ML17347A836

Forwards Application for Renewal of NPDES Permit for Facility Submitted to EPA on 880728

ML17347A836
Person / Time
Site:	Turkey Point
Issue date:	08/03/1988
From:	Conway W FLORIDA POWER & LIGHT CO.
To:	NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
L-88-334, NUDOCS 8808170064
Download: ML17347A836 (41)

Text

AC CELZRAT@QULRg+ Sf DIAQfQ%IQMQRIDP ~~M ACCESSION NBR:8808170064 DOC.DATE: 88/08/03 NOTARIZED: NO DOCKET FACIL:50-250 Turkey Point Plant, Unit 3, Florida Power and Light C 05000250 50-251 Turkey Point Plant, Unit 4, Florida Power and Light C 05000251 AUTH. NAME AUTHOR AFFILIATION CONWAYPW.F. Florida Power & Light Co.

RECIP.NAME RECIPIENT AFFILIATION Document Control Branch (Document Control Desk)

SUBJECT:

Forwards application for renewal of NPDES permit for facility submitted to EPA on 880728.

DISTRIBUTION CODE: COOID COPIES RECEIVED:LTR TITLE: Licensing Submittal: Environmental Rept Amdt

/ ENCL 6

2Related SIZE:

Correspondence NOTES:

RECIPIENT COPIES RECIPIENT COPIES ID CODE/NAME LTTR ENCL ID CODE/NAME LTTR ENCL PD2-2 LA 1 1 PD2-2 PD 1 1 EDISONPG 1 1 INTERNAL: AEOD/DOA 1 1 AEOD/DSP/TPAB 1 1 ARM/DAF/LFMB 1 0 NRR/DEST/ADE 8H 1 1 NRR/DEST/SGB 8D 1 1 NRR/DREP/RPB 10 4 4 NUDOCS-ABSTRACT 1 1 OGC/HDS2 1 0 E~ZZr 01 1 1 EXTERNAL: LPDR 1 1 NRC PDR 1 1 NSIC 1 1 TOTAL NUMBER OF COPIES REQUIRED: LTTR 18 ENCL 16

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FLORIDA POWER & LIGHT COMPANY AUGUST, 3 1988 L-88-334 U. S. Nuclear Regulatory Commission

,Attn: Document Control Desk Washington, D. C. 20555 Gentlemen:

Re: Turkey Point Units 3 and 4 Docket Nos. 50-250 and 50-251 NPDES Renewal A lication As required by Section 3.2.3 of the Turkey Point Plant Environmental Protection Plan, attached is a copy of the application for renewal of the NPDES Permit for Florida Company's Turkey Point Plant. This application was Power'ight submitted to the U. S. Environmental Protection Agency on July 28, 1988.

If there should be any questions, please call us.

Very truly yours, W. F. C y Senior Vice President Nuclear WFC/TCG/gp Attachment cc: Dr. J. Nelson Grace, Regional Administrator, Region II, USNRC Senior Resident Inspector, USNRC, Turkey Point Plant co~ l 8808i70064 880803 PDR ADOCK 05000250 P PNU PEOPLE... SERVING PEOPLE

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=O. OX l '000, 'g'uO BEACH, Fl 334084420 CERTIFIED MAIL RETURN RECEIPT REQUESTED July 28, 1988 Mr. Bruce R. Barrett, Director Mater Management Division U.S. Environmental Protection Agency Region IV 345 Courtland Street, NE Atlanta, GA 30365 Re: Turkey Point Plant NPDES Renewal Application Permit No. FL0001562

Dear Mr. Barrett:

Enclosed is the NPDES Renewal Application or Florida Power &

Light Company's Turkey Point Plant. If there are any questions regarding this application, please direct them to Winifred Perkins at (407) 694-3645 or Ron Hix at (407) 694-3622.

Sincerely, T. R. Fair Manager Environmental Permitting & Programs TRF/RHH/bf Enclosures cc: J. P. Subramani DER DERM an FPL Group company

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~ VEhA U.S. CNVIRONMCNTALPROTCCTION ACCNCY

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I EPA I D NUMSER GENERAL INFORMATION IA GENERAL 0/K I Consoffdaord frsnnirsProgrsnr (Read lhc "Genera( fnerrirer(one" before start(ne.r F F

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+LrNCRAL INSTRUCTIONS<<

I. EPA I.D. NUMaIER If a praplfntsd label has been-provided,.affix it in the designated space: Revfesv the In(olin.

III. FACILITY AME FACILITY lilrOES t I=LJOtslioc

i P'r(R 6 L T TURKEY I" GIST

'"/f ation carefullY if any of It Is lncorrear cross through it snd enter the correct data fn the appropriate fill-In ares befovv-Abo If eny of the prsprintsd data is sbsarrt.(tfre.areeStrs-tfre left of the label grace (lstr.the;infonnelforr

'AILINGADDRES! ;I SA)4U=~ TUI.KcRS c v'VIPON hi(R that shoufd afrpssrl, please provide It1n the rr:J '-uX ~r13 l00 proper fili-fn srss(sf below.;If the Isbsl fs

'~1AI4 I I=L 33101 complete snd correct, youlnaed not complete Items I. III, V, snd Vl (srrcafst.-V(-B Ivhiclr m%T be comp(clad rs(ford(esa)" Complete sll AC ILITY V I 'OCATION items if no label has been provkiatL Refer to the instructions for dstaf~ltem".descrfp-tfolls and for ths lsgsi authorlaatlone Under which this data is collected.

