ML20080H923

Updated Environ Rept for Facility

ML20080H923
Person / Time
Site:	Columbia
Issue date:	09/23/1983
From:	WASHINGTON PUBLIC POWER SUPPLY SYSTEM
To:
References
ENVR-830923, NUDOCS 8309230284
Download: ML20080H923 (750)

Text

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P W shington Public Power Supply System A JOINT oFERATING AGENCY

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S . . . . . . . . . . . . . . . . . . _ . . . . . . . _ . _ _ .. ..... _.... .......,

October 7, 1980 G02-80-221 Docket No. 50-397 Mr. Harold R. Denton, Director Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Washington, D.C. 20555

Subject:

WPPSS Nuclear Project No. 2

,, Environmental Report - Operating License Stage Amendment No. 4 Washington Public Power Supply System hereby submits sixty-one (61) copies, including three notarized originals, of Amendment 4 to the WNP-2 .

ER-OL. The largest portion 'of the amendment supplements' the ecological baseline data and updates the description of the environmental monitoring programs. .

Distribution is being made concurrently aci:ording.to the ER-OL distri-bution list provided by the NRC.

l Very truly yours, M

D L. Renberger Assistant Director, Technology slm Enclosures cc: J. R. Lewis, BPA, w/encls.

830923 PDR AD 030923 C 05000397 PDR l

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4 D Letter, D. L. Renberger to H. R. Denton

Subject:

WPPSS Nuclear Project No. 2

'h Environmental Report -

Operating License Stage Amendment No. 4 STATE OF WASHINGTON )

) ss COUNTY OF BENTON )

D. L. RENBERGER, being first duly sworn, deposes and says: That he is the Assistant Director of Technology, for the WASHINGTON PUBLIC POWER SUPPLY SYSTEM, the applicant herein; that he is authorized to submit the foregoing on behalf of said applicant; that he has read the foregoing and knows the contents thereof; and believes the same to be true to the best of his knowledge.

DATED O 7 , 1980 M D. L. RENBERGER On this day personally appeared before me D. L. RENBERGER to me known to be the individual who executed the foregoing instrument and acknowledged that he signed the same as his free act and deed for the uses and purposes herein mentioned.

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GIVEN under my hand and seal this '7 '5 '

day of C'h ,

1980.

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/ LL Lk, (A . .'(c_

NOTARY PUBLI,Q in and fg the State of Washington, residing at 0/ ..

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C'; ,P W shingtOn Public Power Supply System A JOINT OPERATING AGENCY 4 /

P O Box 968 3000 GEo WASHINGTON WAY RICHL AND. W ASHINGToN 99352 PHONttSO9) 946 1611 Docket No. 50-397 March 21, 1977 G02-77-124 Mr. Benard C. Rusche, Director Office of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D. C. 20555

Subject:

WPPSS NUCLEAR PROJECT N0. 2 ENVIRONMENTAL REPORT - OPERATING LICENSE STAGE SUBMITTAL FOR DOCKETING

Reference:

Letter, R. S. Boyd, NRC to D. L. Renberger, WPPSS, dated February 17, 1977.

Dear Mr. Rusche:

Washington Public Power Supply System is hereby submitting for docketing forty-one (41) copies including three (3) notarized originals of the subject document as requested in the referenced letter. Within (10) days of notification of docketing, distribution will be made according to the attached distribution list and an affidavit to that effect provided.

Environmental Technical Specifications are being prepared for submittal by June 1, 1977.

Very truly yours, 1

l D. L. RENBERGER Assistarit Director Generation and Technology DLR:RKW:vws Attachment i, cc: Distribution List

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Subject:

WPPSS NUCLEAR PROJECT N0. 2 ENVIRONMENTAL REPORT - OPERATING LICENSE STAGE p, SUBMITTAL FOR DOCKETING V

STATE OF WASHINGTON ss

. COUNTY OF BENTON )

D. L. RENBERGER, Being first duly sworn, deposes and says: That he is the Assistant Director, Generation and Technology, for the WASHINGTON PUBLIC POWER SUPPLY SYSTEM, the applicant herein; that he is authorized to submit the foregoing on behalf of said applicant; that he has read the foregoing and knows the contents thereof; and believes the same to be true to the best of his knowledge.

DATED , 1977 c0 I. ~

D. L. RENBERGER On this day personally appeared before me D. L. RENBERGER to me known to be the individual who executed the foregoing instrument and acknowledged that he signed the same as his free act and deed for the uses and purposes therein mentioned.

GIVEN under my hand and seal this /5(/vdayof Ndo [u , 1977.

fo/s.' k~ bf M-Notary Public in and for'the State of Washington "

Residing at '

te 4/h<<

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O DOT REGIONAL OFFICE (1) cc: (transmittal letter only)

Secretarial Representative Director U. S. Department of Transportation Washington State Parks and 3112 Federal Building Recreation Comission 915 Second Avenue P. O. Box 1128 Seattle, Washington 98174 Olympia, Washington 98504 ENVIRONMENTAL PROTECTI3 AGENCY NATIONAL LABORATORY Chief, Energy Systems Analyses (1) Dr. Philip F. Gustafson, Manager (10)

Branch (AW-459) Environmental Statement Project Office of Radiation Programs Argonne National Laboratory U. S. Environmental Protection Agency 9700 South Cass Avenue Room 645, East Tower Argonne, Illinois 60439 401 M Street, S. W.

Washington, D. C. 20460 RIVER BASIN COMMISSION Chief, Environmental Evaluation (1) Pacific Northwest River Basins Branch (WH-548) Commission (2) -

Office of Water and Hazardous Materials P. O. Box 908 U. S. Environmental Protection Agency 1 Columbia River O goom 2818, Waterside Mall Vancouver, Washington 98660 C 401 M Street, S. W.

Washington, D. C. 20460 HOUSING AND URBAN DEVELOPMENT REGIONAL OFFICE EPA REGIONAL OFFICE (4)

Regional Administrator (1)

Environmental Statement Coordinator ATTN: Environmental Clearance U. S. Environmental Protection Agency Officer Region X Office U. S. Department of Housing and 1200 6th Avenue Urban Development Seattle, Washington 98101 Arcade Plaza Building 1321 Second Avenue AR'iY ENGINEERING DISTRICT Seattle, Washington 98101 U. S. Department of the Army (1) cc: (transmittal letter only)

Corps of Engineers, Seattle 4735 East Marginal Way South Mr. Richard H. Broun Seattle, Washington 98134 Environmental Clearance Officer Department of Housing and ADVISORY COUNCIL ON HISTORIC Urban Development PRESERVATION (1) 451 7th Street, S. W., Rm. 7258 Washington, D. C. 20410 Mr. Robert Garvey, Executive Director Advisory Council on Historic Preservation iS22 K Street, N. W. , Suite 430 (q)ashington,D.C. 20005

DISTRIBUTION LIST ENVIRONMENTAL REPORT, AMENDMENTS, AND SUPPLEMENTS (Number in parens indicates number of copies)

DEPARm ENT OF COMMENCE FEDERAL POWER COMMISSION Or. Sidney R. Galler (6)

Deputy Assistant Secretary Mr. Whitman Ridgway, Chief (1) for Environmental Affairs Bureau of Power U. S. Department of Commerce Federal Power Commission, Rm. 5100 14th & Constitution, N. W., Rm. 3425 825 North Capitol Street, N. E.

Washington, D. C. 20230 Washi.1gton, D. C. 20426 Mr. Robert Ochinero, Director (1) Dr. Carl N. Schuster, Jr. (2)

National Oceanographic Data Center Federal Power Commission, Rm. 4016 Environmental Data Service 825 North Capitol Street, N. E.

National Oceanic and Atmospheric Washington, D. C. 20426 Administration U. S. Department of Commerce DEPARTMENT OF TRANSPORTATION Washington, D. C. 20235 (transmittal letter only addressed to:)

DEPART'4ENT OF INTERIOR Mr. Bruce Blancnard, Director (18) Mr. Joseph Canny Office of Environmental Projects Office of Environmental Affairs Review, Room a?39 U. S. Department of Transportation U. S. Departmant of the Interior 400 7th Street, S. W., Rm. 9422 13th & C Streets, N. W. Washington, D. C. 20590 Washington, D. C. 20240 cc: transmittal letter to:

cc: (transmittal letter only)

Chief Capt. William R. Riedel Division of Ecological Services Water Resources Coordinator Bureau of Scort Fisheries & Wildlife .W/S 73 USCG, Room 7306 U. S. Department of the Interior U. S. Department of Trans-lath & C Streets, N. W. portation Washington, D. C. 20240 400 7th Street, S. W.

Washington, D. C. 20590 DEPARTMENT OF HEALTH, EDUCATION AND WELFARE (After DES is issued, send 4 copies of ER & Amendments to Mr. Charles Custard, Director (2) Riedel)

Office of Environmental Affairs U. S. Department of Health, cc: w/l cy of enclosure:

Education and Welfare, Room 524F2 200 Independence Avenue, S. W. Mr. James T. Curtis , Jr. , Dir.

Washington, D. C. 20201 Materials Transportation Bure= '

2100 Second Street, S. W.

Washington, D. C. 20590 t

ADJOINING STATES CLEARINGHOUSES Director, Oregon Department of Energy (1) Office of the Governor (10) 528 Cottage Street, N. E. Office of Program Planning and Fiscal Management Salem, Oregon 97310 Olympia, Washington 98504 Dr. Kelly Woods (1)

Oregon Energy Facility Siting Benton-Franklin Governmental (1)

Conference Council 906 Jadwin Avenue 528 Cottage Street, N. E. Richland, Washington 99352 Salem, Oregon 97310 Librarian / Thermal Reactors Safety (1)

Group Building 130 Brookhaven National hboratory Upton, L. I., New York 11973 -

Atomic Industrial Forum (1)

Q V'

1747 Pennsylvania Avenue, N. W.

Washington, D. C. 20006 LOCAL OFFICIAL Mr. James 0. Zwicker, Chairman (1)

Benton County Board of Comissioners Courthouse Prosser, Washington 99350 STATE OFFICIAL State Planning (1)

Office of Program Planning & Fiscal Management Room 105, House Office Building Olympia, Washington 98501 Mr. Roger Polzin, Executive (1)

Secretary Energy Facility Site Evluation Council '

820 East Fifth Avenue Olympia, Washington 98504

O WPPSS NUCLEAR PROJECT NO. 2 ENVIRONMENTAL

'O REPORT OPERATING LICENSE STAGE DOCKET NO. 50-397 WASHINGTON PUBLIC POWER SUPPLY SYSTEM 3000 GEORGE WASHINGTON WAY RICHLAND WASHINGTON 99352 O '

WNP-2 ER

( ,) ENVIRONMENTAL REPORT OPERATING LICENSE STAGE TABLE OF CONTENTS Chapter Title Page_

1 PURPOSE OF THE PROPOSED FACILITY 1.0-1 1.0 Definition 1.0-1 1.1 Need for Power 1.1-1 1.2 Other Objectives 1.2-1 1.3 Consequences of Delay 1.3-1 2 THE SITE AND ENIVRONMENTAL INTERFACES 2.1-1 2.1 Geography and Demography 2.1-1 2.2 Ecology 2.2-1 2.5 Meteorology 2.3-1 2.4 Hydrology 2.4-1 2.5 Geology 2.5-1 2.6 Regional Historic, Scenic, Cultural, and Natural Features 2.6-1 3 THE PLANT 3.1-1

(')/

N 3.1 External Appearance 3.1-1 3.2 Reactor and Steam-Electric System 3.2-8 3.3 Plant Water Use 3.3-1 3.4 Heat Dissipation System 3.4-1 3.5 Radwaste Systems and Source Term '3.5-l 3.6 Chemical and Biocide Wastes 3.6-1 3.7 Sanitary and Other Wastes 3.7-1 3.8 Reporting of Radioactive Material Movement 3.8-1 3.9 Transmission Facilities 3.9-1 4 ENVIRONMENTAL EFFECTS OF SITE PREPARATION, PLANT AND TRANSMISSION FACILITIES CONSTRUCTION 4.1-1 4.1 Site Preparation and Plant Construction 4.1-1 4.2 Transmission Facilities Constuction 4.2-1 4.3 Resources Committed 4.3-1 4.4 Radioactivity 4.4-1 4.5 Construction Impact Control Program 4.5-1 5 ENVIRONMENTAL EFFECTS OF PLANT OPERATION 5.1-1 5.1 Effects of Operation of Heat Dissipation System 5.1-1 5.2 Radiological Impact from Routine Operation 5.2-1 5.3 Effects of Chemical and Biocide Discharges 5.3-1 5.4 Effects of Sanitary Waste Discharges 5.4-1

((~T_,) 5.5 Effects of Operation and Maintenance of the Transmission Systems 5.5-1 i

WNP-2 ER TABLE OF CONTENTS (Continued)

Chapter Title _Page_

5.6 Other Effects 5.6-1 5.7 Resources Committed 5.7-1 5.8 Decommissioning and Dismantling 5.8-1 6 EFFLUENT AND ENVIRONMENT 7 7 MEASUREMENT AND MONITORING PROGRAMS 6.1-1 6.1 Preoperational Environmental Programs 6.1-1 6.2 Operational Environmental Programs 6.2-1 6.3 Related Environmental Measurement and Monitoring Programs 6.3-1 6.4 Preoperational Environmental Radiological Monitoring Data 6.4-1 7 ENVIRONMENTAL EFFECTS OF ACCIDENTS 7.1 Station Accidents Involving Radioactivity 7.1-1 7.2 Other Accidents 7.2-1 8 ECONOMIC AND SOCIAL EFFECTS OF PLANT CONSTRUCTION AND OPERATION 8.1-1 8.1 Benefits 8.1-1 8.2 Costs 8.2-1 9 ALTERNATIVE ENERGY SOURCES AND SITES 9.1-1 9.1 Alternatives Not Requiring the Creation of New Generating Capacity 9.1-1 9.2 Alternatives Requiring the Creation of New Generating Capacity 9.2-1 9.3 Selection of Candidate Areas 9.3-1 9.4 Cost-Benefit Comparison of Candidate Site -

Plant Alternatives 9.4-1 10 PLANT DESIGN ALTERNATIVES 10.1-1 10.1 Cooling System Alternatives 10.1-1 10.2 Intake System 10.2-1 10.3 Discharge System Alternatives 10.3-1 10.4 Chemical Waste Treatment 10.4-1 10.5 Biocide Treatment 10.5-1 10.6 Sanitary Waste System 10.6-1 10.7 Liquid Radwaste Systems 10.7-1 10.8 Gaseous Radwaste Systems 10.8-1 10.9 Transmission Facilities 10.9-1 10.10 Other S.ystems 10.10-1 11 SUMMA RY BENEFIT-COST ANALYSIS 11.1-1 ii

i

-WNP-2 ER 1

TABLE OF CONTENTS

(Continued) j Chapter Title Page 12 ENVIRONMENTAL APPROVALS AND CONSULTATION 12.1-1 12.1 General State Licensing 12.1-1 i 12.2 General Federal Licensing 12.2-1 12.3 State and Federal Water Related Permits 12.3-1

=

12.4 State, Local and Regional Planning -

Economic Impact 12.4-1 12.5 Specific Permit Status 12.5-1

, 12.6 Other 12.6-1 13 REFERENCES 13.1-1 APPENDIX I. ENVIRONMENTAL TECHNICAL SPECIFICATIONS I-l APPENDIX II. RADIOLOGICAL DOSE MODELS II-t APPENDIX III. STATEMENT BY HISTORIC PRESERVATION OFFICER III- 1 APPENDIX IV. NATIONAL POLLUTANT DISCHARGE ELIMINA. TION SYSTEM WASTE DISCHARGE PERMIT IV-1

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WNP-2 ER-OL LIST OF TABLES Table No.

1.1-1(a) PACIFIC NORTHWEST UTILITIES CONFERENCE COMMITTEE WEST GROUP AREA - COMPARIS0N OF ACTUAL WITH ESTIMATED WINTER PEAK LOADS 1.1-1(b) PACIFIC NORTHWEST UTILITIES CONFERENCE COMMITTEE WEST GROUP AREA - PERCENT DEVIATION BETWEEN ACTUAL AND ESTIMATED WINTER PEAK FIRM LOADS 1.1-2(a) PACIFIC NORTHWEST UTILITIES CONFERENCE COMMITTEE WEST GROUP AREA - COMPARISON OF ACTUAL WITH ESTIMATED 12 MONTHS AVERAGE FIRM LOADS 1.1-2(b) PACIFIC NORTHWEST UTILITIES CONFERENCE COMMITTEE WEST GROUP AREA - PERCENT DEVIATION BETWEEN ACTUAL AND ESTIMATED 12 MONTHS AVERAGE FIRM LOADS 1.1-3

SUMMARY

OF LOADS AND RESOURCES 1.1-4 WEST GROUP RESOURCE ADDITIONS BY SCHEDULED DATE &

COMMERCIAL OPERATION 1.1-5 WEST GROUP RES9URCE ADDITIONS BY PROBABLE ENERGY DATES 1.1-6 PUBLIC AGENCY - BPA ENERGY RESOURCES & REQUIREMENTS 1.1-7 WEST GROUP CAPACITY (PEAK) RESOURCES AND. REQUIREMENTS 1.1-8 WEST GROUP ENERGY RESOURCES AND REQUIREMENTS 2.1-1 POPULATION DISTRIBUTION BY COMPASS SECTOR AND DISTANCE FROM THE SITE 5 2.1-2 DISTANCES FROM WNP-2 TO VARIOUS ACTIVITIES 2.1-3 INDUSTRY WITHIN A 10 MILE RADIUS OF SITE 2.2-1(a) TERRESTRIAL FLORA AND FAUNA NEAR WNP-1/4 AND WNP-2 2.2-1(b) COLUMBIA RIVER BIOTA 4

2.2-2 NUMBER OF SPAWNING FALL CHIN 0OK SALMON AT HANFORD, 1947 - 1977 O

iv Amendment 5 July 1981

WNP-2 ER i

LIST OF TABLES (continued) l Table No.

J

, 2.3-la AVERAGES AND EXTREMES OR CLIMATIC ELEMENTS AT HANFORD i

2.3-lb AVERAGES AND EXTREMES OR CLIMATIC ELEMENTS AT HANFORD (cont.)

i 2.3-2a ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT -

VERY UNSTABLE 2.3.2b ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT -

UNSTABLE j 2.3.2c ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY

! CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT l AND TEMPERATURES BETWEEN 245 AND 33 FT - NEUTRAL l 2.3.2d ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 and 33 FT - STABLE

~

2.3.2e ANNUAL JO. TNT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND j TEMPERATURES BETWEEN 245 AND 33 FT - VERY STABLE 2.3-2f ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT - STABILITY UNKNOWN t

i 2.3-3a ANNUAL JOINT FREQUENCY OF WIND SPEED AND DIRECTION FOR WNP-2 AT 7 FT FROM 4/74 TO 3/75 2.3-3b ANNUAL JOINT FREQUENCY OF WIND SPEED AND DIRECTION FOR WNP-2 AT 33 FT FROM 4/74 TO 3/75

! 2.3-3c ANNUAL JOINT FREQUENCY OF WIND SPEED AND l DIRECTION FOR WNP-2 AT 245 FT FROM 4/74 TO 3/75 2.3-4 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, APRIL 1974 2.3-5 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS

() FOR WNP-2, MAY 1974

! V

WNP-2 ER LIST OF TABLES (continued)

Table No.

2.3-6 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, JUNE 1974 2.3-7 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, JULY 1974 2.3-8 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, AUGUST 1974 2.3-9 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, SEPTEMBER 1974 2.3-10 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, OCTOBER 1974 2.3-11 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, NOVEMBER 1974 2.3-12 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, DECEMBER 1974 2.3-13 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, JANUARY 1975 2.3-14 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, FEBRUARY 1975 2.3-15 MO:;THLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, ! ~.A RC H 1975 2.3-16a-e SEASONAL PERCENT FREQUENCY DISTRIBUTION OF WIND SPEED AND WIND DIRECTION AT HMS VS. ATMOSPHERIC STABILITY USING TEMPERATURE DIFFERENCE BETWEEN 3 AND 200 FOOT LEVELS AND WINDS AT 200 FEET FOR THE PERIOD 1955 - 1970 2.3-17 CLIMATOLOGICAL REPRESENTATIVENESS OF THE YEAR USED IN THE DIFFUSION COMPUTATIONS 2.3-18 COMPARISOlJ OF ONSITE AND LONGTERM DIFFUSION ELEMENTS 2.3-19a JOINT FREQUENCY TABLES BY PASQUILL STABILITY GROUPS FREQUENCY OF OCCURRENCE, WIND DIRECTION VS. SPEED FROM 4/74 THROUGH 3/75 AT WPPSS 2 FOR 33 FT LEVEL (TEMPERATURE CHANGE LESS THAN -2.1 AND GREATER THAN OR EQUAL DEGREES F PER 200 FT)

Vi

WNP-2 ER LIST OF TABLES

( (continued)

Table No.

2.3-19b (TEMPERATURE CHANGE LESS THAN -1/9 AND GREATER THAN OR EQUAL -2.1 DEGREES F PER 200 FT) 2.3-19c (TEMPERATURE CHANGE LESS THAN -1.6 AND GREATER THAN OR EQUAL -1.9 DEGREES F PER 200 FT) 2.3-19d (TEMPERATURE CHANGE LESS THAN -0.5 AND GREATER

! THAN OR EQUAL -1.6 DEGREES F PER 200 FT) 2.3-19e (TEMPERATURE CHANGE LESS TAHN 1.6 AND GREATER THAN OR EQUAL -0.5 DEGREES F PER 200 FT) 2.3-19f (TEMPERATURE CHANGE LESS THAN 4.4 AND GREATER THAN OR EQUAL 1.6 DEGREES F PER 200 FT) 2.3-19g (TEMPERATURE CHANGE LESS THAN AND GREATER THAN OR EQUAL 4.4 DEGREES F PER 200 FT) 2.3-19h (TEMPERATURE CHANGE IN DEGREES F PER 200 FT UNKNOWN)

() COMPARISON OF MONTHLY AVERAGE AND EXTREMES 2.3-20 OF HOURLY AVERAGE AIR TEMPERATURES 2.3-21 COMPARISON OF MONTHLY AVERAGES OF WET BULB TEMPERATURES 2.3-22a FREQUENCY OF OCCURRENCE OF WET BULB VALUES A FUNCTION OF TIME OF DAY BASED ON WNP-2 SITE DATA 4/74 - 3/75 2.3-22b l 2.3-23 MONTHLY AVERAGES OF PSYCHROMETRIC DATA BASED l ON PERIOD OF RECORD 1950 - 1970 l

2.3-24 MISCELLANEOUS SNOWFALL STATISTICS: 1946 - 1970 I 2.3-25 AVERAGE RETURN PERIOD (R) AND EXISTING RECORD (ER) FOR VARIOUS PRECIPITATION AMOUNTS AND INTENSITY l DURING SPECIFIED TIME PERIODS AT HANFORD 2.3-26a WNP-2 ONSITE JOINT FREQUENCY DISTRIBUTION OF WINDS FOR RAIN INTENSITY CLASSES, RAIN INTENSITY GREATER THAN OR EQUAL TO .016 INCHES PER HOUR 2.3-26b RAIN INTENSITY GREATER THAN OR EQUAL TO 0.50 INCHES

() PER HOUR vii l

WNP-2 ER LIST OF TABLES (continued) lll Table No.

2.3-26c RAIN INTENSITY GREATER THAN OR EQUAL TO .100 INCHES PER HOUR 2.3-26d RAIN INTENSITY GREATER THAN OR EQUAL TO .016 INCHES PER HOUR 2.3-26e RAIN INTENSITY GREATER THAN OR EQUAL TO .500 INCHES PER HOUR 2.3-27 MONTHLY AND ANNUAL PREVAILING DIRECTIONS, AVERAGE SPEEDS, AND PEAK GUSTS: 1945 - 1970 AT HMS (50 FT LEVEL) 2.3-28 MONTHLY MEANS OF DAILY MIXING HEIGHT AND AVERAGE 1 WIND SPEED 2.4-1 COLUMBIA RIVER MILE INDEX 2.4-2 MEAN DISCHARGES IN CFS, OF THE COLUMBIA RIVER BELOW PRIEST RAPIDS DAM, WA O

2.4-3 MONTHLY AVERAGE WATER TEMPERATURE, IN C, AT g RICHLAND, WA 2.4-4 MOBTHLY AVERAGE WATER TEMPERATURE, IN C, AT RICHLAND, WA 2.4-5

SUMMARY

OF WATER QUALITY DATA FOR THE COLUMBIA RIVER AT SELECTED SITES 2.4-6 CHEMICAL CHARACTERISTICS OF COLUMBIA RIVER WATER AT 100 F --1970 (RESULTS IN PARTS /MILLION) l 2.4-7a

SUMMARY

OF WATER QUALITY ANALYSES OF THE COLUMBIA RIVER BELOW PRIEST RAPIDS DAM (RIVER MILE 395) FOR 1972 WATER YEAR 2.4-7b 1972 WATER YEAR (cont.)

2.4-7c 1972 WATER YEAR (cont.)

2.4-8 AVERAGE CHEMICAL CONCENTRATIONS IN THE COLUMBIA RIVER AT PRIEST RAPIDS DAM, OCTOBER 1971 TO SEPTEMBER 1972 2.4-9 DISCHARGE LINES TO COLUMBIA RIVER FROM HANFORD RESERVATION 2.4-10 TOTAL ANNUAL DIRECT CHEMICAL DISCHARGE FROM HANFORD RESERVATION TO COLUMBIA RIVER Amendment 1 viii May 1978

WNP-2 ER LIST OF TABLES (continued) i Table No.

2.4-11 MAJOR GEOLOGIC UNITS IN THE HANFORD RESERVATION AREA AND THEIR WATER BEARING PROPERTIES i

1 2.4-12 AVERAGE FIELD PERMEABILITY (FT/ DAY) 1 3.3-1 PLANT WATER USE

,I 3.5-1 NOBLE GAS CONCENTRATION IN THE REACTOR STEAM NUMERICAL VALUES - CONCENTRATIONS IN PRINCIPAL FLGID 1

! 3.5-2 AVERAGE NOBLE GAS RELEASE RATES FROM FUEL 1

3.5-3 CONCENTRATIONS OF HALOGENS IN REACTOR COOLANT i

AT REACTOR VESSEL EXIT NOZZLES (uCi/gm)

) 3.5-4 CONCENTRATIONS OF FISSION PRODUCTS IN REACTOR COOLANT AT REACTOR VESSEL EXIR NOZZLES

,' (uCi/gm) 3.5-5 CONCENTRATIONS OF CORROSION PRODUCTS IN REACTOR COOLANT AT REACTOR VESSEL EXIT NOZZLES

O' (uCi/gm)

! 3.5-6 CONCENTRATIONS OF WATER ACTIVATION PRODUCTS IN REACTOR COOLANT AT REACTOR VESSEL EXIT NOZZLES l (uCi/gm) a 3.5-7 RADIONUCLIDE CONCENTRATIONS IN FUEL POOL i

3.5-8 ESTIMATED RELEASES FROM DRYWELL AND REACTOR BUILDING VENTILATIONS SYSTEMS 3.5-9 ESTIMATED RELEASES FROM TURBINE BUILDING VENTILATION 3.5-10 ESTIMATED RELEASES FROM RADWASTE BUILDING 3.5-11 ESTIMATED RELEASES FROM MECHANICAL VACUUM PUMP 3.5-12 ANNUAL RELEASES OF RADIOACTIVE MATERIAL AS LIQUID 3.5-13 RADWASTE OPERATING EQUIPMENT DESIGN BASIS 3.5-14 RADWASTE SYSTEM - PROCESS PLOW DIAGRAM DATA (9 PAGES) 3.5-15 EQUIPMENT DRAIN SUBSYSTEM SOURCES O

ix Amendmant 1 May 1978

WNP-2 ER LIST OF TABLES lg (continued)

Table No.

3.5-16 FLOOR DRAIN SUBSYSTEM SOURCES 3.5-17 CHEMICAL WASTE SUBSYSTEM SOURCES 3.5-18 OFF-GAS SYSTEM PROCESS DATA 3.5-19 RELEASE POINT DATA 3.5-20 NOBLE GAS RELEASE RATE INTO ATMOSPHERE FROM OFF-GAS SYSTEM 3.5-21 ESTIMATED ANNUAL AVERAGE RELEASES OF RADIOACTIVE MATERIALS FROM BUILDING VENTILATION SYSTEMS, GLAND SEAL AND MECHANICAL VACUUM PUMPS 3.5-22 EXPECTED ANNUAL PRODUCTION OF SOLIDS 3.5-23 SIGNIFICANT ISOTOPE ACTIVITY ON WET SOLIDS AFTER PROCESSING 3.5-24

SUMMARY

OF RADIOACTIVE EFFLUENT MONITORING AND CONTROL POINTS g

3.6-1 WATER COMPOSITION COLUMBIA RIVER, DEMINERALIZER WASTE, COOLING TOWER BLOWDOWN 3.8-1 RADIOACTIVE MATERIAL MOVEMENT 3.9-1 500 KV AND 230 KV LINE ELECTRICAL CHARACTERISTICS 5.1-1 TIMING OF SALMON ACTIVITIES IN THE COLUMBIA RIVER NEAR HANFORD FROM L.O. ROTHFUS TESTIMONY IN TPPSEC 71-1 HEARINGS (EXHIBIT 62) 5.1-2 ESTIMATED A "TAL PERCENT PERSISTENCE OF ELEVATED VISIBLE PLUML LENGTHS 5.1-3 ESTIMATED ANNUAL PERCENT PERSISTENCE OF ELEVATED VISIBLE PLUME LENGTHS WITH THE AIR TEMPERATURE 0 C OR LESS 5.1-4 MONTHLY ELEVATED VISIBLE PLUME LENGTHS PERCENT PERSISTENCES 5.1-5 PREDICTED VISIBLE PLUME WIDTHS IN METERS AS A FUNCTION OF MONTH AND DOWNWIND DISTANCE O

X l

WNP-2 ER l'\d) LIST OF TABLES (continued)

Table No.

5.1-6

SUMMARY

OF FOGGING IMPACT ESTIMATES 5.1-7 INCREASE IN RELATIVE HUMIDITY AT POINTS OF MAXIMUM POTENTIAL IMPACT 5.2-1 RELEASE RATES AND CONCENTRATION OF RADIONUCLIDES IN THE LIQUID EFFLUENTS FROM WNP-2 5.2-2 RELEASE RATES AND CONCENTRATIONS OF RADIONUCLIDES IN THE AIRBORNE EFFLUENTS FROM WNP-2 5.2-3 ANNUAL AVERAGE ATMOSPHERIC DILUTION FACTORS (E/Q')

5.2-4 CONCENTRATIONS OF IMPORTANT RADIONUCLIDES IN VARIOUS ENVIRONMENTAL MEDIA 5.2-5 ASSUMPTIONS USED FOR BIOTA DOSE ESTIMATED 5.2-6 ASSUMPTIONS USED IN ESTIMATING DOSES FROM THE LIQUID PATHWAY

,O

(_/ 5.2-7 ASSUMPTIONS USED IN ESTIMATING DOSES FROM THE GASEOUS PATHWAY 5.2-8 ANNUAL DOSE RATES TO BIOTA ATTRIBUTABLE TO THE WNP-2 NUCLEAR PLANT (mrad /yr) 5.2-9 ESTIMATED ANNUAL DOSES TO AN INDIVIDUAL FROM THE LIQUID AND GASEOUS EFFLUENTS OF WNP-2 5.2-10 ESTIMATED ANNUAL DOSES TO AN INDIVIDUAL FROM THE LIQUID AND GASEOUS EFFLUENTS OF WNP-2, WNP-1, AND WNP-4 5.2-11 FRACTION OF RADIONUCLIDE PASSING THROUGH WATER TREATMENT PLANTS 5.2-12 ASSUMPTIONS FOR ESTIMATING DOSES FROM CROPS AND

< ANIMAL FODDER SUBJECT TO DEPOSITION OF RADIOACTIVE MATERIALS RELEASED BY THE PLANT

, 5.2-13 CUMULATIVE POPULATION, ANNUAL POPULATION DOSE,

! FROM SUBMERSION IN AIR CONTAINING RADIONUCLIDES FROM THE WUP-2 AND COMBINED RELEASES OF WNP-2 AND WNP-1 AND WNP-4 X1

e f WNP-2 ER LIST OF TABLES (continued)

Table No.

5.2-15 ESTIMATED ANNUAL POPULATION DOSES ATTRIBUTABLE TO WNP-2 AND COMBINED RADIONUCLIDE RELEASES OF WNP-1, WNP-2 and WNP-4 5.3-1 MAXIMUM POTENTIAL CHANGE IN COLUMBIA RIVER WATER QUALITY RESULTING FROM WNP-2 CHEMICAL DISCHARGES 5.8-1 PRELIMINARY ESTIMATES OF DISMANTLING AND DECOMMISSIONING COSTS 6.1-1 MASS SIZE DISTRIBUTION OF DRIFT DROPLETS 4 6.1-2 FISH SAMPLING FREQUENCY BY STATION AND METHOD 6.1-3 RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM 1 6.1-4 KEY FOR FIGURE 6.1-3 6.1-5 MAXIMUM VALUES FOR THE LOWER LIMIT OF DETECTION (LLD) 6.2-1 WATER QUALITY MONITORING PROGRAM 4l 6.3-1 ROUTINE ENVIRONMENTAL RADIATION SURVEILLANCE SCHEDULE -

1979 6.3-2 ENVIRON. ENTAL RADIATION SURVEILLANCE NETWORK WASHINGTON STATE DEPARTMENT OF SOCIAL AND HEALTH SERVICES, HEALTH 4l SERVICES DIVISION, JUNE 1978 7.1-1 CLASSIFICATION OF POSTULATED ACCIDENTS AND OCCURRENCES 7.1-2 RADIATION EXPOSURE

SUMMARY

l 7.1-3 TABLE OF EVENT PROBABILITIES 7.1-4 SOME U.S. ACCIDENTAL DEATH STATISTICS FOR 1971 8.1-1 ELECTRIC POWER REQUIREMENTS BY MAJOR CONSUMER CATEGORIES IN THE PACIFIC NORTHWEST 8.2-1 COST COMPONENTS OF WNP-2 l 8.2-2 INFORMATION REQUESTED BY NRC I

8.2-3 ESTIMATED COST OF ELECTRICITY FROM WNP-2

! 8.2-4 POPULATION DATA FOR THE TRI-CITY AREA I

O xii Amendment 4 October 1980 l

WNP-2 ER LIST OF TABLES (continued)

Table No.

8.2-5 PROJECTED SHORT-TERM POPULATION GROWTH IN TRI-CITY AREA 8.2-6

SUMMARY

OF REGIONAL GROWTH INDICATORS 1 10.1-1 CAPITALIZED TOWER ENERGY CONSUMPTION -

10.1-2 COST CAMPARISON OF MECHANICAL DRAFT COOLING TOWERS 10.2-1 INTAKE SCHEMES DIFFERENTIAL COST COMPARISON 10.2-2 COMPARISON OF ALTERNATIVE INTAKE SYSTEMS 10.9-1 ALTERNATIVE TRANSMISSION ROUTES 12.1-1 PERMITS AND APPROVALS REQUIRED FOR PLANT CONSTRUCTION AND OPERATION O

0-- xiii Amendment 1 May 1973 i

!_.., _____.-,_-_.,,...-,.,__m., ,, , , - , , _ , _ . _ , . , . , , _ _ _ _ , , , _ _ , , _ . . , . . , _ , _ _ _ _ _ , . _ _ . _ , , _ . _ _ _ , _ _ _ , _ _ _ , . _ _

WNP-2 ER-OL LIST OF ILLUSTRATIONS Figure No. -

1.1-1 ESTIMATED VERSUS ACTUAL WINTER FIRM PEAK LOADS PNW-WEST GROUP AREA 1.1-2 ESTIMATED VERSUS ACTUAL ANNUAL AVERAGE FIRM LOADS PNW-WEST GROUP AREA 1.1-3 .U.S. & PNW (WEST GROUP AREA) PEAK LOADS 1.1-4 ELECTRIC ENERGY REQUIREMENTS BY MAJOR CONSUMER CATEGORIES PACIFIC NORTHWEST (WEST GROUP AREA) 1.1-5 FACTORS CAUSING INCREASE IN ENERGY SALES TO DOMESTIC CONSUMERS IN WEST GROUP OF PNW 1950-1973 1.1-6 WEST GROUP AREA LOAD CRITICAL WATER 1981-1982 1.1-7 ESTIMATED CAPACITY RESERVES 1977-1987 2

1.1-8 ESTIMATED ENERGY DEFICITS 1978-1987 2.1-1 SITE LOCATION MAP 2.1-2 HANFORD RESERVATION BOUNDARY MAP 2.1-3 SITE PLAN 2.1-4 SITE PLOT PLAN 2.1-5 HANFORD RESERVATION ROAD SYSTEM

. 2.1-6 HANFORD RESERVATION RAILROAD SYSTEM l

2.1-7 PROJECT AREA MAP - 10 MILE RADIUS l

2.1-8 PROJECT AREA MAP - 50 MILE RADIUS i

l 2.1-9 DISTRIBUTION OF TRANSIENT POPULATION 5

l 2.1-10 DELETED l 2.1-11 DELETED i 2.1-12 DELETED l

l l

1 l

O xiv Amendment 5 July 1981 e

_ . _ _ . _ _ _ - _ _ . . . _ . . . . . _ _ . _ _ ....m . . . . . .._ ..

J WNP-2 ER-OL LIST OF ILLUSTRATIONS

~

(continued)

Figure No.

2.1-13 DELETED 2.1-14 DELETED 2.1-15 DELETED 2.1-16 DELETED 5

2.1-17 DELETED i

2.1-18 DELETED 2.1-19 DELETED 2.1-20 DELETED 2.2-1 DISTRIBUTION OF MAJOR PLANT COMMUNITIES (VEGATATION TYPES)

ON THE ERDA HANFORD RESERVATION, BENTON COUNTY, WA 2.2-2 FOOD-WEB 0F COLUMBIA RIVER

2.2-3 SEASONAL FLUCTUATION OF PLANKTON BIOMASS 2.2-4 SEASONAL FLUCTUATION OF NET PRODUCTION RATE OF PERIPHYTON 2.2-5 TIMING 0F UPSTREAM MIGRATIONS IN THE LOWER COLUMBIA RIVER ,

2.3-1 WIND ROSE FOR WNP-2 FOR 4-74 TO 3-75 AT THE 7 FT LEVEL 2.3-2 WIND ROSE FOR WNP-2 FOR 4-74 TO 3-75 AT THE 33 FT LEVEL ,

2.3-3 WIND ROSE FOR WNP-2 FOR 4-74 TO 3-75 AT THE 245 FT LEVEL l

1 i

I O

xv Amendment 5 July 1981

- - . . . _ . _ ~ . . . _ . _ - , _ , _ _ _ . _ _ . , _ _ _ . . -

WNP-2 ER l

l LIST OF ILLUSTRATIONS (continued)

Figure No.

2.3-4 WIND ROSES FOR HANFORD STABILITY CLASSES AT WNP-2 FOR 4-74 TO 3-75 AT THE 33 FT LEVEL 2.3-5 WIND ROSE AS A FUNCTION OF HANFORD STABILITY AND FOR ALL STABILITIES OF HMS BASED ON WINDS AT 200 FT AN3 AIR TEMPERATURE STABILITIES BETWEEN 3 FT AND 200 FT FOR THE PERIOD 1955 THROUGH 1970 2.3-6 SURFACE WIND ROSES FOR VARIOUS LOCATIONS ON AND SURROUNDING THE HANFORD SITE BASED ON FIVE-YEAR AVERAGES (1952-1956). SPEEDS ARE GIVEN IN MILES PER HOUR 2.3-7 MONTHLY HOURLY AVERAGES OF TEMPERATURE AND RELATIVE HUMIDITY 2.3-8 MONTHLY HOURLY AVERAGES OF TEMPERATURE AND RELATIVE HUMIDITY 2.3-9 MONTHLY HOURLY AVERAGES OF TEMPERATURE AND RELATIVE HUMIDITY 2.3-10 ANNUAL HOURLY AVERAGE OF TEMPERATURE AND RELATIVE HUMIDITY 2.3-11 AVERAGE MONTHLY PRECIPITATION AMOUNTS BASED ON THE PERIOD 1912-1970 AT HMS 2.3-12 RAINFALL INTENSITY, DURATION, AND FREQUENCY BASED ON THE PERIOD 1947-1969 AT HMS 2.3-13 PEAK WIND GUST RETURN PROBABILITY DIAGRAM AT HMS 2.4-1 UPPER AND MIDDLE COLUMBIA RIVER BASIN 2.4-2 DISCHARGE DURATION CURVES OF THE COLUMBIA RIVER BELOW PRIEST RAPIDS DAM, WA 2.4-3 FREQUENCY CURVE OF ANNUAL MOMENTAF.Y PEAK FLOWS FOR THE COLUMBIA RIVER BELOW PRIEST RAPIDS DAM, WA 2.4-4 FREQUENCY CURVES OF HIGH AND LOW FLOWS FOR THE COLUMBIA RIVER BELOW PRIEST RAPIDS DAM, WA 2.4-5 CROSS SECTIONS OF THE COLUMBIA RIVER IN THE PLANT VICINITY O

xvi

WNP-2 ER

/^%

b LIST OF ILLUSTRATIONS (continued)

Figure No.

2.4-6 LOCATION OF INTAKE AND DISCHARGE LINES WNP-1, WNP-4 AND WNP-2 2.4-7 ELEVATION CONTOURS OF THE RIVER BOTTOM AT THE WNP-2 DISCHARGE (FEET ABOVE SEA LEVEL) 2.4-8 RIVER WATER SURFACE PROFILES FOR SEVERAL FLOW DISCHARGES IN THE VICINITY OF,THE PLANT SITE 2.4-9 AVERAGE MONTHLY TEMPERATURE COMPARISON FOR PRIEST RAPIDS DAM RICHLAND, FOR 10-YEAR PERIOD 1965-1974 2.4-10 COMPUTED LONG TERM TEMPERATURE ON THE COLUMBIA RIVER AT ROCK ISLAND DAM (1938-1072) 2.4-11 ONE HOUR DURATION FREQUENCY CURVE OF HIGH RIVER WATER TEMPERATURE IN THE VICINITY OF

<s THE PROJECT SITE 2.4-12 TWENTY-FOUR HOUR DURATION FREQUENCY CURVE OF HIGH RIVER WATER TEMPERATURE IN THE VICINITY OF THE PLANT SITE 2.4-13 SEVEN DAY DURATION FREQUENCY CURVE OF HIGH RIVER WATER TEMPERATURE IN THE VICINITY OF THE PROJECT SITE 2.14-14 SIMPLIFIED GEOLOGICAL CROSS SECTION OF THE HANFORD RESERVATION, WASHINGTON 2.4-15 UROUNDWATER CONTOURS AND LOCATIONS OF WELLS FOR THE HANFORD RESERVATION, WASHINGTON, SEPT. 1973 2.4-16 POINTS OF GROUNDWATER WITHDRAWAL IN THE VICINITY 3 OF WNP-2 3.1-1 WNP-2 PLANT SITE 3.1-2 WASHINGTON PUBLIC POWER SUPPLY SYSTEM 3.1-3 MECHANICAL DRAFT COOLING TOWER ELEVATION 3.1-4 MAKE-UP WATER PUMPHOUSE ELEVATION

() 3.1-5 WNP-2 MAKE-UP WATER PUMP HOUSE 3.1-6 WNP-2 EFFLUENT RELEASE POINTS xvii Amendment 3 January 1979

WNP-2 ER LIST OF ILLUSTRATIONS h (continued)

Figure No.

3.2-1 CORE ARRANGEMENT 3.2-2 TYPICAL CORE CELL 3.2-3 FUEL ASSEMBLY ENRICHMENT DISTRIBUTION 3.2-4 STEAM AND RECIRCULATION WATER FLOW PATHS 3.2-5 GE REACTOR SYSTEM HEAT BALANCE FOR RATED POWER 3.2-6 DIRECT CYCLE REACTOR AND TURBINE SYSTEM 3.2-7 NET PLANT HEAT RATE VARIATIONS VS. TURBINE BACK PRESSURE 3.3-1 PLANT SYSTEMS WATER USE DIAGRAM 3.4-1 MECHANICAL DRAFT COOLING TOWERS PLCT PLAN 3.4-2 TOWER CENTER SECTION THRU FILL 3.4-3 COOLING TOWER PERFORMANCE CURVE O

3.4-4 MONTHLY AVERAGE FLOW RATES AND TEMPERATURES 3.4-5 INTAKE SYSTEM PLAN AND PROFILE 3.4-6 MAKE-UP WATER PUMPHOUSE PLAN AND SECTIONS l

3.4-7 PERFORATED INTAKE PLAN AND SECTIONS i 3.4-8 PERFORATED PIPE INTT.KE DISTANCE VS. INTAKE FLOW VELOCITIES l

3.4-9 PERFORATED PIPE INTAKE VELOCITY DISTRIBUTION 3/8" AWAY FROM SCREEN SURFACE 3.4-10 RECTANGULAR SLOT DISCHARGE 3.5-1 FLOW DIAGRAM PROCESS FLOW DIAGRAM LIQUID 3.5-2 FLOW DIAGRAM RADIOACTIVE WASTE SYSTEM EQUIPMENT PROCESSING l

l XViii

i WNP-2 ER-OL O

(,,) LIST OF ILLUSTRATIONS (continued)

Figure No.

3.5-3 FLOW DIAGRAM RADI0 ACTIVE WASTE SYSTEM FLOOR DRAIN PROCESSING 3.5-4 FLOW DIAGRAM CHEMICAL WASTE PROCESSING 3.5-5 FLOW DIAGRAM PROCESS OFF-GAS SYSTEM LOW TEMPERATURE N-67-1020 3.5-6 FLOW DIAGRAM 0FF-GAS PROCESSING SYSTEM RADWASTE BUILDING 3.5-7 FLOW DIAGRAM 0FF-GAS PROCESSING TURBINE BUILDING 3.5-8 FLOW DIAGRAM HVAC-0.G. CHARC0AL ADS 0RBER VAULT RADWASTE BUILDING 3.5-9 FLOW DIAGRAM HEATING & VENTILATION SYSTEM REACTOR BUILDING 3.5-10 FLOW DIAGRAM RADWASTE BUILDING HEATING AND VENTILATION SYSTEM

("'s 3.5-11 FLOW DIAGRAM HEATING & VENTILATION SYSTEM TUR8INE BUILDING 3.5-12 FLOW DIAGRAM RADI0 ACTIVE WASTE DISPOSAL SOLID HANDLING 3.5-13 FLOW DIAGRAM FUEL P0OL C0OLING AND CLEANUP SYSTEM 5

3.7-1 SANITARY WASTE TREATMENT SYSTEM 3.9-1 500 KV, 230 KV, 115 KV POWER LAYOUT 3.9-2 CONFIGURATIONS OF BPA TRANSMISSION TOWERS 3.9-3 230 KV RIGHT-GF-WAY DETAIL MAP 3.9-4 BONNEVILLE POWER ADMINISTRATION'S H. J. ASHE SUBSTATION 4.1-1 CONSTRUCTION PROGRESS

SUMMARY

4.1-2 WNP-2 PERSONNEL ESTIMATE 5.1-1 BLOWDOWN PLUME CENTERLINE TEMPERATURES l4 i

! (~')

V xix Amendment 5 July 1981

WNP-2 ER LIST OF 'LLUSTRATIONS (continued)

Figure No.

5.1-2 PLAN VIEW 0F WNP-2 AND WNP-1/4 BLOWDOWN PLUME IS0 THERMS 5.1-3 CROSS-SECTION OF WNP-2 BLOWDOWN PLUME IS0 THERMS 5.1-4 DELETED 4 5.1-5 DELETED 5.1-6 DELETED 5.1-7 DELETED 5.1-8 DELETED 5.1-9

SUMMARY

OF TEMPERATURE EXPOSURE AND THERMAL TOLERANCE OF JUVENILE SALM0NIDS 5.1-10 EQUILIBRIUM LOSS AND DEATH TIMES AT VARIOUS TEMPERATURES FOR JUVENILE CHIN 0OK SALMON R. E. NAKATANI, EXHIBIT 49, TPPSEC 71-1 hearing 5.1-11 SALT DEPOSITION PATTERNS OUT TO 0.5 MILE (1b/ acre /yr) 5.1-12 SALT DEPOSITION PATTERNS OUT TO 6.9 MILE (1b/ acre /yr) 5.2-1 EXPOSURE PATHWAYS FOR ORGANISMS OTHER THAN MAN 5.2-2 EXPOSURE PATHWAYS TO MAN 6.1-1 AQUATICBIOTAANDWATERQUdLITYSAMPLINGSTATIONSNEAR WNP-1, 2, AND 4 6.1-2 TERRESTRIAL ECOLOGY STUDY SITES IN THE VICINITY OF WNP-2 6.1-3 RADIOLOGICAL SAMPLE STATION LOCATIONS 6.1-4 PERCENT CAN0PY LOVER OF HERBS IN VICINITY OF WNP-2 4

6.1-5 AVERAGE HERB PRIMARY PRODUCTIVITY IN VICINITY OF WNP-2 O

u Amendment 4 October 1980

WNP-2

ER LIST OF ILLUSTRATIONS

()

<~

(continued)

Figure No.

6.3-1 HANFORD EVIRONMENTAL AIR SAMPLING LOCATIONS l4

. 6.3-2 RADIOLOGICAL MONITORING ' STATIONS AT HANFORD OPERATED BY 00E l 6.3-S STATEWIDE SAMPLING LOCATIONS

~

10.2-1 MODIFIED CONVENTIONAL INTAKE PLAN AND SECTION 10.2-2 MODIFIED CONVENTIONAL INTAKE GENERAL ARRANGEMENT PLAN 10.2-3 INFILTRATION BED INTAKE GENERAL ARRANGEMENT PLAN 10.2-4 INFILITRATION BED INTAKE PLAN AND SECTIONS 10.2-5 PERFORATED PIPE INTAKE IN OFF-RIVER CHANNEL 10.9-1 OVERALL MAP 0F ROUTES "A" AND "B" 10.9-2 RIGHT-0F-WAY DETAIL MAP ROUTE "A" 10.9-3 AERIAL PHOTOGRAPH OF LAND CROSSED BY TRANSMISSION LINES

( )) 10.9-4 LAND USE HANFORD RESERVATION 10.9-5 RIGHT-0F-WAY DETAIL MAP ROUTE "B" F

f I Amendment 4 xxi October 1980 i

9 WNPc2 ER v

CHAPTER 1 PURPOSE OF THE PROPOSED FACILITY 1.0 DEFINITION In order to satisfy power needs of the Pacific Northwest region, a nuclear electric generating facility has been proposed to be operated in the State of Washington by the l2 Washington Public Power Supply System (" Supply System").

The proposed nuclear electric generating project, Washington Public Power Supply System Nuclear Project No. 2 (WNP-2) rated at 1,100 MWe, is located on a site within the .2 U. S. Department of Energy (DOE) Hanford Feservation in i Benton County, Washington, approximately 12 miles north of the city of Richland, Washington.

1.0.1 The Supply System The Supply System is a joint operating agency formed under Chapter 43.52 of the Revised Code of Washington. The Supply System was originally formed in 1957. As a joint operating agency, the Supply System is legally empowered "to generate, 7 's produce, transmit, transfer, exchange or sell electric

')

energy and to enter into contracts for any or all such purposes." (RCW 43.52.300) The Supply System is specif-icatlly authorized to issue revenue bonds to finance the construction of projects and facilities undertaken by it.

The management and control of the Supply System is vested in a Board of Directors composed of a representative of each of its members. The members of the Supply System have a pre-ference right to purchase all the energy generated by the Supply System. A joint operating agency may not acquire or operate distribution properties, nor does it have a general taxing authority of any kind.1 The Supply System is specifi-cally authorized to make contracts relating to the purchase, sale, interchange or wheeling of power with the Government of the United States or any agency thereof, or with any municipal corporation or public utility within or outside the State of Washington.

