not ln Trouble Fulfill requests made by the system in trouble. Florida. Power Corporation system d'spatcher, iz necessary, will. contact the. other systems to be sure that the schedules are in-balance., Condition EZ Loss, of Unit. With Rasultan Separation From. The: interconnected; Systems All Svstams With frequency below 59.5'z, plants are to pick, up load: without contacf ing their own system dispatcher until. 59 5 Hz. is reached, then return to control. (Systems using. command'r-mandatory type control will remain on control). At this po'nt all system dis-patchers will set schedules to. the value of system net in archange. (All systems remain on tie line bias cont ol ) lf the frequency does not go below 59.5 H , all system dispatchers should set schedules equal to ~ net inta change and. remain on tie 'ne bias control. S stem Ln T oubla I Zf it is ppa ant "hat there is insuffician g aeration availabla-to res"'ore the frequencv to 60 Hz, it is the respons&il" ty.of-the system in trouble-to take whatever action is. necessar~( to restore the frequency to 60 Hz. After tying 'n with the inta connected

systems, he sys-am. in trouble must contact the other svstems to ad~us" schedules.

VIZ.-7 10/14/76 Cond't'on IZZ - Loss Oz Unit Nith, Resultant Seoaration Prom. The In e corrected Systems and Loss Of Load. By. Underz"equency Relay Action Generally load. restoratior should not be attempted until frequency. has. returneci. to normal ancE ties to: the. in erconnected syst ms. are re-established.. To prevent overloading of ties and a possible .second'eparation from the intezconnec ed. svstems, all load pickup should be= coordinated-with the.r lorida Power Corporation system. d'patcher. The system experiencing the generation loss should not at"empt to pick up load until the load of all other systems has been restoreci, unless-otherwise. instructed'y = lorida Power. Corporat'on system dispatche As. in; Cond'ion IZ,. if, it is apparent that there is insufficient: generation available to. restore the frequency to

60. Hz it is, the responsibility of the system. in trouble. to take; whatever action is necessary to. restore, the frequency to 60 Hz.

Conditions I, IZ and IZZ Eollowing. Any Hajor Disturbanc To insure that schedu1es to the interconnec ed, are held, within limits, all system dispatchers main~n close communications with the Florida Corpo~tion system dispatcher until generation 'tie fJows= a e stabilized 4. Onenin Ties After Statewide Loss of Generat'on sys ems should Power and Following a statewide total loss of generation (black-out), recovery will-be expedited if ties areopeneci at prear anged points. In preparation for startup oz'nd'vidual syst ms, ties should be opened a the switcning points listed on the following page., Por o ".er. situations where tne blackout is not so ex"ens've, opening, of ties: may be required to effect, complete restoration.. Each sit~ation.vilL have. to be individually considereci.

Vii-8 10/14/7 6 FROM Pebbledale (TEC) Ringling (FPL) Manatee (FPL) Lake Tarpon (FPC) Double, Branch (TEC) Lake Wales (FPC) Ft.. Meade (FPC) Pebbledale (TEC) Ariana (TEC) Sandhill (TEC)- Florica Power Co~ (PPC) Brooksville (FPC) Denham {FPC) Sheldon Rd. (TEC) West. Lake Wales (:.PC) Turner (FPC) North Longwood. (FPC) Putnam (FPL) Baldwin (FPL) Bradford (FPL) Cape Canave al (FPL') Hartman (FPL) South (VER) Hypoluxo (FPL) Rio Pinar .(FPC) Woodsmere (FPC) W'ndermere (FPC) Tallahassee Sw'ch (F?C) Crawfordville (FPC) Bradforcville. Nest (FPC) Crawfordville (FPC) Arche r {FPC) Gainesville (GVL) TLe Lines; West, Lake. Wales (=PC) Big, Bend (Tc,C) Big Bend (TEC) Sheldon Rd. (TEC) 2 Ck Higgins. (FPC) Normally Orchid Springs (TEC) Pebbledal (TEC) 230 KV Ft. Meace (FPC) 69 KV Larsen (L'AZ) Highland.. City {LAK) West (LAK) at 69 KV sid Dade City'TEC) Dace City* (TEC) Denham (FPC) Brevard (FPL) Sanford: (FPL) Sanford. (FPL) Greenland, (JEA) Normandy. (JEA)', Normandy (JEA) Indian River (OUC) Substation 1 (FTP) West (VER) by FPL Lake Worth. Plant Sub (L Substation 6 (OUC) Substat'on 2 (OUC) Substation 5 (OUC) Subs ta tion 3 (TAL) Pu dom (TAL) Sub s ta t'n 7 (TAL) Hopkins (TAL) 230 KV Parker Rd. (GVL) Idylwild (FPC) ts. Open e: breake~ WU) TO (T'ie to be opened at th's.end)