II. POLLUTANT CHARACTERISTICS INSTRUCTIONS: Complete A through J to determine whether you need to submit any permit application folmS tO the EPA. If you anssvac "yaa"..to any questions, you must submit this form and the supplemental form listed in the parenthesis following tha question. Mark NXN in the box in the third column if the supplemental form is attached. If,you answer "no" to each question, you need not submit any of these forms. You may answer Nno" if your activity is excluded from permit requirements; saa Section C of the instructions. Sea also, Section O of the instructions for definitions of bold-faced tetmL SPCCIFIC QUCSTIONS O O $1 ~ O N ll Tae NO ~

ATTAcNC SPCCIFIC QUCSTIONS Tao No ATT*CNCO A. Is this facility s publicly owned treatment works 8. Doss or will this facility (either err(sting or profsossdf wnich results in s discharge IO waters of the U.S.t X include 5 concentrated animal feeding operation or IFORM 2AI aquatic animal production fac8lty whfch results in a discharge to waters of the US.? IFORM 28)

Is lnis s SCiiily wnic current y results in I argeS 5 l is a proposed so ily o sr drsn osa escn lo waters of ths U.S. other lhsn those described in in A or B sboyof which will result in a discharge to A or 8 above? FORM 2C of the U 't FORM 2D)

E. Does or will this facility treat, store, or dispose of F, Do you or will you inject at this facility fndustrisl or hazari)ous wsslsst IFORM 3) X municipal effluent below the lowermost stratum con- X taining, within ons quarter mile of the well bore, underground sources of drinking walsrt IFORM 4) ll 1\ $$

0 vou oc wl you Infect al I Is sci I'Iv shy p U wsler or other fluids which sra brought lo the surface H. Do you or will you Inject at this facility fluids for spe-in connection with conventional oil or natural gss pro- X cial processes such as mining of sulfur by the Frasch duction, inject fluids used for. enhanced recovery of , process, solution mining of minerals, in situ combus oil or natural gas, or inject fluids for storage of Ifquid tion of fossil fuel, or recovery of geothermal enerffyL Ir 4

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h drocsrbons? IFORM 4) $4 1$ $4 IFORM 4) s l Is aci Ily a pfo stationary Rrurce w I Is

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one of the 28 Industrial categories Ifsted in the in.

~ s ly 5 p IXIlce I .I NOT one of the 28 industrial categories listed in the ~

strUClions and which will potentially emit 100 tons fnstluCtiOOS end which will potentially emit 260 tons.

per year of sny air pollutant regulated under the par year of eny elf Pollutant fsgUlatsd Under the Cfaarl4 Clean Air Act and msy affect or be located in sn Afr,Aa and may affsa or be located in an attsfnmsnt area? IFORM 6) ~1 ~ rea? IFORM 6) AIC Cr I r r,vr retlkgl 44 III. NAME OF FACILITY SNIP T U R K E Y P 0 I N T P L A N T I~ Il $4 IV. FACILITYCONTACT h .NAMc aI TITLc ((ae4 f(re4 Ia (lilt) ~ . PNoNC (area code Ie no.i .

C 2 BURKETT T 6 CROSS J PLANT MGR 246 130

~4 44 ~4 ~4 ~ I ~1 44 r4 rrr V. FACILITYMAILINGADDRESS h STRCCT OR P.O SOX ~ .~ r 4 rvv'pv44 orlrIrA 3P. O. BOX 4769 CCCSTT OR TOWN

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.F 4 vrm$ 44 4PRINCETON PL 3'3092 i 'm'+~~TCfSXW

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Vl, FACILITYLOCATION AISTRCCT ROUTC.NO OR OTNCR,SPCCIFIC &CNTIFICR -C +sr $4 ~~f4"'@~>>

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5MI EOPFLA CITY ON PALM D 4$ ~ $ $$.4r k Sr COUNTY NAMC A<-

DADE AIL

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'CCSTVOltTOWN '" ~ STAT C ZIfCODCr 6PLORIDA CITY PL 3303 ,OI EPA Form 8610-1 IRev. 1M0) CONTINUE ON REVERSE

ONTINUED FROM THE FRONT Vll. SIC CODES (4&igit, in order of priority)

A III ItST ~ SCCOND (specI fy/ (specify) 7 4 9 1 ELECTRIC SERVICES C THIRD o vouRTH V (specify) (specify J

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Vill.OPERATOR INFORMATION la the usted ln A, NAME l sane VlllrAallo F L 0 R I D A P 0 W E R & L I G H T C 0~

Qg owners YES'I.NO r

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c. sTATus or oecRATDR (Enter the appropriate letterinto the answer box/if "Other", speclfyJ D, PHoNe (area code R.na)...

M c UBLI (other tr)an federal orstate/

407 694)I 3635 C

AL (specify J S c STATE 0 c OTHER (spec(fy) A P c PRIVATE ~S ~ ~ I~ I~ I~ $$ SS C STRCCT OR P.O. OOX 1 4 0 0 0 )Ir<<r<< ~

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P, CITY OR TOWN IX Is the facility located on Indian landsr 8 JUNO BEACH L 3 3 4 0 8 C3YE as ggNO.

I~ ~e ~I ~) e) ~I X. EXISTING ENVIRONMENTALPERMITS A. Nrocs (D(scharr(es to Surface Water/ o. 9 so (A(r Em(ss(ons from Proposed Sources/

9NFL0001 I~

C T I~ II I~

562 'I 0 9

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s. uIc (Underground /niectlon of Flu(ds) C 0TH cR (spec(fy J C 't I C T ~

(spec(fy) 9 U

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State IWWTS

c. ncaA (//asardous Wastes) c 0TH cR (specify J 9RFLD00073 C

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IWO-016

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(specify J County IWWTS XI. MAP Attach to this application a topographic map of the area extending to at leastone mile beyond property boundaries. The mipgmtsttow", ',-

the outline of the facility, the location of each of its existing,and proposed intake and discharge structures, each of its haiartfous wasta-treatment, storage, or disposal facilities, and each well where it injects fluids underground. include all springs, rivers and ather sur'face.

water bodies in the map area. See instructions for precise requirements..