The business of the Supply System is conducted in public meetings of the Board of Directors and all actions taken are by resolution or motion of the Board of Directors, and all records and minutes are public pursuant to the laws of the State of Washington. An Executive Committee composed of 7 members administers the business of the Supply System between regular meetings of the Board of Directors. A Managing g *-

l k# 1.0-1 Amendment 2 October 1978 l

WNP-2 ER Director, appointed by the Board of Directors, ic the chief executive officer of the Supply System and is authorized to administer the business of the Supply System pursuant to rules, resolutions and policies promulgated by the Board of Directors. A joint operating agency such as the Supply System must obtain the approval of legislative bodies of a majority of its members prior to undertaking any project.

All bonds or notes issued by the Supply System must be sold at public bidding and all contracts over a stipulated amount are required to be entered into under public biding proce-dures. The Supply System has no authority to impose any debt or financial obligation on the State of Washington or any of its political subdivisions, including its members.

The authority granted to the Supply System by statute applies equally to the generation of electricity by " water power, by steam power, by nuclear power or by any other means whatsoever" (RCW 43.52.260).

The Supply System, whose membership is made up of 19 opera-ting puolic utility districts and the municipal electrical systems of Richland, Seattle, and Tacoma, all located in the State of Washington, has its principal office in Richland, Washington. It has the power of eminent domain, but is specifically precluded from the condemnation of any plants, works or facilities owned and operated by any city, public utility district or privately-owned electric utility. The l

Supply System will operate WNP-2 and have continuing respon-sibility for its maintenance.

The Supply System owns and operates the Packwood Lake Hydro-Electric Project with a nameplate rating of 27,500-KWA. It also owns and operates an 860,000 kilowatt electric genera-ting plant and associated facilities (the "Hanford Generating Project") located on the Hanford Reservation. Steam is provided from the New Production Reactor ("NPR"), owned and operated by the United States Department of Energy (DOE).

DOE has recently negotiated a contract with the Supply System to supply steam from the NPR until July 1983. The Supply System is building two other nuclear electric generating plants on the Hanford Reservation; such facilities are known as the Washington Public Power Supply System Nuclear Project No. 1 (WNP-1) and the Washington Public Power Supply System Nuclear Project No. 4 (WNP-4). In addition, two nuclear 2

electric generating plants, Washington Public Power Supply System Nuclear Project No. 3 (WNP-3) and Washington Public Power Supp'.y System Nuclear Project No. 5 (WNP-5) are under construction about 16 miles east of Aberdeen in Grays Harbor County, Washington.

1.0-2 Amendment 2 October 1978

WNP-2 ER r~s 1.0.2 WNP-2 i

(

WNP-2 ("the Project") is being undertaken pursuant to the Hydro Thermal Power Program described in Section 1.1 developed jointly by the utilities of the Pacific Northwest and BPA.

The Pacific Northwest Utilities Conference Committee ("PNUCC")

represents the entities serving the loads of the West Group area of the Northwest Power Pool and assembles the loads and resources forecasts of the individual utilities into an 11-year forecast, known as the West Group Forecast past issues of which are on file with the Federal Power Commission (FPC). The forecast includes loads and resources for Northern Idaho, Washington, Oregon (except for the southeastern part of the state), a portion of Northern California, the loads and resources of Pacific Power and Light Company and Bonneville Power Administration (BPA) in Western Montana, the BPA loads and the United States Bureau of Reclamation ("USBR") resources in Southern Idaho. PNUCC also expands the forecast into a 20-year planning document titled, "Long-Range Projection of Power Loads and Resources for Thermal Planning West Group Area". Except for minor corrections and additions to the West Group forecast data, the first ll-year data of the Long-Range Projection is the same as the West Group Forecast.

In its planning, PNUCC seeks to:

a) Optimize available resources; b) Reduce reserves required for adequate system reliability by providing for the inter-utility sharing of reserve requirements; and c) Improve sersice and reliability of the region's inter-connected system.

The Projects have been timed, sized and located to economi-cally meet regional power requirements consistent with the basic philosophy of the Hydro-Thermal Power Program, of contributing to the growth and stability of the Pacific Northwest. The basic tenets of this philosophy are to:

a) Continue to preserve the environmental and natural beauties of the Northwest.

b) Make efficient and economic use of the federal regional transmission system.

c) Obtain the economics of scale from large thermal gen-erating plants.

I i 1.0-3 i

WNP-2 ER d) Coordinate the required large thermal generating plants with existing Pacific Northwest hydro plants, both federal and non-federal, and with future peaking gen-rating units (both hydro-electric and combustion turbine),

to achieve an economical, reliable power supply to meet the electric power requirements of the Pacific Northwest.

WNP-2 will be constructed and operated by the Supply System as part of Phase 1 of the Hydro-Thermal Power Program, a program designed to meet the anticipated needs for power in the Pacific Northwest.

Ninety-four consumer-owned utilities in the Pacific Northwest will participate in WNP-2. The public agency participants, all of which are statutory preference customers of BPA, currently obtain all or part of their power supply and other services from BPA. Each participant's share of annual costs of plant operation will be " net-billed" against the billings made by BPA to the participant on a monthly basis under its power sales and other contracts. Under the net billing arrangement, each participating utility contracts with the Supply System to purchase a portion of the WNP-2 electrical output and in turn sells this electricity to BPA for distri-bution over its regional transmission grid system. In payment for this power, BPA credits the amounts paid by each partici-pant to the Supply System against amounts the participant owes BPA for power purchased and other services. h Since the participant's payments to the Supply System will be net billed, the cost of their shares of the power pro-duced by WNP-2 will be borne by BPA customers. BPA has assured Congress that "any costs or losses to Bonneville under these agreements will be borne by all Ponneville ratepayers through rate adjustments, if necessary".

l l

l l

9 1.0-4

WNP-2 ER 1.1 NEED FOR POWER Until the present decade, the Pacific Northwest has relied on hydro-generation for nearly all of its electric energy requirements. Future hydro-developments in the Pacific Northwest, however, will consist largely of the installation of peaking generation because nearly all the economically feasible regional hydro sites have been developed. The integration of new thermal generating resources with the hydro resources of the Northwest to maximize reliability has

,been a goal of the region's power planning for'many years.

Utilities of the region commenced practicing coordination on 4

a voluntary basis more than 30 years ago by the establish-ment of the Northwest Power Pool (NWPT).

In 1964, 14 utilities and three federal entities formalized this coordination in the crea by signing the long-term f Pacific Northwest Coordination Agreement which expires in 2003, a copy of which is on file with the Federal Power Commission (FPC). To meet the Northwest's firm energy requirements, five Northwest investor-owned utilities, 104 consumer-owned agencies, the Supply System and BPA, acting in concert as the Joint Power Planning Council ("The Council"),

in 1968 conceived the Hydro-Thermal Power Program. The Hydro-Thermal Power Program was approved by the Secretary of O the Interior on October 22, 1968, and the federal portion of the program was approved through 1981 by the Congressional enactment of the Public Works Appropriation Act of 1971.

Installation schedules were established for seven large thermal plants needed in addition to the probable hydro-l generation installation to supply the requirements of the

~

region through the operating year 1981-1982. (Phase 1 of the Hydro-Thermal Power Program.)

A review of load and resource forecasts for the region was '

i undertaken in mid-1973 to reassess the resource requirements of the region because of slippage in the federal hydro installation schedule, the inability of the large Centralia Thermal Project to reach rated capacity because of environ-mental considerations, the energy crisis, and the then impending shutdown of United States Energy Research and Development Administration (ERDA) NPR which furnishes steam to the Hanford Generating Project. Consideration was given in the review to the effect on the use of electrical energy to be expected from a continuing educational program for the efficient use of all types of energy. The revised forecast indicated a continuing deficiency of both capacity and energy.

O 1.1-1

WNP-2 ER Because of the projected resource deficiency, Phase 2 of the Hydro-Thermal Power Program was formulated. It contains a f schedule of thermal plant installations to eliminate, as rapidly as possible, the forecasted resource deficiencies.

This installation schedule (date of commercial operation) extends through 1985. Recently the PNUCC has taken over the functions of the Joint Power Planning Council and the Council has become inactive.

The Supply System serves the region as a bulk power supplier for the numerous consumer-owned utilities throughout the region. As such, facilities built by the Supply System can realistically be considered as regional resources.

1.1.1 Load Characteristics The characteristics of both the Pacific Northwest loads and the electrical power supply system have developed together and are relatively unique within the United States. Most of the regional power is presentJy being generated at hydro-electric projects, many of which are owned by the federal government. Much of the power flows to the distributing utilities over Bonneville Power Administration transmission lines. Customers in the area, other than industrial direct service customers of BPA, are served by either investor-owned utilities, public utility districts, municipal systems, or cooperative rural electrification systems. Due to the region's vast hydro-electric resources electrical energy costs in the Pacific Northwest have been quite low, leading to high per capita consumption of electrical energy. As a consequence, per capita use of other forms of energy are less than they might otherwise have been for some industrial and commercial uses and for such residential uses as cooking, water heating, and space heating. Some electrical-energy-intensive industry has also developed in the region.

The electrical supply resource of the region is entering a transition period since the major part of the economically attractive energy potential obtainable from hydro-electric l projects has already been developed. Because demand fluctu-ates on a daily, weekly, and annual basis, additional capa-city is being installed at existing hydro projects to shape energy to load requirements. The region foresees greater l

usaoe of hydro resources for peaking, with thermal resources suct as WNP-2 operating as baseload units at high plant fac-tore except for times when sufficient water supply is avail-abl*; to displace thermal output.

Tohroperlyasscus the need for the Project, consideration must be given to the unique featufes of the power supply in the Pacific Northwest. Although hydro capability in the area is abundant, firm energy and dependable peaking capacity, produced from existing regional hydro resources, are limited 1.1-2 i

3 0

. - - . - _ _ - - __ .- - - . _ _ - . = - .

WNP-2 ER d

O not only by installed machine capacity but also by usable

water storage volume available to the region. Existing hydro projects in the West Group area have nearly exhausted the sites that can be developed on an economical and environ-mentally acceptable basis. Most additional developments that can meet these conditions are either under construction i or in firm planning stages with substantial amounts of money i committed for planning and engineering. These additional

, projects have been included in load forecasts made by the j Pacific Northwest Utilities Conference Committee (PNUCC).

The West Group utilities have established a " critical period" of adverse water conditions to be used in both planning and i

operations. Adverse stream flows of historical record, coupled with installed machine capability and storage volume usable for power production, determine the length of such critical period. By definition, under a repeat of the most adverse stream flows of historical record, no water is spilled past generating facilities except for water spilled q past existing run-of-the-river facilities that are incapable of fully utilizing such adverse flows. Although additional dependable capacity, needed to shape energy to load require-ments, can be added to the coordinated system by installing additional generators at existing hydro projects, only a small amount of additional firm energy can be produced by 1 O' such additions. As previously stated, there is very little potential in the West Group area for additional reservoir volume required to increase firm energy production. For this reason, the area is required to construct base load thermal plants to supply the forecasted energy requirements of the area and to add hydro capacity to shape such thermal energy production to load requirements.

1.1.1.1 Utility Organizations of the Area Prior to 1940, few high-voltage inter-tie transmission facilities existed between utilities in the Pacific North-west. Existing tielines were used primarily for emergency purposes. Very little benefit was derived from inter-utility or intra , regional diversity. Because of isolated system operation, both firm and nonfirm power were not totally available to serve loads of the area.

Early in the 1940's, war-related industries in the area were rapidly increasing their power requirements on the utilities .

At the urging of the Federal War Production Board, the utilities stepped up construction and installation of gen-erating facilities and joined together to coordinate the i power output of all installed facilities. Bonneville Power Administration had been formed by an act of Congress in 1937 O- and was given authority to construct transmission facilities 1.1-3 4

, - , , . ---,-,. - o ,,.n.,, ..-,,.-,--.-,,,-,,,,n,.,,., ,,,-,,.,,,,-,..,,,,.n.-- , - , , - ~ - , ,- ,,.-- -,,,, ,,

WNP-2 ER in order to market federal power produced by projects in the area built by the Corps of Engineers and the Bureau of Reclamation. These BPA lines formed a transmission network interconnecting most of the utilities in the area and made power from all the major power projects in the Pacific Northwest available on an areawide basis. Because of this transmission network, the area's utilities were able to coordinate resources.

a) The Northwest Power Pool (NWPP)

The NWPP was formed by the operating management of the generating utilities in the Pacific Northwest for the purpose of coordinating the operation of the hydro and thermal resources of the area in order to optimize, to the extent possible, the availability of firm power to serve the loads of the area. Coordinated operation also provided a means:

1) Of resolving problems of interconnected operation of utility systems;

2) Of utilizing to the greatest advantage possible nonfirm power in the area; and

3) of reducing required reserves to a minimum by pooled use of such reser"es.

Membership in the NWPP includes consumer- and investor-owned generating utilities, BPA, the Corps of Engineers the United States Bureau of Reclamation (USBR) and two Canadian utilities. Member utilities in the United States serve loads in the states of Montana, Idaho, Utah, Wyoming, Washington, Oregon and Northern California.

In order to accomplish the objectives of pooling, the NWPP employed a staff of engineers, known as the Coordi-nating Group, to make studies and forecasts, on a short-term basis, necessary to best utilize the pooled resources to serve the loads of the area. A " critical period" concept was developed. Reservoir regulation studies are made on a coordinated system basis and reservoir operating rule curves are established each year for each reservoir, such that with a repeat of the most adverse water conditions of history, firm loads of the area can be carried. Loads above the critical period firm resource capability are relegated to a nonfirm or interruptible basis.

Voluntary coordiantion worked to the advantage of both the utilities and industry and therefore was continued W

after the war ended.

1.1-4

WNP-2 ER i'

f One of: the factors contributing to the successcof1 NWPP

3. was that each member. utility maintained itseindependent utility responsibility in planning and.operatingcits

.g , system but worked through the pool.to coordinatei;these functions with other utilities to the best advantage of

.the region. , ,

44

>r, #

b)- Pacific: Northwest Utilities Conference Committee m

(PNUCC) i- u, ,

wea

, >->nm

,o ,

,The NWPP. devotes.its efforts primarily to..short-term planning and resource coordination and to< current >

operating problems. Management soon recognized the

- < benefits that4 were> afforded to utilities.through..the ef forts of the NWPP- and- decided to expand those < bene-fits:through coordination of long-term planning <for construction and installation of generating-facilities.

t PNUCC was organized,.also on a voluntary, basis,xto

. accomplish this purpose. PNUCC:is an informal-'asso-ciation of public and private utilities in thenPa~cific

.-Northwest. ; Membership is open.to all utilitiesnin the Pacific Northwest but many of the. smaller ~ utilities depend upon BPA to represent them. PNUCC established a Loads and Resources Subcommittee and:delegatedito it c3 the: responsibility for. assembling.the loads andnresources

( ) . forecasts made annually, by. the utility. members: and

. compiling them intoa single forecast: document 2 RWhen PNUCC was formed, lead. time for. installation ofEhydro-generation.was approximately four years. Forecas.ts

.w ere.made for an 11-year. period beyond.the, current

- operating. year.to provide adequate time:foreplanning and installation.of. additionally required resources.

~

By 1968 lead time for: installation of. generating. faci-lities had increased to about 10 years, necessitating

the expansion.of the West; Group forecast tog.a long-range: forecast. covering loads and probable resources

1. for,an additional 9-year period. This.expandednfore-

cast-is titled, "Long-Range Projection of' Power Loads

,- z and. Resources for Thermal: Planning" and is commonly referred to as the " Blue. Book" because of the: color of

.its cover.

• J ^ ""

a<

c) Canadian Treaty and Columbia Storage Power > Exchange On January 17, 1961, the " Treaty Between the' United

- - States,of America and Canada Relating to the Cooperative Development of the Water Resources of the Columbia River Basin" (" Canadian Treaty") was signed by the

_ United States and Canada. Among other things, this t

1.1-5

WNP-2 ER treaty and the notes exchanged pursuant to the treaty provided for the construction, maintenance and operation by Canada of three dams and storage reservoirs in British Columbia on the Columbia River and its tributaries.

The controlled release of water stored in those reser-voirs provides flood control and increases the dependable capacity and usable energy produced at hydro-electric power projects on the Columbia River in the United States. The treaty specifies that the United States and Canada are each entitled to one-half of this increase of dependable capacity and usable energy.

Canada offered to sell its share of the Treaty Benefits to a single entity in the United States in order to obtain money to construct the dams. No single entity with the ability to finance such a purchase existed in the Pacific Northwest so utility management formed a non-profit-no-stock corporation called the Canadian Storage Power (CSPE) to raise the capital required and purchase the Canadian entitlement to the treaty bene-fits (Canadian Entitlement).

CSPE resold the Canadian Entitlement to 41 investor-owned and consumer-owned utilities in the Pacific Northwest under tri-party exchange agreements between h CSPE, Bonneville and the individual utilities whereby CSPE delivers Canadian Entitlement capacity and energy as received from the Columbia River hydro-electric developments in the United States to the purchasing utility. Each utility, in turn, exchanges such capa-city and energy with Bonneville for federal capacity and energy shaped within limits, as necessary to meet the utilities load requirements.

Although the Canadian Entitlement was surplus to the neede of the Pacific Northwest at the time of the purchase, forecasts indicated it would be usable in the area in the early 1970's. The cost of the Canadian Entitlement was higher than the power production costs in the Pacific Northwest but was lower than power production costs in California. Consequently, most of the Canadian Entitlement was in turn sold to California utilities on a five-year pull-back provision. A portion was committed to the State of California through the 1982-1983 operating year. All of the Canadian Entitle-ment sold to California utilities has been withdrawn.

O 1.1-6

WNP-2 ER r3 (Q 1 Pacific Northwest Coordination Agreement d)

Early in the negotiations pertaining to the Canadian Treaty and to CSPE it became apparent that voluntary coordination could not insure compliance with all the provisions and operating procedures that would be required when Canadian Treaty power became available.

Negotiations were therefore started to formalize coordination of generating utilities affected by the Canadian Treaty provisions. On September 15, 1964, the Pacific Northwest Coordination Agreement (" Coordination Agreement") was signed by three federal entities and 14 generating utilities having facilities affected by the treaty.

Among other things, the Coordination Agreement provides, on a regular basis, for:

1) Establishing a Critical Period based on historical water records.

2) Making Critical Period reservoir regulation studies f on an integrated system basis and establishing

(' reservoir operating curves (Energy Content Curves and Critical Rule Curves).

3) Determining Firm Load Carrying Capability (FLCC) for the Coordinated System and for each System.

4) Establishing required forced outage reserves for the Coordinated System and for each System.

5) Coordinating maintenance outages for the best resource usability by each System and by the Coordinated System.

6) Mandatory interchange of capacity and energy between Systems to assure the ability of each System and the Coordinated System to carry firm load up to the determined FLCC.

7) Conservation of nonfirm energy by coordinated use of available reservoir storage volume.

8) Use of third party transmission, as available, for Coordination Agreement requirements.

9) Mandatory release of water from upstream reservoirs, stored above Energy Content Curve, or delivery by

[~')i

\_ upstream reservoir owner of equivalent energy in lieu of water releases.

1.1-7 i

WNP-2 ER

10) Computation of and payment for upstream and coordina-tion benefits, subject to the FPC approval.

11) Determination of priorities on use of facilities for Coordination Agreement requirements.

12) Determination of rates to be paid for Coordination Agreement services.

13) Restoration of FLCC to those Systems whose FLCC is reduced due to the lengthened Critical Period occasioned by the additional storage provided under the Canadian Treaty. Restoration is accom-plished by the Systems who gain FLCC from the increased storage (Columbia River main stream projects) sharing a portion of the gain with the Systems (off stream projects) who lose FLCC.

The Coordination Agreement treats the Coordinated System as being a single utility system having a single capacity and energy requirement and with total resources dedicated to serve that requirement. The NWPP Coor-dinating Grcup was expanded to provide the necessary engineering required to assemble and publish load and resource data relating the immediately upcoming Critical Period, to run reservoir regulating studies for planned reservoir operation, to determine FLCC and reserves and, in general, to guide operations under the Coordi-nation Agreement.

Under provisions of the Coordination Agreement each System representative, in joint meeting with other System 1spresentatives, is permitted to adjust, within limits, the plan for reservoir operation of its System reservoirs to meet its System's individual requirements.

l Such adjustments do not permit the reduction of coordi-nated System firm capability without a commensurate reduction in estimated firm load to be carried.

By coordinating the resources of the Coordination Agreement signatories, both in planning and under l operating conditions, additional firm capability is l made available to the area and nonfirm energy is con-served to a greater extent than is possible under isolated utility planning and operation. Emergency

assistance is provided to each System as required.

Coordinated System-wide sharing of forced outage reserves reduces the amount of such reserves below what would be required under isolated system operation.

Additional resources brought on line by a System become O

1.1-8

WNP-2 ER O a part of the Coordinated System resources unless the System constructing such facilities declares them to be outside the Coordinated System and operates then on an isolated basis.

Signing of the Coordination Agreement did not eliminate the NWPP since some members of the Pool do not have generating facilities that are affected by provisions of the Canadian Treaty, and therefore, are not signa-tory to the Coordination Agreement. The NWPP coordi-nates the resources of its members, including utilities in British Columbia, who are not in the Coordination Agreement with the resources of the Coordinated System and further assists the area by analyzing and, to the extent possible, solving the operating problems of regional interconnected operation as they arise.

e) West Group Area of NWPP NWPP was divided into two groups early in its exis-tence, because of technical communication problems within the NWPP, mainly due to the inability of the telephone company to set up conference calls between all members. Utilities in Montana, Idaho, Utah and Wyoming became the East Group and those in Washington, O Oregon and Northern California, plus BPA, the Corps of Engineers and the USBR became the West Group.

When PNUCC assigned the responsibility for load and resource forecasting to its Subcommittee on Loads and Resources, all NWPP members were requested to submit relevant data to the subcommittee. The East Group and British Columbia declined. The PNUCC Forecast there-fore became known as the West Group Forecast.

The West Group Area utilities serve loads in the area comprised of Northern Idaho, Washington, Oregon except for the southeastern part of the state, a portion of Northern California, the area in Western Montana served by EPA and Pacific Power and Light Company and the area in Southern Idaho served by BPA with resources of the USBR located in that area.

() 1.1-9

WNP-2 ER f) Western Systems Coordinating Council (WSCC) lll In 1967 management of the major utilities in 13 western states organized the WSCC in order to improve system reliability through coordinated planning and operation and to assess adequacy of power resources to meet forecasted load. Full membership is open to all utili-ties in the area who have bulk power supply resources or major transmission facilities that could affect bulk power deliveries. Associate membership is available to all utilities in the area who do not meet the require-ments of full membership. Memberchip is voluntary.

WSCC through its planning and operating committees has formulated and published "WSCC Reliability Criteria" consisting of two parts, namely:

1) Reliability Criteria for System Design

2) Minimum Operating Reliability Criteria Systems in the Pacific Northwest have agreed to adopt these criteria.

WSCC was the first reliability council to be formed.

As other areas organized councils, WSCC promoted the formation of the National Electric Reliability Council (NERC) to which all regional councils belong. NERC g

coordinates the activities of all regional councils and correlates regional council replies to requests from the FPC for information relative to reliability and adequacy of power resources and reserves. The NWPP, as a subregion, reports on such matters for all member utilites through WSCC.

1.1.1.2 West Group Historical Data PNUCC, since it was organized, has coordinated planning and forecasting for the West Group area and has a long-term record of reliability in forecasting. The historical winter peak firm load, the historical 12-month average firm load (energy demand), and the projections of these same values 1l for each year's West Group Forecast from 1967 through 1977 have been summarized in Tables 1.1-1 (a) and (b) and 1.1-2 (a) and (b) respectively. This information has also been presented graphically in Figures 1.1-1 and 1.1-2.

9 1.1-10 Amendment 1 May 1973

WNP-2 ER

~

1.1.1.3 Long Range Projection of Power Loads and Resources for Thermal Planning - West Group Area (Long Range Projection)

Forecasts assembled by the PNUCC Loads and Resources Subcom-mittee treat the West Group area as one large system having a single capacity and energy load requirement and a single critical period capacity and energy capability.

Each utility member of PNUCC annually submits forecasts of the following items by months for the ensuing 11 years, and by years for an additional 9 years:

a) Capacity and energy load requirements; b) Critical period capacity and energy capabilities; c) Schedule of imports into, and exports from, the West Group area; d) Exchanges of capacity and energy with other utilities within the West Group area; e) New resources to be added and existing resources to be s retired.

1 ThefirsyyplyearsareincludedinboththeygytGroup Forecast and in the Long-Range Projection but the final 9 years are included only in the Long-Range Projection.

Table 1.1-3 is a summary, on a noncoincidental basis, of the recently prepared Long-Range Projection for the years 1978-1979 through 1997-1998. This forecast is a basis for planning for transmission line construction, resource instal-lation and reserve requirements for the West Group Area.

Table 1.1-3 shows a cumulative annual load growth for the ll-year period from 1978-1979 through 1988-1989 of 3.9% from 2 16,721,000 average kilowatts to 24,445,000 average kilowatts.

This compares to the estimated national cumulative annual load growth of 4.5% (see Figure 1.1-3).

New generation planned for installation in the West Group Area through 1985 is discussed in Section 1.1.2.

The Pacific Northwest region has strong transmission ties with the Southwest and British Columbia and uses these ties for interregional transfers of surplus capacity and energy and for emergency assistance. Some firm capacity and energy interchanges also flow over these inter-ties. Only the firm interchanges over these ties are included in the compilation of the Long-Range Projection. The need for WNP-2 is based on the forecast contained in Table 1.1-3.

1.1-11 Amendment 2 October 1978

,- - . .-. ~- . ._ _ -- .. -. . . . . - . .

WNP-2 ER 1.1.1.4 Methodology of Forecasts 9

No single method of forecasting loads and resources is employed in compiling the Long-Range Projection. Rather, it is a compilation and summarization of the forecasts of the individual utilities serving the loads of the West Group area. The compilation and summarization is done by the PNUCC Loads and Resource Subcommittee.

The smaller consumer-owned utilities in the West Group area do not submit individual load and resource forecasts directly to the PNUCC Loads and Resource Subcommittee. Forecasts for such utilities are prepared cooperatively by the utility and BPA and are then included in the BPA loads and resource report to PNUCC. The method used by BPA and the utilities in the preparation of the fprecasts is described in a BPA

" Load Estimating Manual".(31 The technique suggested in this manual is to break the load into component parts and examine the factors affecting growth in that component.

Although historical trends are recognized as one method, the need to relate the growth of each component to economic pressures is emphasized. For example, because of the large space heating component of load in the region, that load is usually treated independently within the service area, with population growth and heating load saturation considered.

Seven large member utilities of the Supply System listed below submit individual forecasts to PNUCC.

a) The City of Seattle, Department of Lighting b) The City of Tacoma, Department of Lighting c) Snohomish County Public Utility District No. 1 d) Cowlitz County Public Utility District No. 1 e) Clark County Public Utility District No. 1

-f) Chelan County Public Utility District No. 1 g) Grays Harbor County Public Utility District No. 1 O

1.1-12

WNP-2  !

I ER n

s_- The methodology used by these utilities are described below.

City of Seattle, Department of Lighting Both peak and energy forecasts are based on historical data adjusted to current conditions. Loads are segre-gated by standard classifications: residential, commer,-

cial, light industry and heavy industry. Historical growth trends for each classification are analyzed and an estimated future growth rate assigned. Previous year data are then extrapolated for current year and for the next three years and adjusted to meet the previous 11-year forecast load curve at the end of the third year of the new forecast. If a large adjustment is required, a completely new analysis is done and a new 20-year forecast is prepared. Seattle has recently had a study prepared by an independent consultant, titled Energy 1990, in which an independent load and resource forecast is included.

City of Tacoma, Department of Lighting Loads are segregated as to heat sensitivity. A heat sensitivity curve is drawn for 100% sensitivity at 20-4 s degrees F and 0% sensitivity at 70-degrees F. Normal

~

months temperatures are taken from the Weather Bureau's long-term determination. Previous year's heat sensi-tive loads a.e temperature adjusted by months. A curve fitting program has been developed to extrapolate temperature adjusted historical data on a month by month basis to derive the peak and energy forecasts for an ll-year period. A similar program is used for non-heat sensitive loads. The two forecasts are then combined to give an ll-year forecast of peak and energy requirement for use as required by planning programs.

This forecast is then e :panded by years to complete the 20-year forecast.

Snohomish County PUD The previously mentioned BPA Load Estimating Manual is used as a guide to developing forecasts of peak and

. energy requirements. Power Supply personnel of the District work closely with BPA in applying this guide.

Because of the large loads of such industries as aero-l space and wood processing, adjustments to the metho-dology are incorporated to assure a forecast represen-tative of the utility load.

O 1.1-13 i

t /'

WNP-2 ER New forecasts are made at intervals of approximately O

three years and upgraded yearly. If a yearly review indicates wide variance from previously used data, such as population growth rate, customer usage or industrial expansion, a completely new forecast is prepared.

Cowlitz County PUD Each class of customer is evaluated independently.

Population growth, levels of usage, saturation and expected changes in large industrial loads are con-sidered in the load forecasts.

In estimating the power requirements of the District, a number of general assumptions have been made relative to the future economy of the region. The recent announce-ments of expansions by both Longview Fibre Company and Weyerhaeuser at the Longview site and the dedication to environmental improvements at the sites indicates the local economy will remain strong; therefore, in the current forecast the economy of the county is assumed to remain healthy with continued expansion and techno-logical improvements of the industrial sector.

The load estimated is normalized for average weather conditions and other variable factors that affect the power and energy requirements. It is assumed that awareness of the need to conserve all forms of energy resources will not drastically change the historic pattern of electric energy growth. The assumption is based on the opinion that more efficient use of electric energy will be made, but electric energy will be substi-tuted for other energy resources because of environmental and conservation reasons. The load forecast does not provide for a major conversion from other energy resources to electric energy; for example major conversion to electrified vehicles.

Completely new forecasts are made whenever an annual review of the previous forecast, as pdated, indicates that data relative to population growth rate, industrial expansion or customer usage have changed to the extent that updating of previous load data has given a distorted forecast.

1.1-14

r WNP-2 ER 9

Clark County PUD The District makes its own forecasts of peak and energy requirements essentially based on the BPA guidelines adjusted to fit the District's needs. The forecast is then reviewed in detail with BPA both to ensure that data used are reasonably in accord with regional data and to fit that forecast into those of other BPA cus-tomers. The forecast is updated annually based on the previcus year's data. A completely independent analy-sis and forecast is made whenever there appears to be a major change in the demographic or industrial trends.

Chelan County PUD This utility has two separate systems and makes a separate forecast for each system since the character of the loads in the systems vary somewhat. These two forecasts are then combined into a single utility forecast to be submitted to PNUCC.

Historical records of monthly and annual energy con-sumption and system load factors are used for forecast purposes. By means of computer programs, load growth

,x rates by months are established and monthly percentages

( ) of annual energy consumption are determined. This

\/ historical annual energy consumption curve is plotted and extrapolated for the forecast period. Monthly peak requirements are then determined by applying average historical monthly load factors to torecasted monthly energy consumption.

Grays Harbor County PUD This utility prepares a load forecast in cooperation with BPA based on the BPA guidelines, modified to meet the particular needs of the District. This major load projection is made on approximately four or five year intervals and updated annually.

The methodology used by these utilities has been included to suggest the detail used in developing the Long-Range Projec-tion. Three points should be emphasized. The first is that most of the larger utilities look at their load growth in individual segments, considering population and economic growth within their service areas. Generally they do not rely on straight projections of historical trends but temper such projections with insight into causative factors.

?

l.1-15

WNP-2 ER

~

Secendly, BPA, in its capacity of providing regional trans-misnion facilities, provides an overview of the independent foracasts, particularly for the smaller utilities. Finally, Table 1.1-1 (a) and (b) and 1.1-2 (a) and (b) together with Figures 1.1-1 and 1.1-2 show the degree of accuracy of the PNUCC at predicting peak demand and energy load. This record shows a general success of the methodology as applied.

3.1.15 Accuracy of Forecasts The 10-year history of West Group forecasts compared to loads has been presented in Tables 1.1-1 (a) and (b) and 1.1-2 (a) and (b). The percent accuracy of the forecast is the difference between actual load experienced and the forecasted load, unadjusted for weather, divided by the forecasted load.

For forecasted capacity, the percent accuracy ranges overall 1; from +16.7% to -3.4%. Accuracy for the three operating years next succeeding the date of forecast ranges from

+11.8% to -3.4%. For the operating year next succeeding the date of forecast the accuracy ranges from 11.1% to -3.4%.

The range of accuracy for forecasted energy is as follows:

Overall from 15.9% to -0.7%

2l 1

Next three operating years 9.6% to -0.7%

Next operating year 5.7% to -0.4%

Because of the rapidly changing conditions relative to energy use, it is difficult to estimate the accuracy that has been achieved in the forecasts recently issued. There are a number of factors which must be considered in such an estimate. The operating years 1972-1973 and 1973-1974 (through December 1973) were very dry. Coupled with the national energy shortage, these dry months caused 'a severe reduction in area reservoir storage. All utilities of the area engaged in intensive conservation compaigns and were able to effect, on the average, a 7% to 8% reduction from expected use of electric power. Because of these reductions, no mandatory curtailment of firm loads was required.

Weather conditions changed radically in January 1974 with rain and snow falling in abundant quantities. Reservoirs soon returned to normal elevations and surplus power was generated for transmission to California to assist utilities in that state in fuel consnrvation efforts. Precipitation continued in above-normal amounts, not only assuring reservoir O

1.1-16 Amendment 2 October 1978

WNP-2 ER q) refilling, but also building up a snow pack far above normal with consequent predictions of heavy spill conditions in the run-off months. Campaigns for electric power usa curtailment were rapidly switched to educational programs for wise use of energy. Generation of excess power continued to the point of loading inter-regional transmission lines to max-mimum capacity. Because of the surplus power availability in the area, loads have increased to near normal and export of surplus energy still continues.

The effects of conservation and of conversion to electric power usage are in opposing directions. It is difficult to determine at this time which effect will be dominant in the next few years. West Group utility forecasters have consid-ered these matters and folded them into the recent forecast of future loads. Consensus among those responsible for compiling the forecast is that its accuracy is probably within the range of accuracy of previous forecasts.

1.1.16 Area Purchase from Outside West Group Area Censumer-owned utilities estimate no capacity imports and energy imports of 123 million KWH per year through 1982-1983 operating year and zero purchases of firm capacity and energy from outside the West Group area during the remaining period of the forecast; however, these do from time to time

(~N purchase available nonfirm energy from British Columbia and (ms) California utilities and elsewhere when such nonfirm energy is not available from within the West Group area.

The federal system estimates energy imports during the next decade of up to 4.1 billion kilowatt-hours per year on the basis of energy returned from peak / energy exchange contracts with Caifornia utilities.

Investor-owned utilities estimate an import of capacity and energy ranging from maximum of 2,020,000 kilowatts of capacity and 10.8 billion kilowatt-hours of energy in 1980-1981 down to 240,000 kilowatts of capacity and 0.6 billion kilowatt-hours of energy per year in 1997-1998. Imports include Pacific Power & Light Company transfers from Pacific Power & 2 Light Company Wyoming Division, Portland General Electric Company Contract with Southern California Edison Company, Washington Water Power Company peak / energy exchange contract with San Diego Gas & Electric Company, Washington Water Power Company contracts with the Montana, Idaho, and Utah Power Companies and Puget Sound Power & Light Company contracts with Salt River Project and Utah Power Company.

O (m 1.1-17 Amendment 2 October 1978

\

, WNP-2 ER v

Except for the purchase of plant service power when a plant is not operating, the applicant does not make any purchase of power from either within or outside the region. Its only sales are of power from its projects to the participants in those projects.

1.1.17 Load Components The power needs of a nation or region depend largely upon the size of the population, the standard of living of its people, and the character of its economy. Economists use, as a measure of the standard of living and productivity of an economy, the quantity of energy used residentially, industrially and commercially. The proper perspective for ,

analyzing past load growth and estimated future load growth can be obtained by comparing the power needs in four main categories:

a) Residentie' including farms b) Commercial c) Industrial d) Combined use for irrigation, street and highway lighting and other miscellaneous uses.

Figure 1.1-4 shows load growth past and future by these categories.

Figure 1.1-5 shows that from 1950 to 1973, the increase in total residential load of the Pacific Northwest (from 5 1/2 billion kilowatt-hours in 1950 to 33 billion kilowatt-hours in 1973), was more than five times the 1950 total residen-tial load. Of this total growth, less than 20% was due to the increase in the number of residential consumers occasioned by population growth; thus, approximately 80% resulted from the rise in the use per consumer. The increase in electric space heating load, from 378 million kilowatt-hours in 1950 0 '.

1.1-18 Amendment 2 October 1978

WNP-2 ER O to 10.9 billion kilowatt-hours in 1973 (more than 28 times) was responsible for over 38% of the increase in residential consumption. Unless electric space heating load is limited by supply or regulation, it is predicted that there will be approximately three times as many homes electrically heated 20 years from now. Total residential space heating load is expected to reach 25 billion kilowatthours by that time.

Commercial loads eAd service industries have historically been one of the fa.itest growing segments of our economy. If past trends are used for projection, it is expected that an additional 160,000 new commercial customers will be on line in the next 20 years. Commercial loads are expected to increase from 1.1 billion kilowatt-hours in 1970 to 3.8 billion kilowatt-hours in 1990.

Technological advances historically have resulted in greater availability and use of electrical equipment, increased automation and improved working conditions. These, in turn, have resulted in a higher per capita energy usage, a higher per capita production, and a higher per capita income.

Several of the heavy industries involving the use of elec-trical energy in the Northwest include pulp, paper, plywood, lumber, chlorine, aluminum, fertilizers, steel, and other

manufactured materials produced and used in, or exported

\_ from, the region. Industrial loads are expected to more than double from about 50 to 117 billion kilowatt-hours by 1990.

Figure 1.1-6 is the coordinated System load duration curve for the operating year 1981-1982. This load duration curve is expected to be similar to those for the first few years that WNP-2 is scheduled to be in service.

1.1.1.8 Interruptible Loads As federal hydro project power became available in the late 1930's not all of it was salable to the utilities of the area. The surplus was therefore available to BPA to sell to industry at a very attractive price. During the war years of the early 1940's, the light metals and other industries developed rapidly in the Pacific Northwest. These industries were able to consume large amounts of both firm and nonfirm energy and contributed greatly to the economic and electrical growth of the region. Firm power sales contracts were written by BPA to cover the base loads of these plants and nonfirm power was sold on an interruptible-type contract to provide the industries with power for excess production from 1.1-19

WNP-2 ER time to time without the necessity of increasing the base firm power purchases. Power sold under laterruptible contract could be curtailed any time nonfirm power was unavailable. Until recently, curtailment was made only for lack of nonfirm energy supply since the federal system had a large surplus of installed capacity. However, in recent years, curtailment has been made on several occasions because of insufficient capacity to supply excess energy during heavy load hours. Some utilities have contracts with indus-trial customers for interruptible power and are able to serve such customers either from nonfirm power developed on their own systems or by purchase from BPA or a combination of both. In some instances, utilities have written agree-ments or signed contracts for firm power sales, interrupti-ble on peak hours if required to reduce the utility's peak hour demands. The City of Seattle Lighting Department had such a contract with Alcoa and presently has a letter of agreement with the Boeing Company Wind Tunnel and with Bethlehem Steel Company for such interruptible power.

In recent years, as firm utility loads increased at a rate greater than the rate at which firm resources were being installed and industrial loads also increased, it became necessary for BPA to limit sales of additional firm power to industry. BPA and area industries cooperatively worked out a new type of industrial rate under which industry purchases up to 75% of its load requirements on a " Modified Firm Power" rate and the remainder of its needs on the " Inter-ruptible Power" rate. Modified firm rate is 5 cents per kilowatt per month less than the Firm Power rate. When present direct service 'ndustrial power sales contracts expire, Bonneville Power Administration expects to replace them with contracts for the sale of power under the new I rate schedule for industrial firm power included in BPA's revised rate schedules, which became effective on December 20,1974.

1 The following quote from the 1974 Bonneville Wholesale Power l Rate Schedule describes these classes of power:

l l "1.1 FIRM POWER: Firm power is power which the Admini-strator will make continuously available to a purchaser to meet its load requirements except when restricted because the operation of generating or transmission facilities used by the Administrator to serve such purchaser is suspended, interrupted, interfered with, curtailed or restricted as the result of the occurrence of any condition described in the Uncontrollable Forces 9

1.1-20

WNP-2 ER O or Continuity of Service sections of the General Contract Provisions of the contract. Such restriction of firm power shall not be made until industrial firm power has been restricted in accordance with section 1.4 and dance with section 1.2.

1.2 MODIFIED FIRM POWER: Modified firm power is power which the Administrator will make continuously availa-ble to a purchaser on a contract demand basis subject to:

(a) the restriction applicable to firm power, and (b) the following:

When a restriction is made necessary because the operation of generating or transmission facilities used by the Administrator to serve such purchaser and one or more firm power purchasers is suspended, interrupted, interfered with, curtailed or restricted as a result of the occurrence of any condition described in the Uncontrollable Forces or Contina-ity of Service sections of the General Contract Provisions of the contract, the Administrator shall restrict such purchaser's contract demand for modified firm power to the extent necessary to

) prevent, if possible or minimize restriction of any firm power, provided, however, that (1) such restriction of modified firm power shall not exceed at any time 25 percent of the contract demand therefor and (2) the accumulation of such restrictions of modified firm power during any calendar year, expressed in kilowatt-hours, shall not exceed 500 times the contract demand therefor.

When possible, restrictions or modified firm power will be made ratably with restrictions of indus-trial firm power based on the proportion that the respective contract demands bear to one another.

The extent of such restrictions shall be limited for modified firm power by this subsection and for industrial firm power by section 8 of the General Contract Provisions (Form IND-18) of the contract.

1.3 FIRM CAPACITY: Firm capacity is capacity which the Administrator assures will be available to a pur-chaser on a contract demand basis except when operation of generating or transmission facilities used by the Administrator to serve such purchaser is suspended, interrupted, interfered with, curtailed or restricted as the result of the occurrence of any condition described in the Uncontrollable Forces or Continuity of O

1.1-21

WNP-2 ER Service sections of the General Contract Provisions of the contract.

1.4 INDUSTRIAL FIRM POWER: Industrial firm power is power which the Administrator will make continuously available to a purchaser on a contract demand basis subject to:

(a) the restriction applicable to firm pover, and (b) the following:

(1) The restrictions given in section 8, "Restric-tion of Deliveries," of the General Contract Provisions (Form IND-18) of the contract.

(2) When a restriction is made necessary because of the operation of generating or transmission facilities used by the Administrator to serve such purchaser and one or more firm power purchasers is suspended, interrupted, interfered with, curtailed or restricted as a result of the occurrence of any condition described in the Uncontrollable Forces or Continuity of Service sections of the General Contract Provisions of the contract, the Adminis-trator shall restrict such purchaser's contract demand for industrial firm power to the extent necessary to prevent, if possible, or minimize restriction of any firm power. When possible, restrictions of industrial firm power will be made ratably with restrictions of modified firm power based on the proportion that the respective contract demands bear to one another. The extent of such restrictions shall be limited for modified firm power by section 1.2(b) of the General Rate Schedule Provisions and for industrial firm power by section 8 of the General Contract Provisions (Form IND-18) of the contract.

No additional Firm Power is presently available to BPA for i sale to industry under new long-term contracts.

Availability of non-firm power has been very high over a period of many years, but the building of new dams in the West Group area and cn the Columbia River and its tribu-taries in Canada has converted much of the energy previously available only on a nonfirm basis into firm energy. Future' availability of nonfirm power is expected to be much lower ,

than it has been in the past and will be sold by BPA under the BPA H-5 wholesale non-firm energy rate.

O 1.1-22

t

1 WNP-2 i O 1.1.1.9 Facts Potentially Affecting Demand f

l Electrical power, like many other products, has an elasti-city of demand. This elasticity varies from area to area depending upon the relation between many facters such as

availability of electric power compared to availability of alternate sources of power, relative costs of alternate

~

sources, intensity of promotional advertising and activities with respect to competing types of energy, and energy costs compared to average consumer income. These factors as they j exist in the Pacific Northwest are discussed in this section.

a) Advertising and Energy Conservation The Pacific Northwest electrical energy supply has depended on the development of hydro-electric resources throughout the region, particularly on the Columbia River. The development of this resource was encouraged,

! on a multipurpose basis, for the hydro-electric supply as well as for flood protection, navigation, and irri-gation. In the past, excess energy was available for sale, particularly during high flow, off-peak periods.

By encouraging the sale of such energy, the average price to consumers of the region was reduced to levels among the lowest in the nation.

., As the economical hydro resource approaches full utili-

, zation, the picture changes,-particularly with the advent of the Columbia River's large upstream hydro storage reservoirs which permit considerably more

• latitude in energy usage timing. That the picture was changing was generally foreseen by regional utility management a few years ago, and the advertising policy of the region changed markedly towards conservation -

l' the wise usage of energy. The programs followed by

, some of the larger utilities in the region are:

% ,' 1)- Seattle City Light - Promotional advertising and I- -- activity was ended January 1, 1971. At that time a program of education relative to the wise and

. efficient use of electricity was started. This s program.was carried on mostly through bill stuffers 4

'o

~ and handouts. Early in 1973, an intensive conservation N '

program ^was begun using bill stuffers, handouts,

'~

- radio,'televison, and newspaper advertising.

'Because of the critical shortage that had developed 2

.- .-- in hydro' capability (reduced stream flows and k ' ' - below-normal reservoir elevations) the public was 1 '

u'ged r to reduce their energy consumption as much f; , s

_as possible. ,

O 1.1-23 Amendment 2 October 1978 i "

l 2.C.__._.,.._-__.____....__.___.__.._....___________

WNP-2 ER In 1977 a Conservation Office was established to coordinate and monitor a long-range conservation program with a goal of reducing the projected 1990 demand by about 20 percent. This program involves conservation projects in the residential, commercial, and industrial sectors.

2) Tacoma City Light - Early in 1970, Tacoma ceased all promotional advertising and activity. Little advertising was done until the summer of 1973 when the "Be-A-Watt-Watcher" educational program was started using mostly bill stuffers and handouts.

Consideration is now being given to starting an educational campaign urging installation of storm windows and doors, and adding insulation to homes plus education relative to efficient use of electricity.

3) Snohomish County Public Utility District - Promo-motional advertising and activity was ended early in 1972. An intensive educational program was started in early 1973 apprising customers of the critical hydro capability shortage and advising them to use electricity wisely and efficiently and promoting the installation of home insulation. The present program is based on providing information relative to wise use of energy.

4) Cowlitz County Public Utility District - All promotional advertising and activity ended early in 1972. In the summer of 1972 an educational program was instituted relative to the need for economical use of electricity. In early 1973, an intensive campaign on conservation was begun using all news media, bill stuffers, handouts, etc.

Speakers were made available to civic organizations, church and community groups and schools to help educate the general public on the immediate need to conserve electricity and the long-range need to conserve electricity and the long-range need to conserve energy of all kinds. Presently, the effort is toward economical use of energy in total.

5) Clark County Public Utility District - All promo-tional advertising and activity ceased in early 1972. An educational program on nuclear power production and the wise use of electricity was started late in 1972. Early in 1973, and intensive campaign was stated to inform the public of the hydro capability shortage. Since January 1974 the campaign has gone back to education on economical use of power.

-O 1.1-24 Amendment 2 October 1978

WNP-2 ER O)

(s , 6) Chelan County Public Utility District - Promotional activities and advertising were reduced early in 1972 and ended entirely in August 1972. Early in 1973, an intensive conservation program was put into operation using radio and newspaper advertis-ing. Presently, American Public Power Association's recommended advertising is being used.

7) Electric League of the Pacific Northwest - The utilities of the Puget Sound Area (Seattle City Light, Tacoma City Light, Snohomish County Public Utility District and Puget Sound Power and Light Company), electrical contractors and electrical equipment supply firms are members of this organi-zation. The League has for many years advertised for the benefit of League members. Prior to 1971, thic advertising was promotional in nature. In 1971 and 1972, the thrust was shifted to environ-mental aspects of power production and use. In 1973, the League institued in intense conservation program encouraging installation of insulation and economical use of energy. Advertising was by radio, television and new media. In 1974, the program dropped back to education on efficient use of energy.

b) Bulk Power Costs O/ Prirr to the establishment of BPA in 1937, each utility f in tue area operated essentially on an isolated system basis, providing its own power supply, including reserves, as well as its own required transmission. The few inter-tie transmission lines that existed were relatively light and were used primarily for emergency purposes.

A small amount of nonfirm power transactions occurred from time to time. Power supply was from a mixture of hydro and thermal plants. Cost of power varied from utility to utility.

In 1938 BPA adopted its first schedule of wholesale l2 I power rates based on a kilowatt-year concept. At-site delivery (within 15 miles of generation) was priced at

$14.50 per kilowatt-year and elsewhere on the Bonneville System the charge was $17.50 per kilowatt-year. Based

on a " capacity with associated energy" concept, this l rate translates into 2 mills per kilowatt-hour for 100%

l load factor and 4 mills per kilowatt-hour for 50% load factor. Nonfirm power was sold for $11.50 per kilowatt-year.

l 1.1-25 Amendment 2 October 1978

- _ . _ - , _ _ - _ _ _ _ . , , ~ _ __

WNP-2 ER -

These rates were basically demand charges with no charge for associated energy that could be fitted into a load. A utility with hydro generation and associated reservoir seasonal storage could absorb energy at 100%

load factor for the greater part of the operating year while the utility without such facilities could only absorb energy at its system load factor rate.

As more utilities requested federal power for use in their system load, BPA added rate schedules to meet the needs of these customers. In addition to existing rates, firm capacity rates and demand-energy rates were developed. The nonfirm rate was eventually broken into two parts with a demand rate maintained for " Interrupt-ible Power" and a straight energy rate established for nonfirm energy purchases used for such purposes as thermal displacement.

The cost of power under the BPA wholesale rate schedules remained basically unchanged until December 1965, when the cost of firm power was increased by an average of about 3%. On December 20, 1974 BPA established the rate schedules presently in effect which increased wholesale power costs by an average of 27%. Transition of the power supply available from BPA from mostly hydro generation to a mix of hydro and large thermal power plant generation is the major factor contributing to the necessity for the increase in rates. The con-sumer owned and Federal portions of Phase 1 of the Hydro-Tehrmal Power Program, previously described, melds the higher cost of thermal power into the lower cost federal hydro power through the use of the " net billing" concept previously described. Thus, the cost of nonfederal thermal power delivered to BPA under Phase 1 of the Hydro-Thermal Power Program is spread to l

all BPA ratepayers through the cost-melding process.

WNP-2 is included under the net billing portion of the Phase 1 program.

In addition to increasing the cost of power, the present BPA schedule of rates changes the concept under which power is sold in order to more nearly approach a cout-l of-service concept. The rates are in the form of a l two-part, demand-energy type with the level of the l rates being higher for winter loads than for summer loads.

l 1.1-26 l

1

WNP-2

- ER ,.

%/ BPA estimates that an increase in wholesale power costs to a total requirements customer (a utility that purchases all of its power requirements from BPA) does not have more than a 40% impact on that customer's resale rates since that is the approximate associated with power supply. ggycentage of total costs 2 Future increases in the cost of wholesale power will have an effect on future load requirements. The degree to which the load growth pattern of the area is impacted depends upon several factors. The most important factor to a given utility its ability to meld higher costs of power purchased from the federal system with the relatively stable cost of the hydro that is either self-generated or. purchased from other nonfederal low cost hydro sources. The amount of federal power pur-chased in comparison to the total power supply deter-mines the degree to which the increased cost of federal power will affect the overall cost of power required to serve load.

Another factor relative to the effect on the load growth of a system is the affluence of the customers served by a utility. In a community where the cost of electricity to a customer is relatively low compared to

/~N the customer's income, the rate increase will have k,)

s little effect while in a low income area where the cost of power consumers a much larger share of income, more reduction in growth rate may be noted.