QU"ST1ON 6 Please orovide the following informa. ion: o ~ ] Nhat.s, the. current: s atus of the 500 .'<V system of inter-ties with. Georgia, which was in the planning stage according. to the 1973 report? 6.2 Zs there an emergencv 'nterchange capability of 800 NW from Georgia to Florida as. projected for 197o? 6.3 Are the Georgia Florida. 'nter ies emergency or economic in nature? 6.4 Are the ties set to open at such a (relatively) h'gh fre-quency that they are of 1'ttle use in a large disturbance (such as

1973, 1974, 1977) and that in a moaerate aistur-

,bance they might even make things worse by one.wng.when only a relatively small imbalance exists? 6..5'urnish a description of the organization of Power Coordin-ators and Dispatchers which incluces. the following: a) The numher o power coorainators and dispatchers for each snift; b) How they interact ir. emergency situations and with other ut'ity power. coordinators and dispatcners; anc c) Nhat telemetered data and what communications facilities. are available to themespecially zor communicating with auick-start facilit'es and. with maintenarce crews. RES?OViSZ 6

6. 1-6. 3 The grow h o any cyramic system ecu's acd'-'o..s and changes.

These changes 'nvolve t"ansmission cons-'"'c-tion, relaying pract'ces and operating proced 'res ard are designea to minimize the li.'celihood of an outage. As a result oz the April 3 and 4, 1973 outages, Florida Power 6 Light cont acted w'th Stone S Viebster Zngineerirg Corporation to review. he FPL. power system reliability and to provide recommenaations designed. to ~~approve it. Out of such -.ecommencat'ons and other inte nal studies, F?L has imp ementec .".ume""us charges -'o ou" svs-em since 1973.

n bref, s'nce

'973 "ransmiss'on add'ons have strengthened the t=es between the southern area anc the " st oz Flor'ca. h's 'ncluces an additional tie to Tampa Elec""ic Compary anc new transmission lin s down the west coast o =". hive s and. across the =ver-glaaes to auderdale. The east coast ransmission was strengthened by re'nforc'ng olc lines, accing new 3.ines, and rear=anging c'rc'ts from the midway stat'on southerly

~a ~ ~ through Lauderdale and 'nto the Hiam'rea. Two major add'tional. inierconnections v:th adjoining utities vere also.established at Sanford (Florida Powe= Corporaiion) and at Bradford (Jacksonville. electr'c Authority). During this. same time. frame, additional generation vas, added ai both. Hanaiee; and Pt. Hyers-. (See the status report.-attached, Iten; 8. for speci"ics..) Transmission expansion now under way and scheduled for complet'on by 1980, includes a 230kV tie to. Georgia (this will increase. the transfer in o Florida to abou 800 AN) and 500kV 1'nes. from Levee in. tne H'ami area northerly through Andyiown and. Hartin (the site for tvo new fossil generators) to Hidway. These 500kV 1'nes vill closely tie the entire South Flor'da. a ea from ou" St. Lucie Plant to Dade County into a, strong, ticrhily integrated. network vith further improvement. in system reliability. This system is scneduled for complet'on..during 1980. A 500kV'ystem: of ties with. Georgia is still in the plannirg stage. The laies FCG studv, conductea. in 1975 to determine the ezzects: of changing load. conditions and. altered gene a-tion expansion

plans, showed the 500kV'ie to Georgia to be needed around the middle 1980's..

Today, it seems mo e realistic to assume ihat the recru'red. da e will oe around the. middle 1990's. The-statewide 500kV svsi m is being reported annually to the Federal Energy Regulatory-Commission (FERC) under Order 383-4 (SERC-TAC)., ~ 6.4 The existing Georgia-Florida transmission tie lines serve boih economic and emergency purposes., The present ties are between'lorida Power Corporation and Georgia Power Company, and their operations conform to the ooerating practices of those two companies. At present their transzer capacity is a'ppror'cimately 400 I'lorida Power Corporation's ties v'h the systems to the norih are not ecuipped v'th underfrequency re'ays. Separa-tion oz penis sulaz'lorida usuallv occurs internal to the FPCorp.

svsiem, oetween Suwannee anc. Archer, Ft. Nhite and inglis, etc.,

bu" is noi the result of low frecuency. These lines are ecruipoed with phase d'stance relays for fault protection which respond. to the apparent impedance looking into, the line terminal. This apparent impe ance is a function: of the current. in the line, the voltage at, the

terminal, and the angul~" dizference between these tvo Quan 'ies

~ Z s'ituations whe<<e ihe power t ans fer <<esu ' "he proper coma'at'on of h'gh cu"r nt a..d 'ow voltage, operation oz these "clays 's expected. During recent years these 1'nes have demonstraiad thei abil'ty io v'thst nd moderate overloads (loss of 400 X8 un'is).