XII. NATURE OF BUSINESS (provideabrief descriplion Electric Power Generating Station

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~ ~ I XIII.CERTIFICATION(ass/natttscsforle)

I canlfy Vnda. penlsftyof:fav'v~.'I.

attachmentr and,'.tilit-Minyan;,fiiqu~of;Siiar.

i persfsna(ii/~Feanhecf'nQi' " '" aif "" 'ffss. "ar)bmit ted.

forebtiJKhg~7irfonr(a application, believe tisat'tf)e infoimation ia true accu<<ate and carqplihCJ.ans iwafsr.'thnt2here.araiignificfurt pena false information, inctuding the possibility of fine and imprIconment;.

A. NAMC 4 Ov)IICIAI TITS C (type or print) Sr SION* C C DATC SIONCO T. R. Fair, Manager Environmental Permitting & Programs COMMENTS FOR OFFICIALUSE ONLY.

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.L'w:.ia V EPA Form 3610-1 IRav. 1040) R~ IS.U.S. Ceveraaeat Ir Prtattal Otsfce I T

Isn't'94 ~ 94$

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/59991 II r

EpA i.o. NvMuc,IRRcvpy lrnm iieni I vl ruriii ii OIWB iVo. 2040~86

-'sse'onnt or Ivoe in the unshaded areas onlv. PLD 000733683 Approvel expires 7-31-88 FORM ' U.S. ENVIRONMENTALPROT ON AGKNCY APPLICATION FOR PERMIT TO Dl GE WASTEWATER NPDES iSEPA EXISTING MANUFACTURING,COMMERCIAL,MINING AND SILVICULTURALOPERATIONS Consolidated Permits Program I. OUTFALL LOCATION For each outfall, list the latitude and longitude of its location to the nearest 15 seconds and the name of the receiving water.

A. V L O. LATITUOK C. LONGITUOE NUMOER o. REcEIvING wATER inamel lists I CEO, X. MIII i. SEC ~ I, OEO. X. MIII, ) SEC

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001 25 26 09 80 I 19 52 No discharae to waters of U.S.

I I I II. FLOWS, SOURCES OF POLLUTION, AND TREATMENT TECHNOLOGIES Attach a line drawing showing the water flow through the facility. Indicate sources of intake water, operations contributing wastewater to the effluent, and treatment units labeled to correspond to the more detailed descnptianS in Item B. Construct a water balance on the line drawing by showing average flows between intakes, operations, treatment units, and outfalls. If a water balance cannot be determined (e.fs, /or certain mining actnlitfetJ, provide a pictorial description of the nature and amount of any sources of water and any collection or treatment measures.

I B. For each outfall, provide a description of: (1) All operations contributing wastewater to the effluent, including process wastewater, sanitary wastewater, "ooling water, and storm water runoff; (2) The average flow contributed by each operation; and {3) The treatment received by the wastewater. Continue cn additional Sheets if necessary.

OUT z. OPERATIONlsl coNTRISUTING PLow 3~ TRKATMKNT

'ALLN O, AVERAGE PLOW LIST COOKS PROII

.Erl e. OpKRATION lllsrl linclude unirsl a. DESCRIPTION O.

TALRLE EC I Recirculated condenser 2763 MGD Rec cled, reuse of treated 4C 001 coolina water Units 01, 02, effluent 3 44 auxiliar e ui ment coolin water Screenin No 3 T a tities list d under mass n bers in Part V A B and C rn ~

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~ I "Jll oPIIIcIAL.UsK.oNI Y. fefflileisaa uldellnee eu il ~

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VI <<>> <<<<>>IIIR j I ~ II I

EPA Form 3610-2C IRev. 2-85) PAGE I OF 4 CONT E ONR I l,,lily

".ONTINUED FROM THE FRONT YES (complete the folto>ping tablet ~

C. Except for storm runoff, leaks, or spills, are any~>e discharges aescribed in Items II-A or 8 interm>ttar seasonal I 3.FREQUENCY

+NO is~ection IIIJ

4. FLOW

a. PLOW RATE b. TOTAL VOLUME

'I. OUTFALL 2. OPERATION(LJ a. PAYS b. MONTHS (ln mgit J (specify u>lth unite).:C, DOR- <

NUMBER CONTRIBUTING FLOW PER WEE>A PER YEAR MAXIMVM I VONO TCIIM I, MAX>MOM ATION

'listj (listJ (specify (speci fv I VONV TCOIM OAIVY AvcIIAOc oAII,Y (ln dayeJ auerage I auerage I AVCNA4C N/A i III. PRODUCTION A. Does an effluent guideline limitation promulgated by EPA under Section 304 of the Clean Water Act apply to your fac>hty?

'X>YEs (complete Item IIIBJ NO Ita tO Sect(on IVI

8. Are tne limitations m the applicable effluent guideline expressed in terms of proaucuon (or orher meesure of operer>ont?

YES icomplete Item III Ci g No Ieo io oection II I C. If you answered "yes" to Item III-B.list the quantity which represents an actual measurement of your ievel of production. expressed in the terms and units used in the applicable effluent guideline, and indicate the affected outfaiis.

1, AVERAGE DAILYPRODUCTION 2. AFFECTED C OPCNATIONo AROOVCTo MATCC>AI CTC OIJTFALLS OVANTITY ACN OAT O, VNIT5 OO MCATVNC (tlet outfall numbereJ N/A IV. IMPROVEMENTS AoSttr>oo~orJ or A. Are you now required by any Federal, state or local authority ta meet any implementation schedule for the construction, upgrading Iyof waste-water treatment equipment or practices or any other environmental programs which may affect the discharges described ln this appii but is not limited ta, permILcooditfons~nlsttatfve oranfarcement orders, enforcement compliance schedule letters, or loan conditions.

stipulations,, Iaif>eludes, grant

+YES (complete the folio>utng tableJ +No (go to Item ItrBJ I. IDENTIFICATIONOF CONDITION, 2 AFP'KCTKP OLITFALLS AORKKMKNToKTC S, SRIKF DESCRIPTION OF PROJECT a NOo ILCOVCOC OP O>CCII*OOC O N/A

'o foe

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your dischergesJ you now have underway or which you plan. Indlcat>L whether each program

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is now underway or planned, and Indiattfpgjdlsr>actual or EPA Form 3610-2C (Rev. 2-86) PAGE 2 OF 4 CONTINUE ON PAGE 3

'orm riooroveo.