The West Group area utilities have considered these factors in preparing the data submitted to PNUCC for inclusion in the West Group Forecast. PNUCC is study-ing a program to account for price elasticity of demand.

But at present, the majority of the individual fore-casts do not account for this.

1.1.2 Power Supply The applicant is a member of PNUCC, the cooperative group of utilities in the Pacific Northwest presently responsible for coordinating regional long-range power supply planning.

PNUCC assembles forecasts made by individual utilities and publishes a composite forecast for this group of utilities.

The Northwest Power Pool (NWPP) is the cooperative agency responsible for short-range planning (up to the length of time encompassed by the existing Critical Period of the area) and for day-to-day operation.

,j 1.1-27 Amendment 2 October 1978

- - -~ - __ _ _ . . _ . , _ _ _ _

WNP-2

. ER The NWPP, including both the East Group and the West' Group, is considered a sub-regional group of the Western Systems Coordinating Council and reports to WSCC for the entire area on such matters as: (1) load and resource forecasts; (2) system reliability; (3) transmission capabilities; (4) capacity and energy transfer capability with other regions; (5) answers to Federal Power Commission Dockets which can be submitted on a regional basis; (6) regional operating pro-blems that could affect other areas, and (7) major regional power outages.

The applicant is not a utility and therefore makes no direct report to any of the region's organizations. But all of its resources and operating characteristics are included in all regional reports through the utilities who are parti-cipants in the applicant's projects.

d WNP-2, scheduled for initial operation in December ,19 8 0, will be one of the major thermal projects constructed under Phase 1 of the Hydro-Thermal Power Program, which was planned to meet the load requirements of the West Group area through d 1985. The Hydro-Thermal Power Program is discussed in more detail in Section 1.1.2.1 of this report.

1.1.2.1 Long-Range Planning Prior to 1967, long-range planning for power supply require-ments was carried on individually by each utility in the area with the PNUCC summarizing and correlating load and resource forecasting of the individual utilities and acting as a forum for review of resources required to carry pro-jected firm area loads. Up to that point in time, federal forecasts showed a surplus of federal resources over the amount required to carry forecasted non-federal resources.

Northwest utilities capable of installing resources planned to do so only to the extent that the long-range costs of power from such resources would be less than the expected I costs of federal hydro-power.

By 1967 it was apparent the era of federal resource surplus was rapidly drawing to a close. Also the ability of utilities to install additional hydro capability was limited since few hydro sites remained that could meet the test of economic development as well as environmental acceptability.

Since thermal generation was the only viable alternative to hydro generation, utilities recognized that cooperative long-range planning was necessary to obtain economy of scale for future resource installations. Formation of the Joint O

1.1-28 Amendment 2 i

October 1978

WNP-2 ER O Power Planning Council provided the vehicle for such cooperative planning. The Hydro-Thermal Power Program was conceived by the Council, consisting of 110 electric cooperatives, public utilities and private utilities in'the Pacific North-west. Recently PNUCC whose membership is nearly identical to that of the Council has expanded its responsibilities to include those formerly attributed to the Council and the Council has become inactive. Most of the power supply in the region has been historically generated from hydro-electric resources, but the remaining hydro projects to be developed will be essentially for peaking power rather than for base load. Thermal power will provide an increasing portion of the base load resources in the future. The combination of hydro peaking and large-scale thermal generating plants was found by the Council to be the soundest approach to achieve the aims of the Hydro-Thermal Power Program. The principles of Phase 1 of this program and the federal government's participation through BPA, the Army Corps of Engineers and the Bureau of Reclamation, have been endorsed by current and previous Administrations and by Congress.

In summary, the members of the Council have concluded that the Hydro-Thermal Power Program will:

a) Best preserve the environment, including the natural beauties of the Pacific Northwest.

b) Make efficient and economic use of the Federal Columbia River Power System.

c) Obtain the economies of scale from large thermal gener-ating plants.

d) Meld the large thermal generating plants with exiting hydro generating units and the peaking generation units which will be installed at existing dams, to achieve the most economic and reliable power supply to meet the power requirements of the Pacific Northwest.

Phase 1 of the Hydro-Thermal Power Program of thermal gene-rating plants for installation through 1985* is tabulated as follows:

• Extended from 1981 to 1985 due to slippage in plant construc-tion schedules.

O 1.1-29

WNP-2 ER Scheduled Date of Probable Principal Capacity Commercial Energy Sponsor Location Type (MW) Operation

• Date**

Pacific Power &

Light Co. and The Washington Water Power Company (Centralia Centralia, Coal-Project) WA fired 1,400 Operating Portland General Electric Company St. Helens, (Trojan Project OR Nuclear 1,130 Operating Pacific Power & Rock Light Co. (Jim Springs, Coal- 500 Bridger Project) WY fired 500 Operating Washington Public Power Supply System Nuclear Hanford, Dec 1980 May 1981 2 Project No. 2) WA Nuclear 1,100 Washington Public Power Supply System (Nuclear Hanford, Project No. 1) WA Nuclear 1,25' Dec 1982 June 19 Washington Public Power Supply System (Nuclear Satsop, Project No. 3) WA Nuclear 1,240 Jan 1984 June 1984 Portland General Electric Company (Pebble Springs Boardman Project No. 1) OR Nuclear 1,260 Apr 1986 Apr 1986

• Date on which construction schedule is based.

• • Most probable date energy will be available, based on national experience. This is the basis for resource planning.

1.1-30 Amendment 2 October 1978 9

9

i I

WNP-2 ER

("'s In response to the combined efforts of the Council, BPA, and *

(,,/ the individual utilities involved, legislation was enacted to allow consumer-owned and investor-owned utilities jointly to construct, own and operate generating facilities. Plans for the first of such plants were formulated and executed for the ccnstruction of the 1,400 MW Centralia coal fired thermal project under the joint ownership concept. Four investor-owned utilities own 72 percent of the project and four consumer-owned utilities own the other 28 percent as tenants-in-common.

Under the Hydro-Thermal Power Program, the federal system will supply transmission and install peaking generation at federal projects to integrate the output of thermal plants, to be built by Northwest utilities, into the total genera-ting resources of the area. Phase 1 of the Hydro-Thermal Power Program is expected to provide the resources required in the region through 1985.

Under Phase 2 of the Hydro-Thermal Power Program, announced on December 14, 1973, the area utilities identified addi-tional projects which are currently under investigation to meet forecasted load growth through 1989. While the specific l2 role of BPA has changed somewhat from Phase 1, in Phase 2 the area will continue to build generation and transmission i facilities on a cooperative schedule. The thermal genera-ting plants included in Phase 2 are tablulated as follows:

Scheduled Date of Probable Principal Capacity Commercial Energy Sponsor Location Type (bM) Operation

• Date**

Puget Sound Colstrip, Coal- 330 Operating Power & Light MT fired (Colstrip Project No. 1)

• 2 Puget Sound Colstrip, Coal- 330 Operating Power Supply MT fired (Colstrip Project No. 2)*

Pacific Power & Rock Coal- 334 Dec 1979 Dec 1979 l

Light Co. (Jim Springs, fired l

Bridger Proj.

l No. 4)

• Not specifically identified as a Phase 2 project.

n/

N_ 1.1-31 Amendment 2 October 1978

WNP-2 ER Scheduled Date of Probable Principal Capacity Commercial Energy Sponsor Location Tvpe (MW) Operation

• Date**

Puget Sound Colstrip Coal- 700 Apr 1982 Apr 1982 Power Supply MT fired (Colstrip Project No. 3)*

Portland General Boardman, Corl- 530 July 1980 Nov 1980 Electric Company OR fired (Carty Coal Proj.)

Puget Sound Colstrip, Coal- 700 Feb 1983 Feb 1983 Power & Light MT fired (Colstrip Project No. 4)*

Puget Sound Power Sedro Nuclear 1,288 July 1985 July 1985

& Light Company Wooley, (Skagit Proj. WA No. 1)

Washington Public Hanford, Nuclear 1,250 June 1984 Dec 1984 Power Supply WA 2 System (Nuclear Proj. No. 4)

Washington Public Satsop, Nuclear 1,240 July 1985 Dec 1985 Power Supply WA System (Nuclear Proj. No. 5)

Puget Sound Power Sedro Nuclear 1,288 July 1987 July 1987

& Light Company Wooley, (Skagit Proj. WA No. 2)

Portland General Boardman, Nuclear 1,260 Apr 1989 Apr 1989 Electric Company OR (Pebble Springs Project No. 2)

Although the overall planning of resource installation is carried out on a cooperative basis, each utility reserves the right to determine which project it will participate in and the extent of such participation. Since planning is done on the basis of installing sufficient resources in the area to meet load requirements, individual utility forecasts of power requirements are included in the regional plan.

• Not specifically identified as a Phase 2 project.

1.1-32 Amendment 2 October 1978

WNP-2 ER O 1.1.2.2 Short-Term Planning The NWPP carries out the short-term, cooperative planning for all systems in the pool. This short-term planning consists of:

a) Planning the coordinated use of both federal and non-federal resources, including pooling of reserve require-ments, to provide the greatest practicable output of firm power from those resources.

b) Determining the length of the Critical Period to be used and the adverse water available for power pro-duction in that period.

c) Determining t' amount of firm capacity and energy loads that ce be carried under adverse water conditions by each membee of the pool and by the pool as a whole.

d) Determining operating rule curves for each reservoir included in pool resources.

In addition to the short-term planning functions for NWPP, 4

the Coordinating Group performs additional short-term plan-gS ning functions required by the Coordination Agreement such

( as (1) Computing the reserve requirements of each System and the Coordinated System: (2) preparing a schedule of capacity and energy interchanges between Systems based on water availability under adverse conditions; and (3) other plan-ning functions, sone of which are listed under d) " Pacific Northwest Coordination Agreement" in Section 1.1.1.1 of this i report.

Under c) above, any System having either capacity or energy load greater than the amount of firm resource available to that System must:

a) Supply firm resources at least equal to the indicated deficiency, from those within the Coordinated System which are not currently committed to serve Coordinated System firm loads, or b) Supply firm resources at least equal to the indicated deficiency, from outside the Coordinated System; or c) Assign the estimated firm load which is above the capability to carry such load (as determined in b) above) to a nonfirm status and serve it only from

nonfirm power available from any source; or O

1.1-33

WNP-2 ER d) Totally interrupt such excess firm load if no nonfirm power is available.

Although these planning functions are carried out on a group basis, each system maintains the right, within limits, to operate its system to meet its system requirements. One such limitation contained in the Coordination Agreement is that planned reservoir operation cannot be altered to a degree that will cause spill of firm energy on the Coordinated System.

1.1.3 Capacity Requirements In order to determine system generating capacity requirements, a number of factors must be considered, not the least of which is the amount of firm caoacity load that the system expects to serve. Other factors to consider include:

a) Capacity required to replace units out of service for scheduled maintenance; b) Capacity required for replacing the capacity of units that are forced out of service or that are forced to reduce output; c) Capacity to serve unanticipated load growth; and d) Capacity required to assure system reliability.

The forecasting methods used in the West Group area to determine the future capacity load that the system expects to serve were discussed in Section 1.1.1.4. All the other factors can be grouped under the general heading of reserves.

1.1.3.1 Capacity Reserves System reliability (the ability to serve firm load with interruptions held to a level acceptable to both customer and system) is dependent upon the amount of capacity availa-ble to the system with which to serve the requirements of its customers at the time those requirements occur and is

! measured in percent. Thus, a system with 100 percent relia-bility would always be capable of serving its customers' requirements without interruption ot- curtailment. It is entirely possible, although not economically feasible, to install enough generating capability to attain 100 percent reliability of power supply and to install enough transmis-sion, transformation and distribution equipment to deliver 4 I

that capacity to customers without interruption. Each system, or pool of systems, must therefore determine the level of reliability it can maintain, on an economic basis, I that will be acceptable to customers. '

1.1-34 l

l l

WNP-2 ER

( The degree of reliability attainable on a system or pool of systems is dependent upon the amount of capacity maintained in the system over and above the capacity demand of the load being served. This capacity surplus to load can be generally classified as reserves. All of the factors previously mentioned that go into determining the total generating capacity requirements of a system, except load requirements, can be put in this classification.

Some of the factora previously mentioned overlap; therefore, a subdivinion of classification is helpful in discussing reserves in general. One possible subdivision is as follows:

a) Standby Reserves

1) Load Growth Reserves for:

(a) Forecasted Load Growth (b) Unexpected Load Growth

2) Scheduled Maintenance Reserves

3) Forced Outage Reserves for

( (a) Total Unit Outage (b) Partial Unit Outage (c) Capacity unattainable due to nonpower purposes (d) Capacity unattainable due to operating conditions b) Spinning Reserves

1) Reserves for largest single contingency outage for:

(a) Generation Outage (b) Transmission Line Outage

2) Reserve for continuous load regulation

3) Reserves for frequency bias obligations Spinning reserves are standby reserves that are immediately available to replace generation forced out of service or curtailed for any reason.

O 1.1-35

WNP-2 ER Reliability can also be expressed in terms of the frequency of loss of load due to power supply being less than load requirements. Although many large utilities use a criteria for adequacy of reliability based on loss of load not more frequently than once in 10 years, the West Group area uses a criteria of loss of load not more often than every 20 years. Excerpts from the 1970 FPC National Power Survey relative to adequacy of reserve levels follows:

Reserve Practices

" Individual systems and power pools utilize a variety of methods for determining appropriate reserve levels.

The methods vary from use of a simple percent of peak load, to matching reserves to the capability of the largest unit or pair of units in service, to very complicated calculations of outage probability taking into consideration such elements as number and size of units, forced outage rates, and expected load patterns.

Reserve margins considered adequate for most systems, including the spinning reserve component, range between 15 and 25 percent of peak load.

Euch system, pool, or coordinating group develops spinning reserve criteria which it believes will show the minimum appropriate reserve for that particular power supply entity. Generally, the level of such reserve and its distribution among generating units takes into consideration the system characteristics and rate of required responses. The variations in practices reflect such things as differences in sizes and types of units, the number and capability of transmission interconnections, the geographical extent and configu-ration of a system, and pertinent operating agreements among interconnected systems."

The West Group Systems of the Northwest Power Pool serve a large geographical area. Major systems serving customers in the West Group area are parties to the Pacific Northwest Coordination Agreement. A major benefit of such an agree-ment is to provide for capacity reserves on a coordinated use basis. The Coordination Agreement states "The Coordinated System shall maintain reserve capacity at a level sufficient to protect against loss of load to the extent the probability of load loss in a contract year shall be no greater than the equivalent of one day in 20 years. The de- rmination of such probability shall be based upon charat . eristics of peak load variability and generating equipment forced outage rates."

O 1.1-36

6 WNP-2 ER

) The Coordination Agreement provides that every utility, to s_/ the extent practicable, will operate its own system as though the coordinated System were being operated by a single entity.

Provision for capacity and energy exchanges assures each utility of assistance from the entire Coordinated System such that a loss of resources on one system will not cause loss of load on that system as long as there are resources in the area capable of carrying the total area load, and assures that nonfirm loads of the area will be curtailed in order to supply power to firm _ loads regardless of the utili-ties involved.

The Coordination Agreement is a contractual agreement which determines the actual reserves that each utility is required to maintain under normal cperating conditions during the current operating period, based on the " Critical Period" of record (adverse water).

The region is presently experiencing a shift from a system which is nearly all hydro to one of combined hydro and thermal generation. Such a shift in the nature of power supply requires a corresponding shift in reserve planning.

Past experience has shown a reserve of 5 percent of installed hydro generating capacity to be adequate and for planning purposes the area had assumed a thermal reserve requirement

, equal to 15 percent of installed thermal capacity. Recently, agreement has been reached in the PNUCC that the following criteria for capacity reserves will be used for planning:

a) For the first operating year of the forecast total planned reserves for capacity will be 12 percent of total area peak load for January, b) For each subsequent year the percent of area peak load for January required for total reserves will be increased by one percent (1%) of January peak load until the percentage reaches 20 percent.

1.1.3.2 Effects of Operation of the Projects on the Coordinated System For purposes of this statement adjustments have been made to the Long-Range Projection (1978 Blue Book) because of recent l2 changes in expected plant capacity and energy output and expected commercial operating dates for the WPPSS nuclear projects under construction and planned. These changes and 1.1-37 Amendment 2 October 1978 O

WNP-2 ER their effect on the Long-Range Projections are incorporated '

• in Table 1.1-4.

If WNP-2 is available as expected (Probable Energy Date) to meet the winter peak load of the operating year 1981-1982, the capacity reserves, based on the data on the Blue Book will be 22.9 percent of area loads. If WNP-2 does not begin operation as planned the capacity reserves will be reduced to 19.3 percent. Capacity reserves with and without WNP-2 are compared to the desired reserves in Figure 1.1-7.

Thermal plants like WNP-2 are planned as base-load additions to the system and thus are important elements of the energy 2

capability of the system. In the ten year period 1978-1987 there are total energy deficits ranging from 450 to 2373 average megawatts (MWe) with deficits on the order of 2000 MWe in the period 1980-1984, as shown in Figure 1.1-8. The Federal System interruptible loads of approximately 1000 MWe could reduce the deficits to the level shown in Figure 1.1-8 for firm energy. Firm energy deficits range from 64 MWe to 1298 MWe in 1978-1984, with surpluses of 316 MWE to 655 MWe in 1985-1987. However, without WNP-2 there are firm energy deficits in every year 1978-1987.

1.1.4 Statement on Area Need As explained in Section 1.1 and elsewhere in this report, tha applicant does not itself engage in the distribution of electrical power to the retail market but serves as a bulk electrical power supplier to utility systems in the West Group area. The need for capacity and energy was therefore developed in Section 1.1 on the Coordinated System basis rather than on the applicant's requirements. This section contains additional statements relative to regional power requirements and to reserve criteria of the West Group area.

The Public Power Council (PPC), an organization of 104 consumer owned utilities in the Pacific Northwest, has determined that the Project is needed in the area to assure an adequate power supply for such consumer owned utility customers. Table 1.1-6 indicates how the capability of the Project will be utilized in the BPA and Public Agency loads.

The Joint Power Planning Council and the PNUCC have made regional studies to determine the regional resource require-ments and have promulgated the results of these studies by issuance of a tabulation of projects required under Phase 1 and Phase 2 of the Hydro-Thermal Power Program as discussed in Section 1.1.2.1 Tables 1.1-7 and 1.1-8 indicate how the 1.1-38 Amendment 2 October 1978 l

WNP-2 ER Project fits into area resource requirements. Each of these k-- tables shows the regional deficiency with and without the Project. Also each shows such deficiency based on the probable energy date (milestone concept) and on the scheduled date of commercial operation.

PPC and PNUCC committees regularly review updated load forecasts and plant installation schedules in order to ensure a reliable power supply. If needed, requests to

advance or delay plant installation dates will be made by these organizations to plant sponsors.

1.1.4.1 Reserve Criteria of the Area For planning purposes the PNUCC has agreed upon the follow-ing minimum reserve requirements (previously stated in

Section 1.1.3.1) for use in resource requirement analysis for the Long-Range Projection which is the study used by the region in planning power supply.

Starting with the forecast for the 1974-1975 to 1994-1995 years the following criteria for capacity reserves were adopted for planning: 2 a) For the first year of the current forecast total planned reserves for capacity will be 12 percent of total area peak load for January.

! \- b) For each subsequent year the percent of area peak load j for January required for total reserves will be increased I by one percent (1%) of January peak load until the

percentage reaches 20 percent.

Also WSCC through its planning and operating committees has formulated and published "WSCC Reliability Criteria" con-t sisting of two parts, namely:

a) Reliability Criteria for System Design (6) b) Minimum Operating Reliability Criteria (7)

Planned Area Reserves can be found in Figure 1.1-7.

l Required reserves for actual operating conditions are determined in Critical Period Reservoir Regulation Studies l

and Reserve Studies prepared annually for the ensuing Critical Period (presently a 43-1/2 month period). Reserves are i calculated for the Coordinated System by probability methods and distributed among Systems according to iso probability as specified in Exhibit 4 of the Agreement. A more detailed discussion of the reserves required by the Agreement is contained in Section 1.1.3.1.

1.1-39 Amendment 2 October 1978 i

_ _ . , _ . - . . _ _ . - _ _ , _ . . - . _ . ~ . _ , _ , . , , , . _ . . . _ , _ _ _ _ _ _ _ , _ _ _ _ . - - _ _ , . _ , _ . - _ . - . . _ _ _ , - _ . . .

- .=_ = _

WNP-2 ER

\

V 1.2 OTHER OBJECTIVES The applicant has discussed potential beneficial byproduct uses of cooling water from Supply System projects with federal, state and local agencies as well as several poten-tial private sponsors. The Supply System will continue to cooperate with these potential sponsors and report develop-ments in the area of possible agricultural, industrial, recreational and economic aspects of any byproduct use of the project's cooling facilities.

The design, construction and operation of this project, the scheduling of which is vital to the power needs of the region, cannot be made contingent upon unknown restrictions and/or successful implementation of a complex unrelated byproduct use. In the event that the cooling water facili-ties, included as a part of this project, can be adapted to byproduct uses the Supply System will cooperate to the maximum practicable extent.

B

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i l

1.2-1

WNP-2 ER 10

\~ l 1.3 CONSEQUENCES OF DELAY If WNP-2 is delayed beyond the scheduled commercial operation dates the most important direct effects will be to increase the cost of the Project and decrease the energy generating capability that is an integral part of the region's electric generating resource planning schedule. A delay could also produce secondary effects which are less well defined, such as curtailment of power to serve industrial loads.

A delay la Project development schedule prior to commercial operation would cause an increase in cost, the magnitude of which would depend upon when such a delay occurred. Under the present financing scheme for WNP-2, a delay which is incurred near the end of the construction period after essentially all of the construction funds have been expended would cause the largest increase in cost. This would be due to the requirement to pay carrying costs on the funds expended until WNP-2 can begin to generate power and thus revenues.

Additional costs would be incurred for salaries and other fixed costs associated with maintaining the staff for WNP-2.

Shortages of electricity would create increased demands for alternative energy sources such as coal, oil and natural gas. The substitution of fossil fuel resources for electric

(

7"N) energy means using scarce depletable resources, particularly oil or natural gas, when relatively abundant nuclear fuel could be used instead. Power shortages would only intensify our existing shortages of oil and natural gas.

The problem of air pollution, particularly in urban areas, would be aggravated by the substitution of fossil fuels for nuclear or hydro generated electricity. Consequent damages to property and hazards to public health associated with increased air pollution, while difficult to evaluate in monetary terms, would nevertheless be real and substantial.

An industrialized economy depands on electricity. Two-thirds of all electric energy, both in the nation and in the Pacific Northwest, is used in commerce and industry. An inadequate power supply for industry means reduced capital investment, fewer jobs, decreased payrolls, less production and lower living standards. To government it means the increased burden of welfare and unemployment payments, concurrent with a decrease of personal and corporate tax receipts.

O 1.3-1

WNP-2 l

ER 1.3.1 Power Curtailment O

A qualitative calculation of the impact of power curtailment in terms of dollars would be difficult to perform. However, there is presently a method which has been developed on how to curtail the use of electrical power if the system is unable to meet demands. A permanent deficiency in electric power generating sources would result first in a shutdown of large industrial loads utilizing interruptible power. Long term shutdown of these facilities would undoubtedly reduce the residential demand as a result of reduced employment and economy in the area.

In the Northwest, the thermal generating resources must be scheduled to allow the region to serve the firm load require-ments during the period of low flow in the region's rivers (critical water period). During the average water years, it is possible to generate amounts of electric energy that are greater than would be available during a critical water year. This power, however, cannot be sold as firm power and is unusable by the average consumer.

In 1972 the Northwest Power Pool drafted plans for curtail-ing loads in the event of long term power shortages. These plans supplement, but serve an entirely different purpose from, the existing procedures, which cover short term Ic.u shedding. The latter are designed to limit power syster.

breakup in the event of sudden power failures, and expedite the return to normal operation. The load curtailment pro-cedures are intended to minimize the impact of prolonged power shortages. These long term emergencies could result from weather conditions, shortages of transmission capacity, generating capacity, energy capability or combinations thereof.

The load curtailment proposal has been drafted jointly by 18 power generating utilities and agencies serving the four northwestern states, British Columbia, Utah, and portions of adjacent states.

Following curtailment of interruptible power there are three possible curtailment levels that might be followed in an emergency. The first two would be voluntary, and the third would involve mandatory curtailment of firm customer power loads. The first level measures would be implemented by the systems actually experiencing an emergency and consist of the following:

O 1.3-2

1 WNP-2 ER i

a) Level One Curtailment 1

1) Curtail non-essential utility uses such as q floodlighting, sign lichting, display light-ing, office lighting, etc.

2) Eliminate electric heating and air conditioning in utility owned houses, buildings and plants where feasible.

j 3) Indicate, and instruct employees to turn off lights, motors and other uses of electricity when not needed.

4) Discontinue service to electrical customers in accordance with contractual provisions.

5) Request large industrial customers to reduce a non-essential load.

6) Request all other customers to reduce non-essential load by appeals through appropriate news media channels.

fs 7) Where feasible, reduce voltages at the distribution

, ( ,) or subtransmission level.

b) Level Two Curtailment If the above actions do not solve the problem and additional assistance is required, then level two is implemented. This involves assistance from the l balance of Northwest Power Pool systems. Level two curtailment involves essentially the same steps in the same order as level one - with the entire Northwest Power Pool participating.

If application of level one and two measures fail to resolve the problem it will be necessary to curtail customer load on an involuntary basis by individual systems. This would occur at the third level.

c)

Level Three Curtailment Level three constitutes load shedding in a manner

) and sequence which will maintain the integrity of

! the maximum portion of the total system. Level

! three will be accomplished as follows:

i (:)

1 1.3-3

WNP-2 ER

1) Interrupt service to industrial customers to the extent that this can be done after considering customers load and system conditions.

2) Interrupt service to selected distribution feeders throughout the service area for a short period of time, alternating among circuits. Service to distribution feeders should be interrupted in order of the classi-fication priority - that is interrupt service to the least essential first, and so on.

Every effort will be made to provide conti-nuous service to the essential public utilities, police, fire stations, hospitals and the like.

3) Records will be maintained so that during subsequent power shortages, care will be taken to locate interruptions throughout the service area in an equitable manner.

This plan has been formally adopted by the Operating Committee of the Northwest Power Pool and has been submitted via the Western Systems coordinating Council to the Federal Power Commission in response to FPC Docket R-405.

Power cutbacks were experienced in the winters of 1972-1973 and 1973-1974 where interruptible power was curtailed so that water could be conserved for firm power requirements. The costs of these cutbacks are not known but are certainly substan-tial; obviously, this is an adverse situation.

The current power supply with its lack of thermal

base-load generating capacity must be supplemented l as soon as possible to minimize the social and economic damage to the area.

Without new thermal resources added to the region's power supply, the Pacific Northwest faces a period of many years of serious deficiency in capacity.

Although future regional load is expected to l increase at a reduced rate, significant increases in generating capacity will be required and are scheduled. A means for reducing future deficiency, especially in 1980, 1981 and 1982, is completion of the Supply System's WNP-2. One can anticipate that any delays in the completion of this project or other planned projects, according to current O

1.3-4

WNP-2 ER forecasts, will increase the period of inadequate capacity and increase the economic impact on the area. (See Table 1.1-7)

An additional important advantage of WNP-2 is that it will improve the reliability of the area power supply. The Pacific Northwest's reliance on hydro-electric power has made it uniquely dependent upon nature.

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i WNPa[s /

"') . .

ER 4

TAHI.E 1.1-l(a)

! PACIFIC HORTl! WEST UTILITIES COHFEHEHCE COMt11TTEE WEST GROUP 4,HEA COf1PARISON OF ACTUAL WITil ESTIMATED WINTER PEAK LOADS I

(MEGAWATTS)

I 1/

i Date of Estimate 1967-68 1968-39 1969-70 1970-71 1971-72 1972-73 1973-74 1974-75 1975-76 1976-77 1967 (Jan. 17) 13,919 15,021 16,021 16,922 17,427 18,809 20,285 21,675 23,083 24,519 l 1968 (Feb. 1) 15,032 15,943 16,927 17,377 18,848 20,487 21,772 23,086 24,664

1969 (Feb. 15) 15,645 16,634 17,125 18,531 19,843 21,101 22,228 23,450 1970 (Jan. 15) 16,424 17,061 18,593 19,764 21,134 22,267 23,495 i 1971 (Jan. 1) 17,022 18,407 19,742 20,949 22,089 23,278 I

j 1972 (Feb. 1) 17,902 19,270 20,567 21,796 22,945 1973 (Feb. 1) 19,227 20,400 21,649 22,814 I

! 1974 (Feb. 1) 20,413 21,612 23,311 1975 (Feb. 1) 21,333 22,503 I

1976 (Mar. 1) 22,080 f Actual Winter Peak 13,309 15,540 15,030 15,725 16,876 18,259 18,707 18,444 19,580 21,457 ,

4 1/ Minimum temperatures of record occurred at a nusuber of weather stations in the Pacific Northwest j ~ during December 1968 Source: HPA i<equirements Section, unpublished data, February 7, 1978

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WNP-2 ER TABLE 1.1-1(b)

PACIFIC F40RTilWEST UTILITIES CONFERENCE COMMITTEE WEST GROUP AREA PERCEtJT DEVIATIGN DETWEEt3 ACTUAL AND ESTIMATED Wit 3TER PEAK FlkM LOADS 1/ 1975-76 Date ut Estimate 1967-68 1968-69 1969-70 1970-71 1971-72 1972-73 1973-74 1974-75 1976-77 27 12.5 1967 (Jan. 17) 4.4 (3.4f 6.2 7.1 3.2 2.9 7.8 16.3 15.2 1968 (Feb. 1) (3.4) 5.7 7.1 2.9 3.1 8.7 16.7 15.2 13.0 1969 (Feb. 15) 4.0 5.5 1.5 1.5 5.8 14.0 11.9 8.5 4.3 1.1 1.8 5.4 14.1 12.1 8.7 1970 (Jan. 15) 0.9 0.8 5.3 13.4 11.4 7.8 1971 (Jan. 1) 1972 (Feb. 1) (1.6) 3.0 11.8 10.2 6.5 1973 (Feb. 1) 2.8 11.1 9.6 5.9

? '74 (Feb. 1) 11.1 9.4 8.0 8.2 4.6 1975 (Feb. 1) 2.8 1976 (Mar. 1)

-1/ Minimum temperatures of record occurred at a stumber of weather stations in the l'acific (Jorthwest during December 1968 2/ Parentheses () indicato actual loads greater than estimated loads Sources bPA Requirements Section, unpublished data, February 7, 1978.

3: 32 ce 9

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ER I

1 i

i TABLE 1.1-2(a)

PACIFIC HORTilWEST UTILITIES CONFERENCE COMMITTEU WEST GROUP AREA COMPARISON OF ACTUA!. WITil ESTIMATED 12 MONTilS AVEFACE FIRM I.OADSN (MFGAWATTS)

$ Date of Estimate 1967-68 1968-69 1969-70 1970-71 1971-72 1972-73 1973-74 1974-75 1975-76 1976-77 1967 (Jan. 17) 8,888 9,562 10,252 10,826 11,056 11,u52 12,815 13,663 14,508 15,334 9,649 10,970 10,970 11,215 12,112 13,277 14,081 14,842 15,819 1968 (Feb. 1) 10,745 11,020 11,868 12,730 13,565 14,208 11,896 4

1969 (Feb. 15) 10,061 1970 (Jan. 15) 10,617 10,964 11,988 12,779 13,681 14,321 15,033 l

! 1971 (Jan. 1) 10,U07 11,688 12,507 13,279 13,947 14,614 i 1972 (Feb. 1) 11,541 12,375 13,100 13,846 14,482 1973 (Feb. 1) 12,409 13,054 13,807 14,472 1974 (Feb. 1) 12,971 13,678 14,719 1975 (Feb. 1) 13,446 14,173 1976 (Mar. 1) 13,934 i

f 3 Actual 12-Mo. Avg. 8,722 9,628 10,101 10,537 10,694 11,321 11,701 12,329 12,836 13,299 f

l Firm loads differ from total loads by the interruptable loa <ls supplied by DPA to large ,

~1/

! industrial customers. Firm loads are used in this comparison because of the high variability to interruptable loads Scuscus bPA Itequirenents Section, unpublished data, February 7, 1978.

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WNP-2 ER TA BLI: 1.1 - 2 ( t,)

PACIFIC 140RTi! WEST UTILITIES CONF 4:RE!dCE nettt!TTEE W1:ST GROUP ARCA PERCENT DEVIATIOti BE*IHEEN ACTUAL AIJD ESTIMATED 12 MOtJTils AVERAGE FtRM LOADS 1/

t>a t e of Estiaute 1967-68 1968-69 1969-70 1970-71 1971-72 1972-73 1973-74 1974-75 1975-76 1976-77 7/ ~

196'/ (Jan. 17) 1.9 (0.7T 1.5 2.7 3.3 4.5 U.7 9.8 11.5 13.3 1968 (Feb. 1) 0.2 1.9 3.9 4.7 6.5 11.9 12.4 13.5 15.9 1969 (Feb. 15) (0.4) 1.9 3.0 4.6 8.1 9.1, 9.7 10.7 1970 (Jan. 15) 0.8 2.5 5.6 8.4 9.9 10.4 11.5 1971 (Jan. 1) 1.0 3.1 6.4 7.1 8.0 9.0 1972 (Feb. 1) 1.9 5.4 5.9 7.3 8.2 1973 (Feb. 1) 5.7 5.5 7.0 8.1 1974 (Feb. 1) 4.9 6.2 9.6 1975 (Feb. 1) 4.5 6.2 1976 (Mar. 1) 4.6

-1/ Minimum temperatures of record occurred at a nun.ber of weather stations in the I*acific Northwest during December 1968 '

2/ Patentheses () indicato actual loads greater than estimated loads Source: UPA Requirements Section, unpublished data, February 7, 1978.

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SUMMAltY OP LOADS AtJD RESOllHCES I

(Sheet 1 of 3)

F1pires are Janu ary I e.sk and Gmtr ct Yea r Engtr.y in llegawatt s l9T8-79 1919 -f.1 1981-41 1918-82 1982-81 1981-84 8144-85 PW A V r. Og Av f. PF AVG PE AVG pK AVC PK AVG P4 AVC LOA 93 I svSirM LO ADS 1/ 24(.16 1h070 258F 16a6T /F224 17F51 28598 18785 29974 19505 30919 20?l9 *??19 219F2 2 fuP00lS }/ 2144 690 2090 6?9 2108 L41 I Ft 1 496 Ital 059 1562 2r3 1561 21%

• 10T AL LO AQ5 26f64 16F28 27968 11496 2 9 4.* f. 18404 303C3 19288 11589 19444 12541 234?2 13RS2 21171

• E%nU4CES 4 NAIN HY espo J/ 2T242 19682 24989 81611 29?46 II6TF 29748 1178F ?99F3 18719 1C425 19784 1f495 l l 116 5 I N9f Pl H01 NI HVORO 659 411 659 433 659 411 651 433 659 414 659 431 659 4 11 6 intal HYll?O 2F901 12045 2959a 12C66 2910' 5218C 33407 12150 te642 12842 38984 12847 11199 I?l49 F Ex. SM. THOM. 8 MIMC. d/ 243 56 243 96 A lf 55 236 55 256 55 216 55 2.15 54 A C O Mit. tuoHINCS }/ 1225 103 1225 10 1 122c 109 1025 IC9 I?25 109 12?5 IC9 I??5 119 9 HAHFQ40 y/ 0 585 C Els ( SIS 3 515 a SIS 0 C 0 9 Ir Int 04rS 1/ 1697 1594 1946 1680 2020 16Cs 1861 1567 Inl6 1501 115T 1477 sh45 1178 II CINibALIA 4.18 3 989 I 51 3 919 I ll' 909 1383 919 t ill 919 8313 999 I tl 1 589

, 12 800J4H 191C F91 I l it 198 til" 7 91 1831 791 191C Fil 1130 191 1810 198 l' CatSIkiP I t2 11C 258 330 258 1?C 251 331 251 333 256 310 250 110 258 l '. W N a 2 C 0 a S r lla lig) par 110C A?S 1400 5 ? '. lita 479 15 'toA4DHAN lCapfY COAtt C C e i 4FF 1 11 471 3'4 417 35a 417 154 4/1 354 16 COLSIPIP 1 14 0 0 0 C a "

1 14 490 4 45 940 691 9RQ F16 11 wt.P I O 1 C 9 P O 1 0 0 63 1250 765 82',0 915 19 W4P 4 4 0 0 1 P 3 $ C C t 0 C 1254 41F a 11 ww 1 'c c c 3 r  ? O e c 0 a 62 1248 160 i 2? $<44TT l 0 1 1 1 C C 3 0 C C C e 0

• 26 WNd 5 0 3 0 0 r ", "

0 1 0 0 C 0 C 77 8'F ine E S po l' LGS l O O C 0 C 0 1 C 0 G 0 0 0 0 4

R1 '.r AG I T 2 0 G r e r 0 1 0 0 C 6 0 0

• 24 s t ilt.t SPUINGS 2 0 0 0 6 _r .. 0 9 0 0 C 0 C 1 9 as valgt OL S3tACF S 31859 16074 8562% th247 '467F 166*i9 38054 11452 38149 87964 4Cna2 14452 43tal 19786 s

} 2h Hf090 SM.TH"I.9 MI9C.RFS. ~8/ I464 J 1513 0' I St B '

0 459% 0 lhb4 0 .lbr/ 0 IL 58 0 hf h' 27 LAPGf fMFWMAL *ES. 6/ 416 S 496 3 484 3 6s t/ 0 726 0 95T C I T61 e rt O 25 PL4HNit4G JfSE99f* 53' O MP2 0 I ?i* e 143.5 0 1895 C 7C59 0 2197 0 Op pq inaq cenwin erstoVriOfE [ 637 $22 369 th? JIS 548, 521 613 3/1 555 341 593 349 SPS 30 48ALilAfloh TACTOR 9/ 929 e 19'T 1 ISa9 0 1338, 1 If45 0 iff8 C, lit?

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J 'I utfWO M 4 8 ti f f M A'*C C 10/ C 51 0 51 0 51 3 55 0 53 0 54 1 ST 20 $0 51 U

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O 2)3, s ' t.f I wf 590uct' S 79172 15668 31;78 15834 31731 16?65 32/46 trol.1 12861 11569 34498 16049 9b 4 5 8- 89/8C oa .

54- SudPLus (W heriLIT 180t'-leto 14'84 159$. 25'5 -2119, '0406 -2191 ' 9 27 P.i -22 /C 1957 -2173 2 6$4 -1497 ,

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45 iP A I t40. luft94U?It9LE 12/ 931 996 193T IP15 'til" .1108 tili 1815 4065 1065 1075 1015 c.10 a t $385 51 l

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k TAllLE 1.1-3 (Sheet 2 of 3)

Figurce are January Peak and Cont ract Year Energy in Hegavstra l965-86 1986-87 1947-88 1988 89 1989 94 8991 98 (191 92 PK AVG PI: AVG PK AVG PC AVG P< AVG PK AVG p( AVG LO41S I SYS TE M loans 31511 71158 1445:5 22560 16295 21393 3FT40 242F1 19249 ?S182 4Dall 26124 42147 27C80 2 EXPoets 1565 201 98'l 209 24P 2CI 106 174 196 IF4 103 ITI 105 IFl 3 19fAL loans 35016 28954 .4584? 22T09 36543 23694 17846 24445 19155 25356 40916 20298 42651 27251 DESoueCf3 4 MAIN HY900 3 f 518 16697 19514 18696 JO6CT 88680 30618 18674 10683 Il6T4 3a611 libTh '0681 186F4 5 I:49f p Ek9ENT HV000 659 =33 659 413 659 431 65'l 431 659 4 43 659 433 659 bil 6 in t At. Hvnp0 1819T 1211? 11893 12129 ?l?66.12113 3127' 12107 182/2 12101 182T2 128c7 18772 12887 T f W. S*. THDM. t MISC. 225 51 225 53 225 51 225 57 225 58 225 53 '24 5' s CBN9. t uo *lI NE S 1225 809 12?S 509 1225 809 1225 109 '8225 109 4225 109 1725 119 9 HANF93n C 0 t 0 C e 0 0 C C 8 0 ,

? 1 10 adP0uYS 3628 1314 5357 1862 147'l 890 1396 691 1842 602 1028 501 907 447 ,

el C( UT J ALI A 4315 999 t il 3 999 1113 919 1311' 919 1313 913 Its3 989 till 989 82 00 B AH II tc 198 ft'0 T 'l l le3r r91 ll33 791 Il 30 791 Ilgo 731 1850 (11 il tot S(ulo 1 1 2 35C 25l 1:4 261 310 251 113 251 130 251 130 251 '91 258 Ik w'.P 11CC 625 I l e t* 625- 1000 e25 Il01 37* 1933 425 1800 825 llc 1 055 45 10194=1H ICARTY C01L9 4TT 156 411 55 4 471 164 4TT 158 411 358 41/ 35R 477 '59 86 C9tSipIP ' L 4 962 7th 960 T'6 98C T1G 963 F .' h 913 TJ6 980 7'6 143 T'6 17 w9a i 1250 9ss 125c 9's 125C 9's 1251 918 125" 919 126C 918 ISS3 **P 84 WNP 4 125C A60 125E '9'8 125C 918 1250 938 125C 914 8250 938 17s1. 9sa 19 wNP 1 1240 930 124 c 910 I ?nt '932 1240 91C 124C 9 5C ' 1240 9?P I?41' 9ta

?1 S < r. i f i 1248 773 128n 966 12A8 966 1284 966 1258 966 1284 966 1749 966 21 W'M S 1241 414 1240 nst 1240 913 1241 91D 1240 91C 1240 91r 124 G 9'n 2 ? a f lit l' Sap!NGS I C 149 1260 90 3 I?6P 945 1261 945 126C 945 1260 945 1261 945 21 ".wAGli ? 0 t 0 0 12Aa FT' 1288 966 1288 966 12nq 966 12ni 966 FL Pr3tLE SP91NGS 2 3 0 C 9 0 1 .- 199 1261 449 1260 945 1261 945 75 T.IIAL 9FtuinCES 455F3 21614 4705n 22768 4814l 23465 45264 23634 4921C 2416F 49156 24254 4's0 45 24154 26 HYhco.SH.i PML .4 FI SC.pFS. '163? C 1632 0 163F C I f> 3% t 1636 C' 1636 0 161o e 21 LAwCE fpCP44L DE S. 1740 $ 1929 0 2122 0 2122 0 2381 0 2111 e 2141 0 O in "LA*4N!4G PESE*VfS 2360 0 2Til O $414 0 10F9 0 3864 0 1461 0 1115 0 O - 29 LO AJ 6 80wl H pf?fpVFS 615 117 679 ?94 64F bil Fl2 42* F 59 4 38 755 45e 407 471

$h[L U*

'a 60 AL IT At tou F ACIOD 31 HV070 M A INIF H ANCE 1074 G SS 0 ICF4 0 GS 0 ICFF C

C

$8 8014 1 54 C 1074 C

0 51 4t74 0

0 El 1776 1 51 0 .I 17 V*A HH-5W INilpiTF L OS MF 9 50 1 7F i i C 1 0 0 0 C f 3 C t1 7 . ... .... ..... ..... ..... ... . ..... ..... ..... ... . ..__. ..... ..... .....

,, J' Nff vfS000CES 18382 218F'l '1987 22319 40004 22996 39651 21151 40142 23678 39915 2'Fil 39494 2161r o

-a u 54 Suoplus 09 OtFICli 1106 -FF9 1145 -453 3468 -599 179? -1292 987 -86F8 -80Cl 2578 -2962 -16?l co 35 HPA INO. INTENouPiliLL 8095 IC15 1805 1905 1185 IIIS 1825 1875 1135 1815 ll45 1846 1854 1856 O O O

(

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TABI.E 1.1-3 J

s (Sheet 3 of 3)

Figures are January Peak and Cont ract har Cncrgy in Megawatte .

i 1992-93 1991-94 1994-95 1915-96 1996 97 199F-98 PK AVG PF AVG Pr AVG PK AVG PK AVG PM AVG f

, LOA 15 i

i SystFM LoAOS 4405C 24387 45818 29f 51 47659 ft259 49607 31418 51619 32625 51752 39899 i 2 EvP09fS 111 878 I?3 IF2 121 211 tot 239 122 32F 122 32F j

• Int AL LOANS 448$1 28258 45921 29325 4FF62 31470 49783 31649 SIF6C ?2952 5'474 34276 a

DES 0ueCIS

• 4 HAT'I MYD40 30613 18674 '0613 19674 ? G 51.1 186F4 10613 88614 12611 84674 16663 116F4 d

5 IHutPENDENT Hinoo 659 433 659 413 659 431 659 433 659 4 13 659 433 6 1014L HYO*C 11212 8200F 38212 tilt? 38212 12807 38272 12BCT 19212 1210T 19212 124a7 j F IM. SM. TH09 A MISC. 225 51 225 %3 225 55 225 53 225 5' 275 51 l 8 COM9. IO44INES 1225 IC9 1225 109 1225 699 1225 109 1225 109 4225 If9 9 H At:F000 0 0 0 0 C 1 0 0 0 0 0 e 1* lap 0*is FFT 144 616 249 An4 128 321 F* 24C 6F 240 67 il CE4f9ALIA 1113 91'l 1313 919 1113 919 1383 919 I?l' 999 1383 989 12 189 s Att 8810 F91 t i lt F91 1130 F91 l131 798 1130 798 ti1S F98 11 CCLSt>IP l &2 110 251 IM 254 130 258 311 251 Ilt 254 itG 258 14 WNP 2 1800 R25 1100 875 'ICC 875 IIC1 825 ll0G n?5 iia 0 425 i 14 10440 MAN IC Astv CO All 41F '

,58 4TF '48 4FF 154 4FT .' S u blF 158 4F# 5%S j 16 COLSIPip i 14 98C T16 91C l'6 9a6 T'6 983 T*6 94G F16 940 lib

11 We4P l 1250 9.'s $210 918 8250 958 1253 9'8 525c 918 1250 914 1 . In wha 4 1260 3*8 1250 9'8 8250 918 1251 9'4 I?Sc 9 18 125r 9'a

19 Weep i 124C 93r 1240 911 '924P911 1240 9 'O 924C 950 124C 910

?? Skar.it i 1288 966 1233 966 128R 966 82CS 966 1288 966 8 2 t. 8 4t6

, 21 Wra p 5 1240 910 1240 911 1240 131 8241 910 1243 9 10 8240 9'O i 22 Pf91LI SPRINGS 1 126C 945 1260 945 I ?t.f 945 1263 945 126" 944 1260 944 966 I  ?' SKAGli > 4288 966 1288 966 1288 966 128S 966 1298 128a 966 1

d 24 Pl .1:lt f SpeINGS 2 1260 945 1260 126r 945 ' _.... ;.... 945 1264 945 1260 945 126C 94%

25 luiAL PCSOU9CfS 46905 24021 48F64 23956 48612 23826 48449 21780 48168 237F4 48148 21774

. c) n h, at m ?F HYU30.S*.TH'L.t MIMC.oIS. 6616 0 1615 0 1616 0 1636 0 1656 O Ib36 0 OD 27 L&OGE THERMAL RES. 2150 0 2118 0 2181 0 2388 0 2318 0 211f 0 24 PL ANNil4G PESf put % 43?4 4'42 4654 0 50f7 0 SMTS 0 SFSS e j

hfh' 29 LO AO 690WIH RESE*VES 859 501 0

ETS 521 0

927 545 967 4 74 8086 614 la45 6'S et e

{ D ?1 vfALl7AlloN Fact 0* 4018 0 1t78 3 19F8 3 ICF% C IJTS C 1016 0

'" d 31 HYn40 N AINf f N ANCC 0 Si f 50 f 51 1 "I C 51 0 %I U$ ;; 37 IPA NW-SW IHf0pf1F LOSSE9 0 C 1 0 C C 1 e r C 0 t 3,

o3 ..... _____ _..._ __. . ...._ .. ._ __... ..... __... ..___ ___-- _____

11 Nff wt90UWCfs 390l? 21469 '9522 23394 39302 23212 31450 21855 16962 23119 16540 23988 i .

?% CuDPL:ss ne O(F ICit _5136 -4 F44 - F 199 -994 8 _976C .7218 -12261 _1494 _14198 _3&11 -87334-18138 i

?S 1PA [NO. INTERWHPII9LF l164 l164 18F4 1174 1844 1884 1894 4891 1204 1203 1204 1283 i

i

FOOTEOTES FOR TABLE 1.1-3 1/ Area leads are estimated firm leads of private utility and public agency systems, Federal agencies, and EPA industrial customers.

BPA industrial customer loads also include interruptible loads.

Leads also include area trans=1ssion losses.

1/ Exports include deliveries to California utilities under the CSPE ar,reement , peak / energy exchange contracts with PSW, transfers of Centralia power to Cen:ral Valley Preje:c, WP Co. contracts with Utah, Idaho, and Montana Power Companies PSP &I. Co. contracts with Utah Power Co. and Salt River Project, PGE Co. contracts with Pacific Gas and Electric Co. and Southe:n California Edisen Co.,

Eugene Water and Electric Board contracts with Southern California Municipalities, BPA contracts with Montana Power Co. (M.P. Co.)

for geographic preference, wheeling paymants, Hanford-NPR exchange, Hanford-NPR extension, WNP No.1 deliveries, and M.P. Co's. share of restoration from :he West Group Area as per Pacific Northwest Coordination Agreement.

3) Hydro resources are the same as chose shown in the 1978 West Group Forecast Report.

1/ Existing small ther=al and =iscellaucous includes old existing steam plants, sna11 diesel generators, and miscellaneous s=all industrial purchases.

5) Combustion turbines include PP&L's Libby unit, PCE's Bethel, Harbor:en, and Beaver units, PSP &L's Whidbey Island and Whitehorn units, and WP's Othello and Northeast units.

f/ Hanford-NPR operation is based on gross production of 4.5 billien

• kilowatt-hours per year in 1978-79 through 1982-83. The plant is considered not dependable as a peaking resource.

7/ Imports include energy returned to the PNW from peak / energy exchange contracts with PSW utilities, PGE Co. contract with Southern Cali-fornia Edison Co. , PP&L Co. transfers from PP&L Co. Wyoming Divi-sion, PSP &L Co. contract with Montana and Utah Power Companies and Salt River Project, WWF Co. contracts with M:ntana and Idaho Power Companies, and EW&E3 contracts with Southern California Municipalities.

8/ Total reserve requirements on peak are based on 12 percent of the total area loads for the first year, increasing at a rate of one percent per year up to 20 percent, and ra m4ni g at 20 percent thereafter. Reserve requirements on energy are based on one-half year's load growth of utility-type loads. Reserves are broken down into major components.

9) Realization factor is the adjustment to the Federal hydro peaking capability to reflect inability of the Federal system to achieve its full peaking enpabili:y at any one specific instance. .

10/ Hydro maintenance on encrrf is the estimated maintenance required during the critical storage period and is the same as shown in the 1977 West Group Forecast report. Peak hydro maintenance is included with the peak forced outage reserves.

M/ BPA's NW-SW Intertie losse: are associated with deliveries over the Intertie under contracts with Pacific Southwest utilities.

-12/ BPA industrial interruptible loads are served directly by 3PA and are included in Line 1 above. Line losces associated with the interruptible loads are not included.

Amendment 2

T I

l 1

1 a

I 4

4 TABLE 1.1-4 .

i WEST GROUP LARGE TIIERMAL ADDITIONS 4

BASED ON SCIIEDULED DATES OF COMMERCIA L ODERATION (1)

CAPACITY IN MEGAWATTS ENERGY IN AVERAGE MEGAWATTS 4

i s

Stu6 ague ages i 89he 85el 4938 19a4 tsuS

[979 {TmA 1

.I Vesa n t ae.s t enal J.use 40 Sh. ' ' ' ' A'w

-. $k -.Av ! .k .A. W. l*k

.. .A.v 4.'.h .A.v

. t h ' ~ ' ' ' A.w.

. I L.~~.A.v.

A*

1 ~ kw -. .5I89d8~~~A.. $. k. 'w.