6.5 Nits espect to organization, Power Coordinators operate the system unde>> the direction oz an Assistant Fanager oz System: Operations. They di ec-'he activities. oz. the. Division. Dispatchers. There are two Power Coordinators on each shi "; one coordinates generation-, and. one coordinates, transmission. The generation'ower Coordinator works with other u ilities zor ini erchange. The transmission Power Coordinator works with Division. Dispatchers. Division Dispatchers for each shift are as follows: 7-3 3-11 11-7 etiam Nest Palm Beach Sanford Punta Gorda 3 2 2. 2. 3 1l. 1 1. U Telemetered, data includes: Generation from each plant Tie line loading Southern Company net interchange to Florida. Powe>> Corporation System Load Total Generation Net interchange Frequency Power (South oz Lauderdale) Power. (South of Ranch) Voltage (Dade) Voltage (Flagam' Frecuency (Brevard) major Load Area in.ormation (generation, load, interchange, & net. flow between adjacent major load reas) Communication facilities are leased telephone c'rcu' to all Division Dispatchers, all plants, and all other utilities with wnich FPL has tie lines. Gas turbines are available for "cruick start" by the Power Coordinators through supervisory equipment. On Nay 16,

1977, undetermined number o= gas turbines at Port "-verglades we"e ordered on by su-erviso"v.

T..ev were ordered on. too late and we e unable to comp et =he progr~aed st ""-"p secuence before he blackout. Th"ee gas 't'rb'nes were ordered on at Lauderdale. These three completed the star-Up seauence but the auto-synchronizer could not match the voltage of he machine to that of the bus and ther fore wou'd not permit the bre ke to close. The minimum excita-

tion limit of the gas turbine control would not permit the mach'e voltage to come down low. enoug h to match the low bus. voltage., The excitation-lmiits, on-all, GT's: at Lauderdale and. Por Everglades. have been. reset to permit them to synchronize at abnormally low. voltages. Add'itionaly', main step-up power trans"ormer, taps-. have. been-reset..to permit a higher machine. voltage.

QUESTION 7 Please prov de the. followinq information: 7..1 Describe

how, to. what'ex ent,,

and when-the past recommenda. tions. on relays were. implemented'2 7..2: What effect. did: that implementation have on, the Hay 1,6, 1977 disturbance'? 7.3 Discuss the significance of. the Turkey Point Unit 4 and the. 500kV Orange River-Andytown line ecu'pment outaqes to this event and explain why it is-not necessary to include discussion of them in the "Report on System Dis urbance Nay 15, 1977." RESPONSE. 7.1. Following, the distur'bances-in April, 1973, Stone & Webster Enqineering Corporation was retained to conduc an. indepen-den~ investigation of the event.. A report of thei-findings was forwarded to the FPSC'n Aav 18, 1973. As a result or their. findings, thev made specific recommenda-tions as to protectve relay application. All of these recommendations were accepted by FPL and nave. been imple-mented. Specifically, they include: a) individual'nderfrequency relay schemes are now installed on, each generatinp unit of 250 HN or more. For this application FPL. uses a design. comprising parallel sets of two unde freauency relays with the'r contacts in series. This provides reliability and security as wel's limit'nq the amount of generation subject to a common failure. b) Protective circuits on crit'cal transmission terminals have eauipment added "o sense out of step powe" swing conditions and block reclosing following a trip. Approximately forty 240kV and. 138kV line terminals c~o sidered. the most likely to be a fee+ed by s"abil'ty swings are so modified. As new line terminals are constructed, considerat'on. is given-on an individual basis. as to-whether this tvpe of protection is rerz'red. By so do nqq L has 1'mi ed the poss'b '. y 0: ecuip-ment damage or extendinc "he area a==ec c by ". out qe. c) High speed eclosinc is bloc!ced. =or all but phase o ground faults on al'40kV lines south of Ranch Sub-stathon ~ On the basis of ope ating xper'ence, this practice wi'1 be ex"ended to 'nc'ude al'40kV lines and any 138kV or-

ll5 .'<V lines orig'nating from 240kV substations. d) An extensive-rev'ew-of =PL'rotective. practices was conducted by Stone &; webster and "-PL engineers. Results.. oz, this study were. adopt d in. early 1974 and orm the basis of current svst m protec 'on and. control design 7.2 The disturbance of Hay* 16'as 'n'tiated by a phase to ground fault on the Ft.. i<yers-Ranch 240kV line. Protec-tive devices operated properly preventing the disturbance from spreading outside of ihe immediate area affected and allowing the safe shutdown of generating units w'thout major damage. 7.3 The purpose of the repor was to address the disturbance and provide an analysis. oz those events directly related to it..}}