CPA i.o. rIVSsOCRIcopy lrom iiem I Or eorm lr vhfB No. 2040~86 000733683 Approval eroires 1 31.88

'A%TINUED FROM PAGE 2

i. INTAKE AND EFFLUENT CHARACTERISTICS

~. 9, & C: See instructions before proceeding Complete one set of tables for eacn outfall Annotate the outfall number in the space provided.

NOTE: Tables V-A, V.B, and V-C are included on separate sheets numbered V-1 through V.9.

D. Use tne space below to list any of the pollutants listed in Table 2c-3 of the instructions, wnich you know or have reason to believe is discharged or may be cischargeo from any outfall. For every pollutant you list, bnefly describe the reasons you believe it to be present and report any analytical data in your possession.

POLI UTANT 2. SOURCE I. POLI UTANT 2. SOURCE N/A

VI. POTENTIAL DISCHARGES NOT COVERED BY ANALYSIS is any pollutant listed in Item V-C a substance or a component ot a substance wnich you currently use or manufacture aa an intermediate or final p<oductor.

byproducts ~"~ fp~+tf>>'C~>>"...

. oisrrssar.cv>>~'w:

rIO leo ro item Vl BJ N/A EPA Form 3S10-2C (Rev. 2.BS) PAGE'3 OF 4 CONTINUE'ON REVERSE

'.ONTINUED FROM THE FRONT VII. SIOLOG ICAL TOXICITYTESTING DATA Oo you nave any knowledge or reason to believe that any biological test for acute or chronic toxicity has n made on any of your discharges or on- a-""i.s4-

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recetving water in relation to your discharge within the last 3 yearsf

~~ vKS lldentify the testis) and describe their purposes betour) K) tto fao to Section Vfff)

N/A VIII.CONTRACTANALYSIS INFORMATION Were any of the analyses reported in Item V performed by a contract laboratory or consulting firm) ft4t the name. address. and telephone number of, K) vKS analyzed by, each such laboratory or finn betour) and pollutants + No fgo to Sectlotr IX)

A. NAMK 8. ADDRKSS area code e no. list

~ARD Environmental Science & P.O+ Box ESE Engineering, Inc. Gainesville, FL 32602  !(904) 332-3318 All IX. CERTIFICATION rr,4 1 e~'I

/certify under penalty of law that th/s document andallattachments were prepared under my direction or suparvisioninaccordance withe systimiteipnedto assure that tfualifiedpersonnelproperly gather andeyafuate theinformation submitted. Based onmyintfuiry ofthe person or persons who manege thasystam or.

those persons directlyresponsible forgathering theinformation, theinformation submitted/s. to the best ofmyknowledgeandbelief, uue. accurate. andcotnpfete-l am aware that there are significant penalties for submitting falseinfonnation.including the possibility o/ fine andimprisonment for knowing violations.

A, NAMK 4 oFplcIAL TITLK ltype ot'rltrt) O. PHONK ISO. larea code & no.)

T. R. Fair, Manager Environmental Permitting a Programs (407) 694-3635 D. DATK SIC NKD

..((j+ ~CF A4FA

~>>k EPA Forltl 361(AC (Revr 2 85)

EI A >.o Ns>><>UI I' ~ ~ I~ ~ Il Nll IH NI I lf I <)1>>> II

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I <ill > v<l <II ll PLEASE PRINT OR TYPE IN THE UNSHADED AREAS ONLY. You may lcpoii soi>>e or all of l>nil> NI) 2>I IV <k)SO this information on separate sheets fuse the same format) instead of completing these pages. PLD000807461 f AI)l)Ale'.)I '<p)>i's 3 I a>>

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SEE INSTRUCTIONS.

Oi>T > As s N<>

V. INTAKE AND EFFLUENT CHARACTERISTICS (continued fro>n page 3 of Form 2-C) 001

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ART A - You must provide the results of at least one analysis for every pollutant in this table. Complete one t;ilile for iiach outfall. See instructions for adr)i(iona) details.

2.EFFLUENT 3. UNITS 4. INTAK E f<>pli<)>nil)

ON i<>><'rifv If bla)>k) LONG TLRM

. MAXI M Sg g(AY VALUE C.

)/~VALUE a.

4. NO OI" PPLLUTANT 4. MAXIMUMDAILYVALUE u. No. a.CONC EN gf'L u I Ol'NAL S 4. MASS I)I MALS ANA1. VSES I ls) (I) MASS '1 :Is)

CONCCNTNAT<OH (I) )<AS ~ t~ I CONC TNT<<ATION (1) MAI ' s TRAl lON COCCI hfNAT<ON

-:tt em(eel .;

5 (f)OD).

Xyge>l Demand<

1-2 2.6 X 10 2 mgLL lhs 1.05 3T3 X 10

C}le>(lice(

xygen'Demand OP/) I>-. li .