' ' ~ ~ A v.

. l'%. ~ ~~ Av.

i 1

I th ea e .ess.eas (Cestyl . .. Gid Juh #4 tm48'- J . . . . .. Slee LSe J4h Ji

' 43e J4 ese 48m 2s5 4ulnessa. - 664 . . ....

82%e 488 SGS 8J%8 62 #6h 889 6MW-464 . ....

82Se 3#J $$a 8248 J44 $sh ,

) " tear-ssb . . . ....  !

I 8J88 4( 4 894 8 Jeu Af8 J bheJ46-862 . . . . .

4 459 8J68 7%b tas l 8 a.64.le Eg.s t halm - 8 6 4 ....

i j esa.*4 8 wee 4 4 Tut 4 8 an a i il

$$Ji W 4h 4#40 W 8J 49e 584 J49e 6dS $ $J4 2$25 $Mtb $269 4$8% SJag )#$ guS Ahnwel .

SSid W eb $5ld 8665 Shef 2686 6197 3236 6J13 4654 8845 64J5 lu.eu% d'.64 88,874 3847 88.4#J s*4J6 4'uanne 8 4 6 6 ve Imi.4 0 s Aas. sees:y Ts t el m a Jitu aJ s 8886 P e '* Sh4 thf a top Ae.u a.s l ... . lite $he 8JSe 646 SJi 4 8 %^# ,

8480 She J 4SS 8486 J$he $db3 446e Jeuk 446e SJes bbe4 .% 2 $##6 Suke S##4 S56e bid) 6e49 1 e'esensel46 0 wu . .

r 3

! .. . e._8 . u .. ... e . B . . .. ..S.,.

I i t .

?

0 y' t O el 1 at ip

• i Ou <

er p.

1 (D :1

• l l 81 (D .

1 u 1 H ft

, to l 4 FJ m

i i

i j .

i 4, e

TABIE 1.1-5 WEST GROUP LARGE TIIERMA L ADDITIONS BASED ON PROBABLE ENERGY DATE (1)

PEAK CAPACITY IN MEGAWATTS ENERGY IN AVERAGE MEGAWATTS -

Ive% 1986 19md 8984 4989 Vu e 6.wt o u.J {S!T .Itse _ lsd e . _ . J ut, , jses tvut 3""" 30 ST l'h

!!  !'!  !! lh f!  !'! ff l'! f'  !! ff I'h AT l'h  !! !! f3 !h I' ti..as.s (a4 ayn . . 4## la4 8 848 J4 6.Isr - J . . Abu 8teo  %#m Isi 34 429 Shu 439 J'44 43 oblat s age - $64 . .

6J BJSG Ju4 $J%e ble 4JJ 38 Waar 4 6 4 6J 8#40 633 4249 644 tit #5 6m!4* - b 6 4 . .

IJte 37) 894 Bdes 788 898*

g.6 9st-164 . . .

ISS IJ68 ble 44J 455 tst.4. l e bg s t eeg e - 8 6 J . .

p.sq t ems.n i TuaeIma 4746 lu2S J450 43bt JSJG 8988 IJbe 8884 lits 558 e Add Annual .. . Gli ahl Blue #3h 49G tel 4Ji sul 441# luth Je67 56#3 les# J804 6418 48%4 usJS 6een te.te% #446 88.818 u s ss 41.888 SiJ4 Cums.e,l a t a vu . .

4'utel 4 s a Jday Tsat e B h a lys B J'au #4# Jits less lil6 560 But S46 54 de ana.ea l . . 4800 m in J a'se 4468 J623 S$st $44m bl#4 L134 Sils 6u 6 *4 hif8 6833 Cum.u t e t t w.s tied blu llue ### IbJe 483 - ha m.s 4 n. 6.'.ent e.a auge t aas swee t 8-8-#8 OP O:3 et G O *1

• tT O.

mH Bt G D

H tt to

• 4 to G)

O O e O

t O O O i

4 i TABLE 1.1-6 PUBLIC AGENCY - BPA ENERGY RESOURCES AND REQUIREMENTS i (Average Megawatts) k i

Probable Energy Date Scheduled Date i

Estimated Estimated Estimated Unsatisfied Resources Unsatisfied Unsatisfied f WPPSS Requirements Year Ending Requirements Resources Unsatisfied WPPSS Requirements (Adjusted) Requirements June 30 (1) (1) Requirements No. 2 w/o WPPSS-2 (2) (3) No. 2 w/o WPPSS-2 1979 10,980 10,490 490 490 10,490 490 1980 11,453 10,620 833 833 10,602 833

' 550 1,505 1981 12,214 10,809 1,405 110 1,515 11,259 955 i 1982 12,725 11,266 1,459 687 2,146 11,379 1,346 798 2,144 i

1983 13,016 11,376 1,640 825 2,465 11,750 1,266 825 2,091 i

1984 13,290 11,771 1,519 825 2,344 12,237 1,053 825 1,878 1985 13,666 12,866 800 825 1,625 13,272 394 825 1,219 i 1986 14,045 13,811 234 825 1,059 14,168 (123) 825 702 I' 986 1987 14,435 14,205 230 825 1,055 14,274 161 825 1988 14,858 14,080 778 825 1,603 14,080 778 825 1,603 1989 15,294 14,080 1,214 825 2,039 14,080 1,214 825 2,039 (1) Blue Book Tabic 2 adjusted for duplication in Federal and Public Agency values.

{

4 (2) Adjusted for difference in added resources between Probable Energy Date and Scheduled Date.

(3) () denotes surplus resource over requirements Amendment 3 January 1979 r

TABLE 1.1-7 WEST GROUP ENERGY RESOURCES AND REQUIREMENTS (Average Megawatts)

Probable Energy Date Scheduled Date Unsatisfied Unsatisfied Estimated Unsatisfied Unsatisfied Estimated Estimated Requirement Requirement Resources Requirement Requirement Year Ending Requirernents Resources With WPPSS WPPSS Without Adjusted With WPPSS WPPSS Without June 30 (1) (2) No. 2 No. 2 WPPSS No. 2 (3) No. 2 No. 2 WPPSS No. 2 1979 16,721 15,661 1,060 1,060 15,661 1,060 1980 17,496 15,898 1,598 1,598 15,898 1,598 1981 18,404 16,265 2,139 110 2,249 16,800 1,604 550 2,154 1982 19,211 17,013 2,198 687 2,885 17,148 2,063 798 2,861 1983 19,844 17,569 2,275 825 3,100 17,943 1,901 825 2,726 1984 20,422 18,049 2,373 825 3,198 18,515 1,907 825 2,732 1985 21,177 19,280 1,897 825 2,722 19,686 1,491 825 2,316 1986 21,958 21,179 779 825 .1,604 21,474 484 825 1,309 1987 22,759 22,309 450 825 1,275 22,386 373 825 1,198  ;

1988 23,594 22,996 598 825 1,423 22,996 598 825 1,423 1989 24,445 23,153 1,292 825 2,117 23,153 1,292 825 2,117 (1) From 1978 Blue Book, Table 1, Line 3 (2) From 1978 Blue Book, Table 1, Line 33 (3) Estimated Resources adjusted from Probable Energy Date to Scheduled Date.

Amendment 3 g g January 1979g

O 'O O TABLE 1.1-8 WEST GROUP CAPACITY (PEAK) RESOURCES AND REQUIREMENTS (Megawatts)

Probablu Energy Date Scheduled Date Unsatisfied Unsatisfied Unsatisfied Requirement Es timated Unsatisfied Requirements Estimated Estimated Requirements Without Resources Requirement Without Year Ending Requirements Resources With WPPSS WPPSS WPSS No. 2 Adjusted With WPPSS WPPSS WPPSS No.2 June 30 (1) (2) No. 2(4) No. 2 (4) (3) No. 2(4) No. 2 (4) 1979 26,764 29,872 (3,108) (3,108) 29,872 (3,108) (3,108) 1980 27,961 31,371 (3,410) (3,410) 31,371 (3,410) (3,410) 1981 29,336 31,731 (2,395) (2,395) 32,831 (3,495) 1,100 (2,395) 1982 30,300 32,706 (2,406) 1,100 (1,306) 32,706 (2,406) 1,100 (1,306) 1983 31,589 32,867 (1,278) 1,100 (178) 3,4117 (2,528) 1,100 (1,428) 1984 32,541 34,498 (1,957) 1,100 (857) 35,738 (3,197) 1,100 (2,097) 1985 33,802 36,456 (2,654) 1,100 (1,554) 36,456 (2,654) 1,100 (1,554) 1986 35,076 38,382 (3,306) 1,100 (2,206) 38,382 (3,306) 1,100 (2,206) 1987 35,842 38,987 (3,145) 1,100 (2,045) 38,987 (3,145) 1,100 (2,045) 1988 36,543 40,004 (3,461 1,100 (2,351) 40,004 (3,461) 1,100 (2,361) 1989 37,846 39,638 (1,792) 1,100 (692) 39,638 (1,792) 1,100 (692)

(1) From 1978 Blue Book, Table 1, Line 3 (2) From 1978 Blue Book, Table 1, Line 33 (3) Estimated Resources adjusted from Probable Energy Date to the Scheduled Date.

(4) () Indicates surplus over requirements Amendment 3 January 1979

O ESTIMATED VS. ACTUAL WINTER PEAK LOADS PNW-WEST GROUP AREA MW(000)

-26 a*#-24

• • s** ,, 22 EXTR EMELY d

i sr Y 20 COLD WEATHER e*#,s ' i_

i - 4

\ **,,,$a* ACTUAL [

i - - 16 R' i I O eg i 1967 ESTIMATE l

14 12 l

i j 10 t

I h l

6 l'

2 l 0 1967-1968 1970-1971 1973-1974 1976-1977 1

1 1

Amendment 2, October 1978 N 'ASEI2iGTON PU3LIC PCWER SUPPLY SYSTD1 ESTI,vaTED VERSCS ACTUAL WII;TER FIRM :

WPPSS !;UCLIAR PROJECT NC . 2 PEAK LOADS f 2r.Vi!Or.=er.*.al RepCr . PNN-WE ST OPOr+o sorn lEIC. 1.1_1 l

l

O ESTIMATED VS. ACTUAL ANNUAL AVERAGE FIRM LOADS PNW-WEST GROUP AREA M W(000)

-18

-16 1967 ESTIMATE

,***, p

1. p ,# *

• l Wl 12

, mW

-ACTU AL ' 10 l

8 6

4 2

. , , . , o 1967-1968 1970-1971 1973-1974 1976-1977 l Amendment 2, October 1978 WASHINGTON PUBLIC POWER SUPPLY SYSTEM ESTDIATED VERSUS ACTUAL ANNUAL WPPSS NUCLEAR PROJECT NO. 2 AVERAGE FIRM LOADS Inviron:nental Recort ow-wreT < ont e sces l ' FIG .1.1-2 l

l l

l l

~%

d U. S. & PNW (WEST CROUP AREA) ENERGY LOACS 10.000 ,

I# . i i

I i i i i i  !

7.'000 ' I I t I

' I i l l I l I# - i ,

i s i; .

! l l l 1 i 4 000 l

l l l l' l 6

l 1979 1995 I I  ! l

.000 l

I, i i

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.c00 e- i .

i i i i l z 700 .

- 1 1 1

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= soo

! k l k f I l I l um

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( 300

i. _ .

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l i i j. I t  ! 4 i l  ;

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! 1978 1995 l' r j f I  !

100 '

90 . i i , ,

i i i i i e i e i 20 -

i l 3 I l I l  !  ! l l l l l l t i l i  !  !

i i i i i i i i i i 1978 1980 1982 1984 1986 1988 1990 1992 1994 1999 YEAR 11 ELECRICAL #CRL::. SEP ?S.1977

) SLUE SCCE.1978 *9 SRCOGM 1997 - 4 Amendment 2, October 1978 WASHINGTCN PUBLIC POWL4R SUPPLY SYSTE:1 U.S. & PNW (WEST GROUP AREA) PEAK LCADS WPPSS NUCLEAR PROJICT NO. 2 Envir0I: mental Report l FIG. 1.1-3 e ---- -

,- ----m-- ,-----,,v - - - - - - ,- ,,

O

-200 PNW Electric Energy Requirements

- 250 INOU$ TRIAL - 20o s

-iso y e

MS.. . U..S[$_ ,o, RESIDENTIAL l \

1 a 1955 1965 1975 1985 1995 l

V WASHINGTON PUBLIC POWER SUPPLY SYSTEM ELECTRIC ENERGY REQUIREMENTS BY . ' 'R WPPSS NUCLEAR PROJECT NO. 2 CONSDIER CATEGORIES PACIFIC NORT' Environmental Report (WEST GPOUP AerM -

].

FIG. 1.1-4 l

Factors Causing increase in Energy Sales to _,,

Domestic Consumers in PNW 1950 -1973 - 30 PNW - WEST GROUP AREA

- 10 9 AMOUNT OF ENERGY SALES DUE TO:

' ' ELEC. SPACE HEAT a i INCRE ASE IN USE PER CONSUMER OTHER THAN ELEC, SPACE HE AT j r a INCRE ASE IN NO. OF CUSTOMERS sammaissimi.

- 20 i 1 1950 USE EXCLUDING SPACE HE AT s ir iib 8 s

'...g f ':

_ ,3 25

gi? 'o k . . . . .

!!!sl!!  !{AM

- mammenamme suminimumm 5

51 51 5.1 51 0

1950 1960 1970 1973 WASHINGTON PUBLIC POWER SUPPLY SYSTEM FACTORS CAUSING INCREAEE IN ENERGY WPPSS NUCLEAR PROJECT NO. 2 SALES TO DOMESTIC CONSUMERS IN WEST Environmental Report GROUP OF PNW 1950 - 1973 FIG. 1.1-5

0 0

e 1

i0 9

i 0 8

g i 7 0

ra Y i 0 6

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OM R E R 4 1

R V E T U D Y 0 RT H9 N E

C H9 UN T4 0 C 0 CA i 4 R L E N E2 E OI T

R D

A U

G1 A

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V A

N P OL I A T

AM RR UE G

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A i 0 3

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DT D

A EE O TG L AR MA 0 L t X L i 2 A OL U R A N PT N PO '

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1 9 8 7 6 5 4 2 1 Q o $a heEQe  :

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'1979 1980

• 1981 ' 1982 '1983 ' 1984 '1985

• 1986 l 1987i 19888'989 YEAR ENGING JUNE 20 Amendment 2, October 1978

• aSHINGTON PUBLIC POWER SUPPLY SYST E ESTIMATED CAPACITY RESERVES

[

WPPSS NCC' EAR PROJECT No. 2 1979-1989 Inviro:::nantal Repert c'IG . 1.1-7 l

l

O

=_.

2000 - TCTAL ENERGY CEFICIT y' '5 5iav

., EN,E,mcY oEpici?

isx -

f . i

/

l w

/// '// /

l1

\

l ,

/ F! AM ENiM3Y OE81C:7 WITH WNP.*

(/)  :-

/ F I '

W' l l . / .

1978 1979 1980 1981 1982 '1983 '1984 1985 1986 1987 81RM ENE AOY $UR**.US YEARBEG:NING JULY f Amendment 2, October 1978 WASHINGTON PUBLIC POWER SUPPLY SYSTEM ESTIMATED ENERGY RESERVES WPPSS ND* LEAR PROJECT NO. 2 1978-1987 Environmental Repcrt l FIG. i.1-8

l'

/ WNP-2 i ER l .

_,/

/

/ CHAPTER 2

/ THE SITE AND ENVIRONMENT INTERFACES 1

j/ 2.1 GEOGRAPHY AND DEMOGRAPHY 2.1.1 Site Location and Description 2.1.1.1 Soecification of Location The Washington Public Power Supply System's (WPPSS or the Supply System) Nuclear Project No. 2 (WNP-2) is on property leased from the United States Department of Energy (DOE) (formerly the Energy Research and Development Administration) within the Hanford Site in the south-eastern part of the State of Washington (See Figure 2.1-1). The Han-ford Site is comprised of 134 square miles (86,050 acres) in Grant and Franklin Counties, and 425 square miles (271,930 acres) in Benton County (See Figure 2.1-2).

4 WNP-2 is located in Section 5 of Township 11 north, Range 28 east, Willamette Meridian. The center of the primary containment vessel is located at latitude 460 28' 18" N and longitude 1190 19' 58" W.

m The approximate Universal Transverse Mercator Coordinates are 5,148,840 meters north and 320,930 meters east. The plant is (V

)

approximately 31/4 miles west of the Columbia River.

WNP-2 is 12 miles north of the center of Richland, Washington, the nearest incorporated community. Approximate airline distances fran the site to major cities in the Pacific Northwest are listed in the following table.

Direction Distance City From Site From Site Spokane, Washington Northeast 120 miles Butte, Montana East 330 miles Walla Walla, Washington Southeast 55 miles

) Boise, Idaho Southeast 260 miles Portland, Oregon West-Southwest 180 miles Yakima, Washington West 55 miles Seattle, Washington West-Northwest 160 miles Vancouver, British Columbia N orthwest 260 miles 4

Within the Hanford Site, WNP-2 is 18 miles southeast of the Hanford Generating Project and 2 3/4 miles northeast of the Fast Flux Test Facility (FFTF) which is under construction for DOE. WPPSS Nuclear Projects Nos.1 and 4 (WNP-1/4) are under construction 0.9 miles (V ) 2.1-1 Amendment 4 October 1980

1 WNP-2 ER 4

east-southeast and 0.8 m les east-northeast of WNP-2, *espectively.

The H. J. Ashe Substation is located 0.5 miles north J WNP-2 (See Figure 2.1-3).

The site is about 11 miles north of the Richland Airport and 18 miles northwest of both Vista Airport near Kennewick and the Tri-Cities Airport near Pasco. The Tri-Cities and the Richland Airports have regularly scheduled comercial airline service. Hughes Air West 4l serves the Tri-Cities Airport and Cascade Airways services both airports.

Adjacent to the WNP-2 site but not within the confines of the plant boundary, is a 9-acre burial site containing radioactive waste matter disposed by the Atomic Energy Comission (See Figure 2.1-3). Known as the Wye Burial Ground, the area is appropriately marked and will be adequately secured. The area is under the control of the DOE waste management program and is not considered a hazard to the public nor to the plant's operation. Neither the public nor the WNP-2 operating personnel will have access to this burial site.

2.1.1.2 Site Area The Washington Public Power Supply System has leased from DOE 1089 acres of which approximately 202 acres will be modified by construc-tion activities. Of these, only about 30 acres will be used for WNP-2 structures and auxiliary f acilities during its operation. The remain-ing 1059 acres will remain or will be returned to their natural state.

The plant property line is shown in Figure 2.1-3. In addition, Figure 2.1-4 and 3.1-1 show the Lcotion cf pertinent structures, f acilities and the railroad spur linking the site with the Burlington Northern l

Railroad at Richland.

The site area, as defined by the tract of land over which WPPSS will control access of individuals consists of the plant property and the area included within the exclusion area (See Figure 2.1-3). Part of the exclusion area is beyond the property line of WNP-2 and its con-trol is discussed in greater detail in sub-section 2.1.2. The site area is entirely within the boundaries of DOE's Hanford Site.

The site is situated near the middle of a relatively flat, essentially featureless plain which is best described as a desert shrub-steppe with sage brush and bitter brush interspersed with native perennial and alien cheat grasses extending in a northerly, westerly and south-erly direction for several miles. On the east, the site is bounded by the Columbia River. The plain is characterized by slight topographic l

r 2.1-2 Amendment 4 October 1980 1

i

WNP-2 ER relief with a maximum relief across the plant site of approximately ten feet, and a plant site grade level of 441 feet above Mean Sea Level (MSL) (See Figure 2.1.4).

As shown in Figure 2.1-3, the exclusion area is a circle with its center at the reactor and a radius of 1950 meters. This area meets the 10CFR Part 100.11(a)(1) criteria. Industrial facilities located in the site area are the WNP-1/4 projects, the H.J. Ashe Substation, and a permanent meteorological tower. An Emergency Response / Plant 4 Support Facility is planned for a location 3/4 mile southwest of the plant on WPPSS property. Highway and railway f acilities near the site area are shown in Figures 2.1-3, 2.1-5 and 2.1-6.

2.1.1.3 Boundaries for Establishing Effluent Release Limits

, An area slightly larger than one square mile has been established as the limit of the restricted area for which radiation concentrations have been calculated in conformance with 10CFR Part 20.106(a). The 4 restricted area includes the WNP-2 plant and f acilities, meteor-ological tower, a portion of the main railroad line and access road, as well as the Wye Burial Ground (See Figure 2.1-3). The plant's effluent release points are shown in Figures 3.1-6.

2.1.2 Exclusion Area Authority and Control 2.1.2.1 Authority A letter from the DOE Richland Qperations office to the Managing Director of the Supply System (l) advises that DOE has the authority to sell or lease land on the Hanford Site. The letter further states as follows:

"This authority is contained in Section 120 of the Atomic Energy Community Act of 1955, as amended, and Section 161G of the Atomic Energy Act of 1954, as amended. There is also general federal disposal authority available under the Federal Prooerty Admin-istrative Services Act of 1949, as amended."

As shown in Figure 2.1-3, the 1950 meter radius exclusion area does extend outside the plant property at several locations. All land outside the plant property but within the exclusion area is managed by DOE as part of the Hanford Site. In recognition of requirements spec-ified in 10CFR 100.3(a), that require a licensee to have control over access to the ' exclusion area, the following terms have been made a part of the site property lease agreement between the Supply System '

and DOE. Quoting from page 8, item 7 " Exclusion Area":  !

T 2.1-3 Amendment 4 October 1980 l

1

WNP-2 ER "The Commission recognizes the exclusion area as provided for in the operating license and will undertake no action or activity which would interfere with or restrict the Supply System's right to fully comply with this condition of the operating license."

Any actions taken within the exclusion area but outside the plant property are under the control of DOE. All rail shipments on the track which traverses the property are also under control of DOE and are also subject to the above quoted provisions of the Lease.

The only roads which traverse the exclusion area are the WNP-2 and WNP-1/4 ac'.ess roads shown in Figure 2.1-3. Access by land from outside of the Hanford Site to the project site is by other DOE roads. Travel within the exclusion area on the access road will be restricted by the Washington Public Power Supply System.

In the event that evacuation or other control of the exclusion area should become necessary, appropriate notice will be given to the DOE -

Richland Operations Office for control of non-Supply System originated activities.

O i

2.1-4 Amendment 4 October 1980

WNP-2 ER-0L G

b The above provisions provide the necessary assurances that the exclu- -

sion area will be properly controlled. If at some time in the future, the Supply System should decide that an easement would be useful in ensuring continued control, there is a provision in Paragraph 5(b) of the lease as follows:

" Subject to the provisions of Section 161(q) of the Atomic Energy Act of 1954, as amended, the Commission has authority to grant easements for the rights-of-way for roads, transmission lines and for any other purpose and agrees to negotiate with the Supply System for such rights-of-way over the Hanford Operations Area as are necessary to service the Leased Premises."

Pursuant to this provision, the Supply System could obtain from DOE an easement over the exclusion area in question which would assure that neither the construction of permanent structures nor the conducting of activities inconsistent with the exclusion area would be carried on therein.

2.1.2.2 Control of Activities Unrelated to Plant Operation The exclusion area will encompass the WPPSS Nuclear Projects Nos. I and 4, their respective access roads, and the H. J. Ashe Substation.

Other than these facilities there are no activites unrelated to the (V] operation of WNP-2 within the exclusion area. Both WNP-1 and 4 and their respective access roads (see Figure 2.1-3), will be owned and operated by WPPSS. The H. J. Ashe Substation will be owned by the Bonneville Power Administration and is considered a part of WNP-2 nor-mal operation.

2.1.3 Population Distribution Table 2.1-1 presents the compass sector population estimates for 1980 and the forecasts for the same compass sectors by decade from 1990 to 2030.* Cumulative totals are also shown in Table 2.1-1. This table may be keyed to Figures 2.1-7 and 2.1-8 which show the sectors and major population centers within 10 and 50 miles of the site. The pop-ulation centers, within 50 miles of the site are the Tri-City area of

• Population estimates out to 50 miles were derived to serve the licensing requirements of WNP-1, 2, and 4. Therefore, estimates 5 were made relative to the centroid of the triangle formed by the three reactors. This point is located 2800 ft east of WNP-2 and has coordinates Long 119019'18"W, Lat 46028'19" N. This shift does not affect the.overall accuracy or applicability of the population distribution projections.

O 2.1-5 Amendment 5 July 1981

WNP-2 ER-0L Richland, Pasco and Kennewick, and the corm 1 unities lying along the Yakima River from Prosser to Wapato. It can be seen from Figure 2.1-7 that there are no towns located within 10 miles of the site, with the exception of a small part of Richland. There are no residents of incorporated Richland within the 10-mile radius.

5 The 1990 to 2030 forecasts presented here(2) are based on: a) 1979 population figures provided by the Washington State Office of Finan-cial Management; b) Benton and Franklin County Traffic Analysis Zone population distributions; c) computed annual average area growth rates from 1975 through 1979 which were utilized to obtain the total 1980 population estimated for each area, and by the Bonneville Power Administration.(j) hlgNg nty forecasts prepared 2.1.3.1 Population Within 10 Miles The 10-mile radius around the site is shown in Figu e 2.1-7. In 1980, an estimated 1306 people were living within thi;, diJs. The nearest inhabitants occupy farms which are located east .olumbia River and are thinly spread over five compass sectors. There are no permanent inhabitants located within three miles of the site. Only about 80 persons reside between the 3-mile and the 5-mile radii and all are east of the Columbia River. Within a 5-mile radius of the site, there 5 are no proposed public facilities (schools, hospitals, etc.), business facilities, or primary transportation routes for use by large numbers of people.

In 1980, an estimated 1,306 persons, 65% of whom are in the NE to SE sectors in Franklin County east of the Columbia River, resided within a 10-mile radius of the site. This number represents only 0.5% of the total population within a 50-mile radius.

The population within the 10-mile radius is estimated at 2,676 in 1990, 3,614 in 2000, and 3,877 in 2010. By 2020, the population within the 10-mile radius is estimated at 4,073 which is a 212% in-crease over 1980.

No significant changes in land use within five miles are anticipated.

The Hanford Site is expected to remain dedicated primarily to indus-trial use without private residences. No change in the use of the land east of the Columbia River is expected since it currently is ir-rigated to about the maximum amount practicable.

The industrial areas in the northern part of Richland and the residen-tial area SSW of the Yakima River near the Horn Rapids Dam are within 5

the 10-mile radius. The residential area near the Horn Rapids Dam is unincorporated. The primary increase in population within the 10-mile radius is expected to be in this area (see Figure 2.1-7).

O

, 2.1-6 Amendment 5 July 1981 t

0 WNP-2 ER-OL O)

% - 2.1.3.2 Population Between 10 and 50 Miles As indicated in Table 2.1-1, about 251,684 people were estimated to be living within a 50-mile radius of the WNP-2 project in 1980. Begin-ning with the 10-mile radius, the population count increases rapidly because of the Tri-City region to the south and south-southeast.

Total population within the 20-mile radius was estimated to be 91,734 in 1980 or about 37% of the total within 50 miles. When the 30-mile radius is reached, another 52,000 persons can be added to the resident population, making the number of residents within the entire 30-mile 5 radius total 143,735. Most of this zone's population count stems from the contribution of compass sectors containing the Tri-Cities and the residents of the fringe areas. Based on 1980 census reports, the large population centers located Tri-Cities are30-mile in the 10 to the only significantly(33,578),

zone: Richland Kennewick (34,397), and Pasco(17,944). The next 10 miles (to the 40-mile range) adds another 41,135 persons for a total 40-mile radius count of 184,870 while the 50-mile range adds the final 66,814 persons for a total of 251,684 persons living within a 50-mile radius of the construction site in 1980.

The primary future increase in population is expected to be in the SE to SSW sectors which include the entire Tri-Cities and adjoining areas. Little increase is generated westward. The population in-m creases in the rural areas are based on the expected increase in irri-gated agriculture. The rest of the population is primarily in the Tri-City area as a result of increased activity on the Hanford Site and expansion of agricultural activities throughout the general region.

From the estimated 1980 population of 251,684, the population is pro-jected to be 301,943 in 1990, 336,115 in 2000 and 360,395 in 2010 5 within the 50-mile radius. By 2020, the population within the 50-mile radius is estimated at 379,930, and by 2030 at 383,828, which is a 53%

increase over 1980.

2.1.3.3 Transient Population The transient population consists of agricultural workers needed for harvesting crops produced in the region, industrial and construction workers both on and off the Supply System's WNP-1/4 project sites, and sportsmen engaged in hunting, fishing, and boating. Figure 2.1-9 shows the distribution of the transient population relative to the point cited on page 2.1-5. 5 Table 2.1-3 lists industrial employment within ten miles of the pro-ject site. The majority of these individuals are directly involved with research and operation of various programs and facilities for the Department of Energy and its contractors on the Hanford Site. Most of this workday population reside within 10 to 30 miles of the project (OJ 2.1-7 Amendment 5 July 1981

o WNP-2 ER-OL and are included in the totals discussed in Subsection 2.1.3.2. The workday population total of approximately 19,500 includes the WNP-2 construction work force which will be reduced to operating levels at the time of OL issuance.

Agricultural workers within the 50-mile radius during early spring and late fall months, consist mostly of permanent residents numbering be-tween 2000 and 3000 laborers.

In is vest, the agricultural labor force thean summer months34,000.

estimatesi during(D@ak har-b) With-in the 10-mile radius an estimated 1000 migrant workers are employed during the peak months of May and June. These workers are concen trated in the north to south-southeast sectors on the irrigat f rm 5 unitslocatedeastoftheColumbiaRiverinFranklinCounty.lp>>l1 Approximately 925 of these workers reside temporarily between the 5-10 mile radii; the remaining 75 are located within 5 miles of the site.

Hunting and fishing activities within the 10-mile radius are also centered in the north to south-southeast sectors along the Columbia River. The number of fisheden and hunters in this area varies with the season, the weather, the day of the week, and the time of day.

The main hunting season is from mid-October until the end of January, and the main fishing season is from June through November. The heav-iest use of the area for both sports is on weekends and holidays in the early morning hours. It is estimated that the peak numtygt 9f ers and/or fishermen present in the area would total 1,000.to),t8)nunt-It is estimated that, on the average, 10 hunters are present in the area on weekdays; the number increases to 50 on weekends and holi-days. The average number of fishermen present are 50 and 100 for weekdays, and weekends and holidays, respectively. Hunters and fish-ennen also have access to the Yakima River in the SW and SSW sectors where they may total 50.

2.1.4 Uses of Adjacent Lands and Waters Land use within a three (3) mile radius of the WPPSS Nuclear Projects includes the Fast Flux Test Facility (FFTF). Also included are the associated roadways and railroads, circulating water pumphouses on the 5 Columbia River, and the Supply System's Emergency Response / Plant Sup-port Facility. No other facilities are located in this area. Between the three (3) and five (5) mile radii, in the five eastern sectors, is an area devoted to agriculture.

Significant changes in land use outside five miles include urban resi-dential and irrigated agricultural development. Most major new irri-gation developments have occurred in the Hermiston-Boardman area in Oregon and in the Plymouth area in Washington. Other new developments are in the hills adjacent to the Snake River east of Pasco, along the Yakima River west and north of West Richland, and in the hills north-west of the Hanford Site. Significant new irrigation development is expected in the Horse Heaven Hills southwest of the Tri-Cities (about 300,000 acres) and in the Columbia Basin Project north and east of the Columbia River (now totaling 570,000 acres).

2.1-8 Amendment 5 July 1981

WNP-2 ER-OL v'

The principal sources of water for the irrigated areas south and west of the Tri-Cities are the Columbia, Snake, and Yakima Rivers. Ground-water is being pumped in the hills northwest of the Hanford Site and is expected to be used for new areas surrounding Pasco. New irriga-tion in the Columbia Basin Project will receive its water from Grand Coulee Dam on the Columbia River.

Scattered throughout the area within 50 miles of the project are a number of livestock and dairy operations. The number of individual livestock animals per location ranges from one to 250 and are utilized for both personal and comercial beef processing, as well as for breeding. There are eight beef processing plants located within 50 miles that provide beef to outlets outside the area, with the largest plant processing approximately 1000 head per day. The area within 50 miles is predominantly a feeder area during non-growing season, and causes the number of livestock to fluctuate on a seasonal basis.

There are three (3) dairy operations located within ten (10) miles of the site. An estimated 95 additional milk prodycers are located with-in the area between the 10 and 50 mile radii.(91 The milk produced from these dairies is collected and transported to processing plants 5 located as far away as Portland, Oregon and Spokane, Washington.

Table 2.1-2 provides distances to the nearest livestock, dairy (3 animals, and vegetable gardens.

s a Hunting and fishing is extensive within the fifty (50) mile radius.

Much of the farm land is open to hunters, with upland bird and water-fowl being the most popular. Fishing occurs on the Columbia, Snake, Yakima, and Walla Walla Rivers, as well as in isolated lakes and ponds. The Columbia River is the closest area in which hunting and fishing can occur. Fishing and hunting can occur on both banks of the river as far upriver as the Hanford Townsite. Within 10 miles of the site is an area designated as Controlled Hunting Area B. This area contains the Ringold Wildlife Refuge and the Wahluke Wildlife Refuge, consisting of approximately 4,000 acres of Department of Energy land managed by the Washington State Department of Game. Located adjacent to this area's southern boundary ar.d within five miles of the site is the Ringold Fish Hatchery. This facility encourages steelhead fishing within one mile of its location. These three (3) areas experienced a total of 291,000 period between 1978 user-days by(hunters and 1979. 10) and fishermen in a one (1) year O

V 2.1-9 Amendment 5

. July 1981

. - . . - - - . _ - . _ . - - . - . - - . - - - -. .~ . - - . -n-~ .. . - . . . ~ . - . - - _ . _ . - _ . . ~ - . - - .~_. .-u . . _ .

I TABLE 2.1 1 - '

(SHEET 1 OF 2)

POPULATION DISTRIBUTION SY COMPASS SECTOR AND j DISTANCE FROM THE SITE 1980 19 % 2000 2010 2020 2010 Directtori Distance (Eouipass Cumulative (umulative Cumulative Cumulat6ve hies) Sequen t) Number Total Number Total Number Total Number Total huseer Cumulatioe Total tumulat6ve Nun.tyr _ lot 4J_

0-3 All 0 0 0 0 0 0 0 0 0 0 0 0 (

3-5 N-NNE O O O O O O r O O O O b o NE 10 10 35 35 48 48 52 52 55 ENE 22 32 55 h6 86 I 43 78 56 104 60 E 22 54 43 121 112 63 IIS 64 150 L 56 160 60 172 63 181 ESE 22 76 43 64 - 214 164 56 216 60 232 63 244 i SE 4 80 6 64 278 170 9 225 243 SSE-NNW 0 80 Il 11 255 12 290 0 170 0 225 0 243 0 255 0 290 5-10 N 26 106 58 228 17 302 83 326 81 342 88 373 NNE 83 189 126 354 152 454 162

( NE 488 170 512 172 550 155 344 198 552 224 678 240 INE 728 252 164 254 804 114 458 157 709 177 855 190 918

,j 135 200 964 202 1006 E 593 200 909 257 1812 216 1894 ESE 168 290 1254 293 1299 761 276 II85 34 1 1453 366 1560 385 1639 389 SE 190 951 436 168e I 1591 536 1989 575 2135 604 2243 55E 45 996 253 1844 610 2293 308 2297 330 2465 34 7 2590 4

5 SG 1046 272 350 2648 2116 483 2780 $18 2983 544 3134 l 55W 235 1281 535 550 3198 2651 809 3589 867 3350 911 4045 i SW 25 1306 25 920 4118 2676 25 3614 27 3871 28 I WSW-NNW 0 4073 29 4147 1306 0 2676 0 3614 0 38.17 0 4073 0 4147 f 10-20 N 332 1638 371 3047 398 4012 427 4304 449 4522 454

! NNE 328 1%6 371 3418 4601 391 4409 426 4730 447 4969 i

NE 399 2365 562 452 5053  !

3980 588 4997 630 5360 662 ENE 792 3157 5631 669 5722 835 4815 855 5852 917 6277 %4

!- E 461 3618 479 5294 544 63 %

6595 974 66 %

1 E5E 583 6860 613 7208 619 7385 192 3810 430 5724 576 6972 618 l SE 7478 650 1858 657 7972 4155 7965 5221 10945 582I 42193 6242 13720 6561 14419 6627 14599 SSE 49178 57143 63483 14428 83710 j 5 28943 86086 70917 16043 - 89763 19932 94 3'.I 80734 95333 37672 112100 45434 129144 48787 138480 51208 t 55W 1592 145553 51722 I47055

' 87678 1772 183872 1922 131006 2061 5W 3106 140541 2166 147125 2188 149243 90184 3597  !!?469 394 134960 4175 144716

! c% W5W 950 4389 152114 4433 153676 91734 1048 118517 136068  !!88 C I3 W 0 91734 0 118511 1108 0 136068 145904 1243 153362 1260 154936 I 0 0 i

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($ct WNW NW 0

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0 118517 118517 0

0 136068 0 145904 145904 0 153 % 2 153362 0

0 154936 154936 136068 0 145904 0 i g NNW 0 91734 0 118517 0 136068 0 145904 0 153362 153362 0

0 1549 %

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t TABLE 2.1-1 ,

(SHEET 2 OF 2) 1980 1990 2000 2010 2020 2030 Direction 01stanc e (Compass Cumulat6ve Curaula tive Cumulative Cumulattve Cum lative Cum lative (idlesL y ent)

S Number Total Number Total Number Total humter Total Number Stal Nun.ber Total 20-30 N 1501 93235 1837 120354 2055 138123 2203 148107 2316 155678 2339 157215 NNE 5759 98994 6487 126841 7123 145246 7638 155745 8029 163707 8110 165385 NE 2015 101009 2174 129015 2274 147520 2438 158183 2563 166270 2589 167974 ENE 1717 102726 1760 130775 1786 149306 1915 160098 2013 168283 2033 170007 5 151 102877 194 130969 220 149526 236 160334 248 168531 250 170257 ISE 153 103030 240 131209 305 149831 327 160661 344 168675 I48 170605 SE 6138 109168 6512 137721 6738 156569 1225 167886 7594 176469 7670 178275 55E 24116 133284 32559 170280 36360 192929 sa987 206873 42032 218501 42454 220729 5 187 133471 67a 170958 975 193904 1045 207918 1098 219599 1109 221838 55W 875 134346 1218 172176 1426 195330 1529 209447 1607 221206 1623 223461 SW 6165 140511 7147 179323 7737 203 % 7 8296 217743 8720 229926 8808 232269 W5W 1626 142137 1799 181122 1908 204975 2046 219789 2151 232077 2173 234442 W 1191 143328 1325 IJ2447 1429 206404 1532 221321 1610 233687 1626 236068 WNW 185 143513 280 182727 ?97 206701 318 221639 334 234021 338 236406 MW 40 143553 44 182771 48 206749 51 221690 54 234075 55 236461 NNW 182 143735 200 182971 218 206 % 7 234 221924 246 234321 249 236710 30-40 N 980 144715 1096 184065  !!27 .08094 1208 223132 1270 235591 1283 237993 NhE 3198 147913 3663 187728 3983 212077 4271 227403 4490 240081 4536 24?529 hE 650 148563 800 188528 745 212822 199 228202 846 240927 850 243379 f hf 421 148984 447 188975 475 213297 509 535 228711 241462 540 243919 E 128 149112 136 189Ill 141 213438 152 228863 160 241622 162 244081 ESE 167 149279 176 189287 182 213620 193 229058 205 241827 208 244289 SE 464 149743 484 189771 497 214117 533 229591 560 242387 566 244855 SSE 592 150335 844 190615 955 215072 1023 230614 1076 243463 1087 245942 5 4680 155015 5653 196268 6368 221440 6828 237442 1172 250635 7250 253192 55W 256 155211 424 196692 529 221 % 9 567 238009 596 251231 602 253794 SW 473 155744 661 197353 786 222755 842 238851 885 252116 894 254688 WSW 21871 177615 24729 222082 26890 249645 28833 267t84 30362 282478 30665 285353 W 3578 181193 3349 226031 4273 253918 4582 212266 4816 287294 4864 290217 WNW 1399 182592 1459 227490 1579 255497 1693 213959 1780 289074 1798 292015 NW 703 183295 170 228260 836 256333 8% 214855 942 290016 952 292 % 7 NNW 1575 184870 1738 229998 1899 258232 2036 276891 2140 292156 2161 295128 40-50 N 17872 202742 19730 249728 21572 279804 23130 300021 24312 3164A8 24556 31 % 84 NNE 893 203635 1019 250747 1121 280925 1202 301223 1263 317731 1275 320959 NL 926 204561 1139 251886 1275 282200 1367 302590 1437 319168 1451 322410 ENE 213 204774 243 252129 375 282575 402 302992 423 3I9591 427 322837 E 241 205015 258 252387 268 282843 287 J03;19 302 319893 305 323142 ESE 864 205879 925 253312 %I 283804 1030 304309 1083 320976 1095 324237 SE 2084 207963 2245 255557 2349 286153 2518 306827 2646 323622 2673 326910 SSE 1740 20970) 1920 257477 2072 288225 2222 309049 2336 325958 2359 329269 5 16540 226243 16406 273883 17708 305933 18987 328036 19958 345916 C-. > 20158 349427 55W 2610 228853 ?895 276778 2972 308905 3186 331222 3349 349265 3428 CM SW 421 229274 443 217221 476 309381 509 535 352855 331731 349d00

(@n. W5W W

809 18515 230083 248598 892 20481 278113 298594 22179 310346 332525 1035 332766 1088 350888 541 1099 3533 %

354495 2378'O 356546 24996 375884 25247 379142 E3 WNW 1742 250340 1903 300497 2043 334568 2191 358137 2303 378187 2326 382068 g@ nW 812 251152 859 301356 905 335473 970 359707 1020 379207 1030 383098 to g NNW 532 251684 587 301943 642 336115 688 360395 723 379930 C3 730 383828 H U1 9 9 9

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i TABLE 2.1-2 1

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! DISTANCES FROM WNP-2 TO VARIOUS ACTIVITIES l  :

I

. Radius (miles) N NNE NE ENE E ESE SE SSE S SSW SW WSW W- WNW NW NNW ,

t l Site Boundary 0.3 0.3 0.4 1.1 1.5 1.2 0.8 0.7 0.7 0.7 0.6 0.5 0.2 0.2 0.3 0.3

! Milk Animal 5 - - - - - - - - - - - - - - - -

4 i

Nearest Residence 5 - - -

3.9 4.3 4.3 4.9 - - - - - - - - -

g5

! 67 rm i

Nearest Vegetable 5 - - -

3.9 4.3 4.3 4.9 - - - - - - - - _

Garden  ;

i j Nearest Dairy 10 - - - - -

7.5 6.5 - - - - - - - - -

1 ..

l Nearest Livestock 10 f - -

6.0 3.9 4.3 - -

7.5 9.5 9 - - - - - -

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WNP-2 ER-OL TABLE 2.1-3 INDUSTP.Y WITHIN A 10 MILE RADIUS OF SITE NO. OF EMPLOYER EMPLOYEES Department of Energy 400 Area (HEDL-FFTF) 1,187 300 Area (HEDL' 2,918 3000 Area (P!iLI 2,016 1100 Area (Rockwell) 440 600 Area (Rockwell) 220 Pacific Northwest Laboratory (non-D0E) 380 Exxon - Horn Rapids Road facility 750 George Washington Way Facility 90 UNC Commercial 80 tiortec 80 U. S. Testing 55 Sigma 30 Olympic Associates 18 Western Sintering 14 Futronix, Inc. 12 Quadrex 9 Miscellaneous 60 Washingto.1 Public Power Supply System Headquarters Ccmplex 1,021 WNP-2 Site (Construction Fcrce) 3,000 WNP-1/4 Site (Constru: tion Force) 7,000 WNP-2 Site (Projected Operations Personnel 295 WNP-1/4 Site (Projected Operations Personnel) 588 Note: 00E employment outside the 10-Mile radius includes:

200 Area (Rockwell, E-1779, W-1361) 3,140 100 Area (UNC) 993 700 Area (DOE) .,800 Employment totals are as of January 1981.

O Amendment 5 July 1981

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6 WNP-2 ER-OL C

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2.2 ECOLOGY 2.2.1 Terrestrial Ecoloqy The sagebrush-bitterbrush vegetation type surrounds and occupies about 100 square miles on the Department of Energy Hanford Site (Figure 2.2-1). The WNP-2 and WNP-1/4 exclusion zone and corridor to the Columbia River occupy about 8 square miles of the same vegetation. Although sagebrush, Artemisia tridentata, and bitterbrush, Purshia tridentata, are the conspicuous plants in stands without a fire history, much of the land in the vicinity of WNP-2 and WNP-1/4 is devoid of shrubs because of gn extensive wildfire (17,000 acres) which occurred in the summer of 1970.(3) The conspicuous vegetation on the burned acreage consists of about 30 herbaceous species, especially cheatgrass, Bromus tectorum. Other important herbs are bursage, Ambrosia acanthicarpa, Russian tnistle, Salsola kali, and Sandberg bluegrass, Poa sandberoii.

Even without the stresses imposed by wildfire, the vegetation is not repre-sentative of pristine conditions. The widespread occurrence of cheatgrass, an introduced alien weed, suggests that overgrazing by sheep and cattle in past years (pre-1943) has been instrumental in the spread of cheatgrass. There are no plans to reintroduce livestock grazing to the site area nor is there any evidence to expect that cheatgrass will be replaced by native plant species over a 30 to 40 year time span. Cheatgrass does play an important role in comunity function by retarding wind erosion, providing seed for birds and

'v pocket mice, and herbage for insects. 4 Past experience and field observations indicate that the soil is very sandy and susceptible to wind erosion, especially following events that destroy the sparse vegetation cover. Vegetation distrubances must therefore be kept minimal acreage. Reseeding of distrubed soil requires special attention the selection of plant species and planting season to successfully reestat.ish a suitable vegetative cover in a reasonable time period. Table 2.2-la pre-sents a list of terrestrial organisms identified near the project site.

Five vegetation ject site stpdy) in 1974.t29 locations Most of the were establishedaround land imediately in the vicinity of the pro-the construction zones had been burned in the 1970 fire, leaving only small unburned patches of shrubs. Three stands were selected as " unburned" study locations. The other two sites were selected as representative of " burned" vegetation. Plots were 4

read in April or early May at what was judged to be the peak of vegetation development. Five plots, each 0.1 m2, were harvested to cbtain an estimate of peak live above-ground herbaceous phytomass during the years 1975, 1976, 1977 and 1978.

Four species of shrubs were encountered in 1978 on the study plots.(29)

These were bitterbrush, P. tridentata; sagebrush, A. tridentata; and two species of rabbitbrush, Chrysothamnus nauseoseus and C. viscidiflorus. Snow 2.2-1 Amendment 4 October 1980

WNP-2 ER-OL buckwheat, Eriooonum niveum Dougl., a sub-shrub, was abundant in only one plot. One plot was dominated by sagebrush with a sparse representation of rabbitbrush; a second plot was dominated by bitterbrush; and a third consisted of bitterbrush and sagebrush (mixed) in approximately equal proportions.

Total shrub canopy-cover ranged between 14 and 37 percent. The sagebrush plot had the lowest density, 85 shrubs per 1000 m2; the bitterbrush plot had 95 and the mixed plot 114.

In 197S twenty-nine species of herbaceous plants were observed on the study plots.d91 These were grouped into four categories: (1) annual grasses, (2) annual f orbs, (3) perennial grasses and (4) perennial forbs. Cheatgrass, Bromus tectorum, clearly dominated the canopy cover. Nonburned and burned plots were similar as f ar as canopy cover was concerned. Sixteen species of annual forbs were counted on the study plot. Tansy mustard, Descurainia pinnata; tumble mustard, Sisymbrium altissimum; jagged chickweed, Holosteum umbellatum and Russian thistle, Salsola kali, were the most important con-tributors to canopy cover. Annual f orbs contributed about 25 percent to canopy cover and nonburned and burned plots had about the same amount of forb canopy cover. Only two species of perennial grasses were observed on the study plots. Sandberg bluegrass, Poa sandbergii Vasey, contributed 9 percent to canopy cover. Needle and thread, Stipa comata, was present but in small amounts. Nine species of perennial forbs were encountered on the study plots but they contributed only three percent to canopy cover.

4 shows that the A summary smallest of four amount of years canopyof cover field nbservations was produced(1975 -(1978) in 1977. 29) It was also by f ar the driest of the four years with only 1.21 inches of rain between October 1976 and April 1977. This was the only year in which cheatgrass f ailed to

. dominate canopy cover. The 1978 growing season was wetter than usual and .

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cheatgrass promptly regained vegetative dominance. Annual forbs also con-tributed more canopy cover in 1978 than in previous years. Canopy cover was not greatly different between nonburned and burned plots except in 1976 when l

annual grasses contributed 61 percent of the canopy cover in the burned plots compared to only 42 percent in the unburned plots. The production of herb-l aceous phytomass is e pressed as g/m2/yr. The year of lowest production was 1977 when only 10 g/m of dry phytomass was produced. Mean annual lues l ranged between 10 and 195 g/m2 while the 4-year average was 126 g/m and characteristic of the shrub-steppe The animal populations ecosystems are Site.(

of the Hanford sparp{.2/ The only big game mammal is the mule deer, Odocoileus hemionus. With the sparse cover around WNP-2 and WNP-1/4, deer use the area as a f oraging zone, retiring to the sand dune area a mile or so north where they are infrequently disturbed by human trespass. The nearest surf ace water available to deer is the Columbia River. The sparse riparian shrub-willow comunity also provides deer forage but little cover. The bulk of the Hanford Site mule deer herd subsists in the sand dunes area near the abandoned village of Hanf ord, about 7 miles north of WNP-2 and WNP-1/4.

%endment 4 O

2.2-2 October 1980

WNP-2 ER-OL (3

V The important fur-bearing animals are the coyote (Canis latrans) and the badger (Taxidea taxus). These animals are wanderers and use the area as a foraging ground. They are not numerous and accurate estimates of population density and daily movement patterns are the objective of specialized research studies. There is no inf ormation on harvests for pelts because the Hanford Site area is not open for trapping of animals.

The most important medium-sized mamal is the black-tailed jackrabbit (Lepus californicus). Populations of jackrabbits in steppe regions fluctuate widely f rom year to year depending upon a number of environmental variables including weather, predation, and disease.

Small mamal populations were investigated in burned and unburned portions of the(bitterbrush-cheatgrass traps. 29) Five hundred and ecosystem from six individual 1974 torepresenting animals 1978 using live five species were trapped, marked and released over a total of 11,600 trap nights.

The great basin pocket mouse (Perognathus parvus) was the most abundant animal trapped with 418 individuals captured. Second was the deer mouse (Peromyscus maniculatus) with 65 individuals. The northern grasshopper mouse (Onychomys leucogaster) was represented by 15 individuals, the western harvest mouse (Reithrodontomys megalotis) by eight individuals, and the Townsend ground squirrel (Spermophilus townsendii) by one individual. There were more animals trapped in the unburned vegetation than on the grid with a recent fire history.

Clearly the most abundant small mammal in the bitterbrush cheatgrass ecosystem s in terms of population numbers and food chain dynamics is the pocket mouse.

The yearly cycle of activity for this species begins in March and April as the adults emerge from winter torpor to breed. A second peak is normally seen in late summer with the recruitment of young into the population.

4 Birds were cou te in a 20-acre study plot, established in 1976, located just west of WNP-2. 29 The study plot was surveyed on three consecutive mornings of observations during the spring breeding season of 1977 and 1978. The west-ern meadlowlark, horned lark, sage sparrow and white-crowned sparrows were observed most comonly; all other species were observed incidentally.

The habitat in the vicinity of the project site is not suitable for California quall or Chinese ring-necked pheasants, which are more abundant elsewhere or, the Hanford Site, especially riparian habitats along the Columbia River north of WNP-2 and WNP-1/4. Although chukar partridges normally live and reproduce in dry, shrub-steppe habitats, the project area is not suited for these birds. The birds are especially abundant in the Rattlesnake Hills ten miles west of the project site, where the topography is more broken, vegetation more grassy, and the soils stony.