Tl)>>e1 Organic

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2180 4.7 X 10 mgQ, .31)E .. (280 X $0 8

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8.5 1.8 X 10 6.8 3.3 X 10 mgLL lbs 2 0 X 10

) TotaySusoendpd ')

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'., <<I'I I ereturo" r'>)I>Imar) '! effluent 33SQ

,M!It. s. MINIMUM MAXIMUM MINIMUM MAXIMUM Sl ANOARD UNITS 8.03 8.06 8 03 8.06 2.

limitationsguidelin,youmust reason to believe is present. Mark -X" in column 2-b lui U>ch pollutant you believe to be absent. If you mark column 2a for any pollutant AIP $ >

Mark column "X"in column 2-a for each pollutant youknow or have

! 'h)oh is limited either directly;or (ndirectly but expressly, in en 2a. you must provide quantitative provide the re uhs of ai least one analysis for that pollutant For other pollutants for wliichyoumalk data or an explanation of their presence in your discharge. Complete one tal>le for each outfall. See lhe instructions lor adduional details and req>>ir em>>>>le i~ pt I

5. INTAKC f<lpII<)UJII POl LUT TL MARK 'X' 3. EFFLUENT I. I)NITS

a. LONGE>>M

>ANT>AND e. ~ c- LICVEb. O ~ e MAXIMUMDAILYVAI UE . MAXI pM ajar gtLY VALUE C.LONG TfpM pg}lri . VALI)l. I l>O Ol >. NO. 0 I

.CAQ IEVC )IN>< L I MASS

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~ NC A~ I I Is Yes s ICATION (II MASS YSES NO'f(ee>il(cbla) ~ cHT SANT COHCCNTAATIOH (I) MASS CONCCNTNAT<ON (I) MAS ~ CONCCHTHATION (1) I ~ ALL CONC L H I<<AT<OH Lsrernlde ~ ~

2$ ()947-9) <5 <5 m~/L lbs (5 2

. C)lier(ne,-'..-.

nes);Pesldual. Not PreS ntly chio inating msf~L lbs (If'-"<>.l>': 42 .... 2 PCU 41 ....2 100ml 15

.~ I" I 5 5 0.63 1.4 X 10 0.45 2.2 X 10 mg/L lbs 0.46 1.4 X 10 EpA Form 3QO 20 fRev 2 8()} BASED ON 1987-1988 HISTORICAL PA(AE V-I DATA CONTINUE ON REVERSE

• • BASED ON 1986-1987 HISTORICAL DATA

ITEM V 0 CONT INIIED I'itlJM F IIONT ly POLLUT- rr. MARK 'X' 3. EFFLULI< T I Ill I I ~ II I I tt I I 't'I' ANT AND C. l CI II I ~ 'I L I IM CAS NO.

a. NN n. ua. ~

ICVCI ~ c v ~ Ir r IIN r N MAXlMUMI3*rL~ uALtsL u. MAXIM M 3f p( Y VALUu tlf III'rrll 1 rr I I I ~

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I r I rl;I .L ~ 1 i ~ ~ IAI I, rrtl Ill

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((fcuoiloblc J ICNT I ~ Nr CONCCNTNA'IION ltl MA~ I CONE I',N I@r AI I ~ rrr I'I IAAF~ ~ ~ rr,r I~ I

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p. Nltropan, Total Orpanlc 3 (os NJ 0 08 3.2.Z 10 mgLI lhs 1-6 X 1Q.

h 'Oll and Grease

',' 0 mg/L. lhs 2 L Phosphorus (osPJ,'otal P723-14 0)

f. Radloactlvlty X 0.01 .8 ~QL 3.2 Z 1 mglL lhs Q.Ql 2 2.X.10 3

I)) Alpha, Total.

'2) 212 168 2 pCi/L 234 8ata.

Total "A X 110 100 2 pCi/L 67 I3) Rac))un';

Totai I" 1 (4) Radium 220, Total r

'I 14 Ou ata rtrr, (os d04J ~ ~

1 4808.7941 2910 6.2 X 10 2880 1.4 X 10 mg/L lbs 2800 87 X lO I. Sutfkl~

ada)IJ';

m, u 'to.

(os g(73J; A'..

f)4288~

n.)guh actanti C O.l 0.1 mg/L lbs 0.1 I

'usrpt

{7Q))4194);~ <95 495 ug/L lbs ( 95 2 wrote)

Total':1 I7 l".<.-~5l'Ott th!N 3800 8.2 X 10 3595 1.8 X 10 UR/L lbs 3660 1.1 X 10 6

0-r; Total s'.

P44048.4)

~ . Iron, Total f743949 8)

t. Mapnaslum, X 4 23 C 23 ug/L lbs ( 23 2 Total (7439.95.4)

. Mohrbdanum,

-9 >~} QC2 XDO Ug/lr lbs 771 2.4 X 10 ~

Total P 439-98.$ ) 16

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3.6 X 10 84 .1 X 10 2 uggL Ibs 11.3 3.5 X 10 l~ . 10 P %NW P ~ ~P ~

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I 1 lrlIEIIVDEr ttl:.irtlOWa Ib324))".$ i u /L lbs <4 EPA Form 3610-2C tRev. 2-86) PAGE'V-2 CONTINUE ON PAGE V -3

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spA I.o. NUMacR (co<>y from Item I of Form Il OUT<<A <.L r< > ~ '. ',< H ~ Hl

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PART C - Ifyou are a primary industry and this outfall contains process wastewater. refer to Table 2c-2 in the instr<< imns io <I<><<<<i Ire wliicliof Ihu Gc/MS I< actions yo<>><<us<< Io:.I II>r II]!irk-x- i<i << I<<<< i 2-a for all such GCIMS fractions that apply to your industry and for ALLtoxic metals, cyanides, and totul pl>annul:, II y<<II i>>e not ru)u<red to mark coliunn 2.n f I< coi <liu> i<i I'us(ri .i. n i<>pi >I <

ou(falls. and nonrarfuired GCIMS free(fons J, mark-X- in column 2b for each pollutant you know or Ii,.v i ..is<Xi to l>l>lieve is present. Murk -X"in >n>lunin 2 c loi e icli l>oil<>to It y <ii