The region is a hunting ground for birds of prey, with the Swainson's hawk prevalent in spring and sumer and the golden eagle in the winter season. The bald eagle has been observed on the Hanford Site at various times and is the only wildlife species observed to frequent the area that is on the list of O' 2.2-3 Amendment 4 October 1980

WNP-2 ER-OL threatened or endangered species. Habitat significant to the bald eagle will not be disturbed by the construction and operation of WNP-1/4 and WNP-2 project.

The islands in the immediate vicinity of the site and downstream have a mixed composition with a substrate of either sand and gravel or cobblestone and gravel. Sagebrush communities and willows are established on the dunes of the larger islands. Approximately 200 pairs of nesting geese produce 700 goslin annually and an estimated 100 pairs of ducks also nest on these islands ,

The Columbia River is a natural migration route for the Pacific Flyway waterfowl. Several million ducks and geese use the Columbia River Basin 4

during movement to and from the northern breeding grounds. The waterfowl common to the area are shown in Table 2.2-la. An aerial census was made in 1973 to estimate the number of ducks,(Capadian geese, Great blue heron, and eagles nesting on the Columbia River 31.1 In mid-November, more than 20,000 ducks and 1,200 geese were observed resting on the river. The majority of these birds were located upstream of the project site.

Two islands, one near Ringold (river mile 354) and another near Coyote Rapids (river mile 382), are used as rookeries by colonies of California and ring-billed gulls. Approximately 6000 nesting pairs produce 10,000 to 20,000 young annually.

2.2.1.1 Threatened and Endangered Species The plants and animals living in the area are widespread and common in steppe vegetation (rangeland) in the dry parts of Eastern Oregon and Eastern Washing-e ton. However, rangeland acreage diminishes each year primarily as a result of an expanding agricultural use of land through extension of irrigation sys-tems. As the land is converted from rangeland to irrigated cgriculture, native plant and animal populations diminish. One function of the 100 square mile area of Arid Lands Ecology (ALE) Reserve (Rattlesnake Hills Researen on the Hanford Site is to provide a refugium for native plants Natural Area)4) and animals.(

The Bald Eagle (Haliaetus leucocephalus) is the only threatened animal specie (Federal designation) to occur in the area of the WPPSS projects. The pop-ulation on the Hanford DOE Site has increased over the years from five (5) birds in the 1960's to over 15 birds in the late 1970's. Eagles generally arrive during mid-November, with a peak abundance occuring in late November They do not nest 4 through early February, and begin to depart in mid-February.

in the area. There are no other Federally designated threatened or endangered animals or plants living in the WNP-2 and WNP-1/4 site area. The American peregrine f alcon (Falcon peregrinus anatum) is an endangered specie (Federal designation) which may at times appear along the corridors although the exact ranges are not known.

The construction and operation of the nuclear f acilities is not expected to result in the damage or loss of any species presently regarded as endangered 2.2-4 Amendment 4 October 1980

NNP-2 ER-OL A

2.2.2 Aquatic Ecology The physical and chemical characteristics of the Columbia River in the y vicinity of WNP-1, 2 and 4 are presented in Section 2.4. Comprehensive evaluations of the ecological characteristics of the Columbia River are 4 presented in references 5, 6, 7,12, and 32.

Studies concerned with the various aquatic organisms in the Columbia River, relating mainly to influence of reactor operation, were conducted for over 30 year 1973d5-)a andbibliography with apstracts updated in 1979.,331 of these The following investigations paragraphs summarize was published the inl4 essential ecological characteristics of the major communities. Figure 2.2-2 is a simplified diagram of the food-web relationships in selected Columbia River biota and represents probable major energy pathways. The Columbia River '

presents a very complex ecosystem in terms of trophic relationships due to its size, the number of man-made alterations, the diversity of the biota, and the size and diversity of its drainage basin.

Streams in general, especially smaller ones, depend greatly upon allocthonous input of organic matter to drive the energetics of the system. Large rivers, particularly the Columbia because it is a series of lentic reservoirs, contain a significant population of autochthonous primary producers (phytoplankton and periphyton) which contribute the basic energy needs. The der.endence of the free-flowing Columbia River in the Hanford area upon an authochthonous food base is reflected by the f aunal constituents, particularly the herbivores in p) t the second trophic level. Filter-feeding insect larvae such as caddisfly 1arvae, and periphyton grazers such as limpets and some mayfly nymphs are typical forms present. Shredders and large detrital feeders (such as the large stonefly nymphs) which are typical of smaller streams are absent. The presence of large numbers of the herbivorous suckers also attests to the presence of a significant periphytic population. Carnivorous species are numerous, as would be expected in a system of this size. A list of aquatic organisms identified from the Columbia River is presented in Table 2.2-lb. 4 2.2.2.1 Phytopi ankton Diatoms are the dominant algae in the Columbia River, usually representing over 90% of the population. The main genera in the vicinity of WNP-2 and WNP-1/4 include Cyclotella, Asterionella, Melosira, and Synedra; lentic forms that originate in the impoundments behind the upstream dams are dominant in this section of the river. The phytoplankton also contain a number of species derived from the periphyton or sessile algae community. This is particularly true of the Columbia River in the vicinity of the project site because of the fluctuating water levels due to operation of Priest Rapids Dam imediately upstream from Hanford. Periphytic algae exposed to the air for part of the day may dry up and become detached and suspended in the water when the river level rises again. Peak biomass of net phytoplankton is about 2.0 g dry wt/m3 in May and winter values are less than 0.1 g dry wt/m3,(9) Figure 2.2-3 illustrates the seasonal fluctuations in plankton biomass. A spring increase with a second pulse in late summer and autumn wat observed in the

> O V

Amendment 4 2.2-5 October 1980

WNP-2 ER-OL Hanford section of the Columbia River in previous studies.(10,11) The spring pulse is probably related to increasing light and warming of the water rather than to availability of nutrients. The coincident decrease of P04 and NO 3 , essential nutrients for algae growth, may be partially related to uptake by the increasing phytoplankton populations but is also highly influ-enced by the dilution of these nutrients by the increased flows due to high runoff at this time. The extent of dilution depends upon the concentration of these nutrients in the runoff waters. However, these nutrients do not de-crease to concentrations limiting to algae growth at any time of the year.

Green and blue-green algae accur mainly in the warmer months but in sub-stantially fewer numbers than the diatoms.

Aquatic studies were performed in the vicinity of WNP-2 and WNP-1/4, September 1974 through March 1980.(34-39) The Columbia River phytoplankton comunity passing WNP-1/4 and WNP-2 have been examined to determine species composition, relative abundance and pigment concentration. Community comp-4 osition was similar 1975 through 1979. Seasonal trends f or phytoplankton pigment concentrations and density (No/ml) were also similar. Micrograms of chlorophyll a per liter ranged from 1.3 to 20.2, while density values ranged f rom 119 in January to 2878 in May.(38) 2.2.2.2 Periphyton 4 l Dominant diatcm genera include Melosira and Gomphonema and in spring and sumer luxuriant growtM of the filamentous green algae Stigeoclonium and Ulothrix occur. Net Production Rate (NPR), as measured from 14-day colon-ization of artificial substrates, varied from 0.07 mg dry wt/cm2/da in August to less than 0.01 mg dry wt/cm2/ day in December and January.[13)

Figure 2.2-4 shows the seasonal pattern of NPR. This represents the 14-day growth on clean glass slides and not the increment on an established com-munity. NPR was highly correlated with solar energy and chlorophyll a con-centration on the slides during the 2-week exposure. The colonization con-ditions obtained in these studies began f rom a bare surf ace, and af ter 2 weeks the communities were probably still in the log-growth phase. Correlations among biomass measurements were highest between dry weight and ash weight, due mainly to the high population of diatoms with silica frustules.

2.2.2.3 Macrophytes 4 l Macrophytic substrates along the river bed and shoreline in the vicinity of the project site consists mainly of Ringloid formation with sand, gravel, and larger boulders on the surf ace. The widely varying diurnal flows cause large areas along the river shoreline to be alternately flooded and dry during each day. These characteristics have precluded the development of a rooted macro-phyte community such as is cormionly found in sloughs and backwaters.

2.2-6 Amendment 4 October 1980

WNP-2 ER-OL d 2.2.2.4 Zoool ankton The zooplankton population in the Columbia River at WNP-1/4 and WNP-2 is low in number and varies seasonall Seasonal trends for microcrustacea are similar 1974 through 1980. ( 39)y. Copepods dominate in the late f all, winter 4 and spring. Cladocerans dominate in the sumer and early f all. Bosmina sp.

is the dominant cladoceran observed at WNP-1/4 and WNP-2. The density (number /m3) of zooplankters was similar 1974 through 1980. The density ranged from 22 in November to 776 in August.(39) Zooplankton form only a minor portiondietary of theitem (0({%)of river. 6 the total diet) for young salmon in the Hanford 2.2.2.5 Benthos Dominant organisms presently found in the vicinity of WNP-1/4 and WNP-2 site include insect larvae, sponges, molluscs, flatworms, leeches, crayfish, and oligochaetes. The daily fluctuating water levels, due to the manipulation of flow by an upstream hydroelectric dam, have destroyed a part of this f auna in the littoral zone. Near the old Hanford townsite, ten miles upstream, midge larvae (Chironomidae) and caddisfly larvae (Trichoptera) are the most benthic organisms, averaging 121 and 208 organisms 2 /ft , respectively.(numerous 5)

Caddisfly larvae and molluscs (Mollusca) are predominant in terms of biomass, 2

averaging 2.24 and 1.23 g wet wt/ft ,2respectively. Tctal benthic organisms averaged 375/ft2 and 3.59 g wet wt/f t during 1951-52. These figures are approximations of these populations due to the difficulty in sampling all of (q

the bottom in a large river such as the Columbia. Sampling was restricted to the shallow shoreline, and even there variations between replicate samples were sometimes greater than seasonal variations.

Since September 1974 benthic macrof auna and microflora samples have been collected in the vicinity of WNP-1/4 and WNP-2.(34-39) Benthic microflora are dominated by diatoms and the most comon genera are Navicula, Nitzschia and Synedra. The highest density (number /m2) was observed in Mar December when small pennate diatoms dominated the benthic 39 flora.(ch)and 4

Benthic macrof auna populations near WNP-1/4 and WNP-2 are dominated by midge fly (Chironomidae) and caddisfly (Trichoptera) larvae. These two taxa comprise 90% of the benthic macrof auna with other taxa never accounting for more than a few percent of the total comunity. The highest densities have been observed in September. The seasonal trend is for densities to increase between June and September and decrease between September and December.

2.2.2.6 Fish 4

Forty-four specjes Columbia River,(40)of fish have been identified in the Hanford area of thenon or endangered. Table 2.2-1b lists the species present and although most are resident, the anadromous salmon and steelhead trout represent the species of greatest commercial and recreational importance; hence, most fisheries research has been concerned with the salmonids.

O

() Amendment 4 2.2-7 October 1980

1 1

WNP-2 ER-OL Salmon spawn in the f all, leaving eggs to incubate in the redds from late f all to mid-winter. From mid to late winter the eggs hatch into fry which emerge f rom the gravel from February through April . Following emergence, the juveniles begin their migration to the Pacific Ocean. The peak seaward migration of all juvenile salmonids in the lower Columbia River, including those produced in the Hanford reach, occurs in mid-April to mid-June.

However, the out-migration of salmonids produced in areas upstream of Priest Rapids Dam is now later than in the pa apparently because of delays in 4 l passage through the reservoir complex.

The salmonids all have a similar life cycle but each species and race matures at a different rate. This results in differences in timing and duration of life stages and activities. Timing and numbers of upstream migrants are shown in Figure 2.2-5. These data were obtained at, and in the vicinity of, Bonneville Dam. Corps of Engineers fish counts at other d ms)on the Columbia River and major tributaries also show timing of migration. 4 Only slight variations will be noted in timing of migration pulses depending on river miles traveled and migratory pathway, i.e., main channel migrants or tributary migrants. Adult salmonids move through the Hanford portion of the river during all months of the year, but the greatest numbers pass through during the spring to early f all. Peak adult migration periods are generally as 4 l follows:

Sockeye - July-August Chinook - April-May, July-September Coho - September-October Steelhead - August-October Studies on the routes of migration through the Hanford stretch of the river E indicate the preference for the east-northeast bank (across the river from the E intakes for the plants) a 4 l downstream to Richland.(22) pattern which persists from Priest Rapids Dam The Hanford reach of the Columbia River serves as a migration route to and f rom upstream spawning grounds; f all chinook salmon and steelhead trout also spawn in the Hanford section of the river. Population estimates were made of the locally spawning chinook salmon redds in the section of river from Richland to Priest Rapids Dam (Table 2.2-3). For the period 1947 to 1972 the of450to31,600.(26{/ average number Since 1962, of ch the local fallnook salmon chinook spawners salmon spawningwas almost 9500 popula iog represents 15 to 20% of the total f all chinook escapement to the river. 27 1 This recent increase in relative importance of the Hanford section for chinook spawning may result from the destruction of other mainstem spawning grounds by river impoundments.

The chinook juveniles move through the Hanford section of the Columbia in two age classes: young-of-the-year and yearlings. The young-of-the-year in i particular inhabit the areas near shore where they feed as they move downstream. They are present from late winter through midsumer, with greatest numbers in April, May, and June.

2.2-8 Amendment 4 October 1980

4 WNP-2 ER-OL I

, Average annual steelhe9d spawning population estimates for the years 1962-1971 are about 10,000 fish.(28J Counts in 1976 and 1977 were about 9800 and 9200 4 fish, respectively. The annual estimated 1963-1968 sport catch in the section of river from Ringold, just downstream from the Hanford Site boundary, to the mouth of the Snake River (a distance of about 30 miles) was approximately 2700 fish.

The shad, another anadromous species, may also spawn in the Hanford section of the river. Young-of-the-year of this fish are collected during the sumer.

The upstream range of the shad has increased since the mid 1950s, pessibly as the result of increased impoundnent of water in the lower and middle river.

In 1956 fewer than 10 adult shad ascended McNary Dam; in 1%6 about 10,000 passed upstream. The whitefish are resident in the Hanford section of the river and support a winter sport fishery. During the period of maximum plutonium production reactor operation, upstream movement of whitefish and other resident species was demonstrated by the capture of fish containing greater than background levels of radionuclides at Priest Rapids Dam, upstream of the Hanford Reservation.

Other game species such as sturgeon, smallmouth bass, crappie, and sunfish are also f airly abundant in the Hanf ord section of the Columbia, and are important game species.

A total of 37 species representing 12 f amilies of fish have been collected from September 1974 through March 1980 in the vicinity of WNP-1/4 and WNP-2.

I .O i

Greatest catches and, hence, assumed abundance of most fish species near occur in spring and sumer and coincide with spawning, fry emergence and increased movement due to warmer water temperatures. Chinook salmon (Oncorhynchus tshawytscha), Northern squawfish (Ptychocheilus oregonensis), redside shiner 4 (Richardsonius balteatus), sculpins (Cottus spp.), suckers (Catostomus spp.),

and chiselmouth (Acrocheilus aiutaceus) generally comprised over 90% of the annual total catch. Most Hanford fishes are opportunistic and utilize juvenile and adult aquatic insects, mainly caddisflies and midge flies, smaller fish and occasionally zooplankton for food. Bottom feeders ingest periphyton.  !

4 1

i e

O 2.2-9 Amendment 4 October 1980 V

l

WNP-2 ER-0L

{s

-N- TABLE 2.2-la TERRESTRIAL FLORA AND FAUNA NEAR WNP-1/4 and WNP2 Plants Shrubs Big Sagebrush Artemesia tridentata Bitterbrush Purshia tridentata Green rabbitbrush Chrysothamnus viscidiflorus Gray rabbitbrush C. nauseosus Spiny hopsage Grayia spinosa Snow Eriogonum Eriogonum niveum Forbs Longleaf phlox Phlox longifolia Balsamroot Balsamorhiza careyana Sand dock Rumex venosus Scurt pea Psoralea lanceolata Lupine Lupinus laxiflorus Pale evening primrose Genothera pullida Desert mallow Sphaeralcea munroana Cluster lily Brodiaea douglasii Sego lily Calochortus macrocarpus (IT

'~- Tansy mustard Descurainea pinnata Tumble mus .ard Sisymbrium altissimum Cryptantha Cryptantha circumscissa Russian thistle Salsola kali Fleabane Erigeron TTTifolius Grasses Sandberg bluegrass Poa sandbergii Cheatgrass Bromus tectorum Indian ricegrass Oryzopsis hynenoides Squirrel tail Sitanion hystrix Six weeks fescue Festuca octoflora Thickspike wheatgrass Agrophyron dasystachum Riprarian Vegetation Will ow Salix exigua and others Cottonwood Populus trichocarpa Sedges Carex spp.

Rushes Juncus sp.

Horsetail Equisetum sp.

Cocklebur Xanthium sp.

l Allium sp.

Wild onion 7-~ -

(,,/

Amendment 4 October 1980

WNP-2 ER-OL O

TABLE 2.2-la(Cont'dl Birds Mall ard Anas platyrhyn~chos Green-winged teal Nettion carolinense Blue-winged teal Querguedula discors Cinnamon teal Q. cyanoptera Gadwall Chaulelasmus streperus

~

Baldpate Mareca americana Pintail Dafila aruta tzitzihoa Shoveller Spatula clypeata Canvas-back Nyroca valisineria Scaup N. affinis American goldeneye Elaucionetta c1angula americana Buffle-head Charitonetta albeola Ruddy duck Erismatura jamaicensis rubida American merganser Mergus merganser americanus Coot Fulica americana Horned grebe Colymbus auritus Western grebe Aechmophorus occidentalis Pied-billed grebe Podilymbus podiceps Canada goose Branta canadensis Snow goose Chen hyperborea White-fronted goose Anser albif rons Whistling swan Cygnus columbianus Great blue heron Ardea herodius

White pelican Pelicanus erythrorhynchos 1 Cormorant Phalacrocorax auritus

'~

California gull Larus calif ornicus Ring-billed gull L. delewarensis Comon tern Yterna hirundo Foster's tern S. f orster Killdeer UxyeenusTociferus Long-billed curlew Numenius americanus Chukar partridge Alectoris graeca California quail Lophortyx califorica Ring-necked pheasant phasianus colchicus torguatus Sage hen Centrocercus urophasianus Mourning dove Zenzidura macroura Red-tailed hawk Buteo borealis Swainson's hawk B. swainsoni Sparrow hawk Falco sparverius Golden eagle Aquila chrysaetos canadensis Bald eagle Haliaetus leucocephalus Osprey Pandion haliaetus carolinensis Burrowing owl Speotyto cunicularla Horned owl Bubo virginianus Raven Corvus corax American magpie Pica pica hudsonia Amendment 4 October 1980

WNP-2 ER-OL TABLE 2.2-la (Cont'd)

Red-shaf ted flicker Colaptes cafer Horned lark Octocaris alpestris Western meadowlark Sturnella neglecta Loggerhead shrike Lanius ludovicianus Western kingbird Tyrannus verticalis Eastern kingbird Tyranus verticalis Knite-crowned sparrow Zonotrichia leucophrys Sage sparrow Melospiza melodia Say's phoebe Sayornis saya saya Mammals Mule deer Odocoileus hemionus Coyote Canis latrans Bobcat L nx rufus Badger axidea taxus Skunk Mephitis mephitis Weasel Mustela f renata Raccoon Procyon lotor Beaver Castor canadensis Muskrat Cndatra zibethica Porcupine Erethizon dorsa Blacktail jackrabbit Lepus californicus

(-^)g g_, Cottontail rabbit Sylvilagus floridanus Ground squirrel Citellus townsendi Pocket mouse Peranyscus parvus Deer mouse P. maniculatus .

Harvest mouse feithrodontomys megalotis Grasshopper mouse Onchomys leucogaster Pocket gopher Thomomys sp.

Reptiles Northern Pacific Rattlesnake Crotalus viridus oreganus Great Basin gopher snake Pituophis melanoleucus (bull snake) deserticola Western yellow-bellied racer Coluber constrictor mormon Northern side-blotched lizard Uta stansburiana stansburiana Western fence lizard Sceloperus occidentalis Short-horned lizard Phrynosoma couglassi Great basin spadefoot toad Scapniopus intermontanus I

n, Amendment 4 October 1980

WNP-2 ER O

TABLE 2. 2-1 b COLUMBIA RIVER BIOTA (*

wa n , s- o m'n m,a, waa4 Pnyle Artnropoon (conto) Oroes weetatera phyle Acantnocepnals Paylum Arteropoca Orop Decapoos hocoaects so.

C1tss Arachnica teoeca+aceavarmus cut +11 pacif est+cus (1eatus- O'S 58'

3. ce* status ,,.3,,g,,,,,,,,

Q;gh t % "'00't M sp.

Pe*Daoe*v*caus pu1Docof f, g q Class Iplecta Order Co11ancola BulDooactait's sS* Class Crustacea Featly pypogastvetone Payim tryotoa Oroee Coleoctora Orser Anostraca mylw Ta@rson cf yg go, eLeggsp. $teStoceDMalus le,1],1 maecebiotus sp.

Pecttanteile so. rop prootna Phyle mollusca Parale;totaletic LeftW's M C

• cceau t4 Class Gastropose 04aemanetene eracayvv sag n is.

Staua'ct ie autta11*aae g re-teagvla DM pani auttel' + + A. m te e- eiis' v se a

+te Fle*ascola au ttalliaae A. cuseenesulaces sp.

• E.

hij autta1191 *A. C0stata hesagenia sa.

Staqattele eJii"l1 3roo*11 sgaaer*C.s steacapa sp.

81ey*9 31 seat %1sc+s g f atoaste Greer PI'CODt'e8 syceviis vec=$cu lee+1 h c*vstallias acevaerteryn para 11a paespwel v e* fuse g,s,t_a,t1 gryg Isma11stus hg reet este*s Pte eaarcys califocaica E 1 ***' to'8's Depaata 31,13g31 meacetae isogeaus so.

Limassa stagaal's

$cacheleeeec's 1211 Peetooes awetcana L emaet so.

81aaoer5 so. Ceciocsema_91 oviche114 Oroce TricMostera

' ' ' ' ' ' Glossosoma w1oas_

class Stvalvia g.'*I oac + ce s t 's y,eropsycae coceece11t anodeata nuttallicas g3 ge,yggy, nvocoesycae so.

Cere*cula 'lup*aec y g, ,

usecae*ti'ees maces ** tut ,,g,9 tact s 14tito** s f. caHfwaica Leotocella so.

l'1,1,Og colpoisava ,,,,,,,ig, Lmmoo*'lus sp.

saoooals comree;su" ovaceaacula**i i+vocoottia acoosa_

Aaadoats ca1 * *orairas +1 pieveesus tr'aoaellus ericaycenteus occteeataf f s Phylum Anaeltaa Ordee Calanoloa g- 9 ggy Class 011gocneeta Ca*twocarctui sp. - Psve*amyia_ flavida_

0%umteosyche eaomis steeaos* ton 9astantIts 1. stao*vi+aoices Triaa*ulata soetana E 't':l1].11 E. g

g. bisevsnisatui thomasi teucotricata pictices Chaetocastee so, Diaptomus sp. AetMetDsooes saaulicoe*'s Class Mirvoinee g. g mystactees alafimerista placeteelle sentiftes 3*yocentui tstaekkfi Leotoostama steooais 111+acecelh mooret Oroee Cyclopotea Oroer tentooptera

[cwedella punctata Argyractis_ aagulatalts Cr:1ers sp.

Taevyrca ry.og Ns:' cola so. Oroer anonipoca Oroer cistera me15 Doe 11e staCaelis Tipul t oat G ya sD.

Cnicoaom*aae

$tavitum vettatum

$4multue sp.

O

WMP-2 ER TABLE 2.2-lb (Cont'd) na., .

• ,, se e,an.

crea..

Phyte Cyanoonyta (conte) Peytus platynelmintnes Paylum Chiereonyta Payle Chrysoonyta (contd)

(.gggjgjggg Apeaaeaa esc 11 Tar'S* des g g Ulstmeta 23aeta n ,ameo.as ssia : ervie.,

st42 cions, ige,ef

1. elt'nsessor, hatili concesaele 01emonere rispett .[.xdjgtit

2. inneer.*cp class fremotona

1. stamersu 3egsg gtgag*,g annant?2menen HQ 14 Gay actiaccieidus s3.

rancniocetta saars+t*cs E!alagg:1 ellistica fe'=t*" luiact y,,e t ,,,,, s,.

Otra Elia!1 5en'11 3as!sdistiannt SdERlliE311ER$1 1M 3ectylearrus see.

E. 2184:!1 1. Agen!1 g,,,,,c e,,,, ,,,,

• et assses so. L. Ig31g 1 1.st3gggat 35.m aostacarw e*enoem so.

coepesets ss. wn'twr*a lac 1M2 w,w utments J.g!. gSE2 88 E. aavicuDre au Cal 3t*r*

• 2ar'etand g,g ge3 sg. g, g M *a*'"* c"' 8 *C** ** ' 8t' postposisiostano am teeinstra so. E. vertriocase g,,c ,,,,ii ,3,33.g3gg

g. ;g2gg 1 21&a.1 Staura17e so. audoviae.'s vio14Cea Coelastre so. *pononya marvui, pr.yta Pyrencenyta s11c:reente so.

Anetstroseanus ss. 5. M C"8' 88 3*8"18' "'I St ator'aa 50 Enttae*'s 14:32.11 Ce*et*um so.

' P*estdestaanse 30 Tceaceanpus so. a*gge:W# 1.201

'*F i

• Tracneconyta g, y, entracis*** i?.a.3422. wit:sc*+a 44msata c Fantly majasacm cest.nesistes ,,42 g13,,u,1 Payle Chrysoonyta 2 211.21 pleavenorus see Ceettoaeis so. p '

O

" cmtsateura ga!,gg ra.ity w recocnarttacae C''C'"***

P13:211E "'**# .eu entica c.,,n on,,,,,,, ,,,,,, ,g, Idesi!1 sect 4sans , g,,,,, p.et c n v.s are.ne+,

'!n!st!:t 2:sen!An **sim cyaanoayta  !!2921 $8- ,,n,,,,,,

m. :gg an,g s su issi i :s!sa faily La'"aca' j. sain ieiceia galasal!A ansatirA **,neestar*= so.

1 2!.mits1L ose*narse+a testin a so. carvonavnaeus so.

1. mics*' des 1. ca.!zant ,,,,,g,,,,, k ay.!1 insentinens st *aaamiscus Autasi 2 1.!saa N *'"* "- ei n.non. tar,, so.

1 1. zit. *!sig 2 semse= reity centooaynac* act**+ocennatus is.

2. acssaa sen.stocemaius sopsi.s 1.a!asatsi c,,,,,,,,n,,,,,,,

• • uesatuta se.a.gnt:1 2. sannsida ,

g,,,ts,,, ui eunt 9aet.'ar*s 'eanstrata

2. tamts '8"'is C/8""'**

M, v1IL80E1 2 1. var. suci emylum Ascnoletatnes 8%Dr"'diuS But#9 ale Family Juncaceae r* Dei 1&r'8 c'=3tennests Class Aettfers 1 '. 1 ! S 11 8 g,,,,g, E. aer-'seaH P.aa'.1!i s8-

• . emsmens E Inunnasa

'*Y'*'"* ren4eutta so.

E, n:sassag 1 n!A'.1 ac antmocystis so. 5racasets so.

asteeionelle g e. g mgag e. ;,.g actaa . .neer's so. m u.

a. sn ctant, vo*~ ten e is. eirirtwe u.

1. g. st. gesa I,22,1*g.!!1 so. triemece ta so.

tr eors a

aeruetasocaecules.

1. iggt

,,yi, portvera .eeiteii so.

1 *.:s tel i. asts*f ~

1. vichelte L. a12t31' s

(. vt*t c?i foe 8*ancocmoat sp.

l. Jar 8stt'Ca Pmyta Coelentersta _

l I !v=.T1 7t3 *N1C3*# etescaec3 sp.

($$5223:1S aCantW a CPM 3e64custt ~soae*9 Paflocea4 catmoeav acht sult+ccacattus sp.

Met 3Dr**ent so.

Cvst*1tecla 50.

• mnaa a u.

e (a s Classificatica af ter - 7. f. Storee. A. L. 'Js199er, t. C. Steottas, J, d. sytetten. Geaerel !? ology, Fifth e61113n. tGrae. dill Sooa Ca. . Me. fort . 197Z .

8 WNP-2 ER-OL O

TABLE 2.2-Ib (Cont'd)

C canism Phylum Chordata Class Cyclest:mata ntosonenus tricentatus Pacific Lamprey uamaetra aveest River Lam; rey Class Osteientnyes Acioense- transmentanus White Sturgeen Onco-nvnenus tsnawvtsena Chincok Saimco

0. ne-<a Scckeye er Blueback Salmen

!. <>sut:9 Cono or Silver Salmon Talmo caircre-i Steelnead or Rair. cow Trout G arci Cutthroat Trout Ialvelinus malma Dolly Varden a-osocium wiliiamseni Mountain Wnite#ish A;cs a sasicissima American Shac

atast

mus piatv-vrenus Mountain Socker

.

oiumoianus Bricgelip Sucke-

?. macre:netEs Largescale Sucker

!ver'eus caroio Carp Tinca tinca Tench 41cnaresonius baltestus Recsice Shine-Pt eencenelius crecorensis Ncrthern Scuanfish acrocnetius aiutaceus Cniselmouth 99iocneilus caurinus Penmouth al i. cata a:tae Lengncse Cace

7. escuius Speckled Dace T. f ai:stus Leccard Dace Tctalurus aebulesus Srewn Sullhead

i. meias Black Sullhead

[ .

Yellow Sullhead I -l T. natalis I. eu :ctatus Chanrel Catfisn

( ,I

?aste-esteus acu'estus Threessne Stickleoacx

e-

a falves: ens Yellow Perch 5tizeste:icn vitreum Walleye Lecomis macrocnirus Bluegill-L. ciecesus Pumeninseed.

Tomoxis annul a-is White Cracote P. nioramaculatus Black Craccie Fic-octe us sa.moides largemouth Sass M. colceieut Sma11moutn Bass Eota icta Burbet l

cttus asee- Prickly Sculpin

.

eic n:ii Piute Sculpin

!. ee-ciexus Reticulate Sculoin al Tor-ent Sculmin

'  !. -netneus

. E. eairci Mottled Sculmin

• Sand Roller Te ::: sis t-sesmountana

c-econus ciucea'c-mi s Lake abitafish l

Amendment 4 October 1980 t

f L

WNP-2 ER TABLE 2.2-2 0 NUMBER OF SPAWNING FALL CHINOOK SALMON AT IIANFORD, 1947-1977 (population estimate based on 7 fish per redd)

Numb g of Population Year Redd Estimate 1947 240 1680 1948 785 5500 1949 330 2310 1950 316 2210 1951 314 2200 1952 539 -

3770 1953 149 1040 4 1954 157 1100 1935 64 490 1956 92 640 1957 872 6100 1958 1485 10400 1959 281 1970 C. 1960 295 2070 1961 939 6570 1962 1261 8830 f 1963 , 1303 9120 1964 1477 10300 196S 1789 12500 1966 3101 21700 1967 3267 22900 1968 3560 24900 1969 4508 31600 1970 3813 26700 1971 3600 25200 ,

1972 876 6130 ,

1973 2965 20800 j 1974 728 5100

! 1975 2683' 18800 1976 1951 13657 1977 3240 22680

~

(aj Redd counts obtained by aerial surveys. Amendment 2 4 October 1978

O b 94.ISAGEBRUSH/BLUEBUNCH WHEATGRASS FR SAGEBRUSH-BITTERBRUSH l'/////d SAGEBRUSH.

. 3' .

l .. -

~

, :. [-

l

't s O..

t

. , , 'i f l

/ , ',f; p

' . /,/ 9,'. i. ,f'),:., i

. , f.l ?0

, 'N m/'. E . s@,

nsW... ,;/,. ./ i';. ::. ,f mNp_3 H COLUMBIA W*@"9 - : ?c' VER

e. ; ; .._.

~

a \

%5l$$r , i,b j .y.

YAKIA% 1 l

( RIVER 7 [.

r 0_5 MILES DISTRIBUTION OF MAJOR PLAN

• ESE NGTON PU3LIC POWER SUPPLY SYSTEM OOMMUNITIES (VEGETATION TYPES) ~IE' WPPSS NUCLEAR PROJECT NO. 2 ERDA HANFORD RESERVATION, Envircr::::entJ.1 Reper; .BENTON COUNTY, WA

! FIG. 2.2-1 l

O -

h WATERF0WL SWALLOWS CARNIVOROUS FlSH

/

FORAGE FISH -

n ADULT INSECTS HERBlV0ROUS F ISH l CRAWISH q

f DEATH ANDFECES f (BACTERI AL BREAKDOWM MOLLUSCS ZOOPLANKTON INSECT LARVAE MACR 0PHYTES PHYTOPLANKTON WA ER BACTERIA SEDIMENTS (INORGANIC AND ORGANIC)

WASHINGTON PUBLIC POWER SUPPLY SYSTEM FOOD-WEB OF COLUMBIA RIVER WPPSS NUCLEAR PROJECT NO. 2 Environmental Report FIG. 2.2-2 f

O 2.0 1.8 -

1.6 -

E5 91.4 e

9 1.2 -

V 1.0 -

9

$ 0.8 -

> 0.6 -

o

• 0.4 - ,

0.2 -

A Onn _-__.a nn00 0 -

AI S I O I N IDI J I F I MlA I M I J I J I Al SI 1%3 1964 s

WASHINGTON PUBLIC POWER SUPPLY SYSTEM SEASONAL FLUCTUATION OF WPPSS NUCLEAR PROJECT NO. 2 PLANKTON BIOMASS Environmental Report FIG . 2. 2-3

1 1

0 0.08 DRY WEIGHT

_ _ - -- ASH-FREE DRY WEIGHT g 0.06 32 m

E o

1 I-

, ut -

4 a: 0.04 - -

z '

52 o

j n so -

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AUG DEC JAN MAY l 1%3 1964

)

WASHINGTON PUBLIC POWER SUPPLY SYSTEM SEASONAL FLUCTUATION OF NET WPPSS NUCLEAR PROJECT NO. 2 PRODUCTION RATE OF PERIPliYTON Environmental Report FIG. 2.2-4

O CHUM .___

e 8000 COHO W

Gi 4000 5,5 -

2a 0 pgtt 1%6 COMMERCI AL CHINOOK ...

FISHING SEASONS

OPEN SUMMER STEELHEAD i+ e III l SHAD M =

?

SOCKEYE .---- f. .' . ______

,.)dD,', _

80 SUMMER T' -

25 CHINOOK

, 70 - SPRING e#\ s -

20 CHINOOK y 60 -

15 g 50 - WATER TEMPERATURE. BONNEVILLE DAM -

10gE

& 1%5 3 E

-- 5=

40 qg# WINTER STEELHEAD

~' ' ' ' '

0 I I i l I O JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC i e Dotted - Bonneville Dam Fishway data 1966 e Slant - estimated based on gill netting in lower river e Crosshatch - estimated based on 17-yr average run size and timing of gill net catches e Vertical - Bonneville Dam data (minimum estimate, not quantitative)

TIMING OF UPSTREAM MIGRATIONS IN WASHINGTON PUBLIC POWER SUPPLY SYSTEM THE LOWER COLUMBIA RIVER WPPSS NUCLEAR PROJECT NO. 2 Environmental Report FIG. 2.2-5 1

WNP-2 ER 2.3 METEOROLOGY I_,\

~

The Hanford Reservation lies in the Lower Columbia Basin, lowest elevation of any part of Central Washington. The low elevation assists in creating a relatively mild continental steppe climate, subject to somewhat wide seasonal range in temperature. Annual precipitation of approximately 6.4 in.

falls mainly during the winter months. The average summer temperature is 73.7'F, while during the winter months the mean daily temperature is 32.4*F.

The primary source of meteorological data for WNP-2 is the 240-ft tower with a complete meteorological data system, which operated between March 1974 and June 1976. The system l1 will be reactivated upon plant fuel load. The Hanford Meteorology Station (HMS) and the 410-ft Hanford Meteorology Tower located about 14 miles northwest of the WNP-2 site provided the data for the construction permit Environmental Report. A 23-ft temporary meteorology tower was was operated for 2 years previous to the installation of the 240-ft tower for the purpose of evaluating cooling tower orientation.

The meteorological equipment located at these sites is discussed in Subsection 6.1.3. Table 2.3-1 presents the averages and extremes of various climatic elements at Hanford revised to include data up to and including 1975. More comprehensive climgyplogical summaries of Hanford data areThe based on observations up to 1970.

presented by Stone Cj s data for the following subsections are detailed in the tables and figures. While the tables and discussion of the onsite meteorological measurement program pertain specifically to the first year of data (April 1, 1974 - March 31, 1975), 1 the second annual cycle of data displayed the same general characteristics. The complete data set is presented and.

discussed in Section 2.3 of the WNP-2 Final Safety Analysis Report.

2.3.1 Stability, Wind Speed and Direction Annual average wind roses for the site are given in Figures 2.3-1 to -6. The wind rose in Figures 2.3-1, -2 and -3 are for onsite data for the three measurement heights (7, 33 and 245 ft). Figure 2.3-4 gives the onsite wind rose breakdown by four Hanford stability classes at the 33-ft level. HMS wind roses for the 200-ft level derived from 15 years of data (1955-1970) are given in Figure 2.3-5. Surface winds at various stations in the region are summarized as 8-point roses in Figure 2.3-6. The onsite joint frequency of wind speed, direction and stability data for winds at 33 ft are contained in Table 2.3-2 for five classes of Hanford stability criteria while Table 2.3-3 contains the annual summaries for O

2.3-1 Amendment 1 May 1978

WNP-2 ER 7, 33, and 245 ft for direction and speed. Tables 2.3-4 through -15 present joint distributions of wind speed and direction on a monthly basis (April 1974 through March 1975) for the onsite data.

Table 2.3-16 shows the joint distribution of stability, wind speed and direction derived from 15 years (1955-1970) of data taken at the HMS tower. These seasonal and annual tables are based on winds at 200 ft and stability defined by the temperature difference between the surface and 200 ft.

The climatological representativeness of the year of onsite data used in the diffusion computations is listed in Tables 2.3-17 and -18. Table 2.3-17 is a month by month comparison of climatic elements at HMS with longer term values. Average wind speed, insolation, precipitat::.on, and relative humidity were close to the long-term values.

Table 2.3-18 presents a summary comparison of diffusion elements computed from the 1 year of WNP-2 data with similar elements computed from 15 years HMS data. The difference in the number of recorded calms is primarily the result of the lower threshold of the onsite instruments, these differences may also be partly the result of topographic influences.

The wind direction frequencies cannot be expected to necessarily be comparable because of the separation between the stations. ggg Comparison of the HMS and onsite data demonstrate differences which are readily attributable to local topographical effects such as the orientation of the river valley near the site.

Although the differences in the stability classes are partly the result of the layer used for the stability definition, there is some evidence that part of the greater percentage of stable conditions at WNP-2 may be a real difference.

Tables 2.3-19a through -19h contain joint frequency summaries of the ensite data grouped by Pasquill s'tabilities categories.

The nearest routine radiosonde data that may be applied to this region are obtained at Spokane, the only station located in the relatively flat basin region between the Cascade Mountain Range to the west and the Rocky Mountains to the east. These data will be representative in a regional 1 sense, but cannot be expected to be exact in near surface atmospheric structure as a result of the distance (180 km) and elevation differences (site s440'MSL, Spokane s2350'MSL).

Table 2.3-28 gives the monthly average daily maximum and minimum mixing height data for Spokane.

2.3-2 Amendment 1 May 1978 g

i

WNP-2 ER ts 2.3.2 Temperature U

Table 2.3-20 contains a temperature comparison between the WNP-2 site and HMS. These onsite temperatures are from the 8-ft level on the new meteorological system. By assuming an adiabatic lapse rate of 0.548"F/100 ft, over the 283-ft elevation difference between HMS and the WNP-2 site, a temperature difference can be expected of about 1.5 F between the dry bulb temperature data measured at the two sites.

2.3.3 Humidity Table 2.3-21 gives a comparison of monthly wet bulb temperatures from the 1 year of onsite data and HMS. Table 2.3-22 contains the frequency occurrence of wet bulb values as a function of time of day based on data from the onsite meteorological system.

Figures 2.3-7 to -10 indicate diurnal and monthly and annual averages and extremes of temperature and humidity at HMS.

Summaries of onsite humidity data have been prepared both on a monthly and annual basis in joint frequency wind speed direction formats. In addition, computer tapes of hourly summarized operation including humidity data have been generated.

~

During July 1975 the moisture in the lower atmosphere at HMS

(\~)N was abnormally high. In the period of record, 1957-1970, hourly wet bulb temperatures in a range 70 to 74*F had occurred an average of three times each July. In the period July 4 through July 12, 1975, there were 104 hourly observa-tions in the range 70 to 74 F. On July 9 there were 17 consecutive hours in that range. Wet bulb temperatures of 75*F have not occurred in the Hanford area until this episode.

On July 8, 9, and 10 there were a total of seven such hourly observations. The air temperatures were also high during this period. The HMS average relative humidity for July 1975 was 37.5% compared to the record of 40.5 set in 1955.

Figures 2.3-7 to -10 and Table 2.3-1 and Tables 2.3-23 present additional climatological humidity information from the HMS.

2.3.4 Precipitation Precipitation data are presented in Figures 2.3-11 and -12, and Tables 2.3-24 and -25. Tables 2.3-26a through e are joint wind direction and speed summaries of rainfall inten-sities over the year of onsite data. No deviation from the regional low precipitation pattern was found.

O v

2.3-3 Amendment 1 May 1978

WNP-2 ER 2.3.5 High Velocity Winds Surveys of data on high winds over this region indicate that higher winds tend to occur at the higher, more exposed elevations, although all sites in this region have experienced relatively high winds. High wind speeds result from squall lines, frontal passages, tight pressure gradients and thunder-storms. One small tornado has been observed on the Hanford Reservation. There is indication that this area has been affected by hurricanes, but no complete statistics are readily available that present frequency of occurrence of high winds produced or accompanied by a particular meteorological event. The highest reported winds produced at HMS by any cause are tabulated in Table 2.3-27. The Hanford tower is at a slightly higher elevation and hence might be expected to experience higher winds than at the WNP-2 site. Although based on different periods this tendency may be inferred from Tables 2.3-17 and 2.3-18. Figure 2.3-13(2) indicates the return probability of any peak wind gust at HMS again due to any cause. The highest recorded peak gust at the 50-ft level at HMS in the period 1945 to the present was 80 mph.

2.3.6 Severe Weather Since the submission and the construction permit Environmental Report the local climatology for thunderstorms and tornados has not significantly changed. No additional observations of llg tornados have been made in the Hanford region. The frequency of occurrrence of thunderstorms has been updated in Table 2.3-1.

O 2.3-4 Amendment 1 May 1978

)

V J TABLE 2.3-la AVERAGES AND EXTREMES OF CLIMATIC ELEMENTS AT HANFORD (BASED ON ALL AVAILABLE RECORDS TO AND INCLUDING THE YEAR 1975)

I ,............ ...n......u.,,, ..u..........-o, ,,,,,

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n a e a 2 - - - I .

e e i I = 1 = e u,,. ... m ,

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,m. .. , - - ., .

. .. .. .n .. - m .~. , . . . m. ,m -, - . ,m. . - - . im.a. .. . . - n. . o. .. . n ., - - .,

.. m ,.

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........- .n............... u . com.u.a . . so... o.n n- u.=u n,' .;; g,,.,.,m, =;

i.., a n ... . un .....s,. n.. ,.n . .o .m . . n n . m. .. , ,s.-an....,,

n .. u . ...s. an on o. n...,. .

i.n..an in aior n i. =- , .., : . . , ,m.

- i i e i .

y 4 5 t i

t . Im l I le , t- Im im " " ~ " "

ss - - e - m -

2 -

ii i! ! i ! i !  ! i i ! i  ! i l 5 i i l ! i i i I I i  ! i I i ! i ",'".""'"""""'. ,,,,

. . - . . . .m. o m . - - m. = = = m -

o, , ...

.. - ,. .., , . . .m. . m,,. ,. .. ,,,, ., m , .. . - - -

- . .,. o. . .. . - - m, m - - - =

... n . .. o ., ,. m m., . . . o.., m, ., ,m m . - m - - - - -

- o,

.,. . u. m, n .s .i. ,

.,n . ,m. ., m , , u, , . , . m. . .. .n . - - - - -

- . . , - n . s .. .n . . -. ,, .. u m m - m. m im - -

.., . .. .. ~ ,, . ~ n. - ,e ,. ., o ,. .,. , - - .. -

.m .,m.

. n .u. s. - m. .. .,, ., .. - m -

n .. , . . . m,.

s .. , , su m, ,,,, . - , .u. u . .. , . o. . o. . - , . .i

. .m. ,s. ., .o , . -

o, u - . -

, , , ,,,, m, . .n o, . 1,. .u s, . .n ,im,, .i,. m.,

a D.L 8

,., n im

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i. .m

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i.e. M

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M.

s e 1

a

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L

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s. a su i.

f ,, 6L i . ,, . . s. F, ,l . ., i. H. h.s,.y

. . B. . i st, H ,. ., .

L, .. . ., M. .F. . .H H . .sO

WNP-2 ER as s, si s. =, sa il a 11 Il 11 ti li 12 it il 11 11 !I 11 gs l ga c- a* sa na sa  := sm - -

Sc ..

552 ItIf I' i "e ! z lc I ge ne le le lIc c

I'

! l'i-s gs i'=

e ie a ! If i =

f88=ril'1e - i E2

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, :I :a 1 v ei,, 5 :- ,1

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2

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1:2 I :;2 2 :I: 12 :; 2

-2 8 8 3

u 53 ej 53 g 53w3 !s Is 53 1i 54 ,53 c 5a "

a 3a

• a 53 ! $3 * !;

• 5:

a s i

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gg e

i m ne ............ .

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= .. . num,

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ii 'itti I

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av kII,4 3 .f. -'s= e.gs _: :-

3 s.

ei : m21s 3,E..

5 yj

.= I=Ei :21I1I =

=

. . n.n .-.......... .

a a a--ajgj

. - num, .........-.. . '* ggiEst .: , tztf21 g 5 3,-jf..

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, ... atm, ==ce-....=== = 3 g

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= $$$lisiiiililt

. = = = = ===-.--..-==s j le5 {s%j,if t p .; . ~ n.n ............ . _ iin agg h i;{qj;h j,;[i A% ij - litiit initizzz l l, .wo ne ............ .

ggg; gg g

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=

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=

g g jggg z 5 n.n g m o -

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!- .w,o, nun., ==-------.=== am . E m.zI a -i :- 4

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1

. num., . . . . = . . . - . . .

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l = IllitiZE! liff ,

l

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, , , giggjggigggi ,

i .m Illi!!II! Ells? 5 s

.w. n.r -.-......... -

. i j j

.w. num, ===c=====ce .  ! al = tilli! 2Ef fiE12 E 1g

- =

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T Is ss.:

M ,,w --*==.--....  ; g

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= fi!ali IIIstasi

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5 = iiitEi II:: tift ll .m it. ;tti!

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3

, _ _ ..-....=.3 ..

smilifnn ! im!!ishn !

h

WNP-2 ER h

J TABLE 2.3-2a ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT - VERY UNSTABLE (TEMPERATURE CHANGE LESS THAN -2.5 DEGREES F PER 200 FT)

SPEED CLASS ("PH)

CALM 13 c.7 8-12 13-18 19-2c 25-UP UNKND TOTAL Nst 0 0 0 0 0 0 0 0 0

'E O O 0 1 0 0 0 u  !

ENL O 0 0 C 0 0 0 0 0 6

o - o . o . _ _. o .__.o..__ -o ___ o . o - . _ _ __ o EEE 0 0 0 0 0 0 0 0 0

$! 0 0 0 0 0 0 0 0 0 55L 0 0 0 0 0 0 0 0 0 5 0 0 0 2 1 0 0 0 3

$$a 0 0 0 1 0 0 0 0 1 Sa 0 0 --- 0 0 - --- 0 --- ! --- O - - - - l -

=5= 0 0 0 0 0 1 0 0 1 a 0 0 0 0 1 0 1 0 2 a'.*

• 0 0 0 0 0 0 0 0

%4 0 0 0 0 0 0 0 0 0 NNa 0 0 0 0 0 0 0 0 0

O O -0 0------ 0 0 - - -- 0 ---- - - - - vAW 0 0 0 0 0 0 0 0 0 CAL" 0 0 0 0 0 0 0 0 0 t' *. C. 0 0 0 1 0 2 0 0 0 3 fcTA'. 0 0 1 4 a 2 1 0 12 TABLE 2.3-2b ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 and 33 FT - UNSTABLE (TEMPERATURE CHANGE LESS THAN -1.5 AND GREATER THAN OR EQUAL -2.5 DEGREES F PER 200 FT)

SPEED CLASS (MPH)

CALM 13 47 6 12 13-18 19-24 25-UP UNNNO TOTAt.

N '; E 0 '50 20 11 11 0 0 0 48 NE O b 21 15 1 0 0 0 45 kNL 0 1 22 17 0 0 0 u 40 E o ._ _ 3 --._ . n ...._11 ____ p __o - 0 _ __ _ . 0 - 2 .4 LSE O 2 17 $ 0 0 0 0 25 sE 0 1 37 9 0 0 0 0 47

$$t 0 3 63 23 1 0 0 0 92 S 0 4 c% M2 21 5 0 0 15'4 SSa C 3 20 <t 31 7 0 2 120

t. _

o . 7 __ _ _ 3 3 P a. . 32 13 1 -- 10 7

=se .i 5 24 /5 /3 10 5 3 9/

= 0 5 37 30 21 6 / 1 110

=N= 0 7 23 15 19 17 6 0 92 Na 0 6 31 21 15 to 9 0 "6 ssa 0 8 49 37 13 3 1 0  !!1 s c ,$ . pe .. --34.___.tp _ _ o _ _ o _ _ 0 -- t uo -

vLd 0 13 c2 5 0 0 0 0 60 Ca" s 0 0 0 0 0 0 0 0 0 t;sa s] O 2 17 13 3 0 0 15 50 Tofat 0 95 637 443 206 75 24 22 1504

WNP-2 ER TABLE 2.3-2c (sheet 2 of 3)

ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT - NEUTRAL (TEMPERATURE CHANGE LESS THAN -0.5 AND GREATER THAN EQUAL -1.5 DEGREES F PER 200 FT) ._ . - . . .

SPEED CLASS (MPH)

CALM 13 4-7 8.!2 13-in 19=2a 25.yP UNKNO TOTtL Nst 0 18 3B la 2 0 0 2 78

\t 0 18 23 10 2 0 1 0 Su ENE 0 18 32 12 0 0 0 1 e3

. -- F 0 15 .

77---- 7---- 0 -- -- --- - 0 1 --

E S!

51--

O 32 30 4 0 0 0 1 67

• E C 3? u3 e u 0 0 1 63 SSE O 22 of 29 3 0 0 0 121 S 0 23 es I3 31 2 0 1 los 5'a 0 33 62 P3 65 8 3 6 2e*

p p3 _. p *3 ___. 3 5 _ _-- 3 3 -__ . 1 9 -- 4. _ . 1._.-ic4 -

>Sa 0 22 2s 17 16 9 1 0 91 a 0 26 1A 30 26 10 e 3 11 9 asm 0 33 47 41 o G2 30 1 205 sm 0 33 77 53 38 21 5 9 236 NN. 0 39 f,1 33 to 2 0 2 176

% c 20 u 2 --- - s o -- 1 1 0 0 0-- 12o -

v13 0 la 12 0 0 0 0 0 30 Cat" 0 0 0 0 0 0 0 0 0 J.' e.3 0 3 2 3 0 0 0 4 12 TOTAL 0 u33 733 512 285 103 25 33 2124 TABLE 2.3-2d (sheet 2 of 3)

ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT - STABLE (TEMPERATURE CHANGE LESS THAN 3.5 AND GREATER THAN OR EQUAL -0.5 DEGREES F PER 200 FT)

SPEED CLASS ("H)

CALM 13 a.7 6 12 13-tw 19 2s 25.UP UNKNU T C T A I.