> s'asiaweter believe is absent. Ifyou mark column 2a for any pollutant, you must provide the results of at least one aria lysis for t ti.lt I,alt iiwi >t lfyoii mark cohi <un 21> f<>r aiiy p<<ll<>IJ> II, yG>i ill>>a< pio vide >I! I>< i>i< 4 II <

of at least one analysis for that pollutant ) f you know or have reason to believe it will be discharged in I o>><:en<roti.>na <>I 10 pi>b or greater If yui< inaik colunin 2li f<ir o<;rnlei>i. ac<yl<>nitiilo. 2.1 dlnitrophenol, or 2.methyl-4, B dinitrophenol, you must provide the results of at least one analysis lor >.a<:I< of thus<. I.<<I<<i<ants which you hnow or have runs<>i> to believe <Iiut yoi< disci<<<<II,i in concentrations of ) 00ppbor greater. Otherwise, for pollutants for which you mark column 2b, you most oi<tlcr subni t. II.,>: I ono analysis or briefly ilnsciibo tliuio I ons ihe I>ollutunt is exi>octad I<>

be discharged. Note that there are 7 pages to this part; please review each carefully. Complete one table fall 2(>i>ga>;.< Ictions foi a<lditional details and requirenienls NUMBERS

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TURKEY POINT PLANT GENERAL PLANT DESCRIPTION AND DISCUSSION OF MAJOR PROCESSES AND ASSOCIATED WASTE STREAMS Florida Power &, Light Company's Turkey Plant is located at latitude 25 26'09"N and longitude 80Plaint 19'52"W, on Biscayne Bay, approximately nine miles east of Florida City, Florida. The plant and its surrounding area covers approximately 12,700 acres (See Attachment 1).

The plant consists of two fossil fuel units (Units 1 and 2) and two nuclear units (Units 3 and 4). Units 1 and 2 each have 402 megawatt net continuous capability. Unit 1 was put into commercial service in 1967 and Unit 2 was put into commercial service in 1968. Construction, design, and operational aspects are essentially the same for both units. Units 3 and 4 each have 693 megawatt net continuous capability. Unit 3 was put into commercial service in 1972 and Unit 4 was put into commercial service in 1973. Construction, design, and operational aspects are essentially the same for both units. All four units obtain their once through condenser cooling water from and discharge to a closed cycle recirculating cooling canal system (cooling canals). There are no discharges to waters of the United States from the plant site.

Major processes at the Turkey Point Plant which generate wastewater as a function of operating activities for the purpose of steam production to generate electricity are:

Process Units

1. Boiler and Steam Generator Makeup Water Purification Fossil and Nuclear

2. Combustion Residue Fossil Only

3. Boiler Blowdown Fossil Only

4. Steam Generator Blowdown Nuclear Only

5. Chemical Volume Control System Nuclear Only

6. Once-Through Co'ndenser Cooling Water System Fossil and Nuclear

7. Auxiliary Equipment Cooling Water Systems Fossil and Nuclear

8. Condensate Polisher Nuclear Only

9. Intake Screen Wash Fossil and Nuclear Information concerning flow rates for the various. processes described below may be found in Tables 1, 2, and 3.

1. Boiler and Steam Generator Makeu Water Purification (Fossil and Nuclear)

Municipal water is passed through a coagulator and a fine sand filter to remove suspended solids and then passed through

activated carbon filters for additional removal of organic and inorganic suspended solids. The softened, filtered water is further purified by gassing through a cation resin bed where cations such as Mg + and Ca++ are removed, and through an anion resin bed where anions such as S04= and Cl are removed. Finally, it passes through a polishing mixed bed containing both cation and anion resins.

After a period of use, the anion and cation resins become exhausted and must be returned to their original condition (regenerated). Cation resins are regenerated with 5%

(sulfuric acid) where H+ replaces the cations exchangedH2S04 by the resin during the demineralization process. The anion resin bed is regenerated with 5% NaOH (Sodium hydroxide),

where OH replaces anions exchanged by the resin during demineralization.

The sand and carbon filters are backwashed with municipal water to remove trapped suspended solids previously filtered from process water.

Corrosive anion and cation regenerant waste (pH < 2.0 SU or < 12.5 SU) is sent to a totally enclosed treatment facility where the pH is adjusted to a range of > 6.0 SU to < 8.5 SU. This waste is then discharged directly to the cooling canals or routed with the remaining anion and cation regenerant waste and sand and carbon filter backwash waters to the lined concrete neutralization basin (B-1) (see Attachment 2 for location) for neutralization and dilution treatment. Final effluent is discharged to the cooling canals.

2. Combustion Residue (Fossil)

A carbon reinjection system provides a means for collecting carbon and unburned by-products of combustion in the flue gases. This carbon residue is recycled back into the boiler fire to maximize the use of combustible material. The resulting fly ash and slag contain various non-combustible compounds, which are sluiced to one of two solids settling basins (B-2 or B-3) (see Attachment 2 for location).

Combustion residue is also accumulated during various maintenance functions. Supernatant f rom the solids settling basins is discharged to the cooling canals. Residue is chemically fixed on site or removed for vanadium reclamation.

3. Boiler Blowdown (Fossil)

Three forms of sodium phosphate are added to the boiler water for control of calcium and magnesium scaling. Ammonia hydroxide is added for pH control. Hydrazine is added for

oxygen removal. Undesirable boiler water contaminants such as Cl and silica can be introduced from condenser tube leaks.

The boiler blowdown is used to control and maintain desirable boiler water chemistry. Boiler blowdown is taken from the bottom of the steam drum and contains such materials as silica (which can deposit on steam turbine blades), dissolved solids such as sodium phosphate mentioned above, and metals such as copper and iron. Some of the boiler blowdown flashes into steam and discharges into the atmosphere. The remaining liquid portion of boiler blowdown not recovered and reused is routed into the cooling canals.

4. Steam Generator Blowdown (Nuclear)

High purity water is generated by the water treatment plant by way of carbon filtration and anion and cation exchange demineralization. The high quality water is routed to the steam generator for makeup to the water/steam cycle. Ammonium hydroxide is added for pH control and Amerzine (hydrazine based) is added for oxygen removal. Undesirable contaminants such as Cl from condenser leaks can contaminate the steam generator water. Strict operating specifications require that suspended and dissolved solids be maintained at very low levels, therefore, when the level of these parameters increase, they must be reduced by steam generator blowdown.