N '. E O 43 34 S 0 0 0 0 82 NE 0 34 e5 2 3 0 0 3 33 Est 0 23 35 2 0 0 0 6 71 E -

0 --- 2 3 - -2 0 .' O 1- 52 -

E!! 0 14 27 d 0 , 0 0 71 SE o 35 $1 31 2 1 0 0 139 555 0 "3 123 133 12 3 0 1 255 5 0 Ss 114 102 34 1 0 4 317 55- 0 lo 109 7S 52 28 3 5 510

g. _ o ._.-35 33 13 y e _2 -- a . _ - 3 07 -

a$a 0 u5 'M 47 12 o 3 3  !?c

• O 46 78 t0 17 3 0 7 220 a '. a 0 72 111 139 82 24 6 3 437

'.- 0 60 170 135 33 5 0 2 412 P. . 4 e e7 141 c1 7 0 0 a /A4

% 0 - 6 0 ---- 5 5 10- 1 0- 0- 1 -- --- 12 7 -

vt1 0 31 15 3 1 0 0 0 So t al " 1 0 0 0 0 0 0 0 1 U N ' '. 2 0 2 to n 1 0 0 21 40 70faL 1 760 1315 820 295 77 14 65 33a7 I

1

/m TABLE 2.3-2e (j (sheet 3 of 3)

ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT - VERY STABLE (TEMPERATURF CHANGE GREATER THAN OR EQUAL 3.5 DEGREES F PER 200 FT)

S,'(.ED CL A S S ( MoH )

CALM 1, 3 4-7 8-12 13-13 19-2a 25-U" UNKNO TOTAL NNE O 69 al 1 0 0 0 0 111

.N E O 72 37 3 0 0 0 0 112 ENE 0 56 28 0 0 0 0 0 84 E 0 c,1 7_ ._ 0 __ 0_ 0 _ _ . 0 0-- 53 ESE 0 a0  !! 0 0 0 0 0 51 E! 0 20 31 1 0 0 0 0 52 SSE 0 23 63 25 0 0 0 2 119 5 0 /5 t? 59 9 0 0 3 lu3 55= 0 21 G2 20 2 0 0 0 65 5= 0 - 31 -- 2 5 ---. -- S -. _ 0 --- - - 0 0 1--62 as" 0 29 24 S 0 0 0 1 59 a 0 19 16 11 0 0 0 0 "5

>.a 0 38 29 10 1 0 0 1 77

• .. < 0 51 e2 17 0 0 0 2 132 NNa 0 59 75 5 0 0 0 0 139 N c _ 79 _ _ 52 1 0- 0 0 0 - --- 13 2 --

viu 0 26 4 0 0 0 0 0 37 C A' " 0 0 0 0 0 0 0 0 0

.*0 0 0 1 0 0 0 0 10 11 T07tL 0 707 620 154 3 0 0 20 1503 O

TABLE 2.3-2f (sheet 3 of 3)

ANNUAL JOINT FREQUENCY FOR HANFORD STABILITY CLASSES FOR WNP-2 BASED ON WINDS AT 33 FT AND TEMPERATURES BETWEEN 245 AND 33 FT - STABILITY UNKNOWN (TEMPERATURE CHANGE IN DEGREES F PER 200 FT UNKNOWN)

SPEED CLA5S(PPH)

CALM 1-3 a-7 8-12 13-13 19-24 25-U" UNKNo TOTAL N '. ! 0 0 3 0 0 0 0 0 3 E O 1 3 0 0 J 1 0 5 E *. E o 0 2 0 0 0 0 0 2 g

0 . .._ _ 2 ___ _ 3 0 _ __ 0 0 --- -. 0 .- - 5 EsE o 1 1 0 0 0 0 0 2

'E O O 1 1 0 0 0 0 2 l SSE 0 1 2 0 0 0 0

' 0 3 3 0 0 0 2 0 0 0 0 2 SSa 0 0 0 2 1 0 0 0 3

c. _

0 ._.O o 0- 0 o 0 o -- aa 0 0 0 1 0 0 0 0 1 a 0 0 0 0 0 0 0 0 0

= *. a 0 0 0 0 0 0 0 0 0

s. 0 0 3 2 0 i

1 1 0 7 s i. . 0 1 0 0 0 0 0 0 1

! - 6 1 -- - -- 0 1 0 0 0 -- -- 2---

v:d 0 0 0 0 0 0 0 0 0 i CAL" 0 0 0 0 0 0 0 0 0 u '> '. 0 0 3 7 a 0 3 0 214 231 f"N T07at 0 to 2o 12 6 1 0 214 269 l

l l

WNP-2 ER TABLE 2.3-3a ANNUAL JOINT FREQUENCY OF WIND SPEED AND DIRECTION FOR WNP-2 AT 7 FT FROM 4/74 TO 3/75 SPEED CLASS (MPH)

CALM 13 e=7 6-12 13=1S 19-24 25-UP UNKND TOTAL N *. E 0 130 132 34 1 0 0 5 302 M 0 76 92 to 2 0 0 3 163 E' E O 77 85 13 0 0 0 1 176 E o 64 59 8 0 0 0 0 lit EM - - 101 64 6 0- 0 0 0 173 -

SE 0 173 147 29 2 0 0 1 35d SSL 0 236 360 52 3 -

0 0 1 592 5 0 265 G24 231 21 2 0 3 906 S?a 0 2u0 2aA 232 - 66 0 0 3 793 sa 0 259 171 125 e7 10 0 1 651

=Sa 0 1 C '3 143 b 52 9 0 3 501 -

a 0 237 169 103 42 15 0 4 570

==d 0 3c8 212 179 116 27 --- 3 10 855 sa 0 3e6 330 154 66 11 1 6 93u NW 0 257 253 86 - 12 - - - 1 0 3 615 N 0 216 163 74 5 0 0 1 059

- -- v 6 - o IA9 7e e 1 0 4 0 P AS-CJ." 0 0 0 0 0 0 0 0 0 U N n '4 0 0 3 2 0-- 0 - - - 254 259 TOTAL 0 3396 3065 1442 476 78 4 299 8700 TABLE 2.3-3b ANNUAL JOINT FREQUENCY OF WIND SPEED AND DIRECTION FOR WNP-2 AT 33 FT FROM 4/74 TO 3/75 SPEED CLASS (MPH) - - - - -- '-

CALN 1-1 4-7 8-12 13-13 19-24 25-Up UNKND TOTAL wE o 141 1e6 50 13 0 0 2 372

• E

. 0 131 127 32 5 2 0 3 300 ENE 0 163 119 31 0 0 0 7 260 E O 98 69 20 0 0 0 2 tu

.-- ESE -- G 1 1 3 ---- e 4 - - 14 0 -0 0 216 - --

5E 0 F9 131 50 6 1 0 1 327 551 0 92 323 le? In 3 0 3 619 5 0 105 293 3!3 91 8 0 8 e19 554 0 46 FL1 2?9 151 a3 e 13 779 s= S 9a tog no 9m 39 7 7 515

-- a5a 0 101 - - l >a i 94 -43 26 9 --- - r N - -

= 0 8e 181 135 73 19 9 11 097 rNa 0 tcA Als 211 144 71 18 5 812 0 l'; W 22B 88 41 14 13 "3

r. . a 7 174 3n 129 34 5 1 6 699 0 177 2 51 96 24 0 0 1 S c' 9

--- VA4 0 co--- - 73_.6 -1 0 0 0- 1 7 2 - --

t al" 1 0 0 0 0 0 0 0 1 L". P 0 38 2e 9 0 0 264 347 10 fCitt 1 2005 3332 19;5 801 2A 5 64 35" 8760 0

WNP-2 ER tm

(' TABLE 2.3-3c (sheet 2 of 2)

ANNUAL JOINT FREQUENCY OF WIND SPEED AND DIRECTION FOR WNP-2 AT 245 FT FROM 4/74 TO 3/75 SDLED CLt.SS(MPH) _ . _ _ _ . . . . _ . . _ . _ . _

CAL" 1-3 4-7 8-12 13-18 19-24 25 uP tj N K Nti TOTAL NNE O 58 129 101 26 4 0 5 321 NE o 42 113 16 15 2 5 0 255 E' E 0 37 4e 59 11 , 0 1 206 E o 38 9e 35 3 1 0 2 175 ESL ----0 5 9 .- t 14 --- 41 4 3 0- o -- - 2 2 7 .-

SE 0 66 165 91 29 e 4 2 367 SSL 0. 53 274 leo 106 13 4 0 t99 5 0 fu 233 321 219 57 5 1 901 SSd O 62 17u 212 236 169 OC 2 Bd3 Sd 0 62 133 49 1 62 55 1 c96 wSa 0 r,6 -~ 1 16 - 91 - _ 33 -33 5 - 417 a 0 49 144 105 102 et 24 8 405 a '. a 0 57 147 1 87 201 184 15 0 la 89M u o e4 239 295 269 132 71 6 1096 N *. m 0 68 231 203 97 11 1 5 nla N 0 71 187 137 41 6 0 4 d46 v1R a 35 _ . . 31 _._ _ _ 9 --- 5- - 0 0-- 78 CALM 0 0 0 0 0 0 0 0 0 t, W .0 4 5 270 290 0 t 10 0 0 TOTAL 0 95g 2580 2268 1543 688 39C 324 8760 r.

I \ *

()

G

TABLE 2.3-4 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, APRIL 1974 FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED DURING 4/74 AT WPPSS2 FOR 3:

SPEED CLASS (HPH)

CALM 1-3 47 8-12 13-13 19-24 25-UP UNKNO TOTAL NNE O 5 8 e 0 0 0 0 19 NE O 2 15 4 0 0 0 1 22 ENE O 1 2 0 0 0 0 0 3 E O 3 3 0 0 0 0 0 6 ESE 0 6 4 1 0 0 0 0 11 SL 0 4 12 6 1 0 0 0 23 SSE o 4 26 21 0 0 0 3 54 x 5 0 M 18 19 12 0 0 7 64 MZ SSW 0 4 16 29 30 2 0 13 94 "7" SW 0 4 18 9 15 0 4 6 50 WSW 0 3 10 12 5 3 1 7 41 W 0 17 5 14 16 4 1 8 63 WNw 0 7 19 26 40 21 8 2 123 NW 0 5 23 15 9 11 3 1 67 NNW 0 5 11 5 1 0 0 2 30 N O 3 14 5 1 0 0 0 23 VAR 0 2 5 0 0 0 0 0 7 CALM 0 0 0 0 0 0 0 0 so UNKNO 0 0 0 0 0 0 0 14 14 TOIAL 0 69 224 174 131 45 13 64 720 0 0 0

O O O TABLE 2.3-5 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, MAY 1974 FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED DURING S/74 AT WPPSS2 FOR 33 F SPEED CLASS (MPH)

CALH 13 4-7 8-12 13-18 19-24 25-uP UNKNO TOTAL NNL 0 5 11 0 0 0 0 0 16 NE O 7 3 3 0 0 0 0 13 ENE O 1 6 2 0 0 0 0 9 E o 8 6 0 0 0 0 0 la ESE O 6 9 0 0 0 0 0 15 SE O 1 16 1 0 0 0 0 18 SSE O 9 38 13 0 0 0 0 60 S 0 10 27 45 92 10 0 0 0 SSw 0 5 30 49 16 4 2 0 106 SW 0 3 15 18 13 3 0 0 52 HSW 0 6 19 30 13 1 0 0 69 n@

Wm W 0 3 23 35 13 5 0 0 79 E kNH 0 11 24 34 17 0 NW to 0 96 0 4 14 10 13 2 a 0 47 NNW 0 3 15 1 0 0 0 0 23 N 0 4 7 0 0 0 0 1 12 VAR 0 1 8 0 0 0 0 0 15 CALM 0 0 0 0 0 0 0 0 0 UNKNO .

0 0 0 0 0 0 0 8 8 TOTAL 0 93 269 248 95 p7 4 8 144

TABLE 2.3-6 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, JUNE 1974 FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED DURING 6/74 AT WPPSS2 FOR 33 F SPEED CLASS (MPH)

C AL M 15 4=7 8=12 13=18 19-24 25=UP U:4KND TOTAL NNE 0 5 12 1 0 0 0 0 16 NE o 7 -. 9 4 0 0 0 1 21 ENE 0 6 16 9 0 0 0 0 31 E 0 3 14 7 0 0 0 0 24 ESE O 4 16 6 0 0 0 0 26 SE O 4 23 to 0 0 0 0 )7 SSE O 7 34 11 0 0 0 0 52 5 o 1- 20 to 10 55 SSW 0 6 20 12 2 0 1 g 12 1 0 0 51 $m SW o- - 3 -

6 4 5 11 0- 0 29 E WSW 0 3 15 5 3 1 1 0 28 w 0 2 14 13 16 2 3 0 52 WNw 0 2 24 19 10 10 2 0 67 Nw -- 0 --.

3- 15 -

20 6 5 - 2 0 53 NNW 0 6 17 3 0 0 0 0 N

26 0 - 6 11 1 0 0 0 0 la VAN 0 0 4 0 1 0 0 0 5 CALH 0 0 0 0 0 0 0 0 0 UNKNO o 10 38 26 9 0 44 0 127 TOTAL 0 81 317 172 10 26 8 46 720 0 0 0

O O O TABLE 2.3-7 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, JULY 1974 FREQUENCY OF OCCURRENCE, hlND DIRECTION VS SPEED DURING 7/74 AT wPPSS2 FOR 33 i 1

SPEED CLASS (HPH) l CALM 13 .4 = 7 8-12 13-18 19 24 25=uP UNKND TOTAL

! NNE O 3 13 2 0 0 0 0 i ft i NE 0 -

11 12 1 0 0 0 0 24 ENE O 3 9 6 0 0 0 0 18 i E O 10 14 a 0 0 0 0 30 ESE o b to 1 0 0 0 0 25 SL 0 10 2e - 4 0 0 0 0 40 SSE 0 3 31 16 1 0 0 0 51 S 0 6 27 32 5 0 0 0 70 SSN 0 9 le 18 9 2 0 0 54 to $

SW WSW 0 7 6

22 14 6 0 1 0 50 57" 0 12 11 3 1 2 0 35 i

W 0 -7 14 19 9 0 0 0 49 WNW 0 5 18 18 17 5 0 0 63 N ei 0 gg g8 g g- g3 a 0 0 67 NNa 0 10 25 4 2 0 0 0 41 N O 8 22 5 0 0 0 0 35 VAR 0 5 2a 3 0 0 0 0 32

CALM 0 0 0 0 0 0 0 0 0

UNKND 0 0 0 0 0 0 0 36 36 TDTAL 0 120 327 181 e5 12 3 36 744 1

i l

i a

i

TABLE 2.3-8 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, AUGUST 1974 FREuuENCY OF OCCURRENCE, WIND DIRECTION VS SPEED DURING 8/74 AT WPPSS2 FOR 33 SPEED CLASS (MPH)

CALM 13 47 8 12 13 18 19 24 25.UP UNKND TOTAL NNE O 16 21 11 0 0 0 0 46 NE O 12 19 6 3 2 0 0 42 ENE 0 9 6 0 0 0 0 0 15 E O 10 4 4 0 0 0 0 18 ESE o 12 9 0 0 0 0 0 21 SE o 6 25 1 0 0 0 0 32 SSE O 8 39 -

16 0 0 0 0 63 S 0 7 33 28 4 3 0 0 75 SSN 0 11 24 17 13 1 0 0 66 to N SW WSW 0

0 8

9 16 18 8 0 0

1 0

0 0

0 33 57N 1 0 28 W 0 4 13 6 3 0 0 0 26 WNW 0 8 19 13 22 10 1 0 73 NW 0 12 27 12 8 8 0 0 67 NNW 0 4 35 10 0 0 0 0 49 N 0 15 32 10 0 0 0 0 57 VAR 0 12 5 1 0 0 0 0 18 CALM 0 0 0 0 0 0 0 0 0 UNKNO O 0 0 0 0 0 0 13 il TOTAL 0 163 345 144 53 25 1 13 744 O O O

i O O O 3

i TABLE 2.3-9 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, SEPTEMBER 1974 FREGUENCY OF OCCURRENCE, WINO DIRECTION VS SPEED DudING 9/74 AT nPPSS2 FOR 33 SPEED CLASS (MPH)

. CALM 1-3 47 6 12 13 16 19-24 25.UP U.u N O TOTAL NNE O 19 29 10 11 0 0 0 69

! NE 0~ 21 11 5 2 0 0 0 39 3 ENE O 20 20 0 0 0 i

0 0 40 E o 17 .7 0 0 0 0 0 24 l ESE O 15 11 0 0 1 0 0 27 l SE O 7 11 3 0 0 0 0 21 l SSE O 1 13 7

' 0 0 0 0 21 S 0 e 22 25 4 0 0 0 59 SSW 0 5 16 11 3 0 1 0 38 tn N i Sw 0 12 11 3 3 WSW 0 8 5 3 1 0

0 0 0 0 0

29 57M n

17

0. .12 _ 10 10 4 0 wNW 0 0 36 0 9 12 17 12 5 0 Nw 1 56 0 9 19 24 8 4 NNn 0 1 0 65 12 29 14 3 0 0

N 1 59 0 15 38 28 12 0 0 0 93

! VAR 0 10 8 1 0 0 0 0 19

.l CALM 0 0 0 0 0 0, 0 0 0

]' UNAND 0 0 0 0 0 0 0 8 8 TOTAL 0 200 274 162 63 10 3 8 720

)

4 1

i

TABLE 2.3-10 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, OCTOBER 1974 FRE0uENCY OF GCCURRENCE, WIND DIRECTION VS SPEED DURING 10//4 AT WPPSS2 FOR 33 F SPEED CLASS (MPH)

CALM 1-3 47 8-12 13-18 19-24 25 uP UNKND TOTAL NNE O 26 15 1 0 0 0 0 42 NE O 26 17 0 0 0 0 0 43 ENE 0 26 22 1 0 0 0 0 49 E G 20 4 0 0 0 0 0 24 ESE O 15 2 0 0 0 0 0 17 SE O 15 19 2 0 0 0 0 36 SSE O 16 21 8 0 0 0 0 45 S 0 13 25 13 0 0 0 0 $1 SSW 0 15 21 6 0 0 0 0 42 mj Sw 0 12 13- 1 0 0 0 0 26 xm wSW 0 15 11 2 0 0 0 0 28 0 W 0 12 9 to 5 1 0 0 37 WNw 0 21 11 15 11 6 0 0 64 Nw 0 17 17 12 1 0 0 0 53 NNW 0 29 20 9 2 0 0 0 60 N O - 37 24 3 0 0 0 0 64 VAR 0 16 4 0 0 0 0 0 20 CALM 1 0 0 0 0 0 0 0 1 UNKND 0 0 0 0 0 0 0 42 42 TOTAL 1 331 255 83 25 7 0 42 144 O O O

O O O TABLE 2.3-11 MONTHLY SUMMARIES OF JOINT FREQUEMCY OF WINDS FOR WNP-2, NOVEMBER 1974 FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED DURING 11/74 AT WPPS$2 FOR 33 F SPEED CLASS (MPH)

CALM  !=3- 4-7 8-12 13=18 19 24 25=UP UNAND TOTAL NNE O 18 to 4 0 0 0 2 38 NE 0 10 13 2 0 0 0 1 26 ENE O 13 to 7 0 0 0 1 31 E O h-- 2- 0 0 0 0 0 8 ESE 0 12 3 0 0 0 0 0 15 SE -

0 14 13 7 0 0 0 0 34 SSE o 7 28 15 3 0 0 0 53 S 0 12 29 29- 5 0 0 0 75 SSW 0 11 32 14 19 0 E .g 1 0 77 o SW 0 12 20 6 -

8 4 0 0 MSW 9 50 6 0 6 5 2 2 0 0 24 W 0 12 14 3 1 2 0 3 35 WNW 0 22 14 7 5 0 NW 1 2 51 0 27 34 12 0 1 0 1 75 NNW 0 24 34 2 0 0 0 0 60 N 0 10 17- 3- 0 0 0 0 50 VAR 0 11 2 0 0 0 0 0 13 CALM 0 0 -0 0 0 0 0 0 0 UNKNO O 0 0 0 0 0 0 5 5 TOTAL 0 - 250 285 116 43 11 0 15 720 l

TABLE 2.3-12 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, DECEMBER 1974 FREQUENCY OF OCCURRENCE, WIN? DIRECTION VS SPEED DURING 12/T4 AT WPPSS2 FOR 33 i SPEED LLASS(MPH)

CALM l-3 4-7 6-12 13-18 19-24 25-UP UNhdu TOTAL NNL 0 12 5 2 0 0 0 0 17 NE O 9 5 2 0 0 0 0 to ENE O 5 4 0 0 0 0 0 9 E O 6 1 0 0 0 0 0 7 ESL 0 8 1 1 0 0 0 0 10 SE O 9 6 5 1 0 0 0 21 SSE 0 5 2e 2$ 3 1 0 0 60 S 0 11 39 35 14 1 0 0 100 SSH 0 14 23 29 9 4' 3 0 82 g@

Sd 0 14 11 9 2 0 0 0 36 mm NSW 0 16 11 6 3 2 1 0 45 E W 0 20 15 7 3 3 4 0 52 WNW 0 27 25 21 6 1 1 0 81 NW 0 17 59 11 3 0 0 1 91 NNd 0 29 27 o 0 0 0 0 02 N 0 21 12 0 1 0 0 0 34 VAR 0 8 3 1 0 0 0 0 12 CALM 0 0 0 0 0 0 0 0 0 UNKND 0 0 0 0 0 0 0 9 9 TOTAL 0 211 277 160 45 12 9 10 744 9 O O

O O O TABLE 2.3-13 i

MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, JANUARY 1975 FREQUENCY OF OCCURRENCE, WIND DIREC7 ION VS SPEED uuRING 1/75 AT nPPSS2 Fow 33 F SPEED CLASS (MPH) l CALM- -1 3 4-7-- ---8-12 18 24 25-UP UNKNO f074L i

NNE 0 11 17 6 0 0- 0 0 34 j NE - - -- - - 1 3 - - - - --1 1- --- - -4 0 - ----- - 0 0 0 28 ENE O 10 12 5 0 0 0 6 33 i

E 0 5 -- -10 -! 0 - 2 0 18 ESE O 15 5 2 0 0 0 1 23 SE- -

- --- - 1 4 - - --- -- -

0- - -- 1 0 1 27 SSE 0 13 17 15 2 1 0 0 48 5 0 10 14 - -- - 16 -

-6 0 0 0 de SSw 0 6 18 10 15 3 0 0 52 m$

SW 0 15 14- - 5 -- 4 2 1 48 "7N WSW 0 13 16 4 3 6 3 0 45 w 0- 6 -

8 8 -- 4 -

0 0 28 WNW 0 23 to 13 0 0 0 1 51

, N4 0- 20 37- - 19 3 0 0 10 89 NNw 0 29 47 22 0 0 0 a 102 i N O 11 17 - - 15 0 0 0 1 4a i VAR 0 7 3 1 0 0 0 0 11 CALM 0- 0 - - - - - - 0 0- 0 0 0

UNKNO 0 0 0 0 0 0 0 17 17 TOTAL 0 219 - 2 7 4 - -- 147- .- - - - 15 5 44 -

744 i

1 i

TABLE 2.3-14 MONTHLY SUMMARIES OF JOINT FREQUENCY OF WINDS FOR WNP-2, FEBRUARY 1975 FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED DURING 2/15 AT WPPSS2 FOR 33 F SPEED CLASS (MPH)

-C ALM 3 4 7- B-12 13-18 24 25-UP -UNKND TOTAL NNE O 15 15 2 0 0 0 0 32 NE O 8 6- 0 0 0 0 0 16 ENE O 5 8 0 0 0 0 0 13 E O 4 2 0 0 0 - 0 0 6 ESE O 5 5 1 0 0 0 0 11 SE - 6 -10 3 1 0 0 0 20 SSE 0 14 20 13 4 1 0 0 52 S 0 14 11 18 8 2 0 0 53 SSW 0 9 8 10 0 18 1 0 55 ms SW -

0 4 9 3 9 4 4 0 33 5y WSM 0 9 7 3 7 4 1 0 31 N W 0 -

4 11 6 1 1 1 0 24 WNW 0 7 14 9 2 2 1 0 35

- Nw- 0 12 54 45 10 3 2 0 126-NNW 0 14 45 24 14 0 0 0 97 N 0 16 19 19 1 0 0 0 55 VAR 0 5 2 1 0 0 0 0 8 CALM - 0 0 0 0 0 0 0- 0 0 UNKNO O 0 0 0 0 0 0 5 5 TOTAL 0 151 248 157 66 35 10 5 e72 O O O

s O O O TABLE 2.3-15

< MONTHLY SUMMARIES OF-JOINT FREQUENCY OF WINDS FOR WNP-2, MARCH 1975 FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED DURING 3/75 AT WPPSS2 FOR 33 F

! SPEED CLASS (MPH) i C ALM 1 ---u = 7- - - 1-2 18 19-24 25=uP- UNKNO TOTAL

- NNE O 6 8 5 2 0 0 0 21

! NE O 5 ~1 0 0 0 0 10 ENE O 4 4 1 0 0 0 0 9 E O 6- -

'd 2 0 0 0 0 10 ESE O 9 5 1 , 0 0 0 0 15 SE o 2--- 6- -~ " 7 - 3 0 0 0 18

SSE O 5 24 22 3 0 0 0 54 5 0 ,3 28 35 13 0 0 0 79 24 g

i SSN 0 1 1S 16 6 0 0 62 @m SM 0 - ---9 31 14 0 0 73 8 dSW 0 4 7 12 o 6 0 0 37 W 0 ---1 - - 1 2 - -- - - - 0 1 - 0 0 16 dNd 0 6 21 19 2 0 4 0 52 Nd -- 0 13- 32 - -- 2 7 - - - o- 1 4 0 83 NNd 0 9 37 23 12 5 0 0 86

N 0 11 18- 6- -

9 0 0 0 44 l VAR 0 7 5 0 0 0 0 0 12

CALM- 0 0 0- -

0 -0 0 0 0 UNKND 0 0 0 0 0 0 0 63 63 TOTAL 0 97 237- 201 - 105 33 8 63 744 t

TABLE 2.3-16a SEASONAL PERCENT FREQUENCY DISTRIBUTION OF WIND SPEED AND WIND DIRECTION AT HMS VS. ATMOSPIIERIC STABILITY USING TEMPERATURE DIFFERENCE BETWEEN 3 AND 200 FOOT LEVELS AND WINDS AT 200 FEET FOR THE PERIOD 1955-1970 (Windspeeds are in MPH in the left column.)

s E A s 0 y _ _.s_PH LN.G _

NNE NE ENE E ESE SE SSE S, SSW SW WSW. , W _ WNW ,N W NNW . N VAR. CALP T.0 T AI.

0-3 JS_03 15 0.13 0. n9 0.14 MS 0.08 0.11 0 08 0.10 0.17 0.20 00.07 0.21_0.23 16_O 3 t 13 0.14.0.21._0.15_q.3e 0.08 0.08 0.08 0.07 0.14 n og09 7 0.31 0710Og 0.147_0.22 0.12n_ tid- n 23 3,55_

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TABLE 2.3-16e (sheet 5 of 5)

NNNUAL

......... . ..NhE NE,,ENE. E 'ESE . SE, S S E_ . , "S _ SSW _ SW , WSW _ W ,WNW_ , NW_ NAW ,_,

N VAR., CALM, T,OTAL_

0-3 -lS 0.21 0 21 0 15 0.20 0 26 0.38 0 23 0.23 0 20 0.23 0.22 0 40 0 34 0 43 0 37 0.35 0.21 0.48 5.11 HMTiT 0 18 0- iTD 71"C33' O . 4 2 0 20 0.15 0 12 0.f7 0.13 0.21 0 22 0 31 0 2r 0 29 0 1J 0 3D 4.1)

N 0.30 0 34 0 27 0.33 0.36 0,44 0.22 0.15 0 13 0.11 0 10 0 18 0 18 0.33 0.41 0.41 0 13 0 48 4.87

-""" " U' - ~ 0 . 4 9 0 . 6 4 0 3 6 0. 4 0 0. 31"0. 27 ' 0'.12 0.1TO .'10 'O .16 ' O .10 0;14"0714 0 ;2T U ;37 c .5 4 ' 0'. 4 6 0. 0 4 " 5 '. 0 0 -

~

T " T " ' V S ~0 . 21 0 18'0'.14 0.17 0:2 0 ~0 33~ 0.28 ' 0.28 0 ~.24 ~ ~0.35' 0;5 0 0.96~ i; 0r170 0 0;69"c .39"0 0'l DT "7702"

~ ~

MS 0.17 0.15 0.13 0.15 0.22 0.J6 0.21 0.17 0.15 0,21 0.24 0.42 0.50.0.68 0.47 0.31 0.02 0 4.56 N T 12 U 13' IIIItFtr.1TO FU;28%

• u . l u u u f tF;I u u . ii U TI6 tr77-% 5 5. 32 v .15 tr. O i D. 2.9e

_,,U 0.94 0.90 0.,55 0.58 0.53 0.62 0 37 0.,45, 0,.45 0.,51 0.,37,,0.38 0 48 1 13 1 11 1.38 0.30 ,

,0. _10.84, 8 -12

"-" ---"H VSS 00 13

.1100.08 11 00.03 08 00,06'0^.10 07 0 07 0.13 0.210.21 0 11 0 12 0 ,34~6a 59 1 23 2 0050 0.96~

0,19'0;13~0;20~0,24 1.74 0 60 0.20 0 O. 7.65 1.47 -1.53 0.3P t;14 0.00-0; 6.43-N 0.06 0.04 0.03 0.03 0 04 0.09 0.07 0.04 0 06 0.09 0 14 014 0.42 0.78 0 15 0.06 0. O. 2.26 5-41.33 0.12 DTD9 GUV 0!I5 0711 OW4 T3TT59 DT56 0.33 039 1.4T U 52 tT47 0.00 c.

~

U-- o.31 Y3-18" ~VS 0 05"0 03~O'.02'g'.02 Q: 00"0 94 0.1'0~ 0.~ 03 '0 : 0 3 0.~0 9~0. 2 5 0. 43 "1 2 5"i .3 T 0.17 O ' 05 "0 ;" 0 ."- " 4 .14 tt!

MS 0.10 0.05 0.02 v.02 u.02 0.07 0.13 0.15 0.25 0,54 0.87 1.24 3,04 2.23 0.te 0.10 0 O. 9.03 xm "N 0. 05 0 01 0 01' O . 01 0 0 0 ' 0 ; 03 0. 0 4 '0 i05 D : 07 0 '.14'~ 0 24 O i16' O. 44 0.58 0 0c 0.r4 0~- DV-

. "1;94- 8 0 0.26 0.13 0.03 0.01 0.01 0.03 0.04 0.05 0.18 0.54 0.68 0.26 0.64 0.98 0.00 0.14 0. D. 4.07 S0 04 0 0k 0*hk b !O'h[00 ~0*bh 0 !6'h*1k-h[hk' lh -h! O h bh"k.*hh'!*45 h*hh 0lCb O' - --b)-- *hl" N 0.02 0.02 0 00 0.00 0 00 0.01 0 01 0.03 0 08 0.15 0.17 0 05 0 25 0.34 0.01 0.02 0 O. 1 17 "U 0.06 0.05 0'.01 0.00'O; - 0. 0 0 ~0. 01' 0 J 0 2 U .11- 0.34' O .41" U ;12 0 32 0. 63 D i ci 0. D3' O . 0."" ~ 2.1T-0 700 0. 0.~0D 0.00 0.00 0 01"UTF1 0.00 0.00 0 00 0. ~D.

~

OVER 24 VS 0. 07-~ 0. I. D. D. 0.04 MS 0.01 0.01 0. O. O. 0.01 0.02 0.08 0.30 0.47 0.22 0.06 0.55 0.76 0.00 0.01 0. O. 2.5n

-""---"R 0.01 0 01 0 00 0.00 0.-" 'O. ~0 '. 01" 0 4 0 2 U. 0 8 0 ;17 0; 0 9 0. 0 3 0 21"0.~3 7 0. 0 0 0. 01 U . " O '. " " U ;9 3" U 0.02 0.03 0.01 0. D. ,

D. 0.

0.01 0 09 0.40 0.31 0.08 0.17 0.46 0.01 0.00 0. , ,,

O. 1.57 TOTALS

--~75VSV70 0.60 0 tp0554 0 39 0 07 3 6 0T.-4S 47 0U53.070.88 T. 080U;32 83 0O 67 0 .61 it3 A 0 9 5 1. 61 3. 0 5 z 2-2

4. 7 3 4. 8 9 1. 8 3 1. 0 0 0 23 0. 4 8 2 4 2 9 21- 2:4 6-3T23-7;-3 3-fr:96 1T3 4 t 0 7 T. A 4 U.Str3r.5f-N 0.56 0.55 0.42 0.49 0.60 0.82 0.49 0.40 0.48 0.76 0.85 0.72 1.78 2.88 0.95 0.72 0 15 0.48 14.11

--'O 2.252081081.090.94 1.07 0.65 0.84 1.27 2.53 2.43 1.30 2'35 4.90 2 13 2.34 0.77 0.04 30.03 O O O

_~ _ _ _ _ _ ._ _ _ _ . - _ _ . _ - _ _ _

w w m I

l l

1 TABLE 2.3-17 i

CLIMATOLOGICAL REPRESENTATIVENESS OF THE YEAR USED IN THE DIFFUSION COMPUTATIONS (These data are based on climatological observations at the Hadford Meteorology Station located 14 miles northwest of the site) 3' Average Air i Month Insolation 50' Wind Speed Temperattfre Precipitation Relative Humidity

! 1M LT(23) IM LT(31) IM LT(59) IM LT(59) IM LT(30) 4-74 440ly 4751y 10.3 MPH 9.1 MPH 52.9 'P 53.2 *F 0.46" 'O.40" 50.4% 46.5%

i 5-74 590 576 9.0 8.9 57.9 61.8 0.28 0.45 43.5 42.3 6-74 685 628 9.0 9.2 72.6 69.4 0.12 0.57 30.4 39.5 7-74 . 639 659 8.1 8.6 74.5 76.4 0.71 0.14 32.0 31.8

, 8-74 578 558 7.5 8.0 75.5 74.2 T 0.19 33.0 34.8 f 9-74 456 423 7.3 7.5 68.0 65.2 0.01 0.30 33.0 40.6 j 10-74 287 262 5.6 6.7 52.5 53.1 0.21 0.58 46.0 57.0

{ 11-74 107 132 5.5 6.2 41.6 40.0 0.71 0.85 74.7 73.5 hy i 12-74 90 92 5.9 6.0 36.2 32.6 0.97 0.86 78.7 80.1 [

1-75 113 120 6.4 6.6 32.5 29.4 1,43 0.93 79.0 75.2 2-75 208 202 7.5 7.1 33.7 36.2 0.98 0.62 74.0 70.0 i 3-75 348 340 8.9 8.4 42.5 45.2 0.33 0.36 56.0 55.8 AVERAGE 378 372 7. 6 7.7 53.4 53.1 6.21 6.25 52.6 53.9

KEY: LT(N) - long term for N years for entry i IM - single month as listed at left T - Trace 1

f .

1 1

..,3_

WNP-2 ER TABLE 2.3-18 COMPARISON OF ONSITE AND LONG-TERM DIFFUSION ELEMENTS (Annual Percent and Frequency of Occurrence)

WNP-2 Onsite Data "  !!anford Meteorolocy IDI Stability Classification (1 year) Station (15 years)

Very Stable 17.74 24.29 Moderately Stable 38.47 31.58 Neutral 25.05 14.21 Unstable 17.74 30.01 Wind Direction 33' 50' NNE 4.42 3.6 NE 4.22 3.4 ENE 3.07 2.1 E 2.38 2.4 ESE 2.56 2.6 SE 3.88 3.7 SSE 7.35 2.8 S 9.69 3.2 SSW 8.93 4.1 SW 6.11 7.2 WSW 5.07 8.5

.W 5.89 9.8 WNW 9.65 16.0 NW 10.49 16.6 NNW S.27 4.9 N 5.94 4.5 Var 2.04 2.4 Calm 0.01 2.2 Wind Speed (mph)

Calm 0.01 2.20 1-3 23.73 25.43 4-7 39.63 33.30 8-12 23.09 23.89 13-18 9.47 11.58 19-24 3.05 4.45 25-up 0.75 1.36 (a) 4/74 to 3/75 winds at 33 ft, stability based on change in air temperature between 33 and 245 ft. Values normalized to 100%

data.

(b) 1955-1970 winds at 50 ft, stability based on change in air temperature between 3 and 200 ft.

O

WNP-2 ER l

O TABLE 2.3-19a JOINT FREQUENCY TABLES BY PASQUILL STABILITY GROUPS l FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 FOR 33 FT LEVEL (TEMPERATURE CHANGE LESS THAN -2.1 DEGREES F PER 200 FT)

SPEED CLASS (MPH)

CALM 13 47 8-12_.13 16.. 19-24._25.UP UNKNO TO.T.AL_._

NNE. 0 0 2 0 1 0 0 0 3 NE '. 0 0. . 0 .... 6 0 _ _- - o 0 0 .. 6 ._

ENE 0 0 4 3 0 0 0 0 7

......E._ _ 0 0. 2 1 0 n 0 o 1 ESE o 0 'o 1 0 0 0 0 1 SE O O 1 2 .- .- - . 0 . . . _ . - . 0 O. 0 .- _ _. 3. .-

$5E 0 0 3 3 1 0 0 0 7 5 0 0 0 9 . 5 .. ... 3._. . 0 .._ 0 ..__ 17._

SSW 0 0 1 2 5 0 0 0 8

._ S W 0 0 2_ 1 -- - 5 o i o 11 WSW 0 0 0 0 3 2 3 2 10 W 0 0 1 3 .. . 5 .. 2 _2 0 .. _ 13. _

WNd . 0 0 1 2 4 7 2 0 16 NW 0 0 1 1 3. ._ 3. ..4 _ _. _ 0 .' 12 .. .

hNW 0 0 2 6 2 1 1 0 12

.___ .. . N 0 . . . . 0 . .. 2 __ l 3 0 0 0 . 6_

VAR 0 0 0 0 0 0 0 0 0 CALM . 0 0 0 0 ... 0 _ 0_ ._0. .0 . _ _ 0.

UNKNO O o 6 7 , 5 0 0 2 20 g TO7AL . 0 .

0 26 48 .. .42. .._ 22... 13.. - 4. . 157 t *

~

Note: The speed class headings represent * ~ ~ ~ ' " ' ~ ~ ~ ~

the following wind speeds.

. Calm: 0 to 0.22 oph - ._.-. _

1-3: 0.23 to 3.49 mph '

_ . _ _ _ _ 4-7: 3.50 to 7.49 mph 8-12: 7.50 to 12.49 mph .

. 13-18: 12.50 to 10.49 mph . .. . . . . . . . _ .

19-24: 18.50 to 24.49 mph

. . . . . . . . 25-up: 24.50 raph and up . . _ _ _ . . . . . . . . . . . _

O

WNP-2 ER TABLE 2.3-19b (sheet 2 of 8)

FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 FOR 33 FT LEVEL (TEMPERATURE CHANGE LESS THAN -1.9 AND GREATER THAN OR EQUAL -2.1 DEGREES F PER 200 FT)

' ~ ' ' "

SPEED CLASS (MPH)

CALM t=3 0=7 8 = 12. 13*16._19?24._25=UP UNKNO 70TAl....__

NVE O 0 3 4 1 0 0 0 8

~

r '. 0 0 4 3 .. .0 . . 0 _ . .. 0 . . .. . 0. _ __ _ 7. .

. E .: 0 0 0 0 0 0 0 0 0 3

o n

. .....E. _ _ 0. ._ _ 1 1_ .1 0 0 ESE C 0 3 3 0 0 0 0 6 3E 0 0 7 . _ 2 . .. . D . .. 0 0 ._ _ 0. 9__

S$5 0 0 8 3 0 0 0 0 11 S 0 0 4. .17 ~ 7 ._. _._. 0 0 _ _ _ ._ 0 28 SSW 0 0 2 7 1 2 0 ' 0 12 3_ 1 2 0 o 9 SW .0 0 1 W5W 0 1 3 3 1 3 1 1 13 i _ . . . .

W 0 t . 11 ._q.... 7_.. ..0. 0 0 23

. i . WNh 0 0 5 2 6 3 2 0 20

'...... NW _.. o O .- 6 . . . _ _ 7 ._ 4.- 2 1 ___ 0 20

. N4w. 0 1 7 6 4 0 0 0 20

_F 0 0 13 J f n 0 0 t7 VAR 0 1 5 1 0 0 0 0 7

'._. . . .'. . C A t. H .. . 0. ._ 0 . O _ .. . _0 0- 0 0 0 0 UNKND 0 1 2 1 0 0 0 3 7

.. TOIAL. .. 0 ._6. . 5 7 .. . 7 2 _3 6. 11 4 9 220

~~ ~

Note: .The speed class headings represent ._.. _...--

the following wind speeds.

.I Calm: 0 to 0.22 mph -

1-3: 0.23.to 3.49 mph 4-7: 3.50 to 7.49 mph

. 3-12: 7.50 to 12.49 mph

. . . . . . . . . . . 13-18: 12.50 to 18.49 mph

. 19-24: 18.50 to 24.49 mph

. . . . . . . . . 25-up: 24.50 mph and up i

1 O

l l

l WNP-2 l ER i

O

, TABLE 2.3-19c (sheet 3 of 8)

FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 for 33 FT LEVEL (TEMPERATURE' CHANGE LESS THAN -1.6 AND GREATER THAN OR EQUAL -1.9 DEGREES F PER 200 FT)

SPEED CLASS (MPH)

. CALM t=3 4-7 8 12 13 18. 19 24. 25,UP. UNKNO 70TAL._

NNE 0 6 33 16 7 0 0 0 62 NE O e to 5 1 0 .. 0 . . . 0 .. ._ . 2 0 ENE 0 0 12 12 0 0 0 0 24

.___..f._ 0 1._._ 5 7 0 6- -

,.__0 0 13._

ESE O 2 . 13 .

2 0 0 0 0 17

$E O O 19 4. . 0 . 0 .. 0 -

0 .-.23 3SE O t 31 16 0 0 0 0 50 3 0 3 34 40 7 2. . . .-. 0 - . . . 0 .. . 86

$$w 0 1 20 28 21 3 0 1 74

. 311_._ _ 0 - 2. 22. 12 15- 5 0 1 9 Z_.

W3W 0 4 13 17 12 4 0 1 51 W 0 2 19 20. .._ 14 .. _.3 ___ 1 1 -- - 60 WNW 0 3 16 5 6 5 1 0 36 NW 0 6- 17 7.... .4

_. 7.... _.7. -- 0 48 NNW 0 3 2A 13

• 6 2- 0 0 52

_N -= 0._ 4 50. 28 7 0 0 0 09 VAR 0 8 27 3 0 0 0 0 38 CALM 0 0 0 0 0. _..:0. __ 0 .0 0 UNKNO 0 1 9 4 0 0 C 9 23 p T 07 AL- . 0 . 51 382 2 41._.. _.10 3. _.. 31. . 7 12 627._

Note: The speed class headings represent ~~~~~"~'~~'~'

the following wind speeds.

Calm: 0 to 0.22 mph - - ... ~ . _ _

13: 0.23 to 3.49 mph

- ~~-~.-. 4-7 : 3.50 to 7.49 mph 8 12: 7.50 to 12.49 mph

. 13 18: 12.50 to 18.49 mph . . _ . . _ _ _ . .

19 24: 18.50 to 24.49 mph

. . . . . . . . . . . . . . 25-up: 24.50 mph and up O

WNP-2 ER TABLE 2.3-19d (sheet 4 of 8)

FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 FOR 33 FT LEVEL (TEMPERATURE CHANGE LESS THAN -0.5 AND GREATER THAN OR EQUAL -1.6 DEGREES F PER 200 FT)

' ~" ~ ~ ~ ~

SPEED CL'FS'SI APii)

CALM j3 47 8 12 ,[}.10. 19=24 _25*UP _UNKNO._ TOTAL-.._

NNE 0 23 50 24 a 0 0 2 103

. NE. 0 20 26 12 _ .. l .. .. . 2 . _. _ 0.. _ _ . . 0 = _61.__

ENE D 19 38 14 0 0 0 1 72

. . . . . E . ._. 0 .. 17 . 26 .9 0 0 0 1 55 _

ESE O 32 31 4 0 0 0 1 68 SE O 33 53 9. 4 .. 0 __ . 0... 1_. 100. . 1 SSE o 2a 88 30 3 0 0 0 145 l 3 0 2a 7s gl 3u 2 . . 0 . .. ..l... 226 53W 0 35 60 95 69 10 3 7 287

_._ Sw._ _ _ .0. .. 31 .... 34 _ .a2 92 23 _9 1 177 l WSW 0 22 34 22 20 11 1 0 110 d .. 0 20 36 29..__ 30 ._ 11 6 3 _13 5.__. l

. WNW 0 37 53 53 43 32 7 1 226 Nd ._ 0 . 33 Bo .. 59.__._.30 25 5 9 252 _

. . NNW C c3 93 48 I a5 2 0 2 203

._N 0 13. 59 H 12 0 0 0 D 6__

YAR 0 22 22 1 0 0 0 0 45

_ _ . . . C ALM . . . O o 0 0 .. .. 0. ._0 0 -- - ') 0._

UNKNQ 0 3 3 o o 0 0 5 15

. 70f AL , , , , . 0 471 67a . s q 8 . ., 316 ....(16. __ 26.__ ._3.5 2436 1 liote: The speed class headings represent the following wind speeds. -- --- - -

Calm: 0 to 0.22 n:ph 13: 0.23 to 3.49 mph

.,,. 47: 3.50 to 7.49 mph

. 8 12: 7.50 to 12.49 mph 13 18: 12.50 to 10.49 mph ~~

19 24: 18.50 to 24.49 mph 25.up: 24.50 mph and up _ _ _

~

= _ . . . . .. . . _ . . . _ . _

O

r WNP-2 ER O TABLE 2.3-19e D (sheet 5 of 8)

FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 FOR 33 FT LEVEL (TEMPERATURE CHANGE LESS THAN 1.6 AND GREATER THAN OR EQUAL -0.5 DEGREES F PER 200 FT)

CALH .13 .4 = 7 6-12 .13,16 .19,24_. 25eUP._.UNKNO. 707 AL NNE 0 25 12 2 0 0 0 0 39 NE O 22 31 1 . 0 . -. 0 -- 0. _ .. 2. . . . 5 6 . -

ENE o le 25 0 ~0 0 0 3 ao

...E _ 0.. _1 a 18. 2 0 0 0 1 35 _

ESE o 26 15 4 0 0 0 0 45 3E O 23 39 2 2 .._ . 2 - .1. ._.0 0- .87 -

$$E o 31 60 7a 11 3 0 1 189

$$d 5 0 38 67 6 b .. . 29 . . . . . 1 .. . 0..._-.0....201....

08 0 22 59 45 26 3 5 210 3W_ .._ 0._ 19 _ S7 25. 11 6 2 1 193 h3d 0 2a . 40 41 12 6 3 w

3 133 0 32 51 52._.. 15... 3 0 .2 155

%NW 0 50 62 103 82 24 6 1 348 NW 0 33 121 115 0.. ... 0. 306.._

NNN 0 c3 82 43 . . _ .7 32. .. .0 . . 5 . 0 3 178

.N _ . .. 0.. . 36 -.... 35.. 9 1 .0 0 _1 80 VAR 0 14 9 3 1 0 0 0 27 CALM I o 0 . 0 _ _ . 0 . ._ .. .. 0 0 0 1 UNKNO o 1 6 6 1 0 0 11 25 TOTAL 1 .c71 822 616.. 26 9 .. 77 14 36 _ 2306

\, ,/ . . . . . . . . . . _ . . . . - . . . . . . . . _ . - _ .

Note: The speed class headings represent the following wind speeds. -

. Calm: 0 to 0.22 mph _ _ ... _ _.

1 3: 0.23 .to 3.49 mph

. . . . 4 7: 3.50 to 7.49 mph j 0 12: 7.50 to 12.49 mph ,

13 18: 12.50 to 18.49 mph .... .- -

19 24: 18.50 to 24.49 mph

. . . . 25.up: 24.50 mph and up

~

G

WNP-2 ER TABLE 2.3-19f (sheet 6 of 8)

FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 FOR 33 FT LEVEL (TEMPERATURE CHANGE LESS THAN 4.4 AND GREATER THAN OR EQUAL 1.6 DEGREES F PER 200 FT)

.. .- .. .... ~~

SPEED CLAS$(HPH)

NNE, C a t.M 13 c.7 8 12 13 18 19-24. . 25?uP._ uNKNO .. 70T alt .__

0 30 28 3 n 0 0 NE 0 65 o 15 20 2 ENE o 21 3 0 ...0.. .1 'at ~

16 2 0 0 0 3 c2

.. E.. _ .... 0..... 19 .. 6 .0 0 0 0 0. 25 ESE 0 16 16 0 0 0 0

, 0 32 SE O 17 40 to 0 0 0. . 0. . 67_..

1.

35E o 17 76 36 0 0 0 130

$ o 20 63 c7 9 ~ 0 '5~

SSW 0 20 66 0' '144 ~'

35 8 0 0 0 g31

.- . 3 W . . 0... _20 ..32.. _.9 3 0 0 1 65 W3W 0 29 35 7 0 0 0 0 W 71

_ 0 20 32 2 6 . -.- . 2. . 0' 0._ 5.

WNW 65____

0 33 39 43 1 0 .0 2 118 NW NNW 0 34 60 25. .._.l... ..0 -

0 .. 3 .127 0 31 76 8 0 0 0 1 116 9 - 0 36. 33 1 0 o- o o n VAR 0 22 7 0 0 0 0 0 29

. CALM o 0 0 ._ .. 0 __0 _ 0 0 _0 . 0.

UNKND 0 t c 0 0 0 0 to 15 TOTAL.. 0 807 655 .254 23

.0 0 31 1375 flote: The speed class headings represent the following wind speeds. .

Calm: 0 to 0. 6 c;:.

1-3: 0.23 to 3.49 mph 4-7: 3.50 to 7.49 mph 8-12: 7.50 to 12.49 mph

( . . . . . . . 13-18: 12.50 to 18.49 mph ~~~

l 19-24: 18.50 to 24.49 mph l .

. . _ . . . . . 25-up: 24.50 mph and up l

l l

l l

9

WNP-2 ER TABLE 2.3-19g N

(sheet 7 of 8)

FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 FOR 33 FT LEVEL (TEMPERATURE CHANGE GREATER THAN OR EQUAL 4.4 DEGREES F PER 200 FT)

SPEED CLASS (mph)

CALM 1-3 4-7 6-12. 13 16 .19-24. 25.vuP UNKNO... TOTAL.

NNE. 0 53 35  ! 0 0 0 0 89 HE 0 69 29 2 . . . .. 0 . _. . . 0 _. . 0- . 0.._ _.10 0 ENE 0 47 22 0 0 0 0 0 69

_ .. E . _ 0 44_ _-.b _ ._0 Q n o o En ESE 0 36 9 0 0 0 c5 0 0 5L - 0 15 2i , . 0 .. . . 0 . 0 .__ 0. _ . 0 ..._.-. 3 6 .

35E o la c6 18 0 0 0 2 80 5 0 35W 21 51 . 01. _ 0. 0 0-2 -115_

0 18 23 12 1 0 0 0 54

_.5d. 0= 27..._.19. a o a D 1 5i wSd 0 21 13 4 0 0 0 39 1

. '4 . 0 13 11 2.. .._ O . 0. 0 0 26 wNd 0 25 19 3 0 0 0 1 48 NW . 0 44 53 . 13 . 0 ....0 0 1 111.