This blowdown is routed to the cooling canals.

During overhauls (fossil and nuclear) and/or refueling outages (nuclear only) the boilers, steam generators, feedwater systems, and/or condensers may be placed in a static mode where the internal metal surfaces of these components must be protected from corrosion. The typical method used is to fill the system with a hydrazine/ammonia/demineralized water solution. This solution must be drained and discharged to the cooling canals. The solution used to protect the steam generators and condensers in the nuclear plant, when discharged, has a pH of 10.5 standard units and contains 200-300 ppm of hydrazine. Approximately 1,000,000 gallons of the solution is discharged following each overhaul or refueling. (Quantities and hydrazine concentrations discharged by the fossil . units are significantly lower than those discharged by the nuclear units.)

5. Chemical Volume Control S stem (Nuclear)

This waste stream originates from various maintenance and operational activities which take place in the reactor auxiliary building (RAB). Flow from the chemical volume control system is intermittent.

6. Once-Throu h Coolin Water S stem (Fossil and Nuclear)

Water is withdrawn from the closed-loop cooling canal system through two intake canals on the east side of the plants

to cool the system condensers. The waste heat from the steam is transferred to the cooling water in the condensers, and the cooling water is discharged back into the cooling canal system on the west side of the plant. With all 12 circulating water pumps operating, the cooling water f low volume is approximately 1,800,000 gpm. At full load, the cooling water temperature rise is about 16oF.

7. Auxiliar Equi ment Coolin Water S stem (Fossil and Nuclear)

An additional 120,000 gpm of water from the cooling canal system is used to cool, via heat exchangers, the closed cooling water system. This water is pumped from the intake structures and is discharged into the discharge canal on the west side of the plant.

8. Condensate Polisher (Nuclear)

The condensate polishers are utilized during the startup of Units 3 and 4. Effluent from this system is discharged directly to the cooling canals. Flow from this system is intermittent. This effluent may contain small amounts of powdered resin.

9. Intake Screen Wash (Fossil and Nuclear)

Intake traveling screens are used to prevent debris from reaching the condensers. Cooling canal water is pumped through spray nozzles to clean these screens. This wash water is routed to a debris pit at the intake area or to the discharge canal.

Plant maintenance is required to maintain the steam production process, to maximize combustion e fficiency and to minimize air emissions. Routine maintenance cleaning of key plant equipment is performed at scheduled intervals. Maintenance cleaning operations generally result in the generation of wastewater. Maintenance processes producing wastewater are:

Process Units

l. Economizer Hopper Wash Fossil

2. Air Preheater Wash Fossil

3. Stack Wash Fossil

4. Dust Collector Wash Fossil

5. Boiler Fireside Wash Fossil

6. Boiler Waterside Chemical Cleaning Fossil

7. Equipment Area Routine Cleaning Fossil

8. Miscellaneous Fossil and Nuclear

Information concerning flow rates for the various maintenance activities described below may be found in Tables 1, 2, and 3.

Economizer Ho er Wash (Fossil)

The economizer section of the boiler collects combustion by-products during plant operation resulting in slag formation. Periodically, the interior surfaces of the economizer hoppers are washed. Water washing is performed approximately three times per day. The wash water is discharged to one of two onsite solid settling basins.

The supernatant from these basins is discharged to the cooling canals.

2. Air Preheater Wash (Fossil)

Air preheaters operate in an atmosphere near the dewpoint of the exit gases. Since there is some deposition of sulfur compounds on the preheater surface, wash water is typically acidic. Air preheaters are water washed weekly followed by rinsing with a 15% soda ash and sodium tripolyphosphate solution wash. The air preheater wash effluent is routed to and treated in one of two solid settling basins. Supernatant from these basins is discharged to the cooling canals.

3. Stack Wash, (Fossil)

Each stack is washed approximately every five years to remove combustion products which have adhered to the interior stack surfaces. The stack wash water is discharged to one of the two solid settling basins.

Supernatant from these basins is discharged to the cooling canals.

4. Dust Collector (Fl Ash) and Dust Collector Ho er Cleanin (Fossil)

Particulate . materials collected by the dust collectors falls into dust collector hoppers and is either reinjected into the boiler for reburning, or is sluiced to one of the solids settling basins. At present, the collectors and hoppers are not routinely washed. However, if clogging occurs, the appropriate section may be taken apart and the loose ash removed. The ash i:s caught within a curbed area and is sluiced to one of two solids settling basins.

The supernatant from these basins is discharged to the cooling canals.

5. Boiler Fireside Wash (Fossil)

Boiler fireside water wash is typically performed a minimum of once a year per unit. The high pressure water wash

is performed to clean combustion products deposited on boiler tubes during boiler operation. This system is designed to pump the boiler fireside wash water to one of two solids settling basins. The supernatant from these basins is discharged to the cooling canals.

6. Boiler Waterside Chemical Cleanin (Fossil)

Boiler water tube internal surfaces are typically cleaned every three years. Cleaning is usually performed with a 5% HC1 (hydrochloric acid) solution with a copper complexer added. Acid washes of internal boiler surfaces are performed to remove inorganic scale and metal oxides from the boiler tube surfaces. The treated water is then discharged to one of two imperviously lined solids settling basins for precipitation of the metals. The supernatant from these basins is discharged to the cooling canals.

7. E uioment Area Routine Cleanin (Fossil)

Floor drains typically receive small amounts of ash and other particulate materials, detergents, and small amounts of lubricating and fuel oils from floor and equipment cleaning and stormwater run-of f .

The drains are routed to the cooling canals after treatment via an oil separation device.

8. Miscellaneous

1. Non-E ui ment Storm Water Runoff (Fossil and Nuclear)

Storm Water (rainfall) within the plant operating area collects in floor drains and is routed directly to the cooling canals.