NHW 0 52 58 3 0 0 gg3 0 0

_..N_ __ 0.. _63 39 1 0 0 0 o 103 YA2 0 23 3 0 0 0 0 0 2 t, CALM 0 0 0 . 0 .. . ._ . 0 . . _.. O. --D ._ . 0 _.0 UNKNO 0 0 1 0 0 0 0 to 11 107AL o 589 458 194 _. .l. .0. _..0_. ....IO 1170._ __.

(~~ .

k .

Note: The speed class headings represent _ _ _ _ . . . . . ___

the following wind speeds.

Calm: 0 to 0.22 mph - - - - - - . -

1-3: 0.23 to 3.49 mph

.. .. _....... ....- 4 7: 3.50 to 7.49 mph 8 12: 7.50 to 12.49 mph i . . - . - . ..

13-18: 12.50 to 18.49 mph -=

19-24: 18.50 to 24.49 mph

• _ . . . . . . . . . . . . . .- 25.up: 24.50 mph and up --..___

O

WNP-2 ER TABLE 2.3-19h (sheet 8 of 8)

FREQUENCY OF OCCURRENCE, WIND DIRECTION VS SPEED FROM 4/74 THROUGH 3/75 AT WPPSS2 FOR 33 FT LEVEL (TEMPERATURE CHANGE IN DEGREES F PER 200 FT UNKNOWN)

SPEED CLASS (MPH)

. CALM 13 4=7 6 12.. 13'18._19-24 _25,UE _UNKNO.__TQIAL?

NNE 0 0 3 0 0 0 0 0 3

. NE 0 1 . 3 ... . . 1. __ . _ 0 . - _0

. 0 0- 5 ENE O o 2 ' 0 0 0 0 0 2

.. ...E -. 0... __.2 .3 - n 0 0 -Q a- 5 ESE D 1 1 0 0 0 0 0 2 SE 3 0 1 - 1 _. 0:-_.0--- 0--. 0.._.._.2.

53E 0 1 2 0 0 0 0 0 3

. 5 0 0 0 -.. 2..--. 0... .O. 0 0 _2

. SSN 0 0 0 2 1 0 0 0 3 SW_. _0- 0 0 n o e O n n W5N 0 ~0 1 0 0 0 0 0 t

. W 0 0 0 . 0 . _.. 0. .0. 0 Q. 0 WNW 0 0 0 0 0 0 0 .0 0 NW . 0 0 3 1 .. . . .2 ....I_ 0 0 7 NNW 0 1 0 0 0 0 0 0 1 N .0.. 1 .0 1 0 m o o  ?

VAR 0 0 0 0 0 0 0 0 0

. CALM 0 0 0. . 0 . _. . 0. . 0 .0 0._ 0 UNKNO 0 3 7 4 3 0 0 214 231

2. T0TAL . 0 10 26 . 12..._ . 6.. ... 1 0 214 269 Note: The speed class headings represent the following wind speeds.

Calm: 0 to 0.22 mph - -

1-3 : 0.21 to 3.49 mph 47: 3.50 to 7.49 mph 8 12: 7.50 to 12.49 mph

. - - . 13 18: 12.50 to 10.49 mph

{ 19 24: 18.50 to 24.49 mph

_ _ . . . . . . . . . . .. 25.up: 24.50 mph and up

=. ...e..e.

O

O O O TABLE 2.3-20 COMPARISON OF MONTHLY AVERAGE AND EXTREMES OF HOURLY AVERAGE AIR TEMPERATURES WNP-2 (1) HMS (3')

One Year of Data One Year of Data Long-Term Summary (2)

Average Max Min Average Average Max Min Jan 32.3 55.4 18.1 32.0 29.4 66 -23 Feb 33.8 60.4 12.8 33.6 36.2 71 -23 Mar 41.9 64.8 21.8 42.0 45.2 03 26 Apr 52.2 76.2 35.1 52.5 53.2 95 12 May 57.4 84.8 36.9 57.9 61.8 103 28 Jun 72.5 103.5 45.9 73.3 69.4 110 33 Jul 73.6 104.5 49.6 74.8 76.4 115 41 $,

Aug 74.7 103.8 50.6 76.3 74.2 113 40 N Sep 66.9 91.5 45.9 68.3 65.2 102 25 Oct 51.7 80.8 31.7 52.0 53.1 90 6 Nov 42.1 60.5 24.7 42.1 40.0 73 -1 Dec 33.8 59.6 20.8 35.7 32.6 68 -27 YEAR 53.5 104.5 12.8 53.5 53.1 115 -27

(*F)

(1) One year of data at 7', 4/74 to 3/75. All values are hourly averages.

(2) Surface air temperature observations at Hanford townsite and HMS for period 1912-1970. Maximums and minimums are observed values.

WNP-2 ER TABLE 2.3-21 COMPARISON OF MONTHLY AVERAGES OF WET BULB TEMPERATURES WNP-2 HMS HMS One Year (II One Year f Long Term (3)

Jan 30.3 30.0 27.9 Feb 3C 2 31.0 33.6 Mar 36.2 36.0 37.3 Apr 44.7 43.9 42.8 May 47.2 46.5 49.1 Jun 56.0 54.5 54.5 Jul 57.4 41.0 42.3 Aug 58.0 43.2 42.8 Sep 52.6 52.0 52.6 Oct 43.8 42.0 45.4 Nov 39.3 38.0 36.4 Dec 34.5 33.0 31.2 YEAR 44.3 43.4 43.8

( F)

(1) One year of WNP-2 data at 33', 4/74 to 3/75.

(2) One year of HMS data at 3', 4/74 to 3/75.

(3) 20 years of HMS data at 3', 1950-1970.

O

O O O i

i TABLE 2.3-22a FREQUENCY OF OCCURRENCE OF WET BULB VALUES A FUNCTION OF TIME OF DAY BASED ON WNP-2 SITE DATA 4/74 - 3/75 (Wet Bulb intervals are given in the left column in *F.)

TIME OF DAY '

i 1 2 3 4 5 6 7 8 9 to 11 12 13

) =20 0 0 0 0 0 0 0 0 0 0 0 0 0 15 0 0 0 0 0 0 0 0 0 0 0 0 0

• t5-10 0 0 f 0 C 0 0 0 0 0 0 0 0 -

AL* 5 0 0 , 0 0 0 0 0 0 0 0 0 3

-5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5 0 0 0 0 0 0 0 0 0 0 0 0 0 1

5 to O C 0 0 0 0 0 0 0 0 0 0 0 1

13 15 2 2 2 1 1 1 1 2 1 1 1 0 0 15 20 1 2 o 7 9 8 9 6 .5 3- 3__ 3 ..3 2J 25 14 15 1A to 14 16 18 15 9 8 8 6 6 2 ') 30 35 33 35 42 41 43 41 34 30 24 14 10 7 g i; 35 d4 51 46 47 50 45 42 37 32 33 39 43 33 MZ i 35 40 54 51 59 57 oO 67 oo 51 ao 41 45 39 50 %3 t 40 45 71 73 65 65 61 Sh 53 55 52 51 52 50 45 h

! ub 50 43 ea 52 54 51 47 51.__u7__ 30 _ 49__51._ 54. 52.

50 55 4A 50 40 c" 51 51 38 39 43 42 39 44 49 5% $0 39 33 27 23 19 23 39 41 3h 36 ag 50 50 60 e5 8 6 5 3 4 3 8 16 23 33 39 43 46

~5 7C 0 1 0 0 0 0 0 0 3 5 6 a 12 70 75 0 0 0 0 0 0 0 0 0 0 0 0 0 75 60 0 0 0 0 .c _ 0_._.3 -.__.D.._. 0__..0___ 0._-.0 _ _.Q_

90 0 0 0 0 0 0 0 0 0 0 0 0 0 115<N0 4 4 4 4 5 5 5 to 48 37 19 15 12

] TJOL 365 3e5 365 365 365 3e5 36's 365 365 365 365 365 365 4

~

AVERAGE FOR H0UR

,41.658 40.579 40.262 42.287 45,282 46.998 i 41.852 40.930 40.16e 41.040 43.750 46.103 4 '.6o2

TABLE 2.3-22b (sheet 2 of 2)

TIME OF DAY le 15 16 17 16 19 20 21 22 23 24 TOTAL

=20 0 0 0 0 0 0 0 0 0 0 0 0 15 0 0 0 o o 0 0 0 0 0 0 0 0 0 0

-15*10 0 0 0 0 0 0 0 0 0

-1C= 5 0 0 0 0 0 0 0 0 0 0 0 0

-5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5 0 0 0 0 0 0 0 0 0 0 0 0 5 to 0 0 0 0 0 0 0 0 0 0 0 0 13 15 0 0 0 0 1 1 1 1 2 2 2 25 4 2 2 SS 15 20 3 2 2 2 1 1 3 1 23 25 6 e S 7 8 10

• 8 10 9 12 251 25 30 7 7 19 11 14 16 le 23 20 35 39 597 33 35 26 24 26 31 35 el 66 47 55 s7 su ios 35 30 49 51 50 50 52 e6 Gn 88 de 56 u9 1220 00 45 53 51 51 66 ou ce 50 e2 56 $7 o5 153o gh uS 50 _ 50 _ $2 .se. s7 _ 89 52 55 43 52 .d4 52 1178 cm 89 55 48 49 64 112a I 50 55 49 52 51 51 43 42 h) 55 to 52 47 e6 au 51 60 39 45 4e u8 4e 974 60 65 a7 45 du 45 a4 41 35 22 19 11 9 601 a5 yc 15 21 24 23 17 la 2 *- 1 - 1 0 164 70 75 0 0 0 0 0 0 J u 0 0 C C 75 60 . .._0. ___Q _._.0_ _ 0 0 _ 0 . ._ 0_ G 0.. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 90 UN<NO 8 7 6 6 6 3 3 3 4 4 4 234 TufAL 365 365 365 365 305 305 365 365 365 365 365 8760

~

AVERAGE F'lR HDUd' 48.166 48.279 47.205 45.191 43.472 42.290 u8.430 47.950 ce,196 e4.272 42.846 44.266 O O O

~..~~~w.

r .

• s y I

TABLE 2.3-23 MONTHLY AVERAGES OF PSYCHROMETRIC .

DATA BASED ON PERIOD OF RECORD 1950-70 AVERAGES t Jan Feb Mar Apr_ 3ay_ Jun Jul Aug_ Seg , Oct Nov Dec YEAR Dry Bulb 30.3 37.5 44.0 52.5 61.8 69.9 77.5 75.3 67.0 53.2 40.1 33.4 53.5 i Net Bulb 27.9 33.6 37.3 42.8 49.1 54.5 57.9 57.3 52.6 45.4 36.4 31.2 43.8 Rel. Hum. 76.0 69.7 55.0 46.4 41.8 39.4 31.5 34.9 39.9 57.7 72.6 80.8 53.8 Dewpoint 23.2 27.4 27.3 30.4 36.0 41.2 42.3 42.8 39.5 36.9 31.1 27.5 33.8 DRY BULB MONTHLY AVERAGE EXTREMES l Highest 43.0 44.0 48.7 56.2 68.7 75.5 82.8 82.5 72.0 59.1 45.8 38.8 56.3  ;

Year 1953 1958 1963 1956 1958 1969 1960 1967 1967 2952 1954 1953 1958  !

Lowest 12.9 25.8 39.6 48.3 57.2 64.2 73.2 70.6 61.6 50.3 32.3 26.5 51.0 Year 1959 1956 1955 1955 1962 1953 1963 1964 1970 1968 1955 1964 1955+

WET BULB Dd MONTHLY AVESAGE EX7PEMES O

^

Hiqhest 39.3 40.7 40.8 45.1 54.6 58.6 61.2 61.1 56.5 47.7 42.3 35.8 46.5 - hJ Year 1953 1958 1968 1962 1953 1958 1958 1961 1963 1962 1954 1966 1958

'f Lowest 12.4 23.4 32.9 39.3 45.4 51.4 55.6 54.9 48.3 42.4 29.6 25.0 41.8 Year 1950 1956 1955 1955 1959 1354 1954 1964 1970 1960 1955 1964 1955 REL. FUM.

MONTHLY AVERAGE TXTREMES Highest 89.0 87.0 66.0 64.0 *52.0 54.0 40.0 44.0 55.0 74.0 E0.0 90.0 58.0 Yaar 1960 1963 1950 1963 1962+ 1950 1955 1968 1959 1962 1956 1950 1950+

Lowest 60.0 54.0 44,0 37.0 31.0 34.0 22.0 24.0 34.0 42.0 64.0 69.0 +9.0 Year 1963 1967 1965 1966 1966 1960 1959 1967 1952 1952 1963+ 1968 1967 DENPOINT MONTHLY AVERAGE EXTREMES Htqhest 34.4 36.7 34.0 37.1 43.8 47.5 46.6 46.9 45.t 43 5 3C.3 34.3 37.7 Year 1953 1958 1961 1953 1957 1958 1958 1961 1963 1962 1954 1950 1958 Lowest 6.5 17.3 20.3 26.2 30.4 37.5 35.4 38.4 33.0 32.1 24.0 21.0 31.5 Year 1950 1956 1965+ 1955 19f4 1954 -1959 - 1955 1970 1970 1959 1951 1955

+ Also in earlier years

• Although not included in these tables, an average of 631 was recorded in 1943

TABLE 2.3-24 MISCELLANEOUS SNOWFALL STATISTICS: 1946 TIIROUGII 1970 AVERAGE NUMBER OF DAYS WITH DEPTH 1.T 0400 PST Oct Nov Dec Jan reb Mar Season 1" or More 0 1 5 10 5

• 21 3" or More 0 1 2 5 3 0 11 6" or More 0 0 1 3 1 0 5 12* or More 0 0 *

• 0 0

• RECORD GREATEST NUMBER OF DAYS WITH DEPTH AT 0400 PST 1" or More 0 (1955) 11 (1964+) 17 (1969) 31 (1950) 17 (1951) 3 (1955-56) 54 3" or More 0 (1955) 10 (1955) 14 (1969) 23 (1950) 16 0 (1949-50) 33 6" or More C 9 (1964) 12 (1969+) 8 (1965) 23 0 (1949-50) 23 12" or More 0 0 (1964) 4 M (1969) 1 0 0 (1964-65) 4 w-1 PTCORD GREATEST DEPTH (1957) 0.3 (1946) 5.1 (1964) 12.1 (1969) 12.0 (1969) 10.0 t' 357) 2.3 (Dec 1964) 12.1 GREATEST IN 24 HOURS (1957) 0.3 (1955) 4.8 (1965) 5.4 (1954) 7.1 (1959) 5.2 (1957+) 2.2 (Jan 1954) 7.1 AVERAGE PERCENT OF WATER EQUIVALENT OF ALL PRECIPITATION

< 2 14 46 48 29 14 26 l

() Denotes year of occurrence

+ Denotes ale in earlier ycars

Denotes letA than 1/? day l

l t

O O O

g.s 1

/

) g)

~a

(%,/ ,

TABLE 2.3-25 AVERAGE RETURN PERIOD (R) AND EXISTING RECORD (ER) FOR VARIOUS PRECIPITATION AMOUNTS AND INTENSITY DURING SPECIFIED TIME PERIODS AT HANFORD (BASED ON EXTREME VALUE ANALYSIS OF 1947-1969 RECORDS 1 AMOUNT (INCHES) INTENSITY (INCHES PER HOUR)

TIME PERIOD TIME PERIOD R (Years) 20 Min 60 Min 2 Hrs 3 Hrs 6 Hrc 12 Hrs 24 Hrs 20 tiin 60 Min 2 Hrs 3 Hrs 6 Hrs 12 Hrs 24 Hrs 2 0.16 0.26 0.30 0.36 0.48 0.62 0.72 0.49 0.26 0.15 0.12 0.08 0.052 0.030 5 0.24 0.40 0.48 b.55 0.77 0.95 1.06 0.72 0.40 0.24 0.18 0.13 0.079 0.044 10 0.37 0.50 0.59 0.67 0.96 1.17 1.28 1.1 0.50 0.30 0.22 0.16 0.098 0.053 25 0.47 0.62 0.74 0.83 1.21 1.45 1.56 1.4 0.62 0.37 0.28 0.20 0.121 0.065 50 0.53 0.72 0.85 0.96 1.40 1.66 1.77 1.6 0.72 0.42 0.32 0.23 0.138 0.074 100 0.60 0.81 0.96 1.07 1.59 1.87 1.99 1.8 0.81 0.48 0.36 0.27 0.156 0.083 250 0.68 0.93 1.11 1.22 1.82 2.13 2.26 2.0 0.93 0.55 0.41 0.30 0.177 0.094 2C rn 2 500 0.73 1.02 1.22 1.33 2.00 2.34 2.47 2.2 1.02 0.61 0.44 0.33 0.195 0.103 ym '

1000 0.80 1.11 1.33 1.45 2.20 2.55 2.63 2.4 1.11 0.67 0.48 0.37 0.212 0.112 b ER 0.59 0.88 1.08 1.68 1.88 1.91

• 0.59 0.44 0.36 0.28 0.157 0.080 6/12 10/1 10/1 10/1-2 10/1-2 10/1-2 6/12 10/1 10/1 10/1-2 10/1-2 10/1-2 DATE --

1969 1957 1957 1957 1957 1957 1969 1957 1957 1957 1957 1957 No records have been kept for time periods of less than 60 minutes. However, the rain gage chart for 6-12-69 shows that 0.55 inch occurred during a 20-minute period from 1835 to 1855 PST. An additional 0.04 inch occurred between 1855 and 1910 to account for the record 60-minute amount of 0.59 inch.

WNP-2 ER TABLE 2.3-26a WNP-2 ONSITE JOINT FREQUENCY DISTRIBUTION OF WINDS FOR RAIN INTENSITY CLASSES, RAIN INTENSITY GREATER THAN OR EQUAL TO .016 INCHES PER HOUR SPEED CLASS (MPH)

CALM j.3 47 8 12 13 18 19 20 25-u" UNKNO TOTAL NsE O 2 2 0 0 0 0 0 a NE 0 2 3 0 0 0 0 0 5 E '. i 0 2 1 0 0 0 0 0 3 t 0 - 1 - - ~~ - n -- . - - - -- 0 -- . 0 -- _ 0 - -- % - --

ESE 0 7 2 0 0 0 0 0 9 si 0 1 1 2 1 0 0 0 5 SSL 0 a 6 6 4 1 0 0 21 3 0 3 3 5 0 0 0 0 11

$sa 0 3 3 4 3 1 0 0 14 Sa 0 1 ----- 3 --- -- 0 0 - - a5d 0 1 2 1 0 1 0 0 5 d 0 0 3 2 0 0 1 0 6 a%d 0 0 5 7 0 0 0 0 12 Nd 0 5 10 5 1 0 0 0 21 NNd 0 2 10 2 0 0 0 0 14

_ N .

0 0-- 1 0 0- 0 0 0- -

va' 0 2 1 0 0 0 0 0 3 CALM 0 0 0 0 0 0 0 0 0

'"4 ' '. 0 0 0 0 0 0 0 0 1 1 total 0 36 60 3B 10 3 1 1 149 TABLE 2.3-26b WNP-2 ONSITE JOINT FREQUENCY DISTRIBUTION OF WINDS FOR RAIN INTENSITY CLASSES, RAIN INTENSITY GREATER THAN OR EQUAL TO 0.50 INCHES PER HOUR SPEED CLASS (MPH)

CALM t-3 c.7 8-12 13-18 19-24 25-UP UNKNO TOTAL NNE O 1 1 0 0 0 0 0 2

^

NE O 1 0 0 0 0 0 1 ENE O 0 0 0 0 0 0 0 0 t _ 0 _ - 0 _ __ 0 -. o 0 --O 0 -0 0--

1 ESE O O O 0 0 0 0 0 0 55 0 0 0 1 0 0 0 0 1 l SSt 0 0 0 3 2 0 0 0 5 5 0 0 0 0 0 0 0 0 0 Sia 0 0 0 2 0 0 0 0 2 sa -- - C 0 0 0 0 0 0 0-a5d 0 0 0 1 0 0 0 0 1 a 0 0 0 1---- 0 0 - - -- 0 - 0 -

1---

>"a 0 0 2 0 0 0 0 0 2 Nd 0 0 1 3 0 - 0 0 0 6

'sa

. 0 0 1 1 0 0 0 0 2 l

4 - -- 0 -- 0 0 0 0 0 0 0 0-VAA 0 0 0 0 0 0 0 0 0 Cat- 0 0 - 0 - -- . . -. 0 - -0.___. 0 ----- - 0 - - - - - 0

v. < '. 0 0 0 0 0 0 0 0 0 0 TOTAL 0 2 5 12 2 - 0 0 0 21 l

WNP-2 ER TABLE 2.3-26c (sheet 2 ot 3)

WNP-2 ONSITE JOINT FREQUENCY DISTRIBUTION OF WINDS FOR RAIN INTENSITY CLASSES, RAIN INTENSITY GREATER THAN OR EQUAL TO . 100 INCHES PER HOUR SPEED CL ASS (MP68)

CALM  !=3 u-7 8-12 13-18 19-24 25.uP UNKNO TOTAL NNE 0 0 0 0 0 0 0 0 0 AE O O O O ,0 0 0 0 0 ENE 0 0 0 0 0 0 0 0 0 t 0 --

0- -0 0 -0 -0 0 'O 0-15E 0 0 0 0 0 0 0 0 0 O! 0 0 0 0 0 0 0 0 0 SSL 0 0 0 0 0 0 0 0 0 5 0 0 0 0 0 0 0 0 0

$$a 0 0 0 0 0 0 0 0 0

-- Sa 0 --- O O O 0 0 0 0 0-mSa 0 0 0 0 0 0 0 0 0 w o 0 0 0 0 -- 0 0 0 .0 -

asa 0 0 0 0 0 0 0 0 0 Na 0 0 0 0 0 0 0 0 0 NN= 0 0 0 0 0 0 0 0 0

. N ..__.O_ 0 0 0 0 0 0 0 0-VAW 0 0 0 0 0 0 0 0 0 1LM 0 0 0 0-- -0 - - - - - 0 -- 0 -

0 w3 0 0 0 0 0 0 0 0 0 TCfAL 0 0 - 0 - 0 -

0 --- 0- 0 0 O'- TABLE 2.3-26d WNP-2 ONSITE JOINT FREQUENCY DISTRIBUTION OF WINDS FOR RAIN INTENSITY CLASSES, RAIN INTENSITY GREATER THAN OR EQUAL TO . 016 INCHES PER HOUR SPEED CLASS (MPH)

CALM 13 c.7 E-12 13 18 19-2a 25-uP UNKNO Tot &L NNE O 0 0 0 0 0 0 0 0 NE 0 0 0 0 0 0 0 0 0 ENE o 0 0 0 0 0 0 0 0 t o .. o 0 0 0 -- -- O 0- 0-

. ESE C 0 0 0 0 0 0 0 0 SE 0 0 0 0 0 0 0 0 0 SSE C 0 0 0 0 0 0 0 0 d 0 0 0 0 0 0 0 0 0 SSd 0 0 0 0 0 0 0 0 Sm 0 - 0 0 0 S. 0 0 0 0-a5a 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 - O a'a 0 0 0 0 0 0 0 0 0 Na' O 0 0 0 0 0 0 0 0 NN" 0 0 0 0 0 0 0 0 0

. ta . . . _ _ . O _. 0 -- O 0 0 0- 0 0 0-VAR 0 0 0 0 0 0 0 0 0 CAL" 0 0 0 0 0 0 0 0 0 UN<NG 0 0 0 0 0 0 0 0 0 10fAL 0 0 0 0 0 0 0 0 0

..,,-.------...--.n,,--, -

_ , - - - - - , . - - , - . , . , - - , , . . - _ . , - ,, --..n., _ _ - - ,. . - - - - - - , , , , - , ,

WNP-2 ER TABLE 2.3-26e (sheet 3 of 3)

WNP-2 ONSITE JOINT FREQUENCY DISTRIBUTION OF WINDS FOR RAIN INTENSITY CLASSES, RAIN INTENSITY OREATER THAN OR EQUAL TO .500 INCHES PER HOUR SPEED CLASS (HPH)

CALM 13 4=7 8-12 13-18 19-2a 25-UP UN4NO TOTAL NNE 0 0 0 0 0 0 0 0 0

'E O O 0 0 0 0 0 0 0 E *. E 0 0 0 0 0 0 0 0 0 E o o _. . - 0 . ._ _ 0 O _ __ o _ - _ ._ 0 __ . . O___ c __

E .a i 0 0 0 0 0 0 0 0 0 SE O 0 0 0 0 0 0 0 0

$$E o 0 0 0 1 0 0 0 1 5 0 0 0 0 0 0 0 0 0 SSa 0 0 0 0 0 0 0 0 0

- c. o _ 0 __o 0 0 -

0 -- 0 0-asa 0 0 0 0 0 0 0 0 0 d 0 0 0 0 -

0 0 0 0 0

• Na 0 0 1 0 0 0 0 0 1 Sa 0 0 0 0 0 0 0 0 0 NNa 0 0 0 1 0 0 0 0 1

_ N .- 0 -- 0 0 0 0 0 .0 0 0-VAR 0 0 0 0 0 0 0 0 0 CAL" 0 0 0 0 0 0 0 0 0 L' N '. s 0 0 0 0 0 0 0 0 0 0 T3faL 0 0 t i 1 0 3 0 3 O

O

WNP-2 fN y ER TABLE 2.3-27 MONTHLY AND ANNUAL PREVAILING DIRECTIONS, AVERAGE SPEEDS, AND PEAK GUSTS: 1945-1970 AT HMS (50 foot level) ,

PREVIOUS AVEMGE HIGHEST LOWEST PEAK GUST MONTH DENS I""f SPEED AVERAGE YEAR AVERAGE YEAR SPEED DENSITY YEAR NW 6.4 9.6* 1953 3.1 1955 65 " S 1967 Jan 7.0 9.4 1961 4.6 1963 63 SW 1965 Feb NW WNW 3. 4 10.7 1964 5.9 1958 70 SW 1956 Mar W:3W 9.0 11.1 1959 7.4 1958 60 WSW 1969 Apr-3.3 10.5 1965+ 5.3 1957 71 SSW 1948 May WN 1 WNW 9. 2 10.7 1949 7.7 1950+ 72 SW 1957 Jun WNW 3.6 9.6 1963 6.9 1955 55 WSW 1968 Jul Wim 3.0 9.1 1946 6.0 1956 66 SW 1961 Aug WNW 7.5 9.2 1961 5.4 1957 65 SSW 1953 Sep hT4 6.7 9.1 1946 4.4 1952 63 SSW 1950 Get 6.2 7.9 1945 2.9 1956 54 SSW 1949 Nov NW 6.0 9.3 1969 3.9 1963+ 71 SW 1955 Dec NW

3. 3 1968+ 6.3 1957 72 " SW 1957 YI*AR WNW 7.6 (Jun)

• Ine average speed for January, 1972, das 10.3 =ph.

" On January 11, 1972, 1 new all-time, record peak gust of 80 mph was established.

L.)

e c, r wr- e--c yg-,-w- ,--.y--- - , - m,--, e, --,--w,--<,,=,----e- --y..m.-+ ..w+,w.., -w- ,,--e m-,,,w.. - --.-,-,-ei

TABLE 2.3-28 a

M0flTHLY MEAtlS OF DAILY MIXING HEIGilT AtlD AVERAGE WIfl0 SPEED Average Daily Minimum Average Daily Maximum (Morning) (Afternoon) tieters Meters /sec Meters Meters /sec Jariuary 302 4.8 295 4.6 February 341 4.8 658 5.3 March 388 5.6 1331 5.6 April 350 5.4 1966 6.7 May 288 4.7 2243 5.9 June 263 4.3 2440 5.7 July 208 3.9 2703 5.2 August 235 4.1 2439 4.8 September 189 3.6 1922 4.9 October 192 3.8 1076 5.2 flovember 300 4.3 505 4.6 YN December 367 4.5 316 4.6

• < g U$

ae"

a. Spokane, WA, Radisonde Data, Period of Record 1/60 - 12/64.

S 9 e

l N

O l

/

/ 1 W -

E 0 1 2 3 4 5 6 7 i . _

l l

WIND SPEED GROUPS (MPH)  :

0-3 LINE 4-7 SHADE M

8-12 OPEN 13 - 18 SHADE s 19 - 24 OPEN 25 UP SHADE Amendment 4. October 1930 0 WASHINGTON PUBLIC POWER SUPPLY SYSTEM WPPSS NUCLEAR PROJECT NO. 2 Environmental Report WIND ROSE FOR WNP-2 FOR 4-74 TO 3-75 AT THE 7 FT LEVEL

, ' FIG. 2. 3- 1

l 4

O

=

l l

W l

O -=-

a i

0 1 2 3 4 5 6 7 1

WIND SPEED GROUPS (MPH) 0-3 LINE 4-7 SHADE -

8 - 12 OPEN 13-18 SHADE 19 - 24 OPEN 25 UP SHADE O WASHINGTON PUBLIC POWER SUPPLY SYSTEM WPPSS NUCLEAR PROJECT NO. 2 WIND ROSE FOR WNP-2 FOR 4-74 TO 3-75 AT THE 33 FT LEVEL Environmental Report FIG. 2.3-2

i >

I l

O l

/

N W E L _-,

J 1

O 0 1 2 3 4 5 6 7 1 -

o l

WIND SPEED GROUPS (MPH) 0-3 LINE I 4-7 SHADE 8 - 12 OPEN 13 - 18 SHADE l l 19 - 24 OPEN 25 UP SHADE s Amendment 4, October 1980 WASHINGTON PUBLIC POWER SUPPLY SYSTEM WIND ROSE FOR WNP-2 FOR WPPSS NUCLEAR PROJECT NO. 2 4-74 TO 3-75 AT 245 FT LEVEL Environmental Report

. ' FIG. 2.3-3

~ . _ _ _ _ . _- _ _ _ . . . - . _ _ _ . . . - - . . - _ . - - -. . . _ . . . _ _

I I

O PtRC[NT SCALI g WIND SP((D CROUP 5 (MPHI j x 0-3 LINE $ 'h.

a.7 5HADE + .' 7 8 - 12 OPEN g , -d 9 13 - 18 19 74 5HADt OPEN 9

IEZ 4 '

25 UP SHADE ,# , y N n,

// .

\

STABILITY DEFINITION OF AT IS I200 f t J UN5fABLI: AT < -1.5 **

N[UTRAL: -0.5 > AT > - 1.5 ,

MODERAT[LY STAB LI: 3.5 > AT > -0.5 VERY STABLE: AT>3.5 UNSTABLE 1 NEUTRAL

~

x

\

g O

CN -

I

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N 'N k-// /

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MODERATELY VERY f/  ;

STABLE ,'  ;

STABLE

'\ \

/ \l h s/

E O WASHINGTON PUBLIC POWER SUPPLY SYSTEM WPPSS NUCLEAR PROJECT NO. 2 WIND ROSES FOR HANFORD STABILITY CLASSES AT WNP-2 FOR 4-74 TO 3-75 Environmental Report AT THE 33 FT LEVEL FIG. 2.3-4

+ e 4 \

j' 9

k '

, 44 1*

g um : - . G T1  :

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gg , .T  ;

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UNSTABif ai < -1.5 l 4 NEUTRA L

-0.5 > AT 2 1.5

-N. MODERATELY 51A8tf 3.5 > a! 2 -0.5 Vf RY 5 FABLE. AT 2 3.5

%x\ N

\ y 9

0 l l 0 25 05 I

P[wl(NT SC AL [

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1 i

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[M2 i aIND $Pi[0 CR P5iMPH All 51 Akillfib 0 1 2 3 4 5 PiRC f NT F fW515f[N((

• ( All FOC ilt 5f APitiflE5 WIND ROSES AS A FUNCTION OF HANFORD STABILITV Min Pop A T.T. STABILITTF9 OF HMS BASED ON WIMDS AT 200 FT WASHINGTON PUBLIC POWER SUPPLY SYSTEM AND AIR TEMPERATURE STABILITIES WPPSS NUCLEAR PROJECT NO. 2 BE N EN 3 FT AND 200 FT FOR M Environmental Report ERIOD l E THROUGH W O FIG. 2.3-5 l

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r] t

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l SURFACE WIND ROSES FOR VARIOUS LOCA- )

SHINGTON PUBLIC POWER SUPPLY SYSTEM TIONS ON AND SURROUNDING THE HANFORD WPPSS NUCLEAR PROJECT NO. 2 SITE BASED ON FIVE-YEAR AVERAGES Environmental Report (1952-1956). SPEEDS ARE GIVEN IN MILES PER HOUR FIG. 2.3-6 l I

O MONTHLY AND ANNU AL HOURLY AVE R AGE S OF DRY BULB ID.B.) AND WE T BULB 4W.B. ) TEMPE R A TURE REL ATIVI HUMIDITY IR. H. l. AND TEMPER ATURE OF THE DEW POINT ID.P.

41951 -1910 e 90 90 JANUARY 80 .........-- -- .. R. H. - FEBRUARY

' 80 - -

,,....... . g, 9_

10 10 60 60 -

50 So o 40 - W.B. TE VP. D. B.

40 2 -~~~

30 TE MP. D. B.

[ {_____,,"'D.B. ------------_.

' ~ ~ - -

_ - _ _. _ _ __ -_~~~ - --___

---

- _-. ~ ~ - ~w.B. ~--- _

10 10 0

0 02 D4 06 08 10 12 14 16 18 20 22 24 02 04 06 08 10 !? 14 16 18 20 22 24 PST PST 90 90 MARCH APRIL 80 80 -

70 10 -

60 R. H.

,. ~~,..' 60 ~~ .. *' '

TEMP. D. B.

R. H.

50 50 -

TEMP D.B.

'. s' o .'N~ ----t's-~.

W.B.

40

1. ~~

' ....... Q 40 ~~~ _,/ .

- m ' ~~

' - - - " ~ ~ ~ - !'Ja'r ; ~J : - - - - - - -

30 - D.B. 30

- - - . , . - - - - - - - - - - - - - 9 p.

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1 WNP-2 ER-OL O

v 2.4 HYDROLOGY The WNP-2 site is located at an elevation of 441 f t above mean sea level (MSL) about 3 miles west of the Columbia River at River Mile 351.75 and about 8 miles northeast of the Yakima River at Horn Rapids Dam.

The major waters that could be affected or influenced by plant oper-ation are the Columbia River and the groundwaters of the site and the immediate environs.

2.4.1 Surf ace Water 2.4.1.1 Columbia River Hydroloqy and Physical Characteristics The Columbia River and its tributaries are the dominant water systems in the Pacific Northwest region (Figure 2.4-1). The main stem of the Columbia River originates at Columbia Lake on the west slope of the Canadian Rockies and flows into the Pacific Ocean near Astoria, Oregon. The river drains a total area of approximately 258,000 square miles in Canada, Washington, Oregon, Idaho, Montana, Utah, Wyoming, and Nevada. The Columbia River drpigage upstream of the site is

, approximately 96,000 square miles.lli Since a large part of the Columbia River originates as runoff caused by snowmelt, high dis-(V )

charges are experienced in late spring or early summer while low discharges occur in winter.

Numerous dams and reservoirs have been constructed in the Columbia River Basin for power production, irrigation, navigation, flood control, and recreation. Table 2.4-1 lists the major Columbia River tributaries and main stem dgms with their location by river mile above the Columbia River mouth.(2; The reservoirs maintain approximately ,

46.7 million acre-ft of agtjve storage of which 37.5 million acre-ft are upstream of the site.(3 1 Arrow and Mica Dams in Canada and Grand Coulee and John Day dams in the United States are the only main stem projects providing sufficient storage for seasonal flow regula-tion, while the remaining main stem dams are run-of-river projects t providing only daily flow control. Much of the activities of flood control and hydroelectric power production are presently contro)4lgd under the Columbia Treaty between Canada and the United States.l 1 The Columbia River is tide-affected from the mouth to Bonneville Dam (River Mile 146). The only other free flowing stretch of the river is the 49-mile reach downstream from Priest Rapids Dam (River Mile 397) to the head (approximately River Mile 348) of the reservoir behind McNary Dam. The proposed Ben Franklin hydroelectric dam site on the O 2.4-1 Amendment 4 O October 1930 .

WNP-2 ER-OL Columbia River is about four miles downstream f rom the WNP-2 site.

The planning studies for this project by the Corps of Engineers were suspended in 1969 and reinitiated in 1978 as part of the development of a management plan for the Hanford reach. While the Benton and 4 Franklin County Public Utility Districts have shown a recurring interest in revitalizing the project, previous studies have disclosed significant economic and environmental impediments.

The flows in the Columbia River in the vicinity of the site are highly regulated by Priest Rapids Dam located approximately 45 river miles upstream from the site. The momentary minimum discharge of the Colum-bia River at Priest Rapids was recorded to be 4120 cfs in 1936 before the construction of Priest Rapids Dam which was built in 1956. After the construction of the dam, the daily river discharge at Priest Rapids has never been below 36,000 cfs, the minimum flow adminis-tratively set by the Federal Power Commission License. The annual le 394.5 (634.8 KM) just average discharge measured at the downstream from the dam is 120,200 cfs.River (

4 Monthly discharges below Priest Rapids Dam for the period 1928 through 1958 adjusted for 1970 conditions are presented in Table 2.4-2.(5)

The listed flow values represent measured flows which were adjusted to reflect flow regulation by dams and diversions existing in 1970.

Discharge duration curves derived from these values are shown in Figure 2.4-2. Because of the regulation, it is estimated that the minimum and maximum mean monthly flows will be 60,000 and 260,000 cfs in the vicinity of the site. The flow in this reach varies not only due to seasonal floods but also due to daily regulation by the power-producing Priest Rapids Dam. Flows during the late summer, f all, and winter may vary f rom a low of 36,000 cfs to as much as 160,000 cfs during a single day.

Tne four largest known floods occurred in 1876, 1894, 1948 and 1956.

The 1894 flood was the maximum known flood on the Columbia River near the proposed site and had an estimated discharge of 740,000 cfs. The 1argest recorded flood occurred in 1948 when a flow of 692,600 cfs was recorded at Hanford. The maximum possible flood (MPF) under present regulated conditions has been estimated by the U.S. Corps of Engineers to be 1,440,000 cfs at Ringold (River Mile 357).

Figure 2.4-3 shows the exceedance frequency for annual momentary peak flows justedbelow Priest for 1970 Rapids Dpm) conditions.t 7 derived from 1913curves The frequency to 1965 forrecords ad-both high and low flows f or the period 1929-1958 adjusted for 1970 conditions are given in Figure 2.5-4. The minimum calculated 7-day average flow between 1960 and 1972 was 46,000 cfs.

2.4-2 Amendment 4 October 1980

l WNP-2 ER-OL b) q River cross sections have been determined for a number of flows.(8) 4 Cross sections between River Miles 351 and 352 are shown in Figure 2.4-5.l91 The river width in the vicinity of the project varies between 1200 and 1800 f t, depending on the flow. Figure 2.4-6 shows the location of the WNP-2 and WNP-1/4 intake / discharge structures and Figure 2.4-7 shows river bottom contours near the outf all. River several flows in the vicinity of the site water  : irf ace are showa profiles in Figure for(10,11,12) Diurnal depth fluctuations 2.4-8. l4 caused by Priest Rapids Dam regulation can be as much five feet. The maximum velocities measured vary from less than three feet per second (fps) to over 11 fps, again depending on the river cross section and flow rate.

WNP-2 is at an elevation of 441 f t above MSL, which is approximately 65 ft above the water surf ace of the maximtsn recorded flood, approx-imately 50 f t above the water surf ace of the maximum possible flood, and approximately 22 f t above the water surf ace elevation estimated l4 for a Grand Coulee Dam f ailure.(10,11,12) The pumphouse for the WNP-2 plant water intake is at an elevatico of 375 ft above MSL, which is the approximate water surface elevation of the maximum recorded fl ood.

A low flow test of the Columbia River conducted on April 10, 1976 controlled the flow to 36,000 cfs for the purpose of verifying river

(~N surf ace elevations. Test results indicate that the river water surf ace

( elevation in the area of the WNP-2 intakes and discharge is approx-imately 341.7 f t MSL instead of the 343.0 f t MSL value determined from previously available data.

2.4.1.2 Columbia River Temoeratures Water temperatures and below the site forof the many Columbia (River)have years.13-18 been Tables recorded 2.4-3 both above and 2.4-4 present the monthly average and extreme temperatures just below Priest Rapids Dam (1961-1974) and at Richland (1965-1974), respectively. A comparison of monthly average temperatures between the two locations is shown in Figure 2.4-9.

Monthly average temperatures at the two locations range from 1.50C (34.70F) to 20.20C (68.40F), with the lowest temperatures generally occurring in February and the highest in August. Average monthly temperatures for the 10-year period (1%5-1974) range from 3.30C (37.90F) to 18.30C (64.90F) below Priest Rapids Dam and from 4.20C (39.60F) to 19.30C (66.70F) at Richland, indicating a slight warming.from Priest Rapids Dam to Richlind. Average daily temperatures at the two locations show a low of J.30C (32.SoF) and f% 2.4-3 Amendment 4 Q 1 October 1980

W4P-2 ER-OL 9

a high of 20.20C (68.40F) below Priest Rapids Dam and a low of 0.20C (32.40F) and a high of 21.50C (70.70F) at Richland. A diurnal variation in water temperature of about 2.20C (40F) in the spring and summer, and 1.10C (20F) in the f all and winter, can be expected to occur as a result of diurnal reservoir discharge. var-iations from Priest Rapids Dam.

The free flowing stretch of river along the Hanford reach responds more rapidly to thermal modification f rom both weather and industrial inputs than impounded regions. Hence, in this stretch of river, warming in the sumer and cooling in the winter occur more rapidly.

Studies indicate that about 65% of the heat input in the Hanford reach of the river is dissipated by the time it reaches the Washington-Oregon border.(18) The temperature rise from natural heating along the Hanf ord stretch during August and September is about 0.5 to 0.750C (0.9 to 1.350F).

Upstream impoundments have influenced water temperatures by delaying the arrival of peak sumer water temperatures, reducing (summerThewater temperatures, and increasing winter water temperatures.14) change in average annual water temperatures, however, has been less than 10C (20F) over the past 30 years. These treads are shown in Figure 2.4-10 f or the years 1938-1972 at Rocky Reach Dam. The river has not frozen over in the Hanford reach during, at least, the last 25 4 years.

The Columbia River has been thermally modified since 1944 by the operation of up to nine plutonium production reactors at Hanford.

This modification was quite significant since the heat additionsA from man-made thermal energy sources were over 23,000 MW in 1964.

portion of the heat load was added directly toInthe river by addition, reactor numerous 4 effluents at temperatures in excess of 850C.

" warm springs" were c eated along the plant shoreline by disposing of warm wastewater in trenches that paralleled the shore. Only one reactor,100-N, remains in operation at present.

One-hour, 24-hour, and 7-day frequency duration curves projected for 1980 dam operations f or high river water temperatures at the project i

' site are shown in Figures 2.4-11 through 2.4-13.

4 2.4-4 Amendment 4 October 1980

WNP-2 ER

/~i b'

2.4.1.3 Columbia River Water Quality The water quality of the Columbia River is quite good.( ,19,20)

The Columbia River is classified as " Class A Excellent" from its mouth to Grand Coulee Dam by the Washington State Department of Ecology. This means that the water is generally satisfactory for use es water supply (domestic, industrial, agricultural), wildlife habitat, stock watering, general recreation and aesthetic enjoyment, commerce and navigation, and fish and shellfish reproduction, rearing and harvest.

Applicablewaterqualitysyggpardsandregulationsimposed are presented in Section 5.1 by the State of Washington and 5.3 A summary of mean and extreme values for important water quality parameters derived from measurements taken at different periods between 1957 and 1973 at 99 1ggtgg)1ocations !1 in this region is presented in Table 2.4-5. The Columbia River shows little change in mineralization from the International Boundary at Northport, Washington (River Mile 734),

to the point of its confluence with the Snake River (River Mile 324). As it enters the United States from Canada it is a calcium bicarbonate type water with an average dissolved-solids concentration of approximately 90 mg/l (milligrams per liter). In samples collected daily at Northport since 1952, the dissolved-solids have ranged between 71-158 mg/2. The

(~' water is moderately hard, ranging from 50-159 mg/2 in hardness.

A In the vicinity of the proposed project, the dissolved-solids have ranged between 70-154 mg/t, and the hardness between 55-85 mg/t.

Mean dissolved oxygen (DO) levels in all reaches of the Columbia River from Northport to Pasco have an average value of about 10 mg/t; the minimum dissolved oxygen concentration reported was 6.8 mg/2 at Pasco. The Washington Water Quality Standards impose that no wastes be discharged into the Columbia River that cause dissolved oxygen levels to fall below 9.5 mg/l above Grand Coulee Dam or 8.0 mg/2 below Grand Coulee Dam.

The average coliform count below Priest Rapids Dam is 131/100 mt which is much less than 240/100 mt imposed by the Washington State Water Quality Standards in this area.

Turbidity in the river is very low, generally measuring less than 5 Jackson Turbidity Units (JTU). The pH is normally slightly alkaline (up to 8.6).

The passage of water over the spillways of upstream dams has caused nitrogen supersaturation in the river water. Values of dissolved nitrogen in excess of 120% of saturation have q

2.4-5 Amendment 1 May 1978

WNP-2 ER been observed below Priest Rapids Dam and in the Hanford It is anticipated that increased flow lh reach of the river.

regulation by new upstream dams will decrease the amount of water spilled over the dam spillways, and as a consequence, decrease the nitrogen supersaturation problem.

Table 2.4-6 shows the chemical characteristics of the river water measured at 100-F Area (River Mile 374) of the Hanford Reservation. (22) A summary of water quality measurements of the river below Priest Rapids Dam (River Mile 395) for the 1972 water year is presented in Table 2.4-7.(22) Averages computed from these measurements are listed in Table 2.4-8.

Samples for chemical analyses of Columbia River are taken routinely at Priest Rapids Dam, at Vernita, the 300 Area, and Richland. (23) Several investigations studied the effect of reactor effluent on chemica] quality of the water. One report (24) includes analyses of river samples taken semi-monthly at Vernita (downstream of Priest Rapids Dam but upstream from the Hanford Reservation) and within the Hanford boundaries but downstream of reactor effluent discharges.

Other than hexavalent chrcmium, statistical comparison of the mean sample values showed no significant differences at i the 90% confidence level in any of the species.

Hanford Effluents 2.4.1.4 Fourteen liquid effluent lines from Hanford facilities dis-9 charge their contents directly to the Columbia River.(25)

Pertinent data for each discharge are given in Table 2.4-9, and a summary of annual amounts of the principal chemical discharges is given in Table 2.4-10.

At present, the only thermal discharges of sufficient magni-tude to affect Columbia River temperatures occur either from the 100-N Reactor or from the associated WPPSS Hanford Generating Plant (HGP) when the N Reactor is operating.

The largest heated stream arising from this operation is the cooling water from the HGP (Table 2. 4-9) , which has a thermal capacity of 3780 MW (megawatts) and an electrical capacity of 860 MW. The cooling water flow rate is 940 to 1260 cfs depending on incoming river temperature, and is discharged at 15 to 20 C (27 to 36*F) above ambient river temperature.

Surveys (26) of the thermal plume created by this discharge showed a maximum measured temperature increment in the plume of 4.5*C (8.1 F) with a river flow rate of 44,000 cfs, and a maximum increment of 2.5*C (4. 5* F) at 100 yards downstream at which point the width of the plume becomes well mixed across the river width. Directly below an island some O

2.4-6

WNP-2 ER 2.4.1.3 Columbia River Water Quality The water quality of the Columbia River is quite good ( ' ' }

The Columbia River is classified as " Class A Excellent" from its mouth to Grand Coulee Dam by the Washington State Department of Ecologv. This means that the water is generally satisfactory for use as water supply (domestic, industrial, agricultural), wildlife habitat, stock watering, general recreation and aesthetic enjoyment, commerce and navigation, and fish and shellfish reproduction, rearing and harvest.

Applicablewaterqualitysyggpardsandregulationsimposed are presented in Section 5.1 by the State of Washington and 5.3 A summary of mean and extreme values for important water quality parameters derived from measurements taken at 1 different periods between 1957 and 1973 at 99 1ggtgg) locations in this region is presented in Table 2.4-5. The Columbia River shows little change in mineralization from the International Boundary at Northport, Washington (River Mile 734),

to the point of its confluence with the Snake River (River Mile 324). As it enters the United States from Canada it is a calcium bicarbonate type water with an average dissolved-solids concentration of approximately 90 mg/t (milligrams per liter). In samples collected daily at Northport since 1952, the dissolved-solids have ranged between 71-158 mg/t. The water is moderately hard, ranging from 50-159 mg/L in hardness.

O In the vicinity of the proposed project, the dissolved-solids have ranged between 70-154 mg/t, and the hardness between 55-85 mg/t.

Mean dissolved oxygen (DO) levels in all reaches of the Columbia River from Northport to Pasco have an average value of about 10 mg/t; the minimum dissolved oxygen concentration reported was 6.8 mg/t at Pasco. The Washington Water Quality Standards impose that no wastes be discharged into the Columbia River that cause dissolved oxygen levels to fall below 9.5 mg/t above Grand Coulee Dam or 8.0 mg/L below Grand Coulee Dam.

The average coliform count below Priest Rapids' Dam is 131/100 mt which is much less than 240/100 mt imposed by the Washington State Water Quality Standards in this area.

Turbidity in the river is very low, generally measuring less than 5 Jackson Turbidity Units (JTU). The pH is normally slightly alkaline (up to 8.6).

The passage of water over the spillways of upstream dams has caused nitrogen supersaturation in the river water. Values of dissolved nitrogen in excess of 120% of saturation have A

U 2.4-5 Amendment 1 May 1978

WNP-2 ER

• been observed below Priest Rapids Dam and in the Hanford reach of the river. It is anticipated that increased flow

' regulation by new upstream dams will decrease the amount of water spilled over the dam spillways, and as a consequence, decrease the nitrogen supersaturation problem.

Table 2.4-6 shows the chemical characteristics of the river watermeasurgg29t100-FArea (River Mile 374) of the Hanford A summary of water quality measurements of Reservation the river below Priest Rapids Dam (River Mi1T2}y5)Averages for the 1972 water year is presented in Table 2.4-7 computed from these measurements are listed in Table 2.4-8.

Samples for chemical analyses of Columbia River are taken routinelyatyggystRapidsDam,atVernita, the 300 Area, Several investigations studied the effect and Richland.

of reagggy includes effluent on chemical quality of the water. One analyses of river samples taken semi-report monthly at Vernita (downstream of Priest Rapids Dam but upstream from the Hanford Reservation) and within the Hanford boundaries but downstream of reactor effluent discharges.

Other than hexavalent chromium, statistical comparison of the mean sample values showed no significant differences at the 90% confidence level in any of the species.

2.4.1.4 Hanford Effluents Fourteen liquid effluent lines from Hanford facilitie d chargetheircontentsdirectlytotheColumbiaRiver.g3fs-2l Pertinent data on quantities and contituents for each discharge are given in Table 2.4-9, and a summary of annual amounts of the principal chemical discharges is given in Table 2.4-10.

At present, the only thermal discharges of sufficient magni-tude to affect Columbia River temperatures occur either from the 100-N Reactor or from the associated WPPSS Hanford Generating Plant (HGP) when the N Reactor is operating.

The largest heated stream arising from this operation is the cooling water from the HGP (River Mile 380), which has a thermal capacity of 3780 MW (megawatts) and an electrical capacity of 860 MW. The cooling water flow rate is 940 to 1260 cfs depending on incoming river temperature, and is discharged at 19 to 2 4 C (35 to 4 3 F) above ambient river temperature (Table 2.4-9). The calculated temperature 2 increment for complete mixing (about 21/2 miles downstream) at the minimum river flow rate of 36,000 cfs would be 0.6 C (1.l*F).