2. Sanitar Sewer (Fossil and Nuclear)

Sanitary'aste from showers, water closets, and other personnel-related water wastes are routed to a county-approved on-site septic tank system on the fossil side. On the nuclear side there is a sewage treatment plant which discharges to a well onsite.

Attachment 2 TURKEY POlNT PLANT FUEL. OIL STORAGE AREA SCALE 250 UNI UN z Q UNIT 3 00 t LEGENO Central Hazardous Waste Storage for Disposal Area Direction of Water Flow

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Attachment 4 DRINKING WELL INVENTORY WITHIN A ONE-QUARTER MILE RADIUS OP THE TURKEY POINT PLANT FPL is not aware of any drinking water wells located within one-quarter mile of the Turkey Point Plant. Drinking water for facilities located in this area, including the Turkey Point Plant is provided by Metro-Dade Water a Sewer Authority.

Attachment 5 TURKEY POINT 40 C F.R 117 12 ( ~ )(2) DISCLOSURE STORED ON SITE QUhNTITIES CHEMICAL LIST NUMBER DISPOSAL TYPICAL USE AVG. MAX. PURCHASED PHYSICAL STATE METHOD Ammonium Boiler/Steam Feedwater Hydroxide 28 1150 gal Generator pH control 825 gal 55 gal drum liquid Blowdown Disodium Boiler Water Phosphate 245 625 lb. 750 lb.

Treatment 50 lb. bag solid Boiler Blowdown Sodium Hydroxide 241 Anion Regenerant 5,000 gal. 8,000 gal. 3,000 gal. liquid Neutralization truckload Basin Sul furic 251 Acid Cation Regenerant 5,000 gal. 8,000 ga . 3,000 gal. liquid Neutralization truckload Basin Trisodium Phosphate 246 Boiler Water 625 lb. 750 lb. 50 lb. bag solid Boiler Treatment Blowdown Paint ToToene 263 Thinners Paint Thinners and Approved Chem.

330 gal. gal.

liquid and Solvents 440 gal. 55 drum Waste Disposer Xylene 277 Solvents Potassium Corrosion 216 50 lb. 100 lb. 10 lb. bag sol id Bichromate Control Approved Chem.

Waste Disposer Potassium Chromate 217 Corrosion 50 lb. 100 lb. 10 lb. bag sol id Approved Chem.

Control Waste Dispoer

i TABLE 1 TURKEY POINT PLANT UNITS 1 & 2 WATER DISCHARGE FLOWRATES Average Annual CatecaCor r Flowrate ( allons/ r)

Coolin Water:

Main Condenser Cooling 289,091 x 106 Auxiliary Cooling 12,609 x 106 Screen Wash 159 x 106 Sub-Total Cooling and Screen Wash Water Related Flows 301,859 x 106 Blowdown:

Boiler 2,733,000 Process/Maintenance:

Boiler Chemical Cleaning 210,000*

Air Preheater 4,257,000 Stack Wash 53,000 Boiler Fireside Wash 1,104,000 Hopper & Drain Flush 3,627,000 Dust Collector Wash 3,522,000 Total To Solids Settling Basin 12,563,000 Floor/E ui ment Area Draina e:

Equipment Area Drainage to Oily Water Separators (East & Dike Area)** 2,891,000 Non-Equipment Area Drainage 11,773,000 Water Purification Plant Wastes:

Boiler Water Make-Up Pretreat:

(Coagulator Blowdown) 6,885,000 (Sandfilter Backwash) .

2,'943,000 Make-up Treatment (Carbon Filter (Backwash) 631,000 Demineralizers (Cation/Anion/Mixed Bed) 9,145,,000 Sub-Total to Neutralization Basin 19,814,000

• Discharge to Neutralization Basin For Treatment

• • Discharged to Fuel Oil Tank Farm Diked Area

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TABLE 2 TURKEY POINT PLANT UNITS 3 & 4 WATER'DISCHARGE FLOWRATES Average Annual cate caCoi r Flowrate (Gallons/Yr)

Coolin Water:

Main Condenser Cooling Water 655,970 x 106 Auxiliary Cooling Water 50,455 x 106 Screen Wash 191 x 106 Sub-Total Cooling and Screen Wash Water Related Flows 706,616 x 10 Blowdown:

Steam Generator 139,810,000 Condensate Polisher 683,000 Process/Maintenance:

Chemical Volume Control System Monitor Tanks 4,888,000 Floor/E ui ment Area Draina e:

Equipment Area Drainage to oily water Separator (West) 631,000 Non-Equipment Area Drainage 28,225,000 Water Purification Plant Wastes:

Steam Generator Make-Up Pretreatment:

(Coagulator Blowdown) 32,955,000 (Sandfilter Backwash) 14,139,000 Make-up Treatment (Carbon filter Backwash) 2,786,000 Demineralizers (Cation/Anion/Mixed Bed) 41,995,000 Sub-Total to Neutralization Basin 91,875,000

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TURKEY POINT PLANT WATER DISCHARGE FLOWRATE

SUMMARY

Av . Flowrates catecaoCrr Gallons/Yr Gallons/Da Coolin Water:

Units 1 & 2 301,859 x 106 Units 3 & 4 706,616 x 106 Total 1,008,475 x 106 2,763 x 106 Floor/E uioment Area Draina e (Units 1, 2, 3, 4):

Oily (To Oil/Water Separators) 3,522,000 Non-Oily 39i998,000 Total 43,520,00 119,000 Chemical Waste Treatment Facilit (Units 1, 2, 3, 4):

Solids Settling Basins (For Fossil Process/

Maintenance Wastes) 12,563,000 Neutralization Basin (For Water Plant Wastes) ],] lg689~000 Total 124,252,000 340,000 Blowdowns:

Boiler (Units 1 & 2) 2,733,000 Steam Generator (Units 3 & 4) 139,810,000 Condensate Polishing (Units 3 & 4) 683,000 Total 143,226i000 392,000 Chemical Volume Control S stem Monitoring Tanks (Units 3 & 4): 4,888,000 13,000

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