During operation, N Reactor, immediately downstream from HGP, discharges a cooling water stream of about 140 cfs,with a temperature up to 16 C (28.8 F) above ambient river tem-perature, to the river. This discharge increases the river 2.4-6 Amendment 2 October 1978

UNP-2 ER temperature by only 0.14*C (0.25*F) at the minimum river s flow rate of 36,000 cfs and 0.0jjc) (0.08'F) at the average river flow rate of 120,000 cfs q )

Chemicals are released to the Columbia River at three loca-tions: Ik2gpe100-NArea, 2) the 100-K Area, and 3) the The primary source of chemicals released to 300 Area the river is the 100-N Reactor operation. The quantities of chemicals released are shown in Table 2.4-10. In addition to these chemicals, impurities removed from the river water by the treatment plants also are returned to the river. The intermittent filter backwash contains suspended solids, principally an aluminum hydroxide floc, plus an accumulation of suspended solids removed from the raw river water during 2 the filtration process. Several of the smaller effluent streams, consisting largely of treated water, may contain free chlorine at concentrations up to a maximum of 1 mg/t.

Other chemical concentrations in treated water are mostly the result of use of alum (aluminum sulfate) and small quantities of polyacrylamide filter aids in the water filtration plant.

While the production reactors which were cooled directly with river water have been shutdown, the Hanford reservation still has several sources of low level radioactive effluents.

These include cooling water at 100-N, animal farm waste at 100-F and 300 Areas, and trituim migrating to S

groundwaterfromthe200Areadisposalsites.ggyriverwith d 2.4.2 Groundwater The Hanford Reservation is underlain by three principal rock types, from top to bottom: 1) unconsolidated silts, sands, and gravels; 2) semiconsolidated lake and stream sediments (Ringold formation); and 3) dgggy, hard basalt which forms the bedrock beneath the area The lithologic character and water bearing preperties of the several geologic units occurring in the Hanford area are summarized in Table 2.4-11.

In general, groundwater in the superficial sediments occurs under unconfined conditions, while water in the basalt bedrock occurs mainly under confined conditions. In some areas the lower zone of the Ringold formation is a confined aquifer, separated from the unconfined aquifer by thick clay beds, and possesses a distinct hydraulic potential. Figure 2.5-14 shows a simplified geological cross section of the Hanford Reservation. Wells 699-9-E2, 699-10-E12, 699-14-E6, shown in this figure are located in the vicinity of the project site.

The Ellensburg Formation (beds between basalt flows) and Ringold Formation beds are ficod-plain and shallow lake 1 deposits. The glacio-fluvial sediments are largely the result of several catastrophic floods. These sediments D

b 2.4-7 Amendment 2 October 1978 i

WEP-2 ER (actually Pasco Gravels) are about 100 times as permeable as the Ringold Formation gravels, both of which exist at the plant site. The average field permeabilities, determined by a variety of methods, for the Ringold Formation gravel, the glaciofluvial sediments (Pasco Gravels) and mixes of the two are given in Table 2.4-12. The values were obtained on ma-1 terials comparable to those at the FFTF and WNP-2 sites and, of course, are appreciably higher than at sites where the Touchet Silts and Ringold Silts and clays predominate. The median specific yield or available porosity is estimated to range between 4.8 to 11% and the average effective porosity is about 9%.

From 1944 through 1972, the Hanford chemical processing planta gischarged to the ground over 130 billion gallons (4 x 10 acre-ft) of wastewater and cooling water with a profound effect on the regional water table. Figure 2.4-15 shows the unconfined water table contours over the area interpreted from measurements in September 1973. It also indicates the locations of wells. As shown in this figure, the impermeable aquifer boundaries are the Rattlesnake Hills, Yakima Ridge, and Umtanum Ridge on the west and southwest sides of the Reservation. Gable Mountain and Gable Butte also impede the groundwater flow.

The current estimate of the maximum saturated thickness of the unconfined aquifer is about 230 ft. In the vicinity of the project site this thickness is approximately 100 ft to 160 ft. The depth to the water table varies greatly from place to place depending chiefly on local topography, rang-ing from less than one to more than 300 ft below the land surface. The ground surface is about 60 to 70 ft above the water table at the WNP-2 Site.

The groundwater flows to the Columbia River in a direction perpendicular to the contour lines shown in Figure 2.4-15.

Groundwaterflowneartheriverupto3milesjggyndis affected by seasonal river stage fluctuations.

2.4-8 Amcndment 2 October 1978

WNP-2 ER .

The natural recharge due to precipitation over the low lands of the Hanford Reservation is not measurable. The major

'^g artificial recharge of groundwater to the unconfined aquifer (j occurs near the 200 East and 200 West Areas. As is clearly shown in Figure 2.4-15, the large volumes of process water disposed to ponds at this site have caused the formation of significant mounds in the water table. 3 Upon reaching the water table, chemical and radioactive contaminants from the 200 Area disposal sites are convected in the di e ti n f gr undwater m vement. Nitrate (NOk29^3h) tritium (5H ) ions had reached the project site in 1972 3

Hgggver, the plume of gross beta emitters calculated as

( Ru) does not reach the site at not likely to do so in the future.gggy present time and is East of the Columbia River is a very intensive 500,000 acre irrigated farming area (Columbia Basin Project area). The water table in that region is 40 to 60 ft higher than the river elevation. The water table in the region beygeyn Eltopia and Pasco has risen 40 to 60 ft since 1960 due to an increase in irrigation in the area. Although no specific studies have been conducted, it is apparent from the water table elevations that the flow of water is into the Columbia River. It is believed that there is a hydrau-lic connection between the unconfined aquifers under the Hanford Reservation and under the Columbia Basin project area. Groundwater east of the Columbia River may be contaminated by the agricultural activities. However, the Columbia River O acts as a discharge boundary for the unconfined aquifers.

An underground disposal site for radioactive wastes is located immediately adjacent to the northwest corner of the WNP-2 site (Figure 2.1-3) . The disposal site covers an area of 8.6 acres and was used between 1962 and 1967 to dispose

ofabroadspectrumoflow-tohigh-level primarily fission products and plutonium.

(3gpioactivewastes, Cartoned low-level waste was buried in trenches, and medium to high-level waste was buried in caissons or pipe facilities. The buried wastes are approximately 45 ft above the water table.

4 The points of groundwater withdrawal in the vicinity of the WNP-2 site are shown in Figure 2.4-16. Two on-site wells

draw from the unconfined aquifer in the Ringold formation and a third well penetrates the confined aquifer in the underlying basalt flows. During construction these wells supply potable /

sanitary water requirements and provide water to support construction activities (concrete, dust control, pipe flushing, fire suppression, etc.). Well water consumption for these purposes is not expected to exceed 10,000 gpd for the balance 3 of construction. For the operating phase, the wells will provide potable and service water to the plant during outages.

, The design is for a peak requirement of 250 gpm although average usage should be less than 20 gpm. When the plant is

< operating, normal water supply will be from the river and s the wells will serve as a stand-by supply for service and I supplemeci;l fire protection.

2.4-9 Amendment 3 January 1979

WNP-2 ER TABLE 2.4-1 O

COLUMBIA RIVER MILE INDEX Description River Mile River Moutb 0.0

. Bonneville Dam 146.1 The Dalles Dam 191.5 John Day Dam 215.6 McNary Dam 292.0 Snake River 324.2 Yakima River 335.2 WNP-2 Intake and Discharge 351.75 Proposed WNP-1 and 4 Intake and Discharge 351.85 Existing Hanford Generating Plant 380.0 Priest Rapids Dam 397.1 Wanapum Dam 415.8 Rock Island Dam 453.4 Wenatchee River 468.4 Rocky Reach Dam 473.7 Chelan River 503.3 Wells Dam 515.6 Chief Joseph Dam 545.1 Grand Coulee Dam 597.6 Spokane River 638.9 United States-Canadian Boundary 745.0 l

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WNP-2 ER O

TABLE 2.4-3 MONTHLY AVERAGE WATER TEMPERATURE, IN 'C, AT PRIEST RAPIDS DAM, WA(a)

Month Annual Tin g Jul g Sg Oct Nov Dec Average Year Feb Mar A r_

J M Jun A 1961 5.4 4.7 4.7 7.4 30.4 13.7 17.3 18.9 17.8 14.9 10.4 6.6 11.0 1962 4.1 3.6 3.6 6.5 10.0 13.7 16.1 17.4 17.1 14.8 11.9 8.9 10.6 1963 5.3 3.8 4.6 6.5 10.4 14.0 16.6 18.4 18.3 16.3 11.9 7.7 11.2 1964 5.5 4.6 4.7 7.2 9.7 12.8 15.3 17.1 16.3 14.6 10.8 6.3 10.4 1965 4.4 3.3 4.1 6.6 10.0 13.3 16.1 18.4 17.3 15.3 11.9 7.8 10.7 1966 4.8 4.1 4.5 7.8 10.6 12.4 15.3 17.5 17.5 14.6 11.6 8.4 10.8 1967 5.9 3.7 5.0 6.8 10.1 13.3 16.1 18.5 18.2 15.4 11.3 7.2 11.1 1968 4.6 3.3 4.6 7.1 11.1 13.4 16.1 17.5 17.2 14.2 10.9 6.8 .10.6 1969 2.4 1.5 3.4 7.2 10,8 14.6 17.1 18.2 17.7 14.8 11.5 7.6 10.6 1970 4.3 4.1 4.8 6.8 10.9 14.8 18.0 19.2 17.5 15.2 10.6 6.2 11.0 1971 4.0 3.5 3.6 6.6 10.7 12.6 15.3 18.4 17.2 15.2 11.3 6.8 10.4 1972 3.6 1.9 4.0 7.2 10.6 12.9 15.2 17.3 16.0 15.4 11.3 7.3 10.3 1973 2.3 2.9 4.8 7.7 12.5 15.4 17.6 18.8 17.8 15.2 10.3 7.7 11.1 1974 4.0 3.0 4.9 7.7 10.8 13.6 17.2 18.7 18.4 15.5 11.d 8.6 11.2 Average 1965-74 4.0 3.3 4.4 7.2 10.8 13.6 16.4 18.3 17.6 15.1 11.3 7.4 10.8 Minimum Daily 0.3 0.3 2.2 4.3 7.5 10.6 13.1 16.6 15.3 12.2 7.7 2.3 --

Maximum Daily 7.6 6.2 6.9 10.1 14.6 17.1 19.3 20.2 20.0 18.7 14.4 10.5 --

Tan secords since August 1960. Recorded values adjusted by computer-simulation to comrensate for measurement errors and missing data.

O

i i WNP-2 1

1 ER .

i

9 4

TABLE 2.4-4 l MONTHLY AVERAGE WATER TEMPERATURE, l IN C, AT RICHLAND, WA(a) f I

Month Annual

! Year Jan Feb Mar A[- r g M Jun Jul Aug 31 Oct Nov Lee Average j

196, 6.1 5.4 6.3 9.1 11.0 14.2 17.3 19.8 18.5 16.4 12.6 8.4 12.1 l 1966 5. 9 6.2 6.8 10.3 12.1 13.5 16.2 19.8 19.4 15.6 12.6 9.5 12.2 l 1967 7.4 7.0 6.6 8.8 12.0 13.9 17.0 20.2 19.4 16.1 12.0 7.8 12.4 196d 5.7 5.0 6.0 8.8 12.8 14.3 17.0 18.7 18.3 15.0 11.4 7.4 11.7 f

j 19t9 2.7 1.9 4.3 8.0 11.4 15.3 17.9 19.3 18.0 1".2 11.7 7.0 11.1 1970 5. 3 4.9 5.7 7.9 11.7 15.4 19.0 19.9 17.5 14.9 10.6 }.9 11.6 1971 4.2 3.4 3.8 7.0 11.1 12.9 16.4 19.5 17.8 15.] 10.7 6.2 10.7 1972 3.3 2.2 3.7 7.0 11.0 13.3 15.5 19.1 16.9 14.0 10.5 6.1 10.1 1973 3.2 3.0 4.7 7.8 12.9 15.6 18.3 19.6 18.3 15.0 9.9 7.6 11.3 1974 3.2 3.2 5.2 8.2 11.3 13.7 17.4 19.4 18.8 15.4 11.5 7.9 11.3

1. $ 4.7 4.2 5.3 8.3 11.7 14.2 17.2 19,3 18.4 15.3 11.4 7.4 11.4 0.2 0.7 2.4 5.1 3.6 11.2 ~14.2 17.3 14.o 11.1 7.7 2.4 --

g""" 8.3 8.3 a.6 12.8 15.0 17.7 20.4 21.5 21.1 10.5 15.9 11.3 --

(a) Records since June 1964.

O

TABLE 2.4-5

SUMMARY

OF WATER QUALITY DATA FOR THE COLUMBIA RIVER AT SELECTED SITES Coliform Color Ortho D.P. T MPN/ PT-CO Hard. Turbidity PO4-P NO3-N (mg/t) ('C) 100 mt pH Units (mg/1) (JTU) (mg/t) (mg/1)

Northport, WA (River Mile 734)

Mean 11.5 9.8 385 7.6 4 78 17 0.05 0.05 Minimum 10.2 0.0 36 6.6 0 50 0 0.00 0.00 Maximum 14.3 21.0 2,000 8.5 30 159 32 0.18 0.40 Wenatchee, WA (River Mile 471)

Mean 11.8 11.0 310 8.0 5 66 4 0.03 0.07 Minimum 8.0 2.5 2 6.9 0 50 0 0.01 0.00 Maximum 15.5 21.6 7,300 8.6 25 112 25 0.04 0.14 E M2 Columbia River below I A

Rock Island Dam (River Mile 451) .

Mean 12.3 10.6 691 7.8 8 82 4! --

0.10 Minimum 9.3 1.5 10 6.4 3 55 1 0.00 0.01 Maximum 15.9 19.6 8,000 8.4 30 132 32 0.07 0.73 Columbia River below Priest Rapids Dam (River Mile 395)

Mean 11.9 11.4 131 7.7 5 69 3 0.08 0.10 Minimum 9.5 1.8 0 6.5 0 55 0 0.01 0.02 Maximum 15.9 19.2 2,000 8.5 33 81 29 0.15 1.50 Columbia River, Pasco, WA (River Mile 330)

Mean 10.8 12.2 182 8.1 8 73 15 0.1 0.19 Minimum 6.8 3.0 1 6.8 0 40 0 0.01 0.05 Maximum 14.3 22.0 4,800 8.6 68 90 140 0.02 0.37 O O O

n fm p TABLE 2.4-6 CHEMICAL CHARACTERISTICS OF COLUMBIA RIVER WATER AT 100 F--1970 (RESULTS IN PARTS /MILLION)

Diss Phth MO Hard-Date M1 Pe Cu Ca SO 4 M_4 CI O 2-Alk A] ness Solids 1/6 6.0 0.03 0.002 20. 15. 0.00 0.33 NA 2.0 68. 74. 93.

1/20 4.0 0.01 0.004 22. 15. 0.05 0.36 7.8 2.0 71. 73. 84.

2/3 5.0 0.01 0.002 21. 13. 0.06 0.33 12. 2.0 69. 72. 100 2/17 5.0 0.01 0.004 22. 19. 0.01 0.33 11. 2.0 68. 75. 100 3/3 5.4 0.02 0.002 22. 17. 0.04 0.26 8.3 1.0 65. 76. 96.

3/17 6.2 0.03 0.004 19. 17. 0.02 0.50 13. 1.0 65. 73. 81.

3/31 6.2 0.07 0.005 20. 17. 0.02 0.39 12. 2.0 69. 76. 81.

4/14 4.4 0.22 0.002 24. 20. 0.05 0.60 12. 1.0 66. 77. 100 4/28 6.3 0.12 0.005 22. 24. 0.02 0.56 12. 1.0 70. 82. 120 3C tt 2:

5/12 5.5 0.02 0.02 25. 23. 0.005 0.40 12. 2.0 72. 85. 100 W 'O I

6/16 4.6 0.00 0.01 22. 13. 0.04 0.29 11. 2.0 56. 68. /4. NJ 7/21 4.2 0.09 0.007 23. 15. 0.02 0.16 9.6 1.0 61. 76. 75.

8/4 3.9 0.02 0.007 25. 17. 0.02 0.46 9.6 .1.0 70. 78. 86.

8/18 4.0 0.03 0.004 24. 13. 0.02 0.26 8.9 1.0 70; 77. 110 9/8 4.8 0.03 0.005 23. 15. 0.08 0.43 9.0 3.0 70. 77. 73.

9/22 5.3 0.02 0.002 17. 13. 0.03 0.26 9.4 2.0 63. 65. 37.

10/6 4.0 0.03 0.003 21. 20 0.02 0.66 8.2 2.0 66. 70. 99.

10/20 5.4 0.02 0.006 16. 12. 0.01 0.32 11. 0.0 92. 66. 80.

11/3 5.3 0.01 0.001 19. 18. 0.11 .0.49 NA 2.0 70. 68. 80.

11/16 4.9 0.02 0.003 20. 15. 0.11 0.58 9.8 6.0 69. 70. 86.

12/1 3.8 0.01 0.002 20. 16. 0.01 0.46 NA 2.0 66. 65. 92.

12/15 6.6 0.01 0.000 18. 16. 0.11 0.53 NA 2.0 76. 73. 97.

g 5.0 0.04 0.006 22. 16. 0.04 0.40 10. 1.8 68. 74. 90.

NA Indicates there was no analysis made. Analysis was made from sing grab samples, e

TABLE 2.4-7a

SUMMARY

OF WATER QUALITY ANALYSES OF THE COLUMBIA RIVER BELOW PRIEST RAPIDS DAM (RIVER MILE 395) FOR 1972 WATER YEAR 70TAL Dl550LvtD DISSOLVED 01550LVED 01550LvtD ALKAttfulTY D1550LvtD D1550LvfD KJELDAHL INSTANTANEQUS CALCluM MAGPE51UAl 500iUM POTA5510M BICARBONATE AS SULFATE CHLORIDE hlTROGEN tCal tNm (Ki (HCO31 (50 46 4C0 (Ni 015 CHARGE (Ab) CACO 3 DATE y tCF$l (EU (EU (MC'LI (E U (MGU LEU IEU (EU (EU OCT0tER 11 1630 10em 19 4.2 2.2 LO 74 61 12 L5 4 12 18 1410 91E0 19 4.2 2.4 11 73 e0 13 2.0 all NOVl>8ER 13 1410 10lO 19 4.4 2.3 Lt 74 61 li af (LOS 15 1300 10sWO 19 4.0 17 L5 72 59 11 10 a79 DECD48ER ledGD 21 47 2.0 17 76 62 15 LO 4 02 13 1515 27 IMO 132DID 20 4.5 2.1 L1 75 62 13 19 (L15 JAMJARY J 1350 132E 21 4.9 13 ILS 79 65 14 L1 al2 g MZ FESRUARY 22 48 10 a8 78 es 14 L7 aos WT OF 11.5 107000 21 1350 135(D0 21 (7 14 LI 82 67 14 Le all MARC,,

13 1410 17EID 21 4.9 11 L2 2 66 14 L2 R 30 27 1410 151m 21 4.9 14 10  ?? 63 10 L2 all APRIL 10 1440 215GIl 20 4.8 10 at 77 63 16 0.6 and 24 1325 13eGD 21 4.9 14 L4 W 66 L6 (L 19

1. 6Y 08 1425 I?5GD 20 4.9 2.5 LO 76 62 15 0.6 a t9 22 1140 3L4000 19 4.4 17 07 68 56 14 19 0 39 JUNE 12 14 10 40eGD 16 16 L4 (L9 64 52 95 L8 E93 26 1435 4100(D  !? 17 L8 08 65 53 98 a7 0.37 JULY 10 1440 241 @ 17 16 L3 E7 56 46 16 Lo a84 24 1510 1970(D 18 18 L6 E8 e4 52 8.6 LO a tt AUGUST OF 1500 180000 18 17 L4 0. 7 45 53 9.6 03 a24 21 1440 144000 18 17 L7 a7 67 55 95 C.9 Q 79 SEPTEMBER 11 1410 131GD 19 19 14 G. 7 63 57 v8 L3 0 11 25 1510 920(D 18 4.2 L9 00 70 57 11 06 0 13 9 9 9

n TABLE 2.4-7b (sheet 2 of 3)

DISSOLVED DIS 5OLVED DISSOLVED AMMONIA 04550tvED ORTH 0 TOTAL 53L105 NITRITE NITROGEh NITR ATE PHOSPHORUS PHOSPHORui (RE540UE HARDNESS NON{AR$0NATE SPECIFIC 00 tNI tw (P) (P) AT 15'Cl (Ca met HARONE55 CONOUC1ANCE pH DATE IMGlu (MGlu (MGlu (MGlu IMGlu IMCO paCfD HAGlu iMICROMM05) IUNITS:

OC100ER 11 (LGD 4 05 all (LOW 405 82 45 4 leo 7.8 18 1 50 (LO6 4 07 ROIS EDW 98 45 5 H0 F.8 NOVEMBER W alIB 1 01 1 16 Q.02 405 90 to 5 W5 f.F 15 (Lolo all all a010 E090 W ed 5 W5 T.8 DECDn8ER 13 (L010 (LOl a20 10N) 102 92 F2 9 151 F.4

?F 1 010 a00 E25 ae &SW W GS T le T.6 JANUARY M RGB (LO3 a45 &OBO 0 030 90 F1 8 lie i*

}

FEteUARY

' OF 1 010 (LOI 4 00 (LOW atu FB 75  !! 171 F.4 N

21 ale) a05 al8 402 105 112 72 5 145 7.8 MARCH . I 13 ILO10 (LO5 a32 EDIO ace 0 152 Tl F IM 15 BJ

. 27 1 010 40F L5 ROM (LO70 136 F) 9 150 '7.8 l' Artil 10 E010 4 03 (LM 102 a050 iM 70 F 1% 10 20 a010 4 05 E05 E010 E0a0 15 F3 7 ISO 10 MAY l W EGB E05 4 00 ROM ILOW IM 70 $ les 10 l 22 a34 E05 R0F 4 010 4 050 15) 66 10 170 7.8

) JUNE E05 12 4 010 RIO LI EOS IM 55 2 125 7.4 26 0.0tB 4 05 al0 E010 ROM 112 58 4 IM TF JULY

]

10 a(Is EIS 4 15 4 010 (LOW 112 57 11 110 7.6 i

20 E010 E02 R22 EGE E020 70 61 8 135 11 AUGUST 07 E010 0 08 a09 0.GE E020 los 60 F 14e 82 21 3.0 10 E24 ato 0.010 a020 los a0 5 IM F.9 SEPTEMB(k 11 r 0tE '1 01 Q to R0tB E010 82 el 7 140 al 25 '3 010 ' Ji J 0 t) 0.010 E0W 48 L' 5 IM M

TABLE 2.4-7c (sheet 3 of 3)

COLOR IMMEDIATE Dl550Lvt0 01550Lv!D 01550LVED TOTAL Dl550Lvt0 (PLATINUM 01550Lvt0 COLIFORM CHROMtUM COPPER LEAD MERCURY ZINC TDAPERATURE COBALT TUR810?TY OKYGEN (COL, PG ICrt ICut (Pet (Mgl (2n6 DATE (DEG C) UNITS) uTU) (MGlu 15) MU IUGlu 60Glu (UGfu IUGlu IUGlu OCTOGER 11 17.9 9 4 9.9 100 -

18 til 26 2 E0 2XD -

2 2 at 0 NOVDaBG 08 11L5 12 2 E8 > lls - - - --- ~

15 IL7 5 2 E4 50 - - - - --

DECDASG 13 L2 27 2 IL7 50 - -

E3 10 27 12 7 I 115 ---- - - - --- --

JAftlARY 38 10 8 2 112 -~ 0 1 2 Lt 20 FEORUARY W LS 7 2 115 m 0 6 3 E5 W 16 to 116 50 0 2 3 48 20 M 21 12 MT MARCH l 13 47 12 4 114 40 0 t e al 50 N 27 il 21 7 119 65 0 1 9 al 80 APRIL 10 7.8 17 4 lie 250 0 1 8 a6 5) at 1Q0 13 3 IL) 100 0 1 3 at 50 MAY 08 9.4 12 4 113 130 0 1 5 &O 40 22 IL7 21 9 118 4tD 0 1 5 al 50 JUNE 12 til 13 29 11 0 400 0 9 7e 43 40 5 118 21 2 0 2 6 ai 50 26 116 16 JULY 10 112 18 3 110 45) 0 2 5 at 20 24 17.5 12 4 IL6 1300 0 2 5 at 20 AUGUST 07 19.2 13 2 IL) 11G 0 0 2 al 10 21 lit 9 2 ILO Um 0 2 2 a6 E SEPTEM8ER 11 117 14 1 lal 400 0 2 4 13 C 25 14 8 12 I ILO 22 0 0 to 1 2.5 20 0 0 0

WNP-2 ER

() TABLE 2.4-8 AVERAGE CHEMICAL CONCENTRATIONS IN THE COLUMBIA RIVER AT PRIEST RAPIDS DAM, OCTOBER 1971 TO SEPTEMBER 1972 Chemical Concentration l Calcium 19. (mg/t)

Magnesium 4.3 (mg/t)

Sodium 2.1 (mg/t)

Potassium 1.4 (mg/t)

Chromium 0

, Copper 2.6 (pg/t)

Lead 8.0 (pg/t)

Total Mecury 0.9 (pg/t)

Zinc 32.0 (pg/L)

Bicarbonate 72. (mg/t)

Sulfate 13. (mg/t)

/\ Chloride 1.5 (mg/L)

L) Kjeldahl Nitrogen .29 (mg/t)

Ammonia Nitrogen .07 (mg/L)

Nitrite Nitrogen .006 (mg/t)

Nitrate Nitrogen .26 (mg/t) i Ortho-Phosphorus .013 (mg/t)

Total Phosphorus .037 (mg/t)

Total Alkalinity 59. (mg/L)

Hardness 66. (mg/t)

Noncarbonate Hardness 06.8 (mg/t)

Specific Conductance 158. (micro-mhos) pH 7.8 (units)

Dissolved Solids 107. (mg/t)

Color 15. (platinum - cobalt units)

/"'\

V

TABLE 2.4-9 DISCHARGE LINES TO COLUMBIA RIVER FROM HANFORD RESERVATION Use Tempereture other potential water uuality Effects Area Discharge Lines D3scha qe Rates. ( f s Quant it a es 6,000 gallone sackflush pump inlet screens Ambtent None - untreated raw river water 100-s/C 12-in, steel pape 42-kn. steet pape 2.2 Drasas and filter inackwash 2.0*C, above Total Solids, Turbadaty. Aluminum. Sulfate, 100-8/C above ambient Chloride 1.1 5.000 gallons Backflush pump anlet screens Ambaent None - untreated river water 100-se and sw 3 times a year Two 84-an. steel papes 1.1 Drains, overflow and cooltag water 2. a *C above Total solids, Turbadaty, A1mism, Self ate.

100-me ambaent Chlor nde, Chlor ane (0.25 mg/ t )

and sw for compressors and peps 100-N 75,000 gallone Backflush pump anlet screens Amt.nent Wome - untreated raver water 3 times a day overflow from f altered water and 11 to 20*C Total Solids, Assenta (as went as radio-100-N 3- by 4-f t concrete chute 1.1 act&ve wagte) chlorine (0.05 mg/t ) Tur b 1d a t y raw water storage tanks, condon- above ambaent sete f rom medium pressure staae system, filter backwash 0.01 F Litered water over fl,bw. and waste 6 to 8'C Sulf ate. Chlornde Chlorane (0.05 mg/t) 100-N 42-an. steel pape from flocr drains above ambaent 100- N 66 dan. pape to 12-f t concrete 140 Turbine condenser cooling water 16*C above Aluminum. Turbada ty flume on riverbank and graphate heat enchanger cool- ambtent ing water 102-in. steel pape 300 (estnemes 140 and Steam condenser cooling water 5.5'C above Turbadaty. Asmonta, Sulf ate, Iron, Sodium.

100- N ambaent toccasnonally 0. 3 mg/l orthophosphatel, 410 cf s) Chlor ane - 2 to 40 ppb N

wppsS 112-in. steet pape ,40 wh.n river .25'C steam condenser cootan, water 15 to 20*C bove ambaent (same as abovei yg 1260 when river *25*C ,

10 0-D 'OR 12-kn. steel pape 6.000 gallons sackflush pump anlet screens Amb&ent None

• untreated river water y once a month once a month Falter backwash and process Total Solads. Turbadaty, Aluntnum 100-D/DR Two 42-nn. steel papes 4.4 (2.2 to 22) coolant end wash) water, hydree-

2. 0*C above Su. fate, Chorade. Chlor ane 10.14 mg/t )

ambaent lac test loop water) taasamum 2.2 mg/ t i

2. 2 t aver age l 6 to 12/ day Falter backwash (f rom water treet- Ambaent Total bol ads, Turbad tty, Aluminum. Sulfate.

300 2 4 -in . concrete pape terms-nating as a 30-an. half-round batches of ment plant) *Separon* ta propraetary polyacrylamade 12,000 ge11ons f alter aldt Chlortne t o. 5 mg/ t l corrogated metal pape Air condat&oner coolang water and 25'C above Alumanum, Sul f ate Chlor tne is0.5 mg/ t )

300 36-sn. steel pape 0.01 floor drains arabaent Drainage from roof and parkang Total Solads. Turbadtty, Organte matrogen 300 12-in. steel p .m 1.1 (0.04 to 2. 31 2 to 1*C lot, tanke for aquatic organisms above ambient O O O

WNP-2 ER O

TABLE 2.4-10 TOTAL ANNUAL DIRECT CHEMICAL DISCHARGE FROM HANFORD RESERVATION TO COLUMBIA RIVER Quantity from All Facilities Materials (tons)

Aluminum Sulfate 260 Chlorine 20 Polyacrylamide 0.8 Salt (rock) 22

(~N Sodium Dichromate 2

\-% Sulfuric Acid 650 Ammonium Hydroxide 60 Hydrazine 8 Morpholine 1.5 Sodium Hydroxide 230

'ss_

TABLE 2.4-11 MAJOR GEOLOGIC UNITS IN THE HANPORD RESERVATION AREA AND THEIR WATER BEARING PROPERTIES System Series Geologic Unit Material Water-Bearing Properties _

Fluviatile and glacio- Sands and gravels occur- Where below the water table, such deposits fluviatile sediments ing chiefly as glacial have very high permeability and are capable and the Touchet forma- outwash. Unconsolidated, of storing vast amounts of water. Highest tion. tending toward coarse- permeability value determined was ness and angularity of 12,000 ft/ day.

(0-200 ft thick) grains, essentially free of fines.

Pleistocene Palouse soil Wind deposited silt. Occurs everywhere above the water table.

(0-40 ft thick)

Quaternary Ringold formation Well-bedded lacustrine Has relatively low permeability; values silts and sands and range f rom -I to 200 f t/ day. Storage capa-(200-1,200 ft thick) local beds of clay and city correspondingly: low. In very minor gravel. Poorly sorted, part, a few beds of gravel and sand are locally semi-consolidat- sufficiently clean that permeability is tg ed or cemented. Gener- moderately larger on the other hand, some ym ally divided into the beds of silty clay or clay are essentially 1 lower " blue clay" por- impermeable. bJ tion which contains con-siderable sand and gravel, the middle con-glomerate portion, and the upper silts and fine sand portion.

Miocene and Columbia River basalt Basaltic lavas with Rocks are generally dense except for numer-Pliocene series, interbedded sedimentary ous shrinkage cracks, interflow scoria zones, rocks, considerably de- and interbedded sediments. Permeability of

(>10,000 ft thick) formed. Underlie the rocks is small (e.g., 0.002 to 9 ft/ day) but unconsolidated sedi- transmissivity of a thick section may be con-ments. siderable (70 to 700 ft2/ day)

?  ? Rocks of unknown age, Probable metasediments  ?

type, and structure. and metavolcanics.

O O O

WNP-2 ER 0

e TABLE 2.4-12 .

AVERAGE FIELD PERMEABILITY (FT/ DAY) specific j Pumping Capacity Tracer Cyclic Gradient Tested Tests Tests Tests Fluctuations Method

Glaciofluvial 1700-9000 1300-900 8000 2200-7600 ---

! (gravels) 12o-800 O 120-evo 120-sao ---

c1 ci 1 d Ringold (gravels)

. Ringold 1-200 8-40 --- 20-66 13-40 (gravels) l i

i l

l

O Amendment 1 l

' May 1978

l l

l

' CANADA ,, _,

/ __

UNITED STATES Northport l l 1

~

9

% 1 5

(% 9 l q Chief Joseph Dam

[

Y+

k Grand 1 Coulee SPDKANE Dam i i

Wells Dam RIVER Rocky Reach Dam Spokane Rock Island Dam h

. 8 O \  :

Wanapum Dam Lower Granite Pries t Rapids Dam **

Lower Monumen tal Dam 6 \

$P Hanfor Reservation M /

Richi 4I nV [ Little Goose Dam Lewiston iPasco g

• Ice Harbor Dam Kennewick _pg g _ __ ,,

COLUMBIA OREGON RIVER John Day Dam McNa ry Dam DAMS IN THE COLUMBIA RIVER BASIN f, AEC TEMPERATURE The Dalles Dam " MONITORING STATIONS g OTHER TEMPERATURE STATIONS l

WASHINGTON PUBLIC POWER SUPPLY SYSTEM WPPSS NUCLEAR PP.OJECT NO. 2 UPPER AND MIDDLE COLUM3IA RIVER BASIN Environmental Report -

FIG. 2.4-1

I I I l l l 300 - PERIOD: 1929-1958 -

1970 CONDITIONS m 200 - _

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WASHINGTON PUBLIC POWER SUPPLY SYSTEM DISCHARGE DURATION CURVES OF THE WPPSS NUCLEAR PROJECT NO. 2 COLUMBIA RIVER BELOW Environmental Report PRIEST RAPIDS DAM, WA FIG. 2.4-2 l

O O O s

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Environmental Report FIG . 2. 4-10

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1 GROUNDWATER CONTOURS AND LOCATIONS p) y, WASHINGTON PUBLIC POWER SUPPLY SYSTEM OF WELLS FOR THE HANFORD WPPSS NUCLEAR PROJECT NO. 2 RESERVATION, WASHINGTON Environmental Report SEPTEMBER, 1973 FIG. 2.4-15

3 WELLS @ 234,244 AND 695 FEET CONSTRUCTION 10,000 GPD / OPERATION SUPPORT ]

WNP-4 2 WELLS @ 372 FEET AND 465 FEET

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WNP-2 ER

(_s 2.5 GEOLOGY The basic geology of the site and region was described in the AEC Final Environmental Statement (December 1972). Additional geologic and seismic studies of the site area have been conducted in. support of construction and safety studies for WNP-1 and WNP-4. Applicable results are reported in the WNP-2 FSAR. These additional studies have not indicated any need to further evalu-ate the interface between the plant and its operation, and the geologic environment.

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2.5-1

WNP-2 ER

~ 2.6 REGIONAL HISTORIC, SCENIC, CULTURAL AND NATURAL FEATURES a.

Nohistoricplacyg)aslistedinthe"NationalRegisterof Historic Places" occur within a 30-mile radius of the WNP-2 site. The three nearest sites on the National Register are Olmstead Place State Park, Marmes Rockshelter, and Whitman Mission National Historic Site. Olmstead Place State Park is located 70 miles northwest of the Project near Ellensberg, Washington. Marmes Rockshelter is 52 miles northeast of the Project near the confluence of the Palouse and Snake Rivers, and the Whitman Mission is 53 miles to the southeast near Walla Walla, Washington. One natural land-mark listed in the National Register (l) is within a 50-mile radius of the proposed Project. This is the Ginkgo Petrified Forest State Park, approximately 47 miles to the northwest.

None of these sites will be affected by the Project.

However, as of February 10, 1976, three years following the granting of permits and authorities to construct WNP-2, six properties have been determined to be eligible for inclusion on the " National Register of Historic Places" and are within a 30-mile radius of the WNP-2 site (1) These properties are entitled to the same protective measures provided for pro-perties on the National Register pursuant to the procedures of the President's Advisory Council on Historic Preservation.

The six properties are: the Hanford Island Archaeological Site, 18 miles north of Richland; the Hanford North Archae-ological District, 22 miles north of Richland; the Paris Archaeological Site, Hanford Works Reservation; the Snively Canyon Archaeological District, 25 miles northwest of Richland; the Wooded Island Archaeological District, north of Richland; and the Savage Island Archaeological District 15 miles north of Richland.

The location of all six of the properties is within the boundary of the Hanford Reservation which has provided protection to these archaeological sites from destruction by relic collectors through security procedures and restricted access. The Wooded Island Archaeological District is located about two miles south of the WNP-2 intake, and the WNP-2 pumphouse will be visible from the north end of Wooded Island. Other than this specific visual alteration, none of the six properties are anticipated to be adversely affected by WNP-2. The State Historic Preservation Officers review of the impact of plant operation on the Wooded Island site is contained in Appendix III.

2.6-1

WNP-2 ER The historic-ethnographic people who aboriginally occupied the stretch of Columbia River from Priest Rapids to Pasco, Washington, were the Wanapam* Indians (" River People").

Historically, th PriestRapids,(2ymainvillageoftheWanapamwaslocatedat approximately 43 miles upstream from the WNP-2 area. There is archaeological evidence, however, that other village sites closer to the project area were important in prehistoric times, such as the extensive village at Wahluke, located 24 miles upstream from the Project area, which was excavated in 1926-27 by the U.S. National Museum. (3)

There is no ethnographic evidence that the Wanapam people occupied the immediate Project area. The last Wanapam occupation of the Project area was in 1943 when the Hanford Reservation was established and the area evacuated. Today, remaining descendants of the Wanapam people live at Priest Rapids and on the Yakima Indian Reservation. Their recent history has been preserved by Relander.(4)

The archaeology of the middle Columbia River in South Central Washington is largely unknown. Large-scale research was conducted in the McNary) Dam the early 1950's.(5,6,7 Reservoir area to the south in Upstream, approximately 69 miles, some research was conducted in the Wanapum Dam Reservoir area.(8,9) The only archaeolo Reservation since Krieger's (3) gywork conducted on the at Wahluke wasHanford a p inarysurveyandtestprogramalongtheColumbiaRiveryggpm-and a field and laboratory investigation near the Hanford No. 1 Generating Plant carried out by Rice (ll) under contract with the Washington Public Power Supply System. This study provided a comparative collection of artifacts from an area that has not been studied for over 40 years. It also pro-vided archaeological evidence that demonstrated aboriginal culture stability and continuity for at least 6500 years.

It further demonstrated that the archaeological resource within the Hanford area is considerable and warrants further investigation and preservation.

The services of Dr. David G. Rice, Associate Professor of Anthropology, University of Idaho, a professional archae-ologist with experience in the Pacific Northwest, were retained by Burns and Roe, Inc. (architect engineer for WNP-

2) in order to determine whether or not archaeological and historical resources might be affected by project construc-tion or transmission line relocation for WNP-2.

Field examination of the) complete August 19, 1972(12 Project and of the area was pumphouse and conducted intake areaon again between January 6 and 10, 1975 and on February 3, 1975.(13)

• Stu6ents of Anthropology spell the Indian name as Wanapam.

Historical references spell it Wanapum.

2.6-2

WNP-2 ER S' No archaeological features or historic structures were observed at the reactor site.(12) Geological work at the reactor site indicates that the sediments present include glacial flood gravels and associated sediments which by their nature are not likely to contain archaeological deposits. These observations also pertain to the corridor between the reactor site and the Columbia River.l14)

During the 1972 field examination, evidence was observed of intermittent occupation by aboriginal people adjacent to the west bank of the Columbia River in the vicinity of the WNP-2 pumphouse and water intake. Neither surface concentrations of archaeological materials nor any accumulated depth of occupational debris were observed. Also no historical structures or features were observed. Dr. Rice recommended that no further archaeological or historical work be provided for WNP-2 except that the excavation of the pumphouse be re-examinedatthetimeofconstructionforp7ggpblesub-surface evidence of aboriginal occupation Approximately 40C to 500 ft. southeast of the intake water pumphouse area are two archaeological sites (45-BN-ll3 and 45-BN-ll4) located on the gravel beach on the west bank of the Columbia River. These sites will not be disturbed, and future access will remain unchanged.

In January 1975, Dr. Rice conducted archaeological investigations

('N in the area of the WNP-2 pumphouse and water intake to (s l determine whether or not subsurface evidence for aboriginal occupation existed. Scattered fire cracked rocks and three cobble implements were recovered in an area 40 feet by 30 feet. Dr. Rice's interpretation of the cultural materials observed is that the immediate project area was intermittently used as a camp site by small groups of prehistoric peoples over the last few hundred years. Their stay at these camps was evidently brief judging from the sparse accumulation of cultural material and artifacts. Since aeolian sediments overlie the cultural material and since the cultural material lies comformably upon overbank river deposits, Dr. Rice concluded that the archaeological material has been deflated by wind erosion into a single floor. The absence of organic material like bone or shell tends to corroborate this view.

No earlier occupations were encountered in the sediments of the river terrace. Dr. Rice recommended that no further archaeological work be provided for the construction site of the WNP-2 pumphouse and water intake.(13)

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2.6-3

/

WNP-2 ER The transmission line from the Project makes connection to the Bonneville Power Administrations 500 kV switchyard in the 100-N Area of the Hanford Reservation. (See Figure 2.1-2 for location of the 100-N Area). The 18.3 mile long by 135 ft. wide corridor goes in almost a straight line from WNP-2 to the switchyard. Since the corridor is well inland from the Columbia River it does not traverse areas likely to be rich in artifacts from earlier river-oriented tribes.

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'l CHAPTER 3 THE PLANT 3.1 EXTERNAL APPEARANCE Figure 2.1-4 shows the relative location of the WNP-2 plant, makeup water pumphouse, adjacent roads, railroads and trans-mission lines. Figure 2.1-3 shows the layout of the buildings, structures, roads, and railroads for the plant.

Figure 3.1-1 is a color oblique aerial photograph from the west of the construction site looking east with the Columbia River in the background. Shown in the photograph are the main plant buildings, spray ponds, and cooling towers.

Figure 3.1-2 is an artist's conception of the finished plant (looking south-west) including the spray ponds and the cooling towers.

Two spray ponds are located approximately 600 ft. southeast of the diesel generator building. Each is 250 ft. square and 15 ft. deep.

Six round concrete mechanical (induced) draft cooling towers

-^ (See Figures 3.1-3 and '.4-1), each 60 ft. high and 200 ft.

('~'s) in diameter, and the ciaculating water pumphouse, are located approximately 700 ft. south of the radwaste and control building.

The makeup water pumphouse (See Figures 3.1-4 and 3.1-5) is located 3 miles east of the plant on the west shore of the Columbia River Mile 352 (at an elevation of 374 ft. 6" above MSL), and will supply makeup water for WNP-2.

The bottle storage building, for storing hydrogen, carbon dioxide and nitrogen, is located 367 ft. north of the turbine generator building (See Figure 2.1-4).

Two 400,000 gallon, 40 ft. high condensate storage tanks are located 36 feet north of the turbine generator building. An 800,000 gallon concrete dike, surrounding the tanks, will contain any spills.

The locations and elevations of all gaseous and liquid radio-active release points are shown in Figure 3.1-6.

All of the structures are functional in design and the maxi-mum effort has been made to achieve an esthetically pleasing appearance. Within the plant fence line, the grounds will es be seeded with grass or stabilized with gravel. Unused

/ ) plant property not seeded or graveled will be left in

%.J 3.1-1

WNP-2 ER its natural state. Nothing will be allowed to grow within 20 feet of the plant security fence line.

Seclusion of the plant is achieved by it's location within the llanford Reservation where travel by the general public is restricted. Low profile mechanical draft cooling towers and appropriate coloring of the plant, facilitate the intre-gation of the plant with the desert plain surrounding the site.

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_- WMP-2 is a single unit nuclear electric generating plant having a nominal electric power output of approximately 1100 MWe. The plant, designed by the architect-engineer Burns and Roe, Inc., consists of a boiling water reactor, turbine generator, evaporative cooling tower system, a pumphouse which takes makeup water from the Columbia River, a 500 kilo-volt transmission line leading to the Bonneville Power Administration's H. J. Ashe Substation adjacent to the site, and other associated facilities required for the generation of electric power.

3.2.1 Nuclear Sts .m Supply System The Nuclear Steam Supply System (NSSS) consists of a General Electric Co. boiling water reactor and the necessary auxiliary systems required to control, contain, and service the nuclear core. The system has a guaranteed output of 3323 megawatts.

A reactor pressure vessel houses the nuclear core where nuclear fission provides the energy required to produce steam. The core contains 764 fuel assemblies, 185 control rod assemblies, and other supporting hardware. The fuel consists of uranium dioxide pellets with enrichments varying l2 from natural (0.71) to 3.0 weight percent U-235 clad with e zircaloy.

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The initial core will contain fuel assemblies having an j2 average enrichment ranging from approximately 0.71 to 2.19 weight percent U-235. The core average enrichment will be about 1.87% U-235 depending on initial cycle requirements. I Each assembly will contain between one and seven different l2 enrichment rods. Selected rods in each assembly will, The in addition, be blended with gadolinium burnable poison.

reload fuel will also contain four different enrichment rodsThe with an average enrichment between 2.5% and 3.1% U-235.

reload fuel average enrichment will be about 2.71% U-235 depending on operating cycle requirements.

Five to seven different U-235 enrichments are used in the en- l2 riched fuel assemblies to reduce the local power peaking.

Low enrichment uranium rods are used in the corner rods and in the rods nearer the water gaps; higher enrichment uranium is used in the central part of the fuel bundle. The fuel rods are equipped with characteristic mechanical end fittings to assure proper assembly preventing a higher enrichment rod to be fitted in a location of a lower enrichment rod. The general layout of the core, core cell, and fuel 3.2-2, assembly and 3.2-3.

uranium enrichment is shown in Figures 3.2-1, Cooling of the core is accomplished by boiling water which is s

recirculated using jet pumps located in the peripheral area

/esi V Amendment 2 3.2-1 October 1978

WP-2 ER around the core inside the reactor. The pumps are powered from tw'e' externally located motor driven centrifugal pumps which draw a fraction of the reactor water from the vessel and return it with increased pressure, to the jet pumps.

(See Figure 3.2-4) The power level and rate of steam produc-tion is controlled by hydraulically activated control rods.

The steam that is produced in the core is separated from the reactor water and dried in the top of the vessel prior to exit from the vessel. The guaranteed steam flow is 14,295,000 lbs. per hour with 985 psi absolute and 0.3% moisture outlet conditions. The thermodynamic parameters of the reactor are shown in Figure 3.2-5.

The reactor is controlled at a nearly constant pressure.

During normal operaticns, the steam admitted to the turbine -

is controlled by the turbine initial pressure regulator which maintains essentially constant pressure at the turbine inlet, thus controlling the vessel pressure. The integration of the turbine pressure regulator / control system and the reactor recirculation flow control system permits the quantity of steam being produced to respond automatically to the tur-bine demand.

The nuclear system is supported by the specialized functions of its auxiliary systems. The major auxiliary systems used for normal operation are:

Reactor Water Cleanup System Residual Heat Removal System Fuel Pool Cooling and Filtering System Cooling Water Systems Radioactive Waste Disposal Systems Details of these systems are described in the Final Safety Analysis Report.

Other auxiliary systems are provided as backup or emergency systems to ensure safe shutdown of the reactor during any design basis accident including those resulting from natural phenomenen such as earthquakes, tornadoes, and floods.

3.2.2 Turbine System The turbine system (See Figure 3.2-6) uses the Rankine steam cycle with a closed regenerative feedwater heating cycle.

Steam leaves the reactor vessel at 985 psia and enters the turbine at 970 psia with a .38% moisture content. The turbime-is an 1800 rpm tandem compound turbine generator of .-

0 3.2-2

WNP-2 i ER J

Westinghouse Electric Corp. manufacture having a six-flow exhaust end with 44" last stage blades. Steam is exhausted into a condenser with 792,000 sq. ft, of surface and designed

! for a 2.5 in. backpressure. The net plant heat rates at the i '

backpressure variations ranging from 1" Hg to 4" Hg for maxi-3 mum load at 5% overpressure, 75%, and 50% are plotted in Figure 3.2-7. Six stages of regenerative feedwater heating are provided including four from the low-pressure turbines, arranged in three parallel strings and two from the high-1 pressure turbine, arranged in two parallel strings. The final design feedwater temperature at normal full load is 4200F.

The power cycle includes a reheater at the high-pressure tur-bine exhaust. Reheating is accomplished in two stages by

! using steam from the reactor and from one extraction stage of i the high pressure turbine. Two reheater moisture separator i

assemblies are used.

The turbine generator is guaranteed to deliver 1154 MWe, measured at the generator terminals, when operated at steam conditions listed above, associted with Nuclear Steam Supply l System (NSSS) guaranteed power. In-plant electric power con-sumption is expected to be approximately 50 MWe resulting in an estimated net plant electrical output of approximately 1104 MWe.

! O The turbine building is arranged with the longitudinal axis of the turbine-generator oriented in an approximate east-west direction. The reactor building is immediately south of the turbine building (See Figure 2.1-4).

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ciu. INcME3 4.84 l0.:s1 1.58 0.3a 0.158 lo.640 Amendr.ent 2, October 1978 NASHINGTON PUBLIC POWER SUPPLY SYSTEM WPICAL COE CLL WPPSS NUCLEAR PROJECT NO. 2 Environmental Report FIG. 3.2-2

8 x 8 LATTICE (2.10% ENRICHMENT) 6 5 4 3 3 4 5 6 5 4 2 1 1 1 3 5 4 2 1 1 1 9 1 4 3 1 1 7 10 1 1 3 3 1 1 10 8 1 2 3 4 1 9 1 1 2 2 4 5 3 1 1 2 2 4 5 6 5 4 3 3 4 5 6 ROD TYPE NO. WT % U235' 1 19 3.00 2 7 2.60 3 10 2.20 4 10 2.00 5 8 1.70 6 4 1.30 7 1 Gd203 8 1 Gd203 9 2 Gd203 10 2 WATER ROD

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LEGEND ASSUMED SYSTEM LOS$E5 O

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,O. 14,389,000 # 14,256,000 #

, 35,700,000 # 3323MWI 420 F, 397.8 h j( 420.0 F 397.6 h 534 F, 528.7 h i/ i f TOTAL CORE 2RECIRCULATl0N LOOPS FLOW 20 INTERNAL JET PUMPS 108.5 x106 ,

Ah= 1.2 9 e 1,Iiilj Core thennal power 3323.0 MW Pump heating + 12.4 t g.m Cleanup demin. 436 F system loss - 4.4 415.3 h Other system losses -

1.1 CLEANUP TURBINE CYCLE USE 3329.9 MW i i DEMINERALIZER t

SYSTEM l l R00 DRIVE 39,000 # 133,000 #

FEED FLOW 80 F 533 F i 48 h 527.5 h l - _-

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WASHINGTON PUBLIC POWER SUPPLY SYSTEM GE REACTOR SYSTEM HEAT BALANCE WPPSS NUCLEAR PROJECT NO. 2 FOR RATED POWER Environmental Report FIG. 3.2-5 l

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4 WNP-2 ER

/

(_m) 3.3 PLANT WATER USE 3.3.1 Overall Plant Water to meet normal operating requirements is withdrawn from the Columbia River by the cooling tower makeup pumps. Hydro-logical data for the river are presented in Section 2.4.1.

During periods when the cooling tower makeup pumps are not operating, small quantities of makeup demineralized water and potable water may be produced using the standby well water supply. The quantity of plant makeup water withdrawn from the Columbia River is primarily dependent upon water losses from the circulating water system in the form of cooling tower evaporation, drift and blowdown. Other systems in the plant water balance include: process water treatment system, potable water and sanitary waste system, and chemical and radwaste systems.

Figure 3.3-1 is a water use flow diagran for the plant.

Table 3.3-1 lists plant water use when operating at maximum power operation (expected average power operation) and tempor-ary shutdown conditions. Average consumptive water use, that is, water withdrawn but not returned to the river, at 100%

load factor, is approximately 13,000 gpm which is 0.026% of the annual average Columbia River flow and 0.08% of the mini-s mum licensed river flow of 16,200,000 gpm.

(~A L~

3.3.2 Heat Dissipation System A recirculating cooling water system with mechanical draft wet cooling towers will dissipate excess heat from the condens-ing steam in the main condenser and other plant auxiliary heat exchange equipment, to the atmosphere. The temperature of the closed cycle cooling water is increased by about 280F by passing through the main condenser and other plant auxil-iary heat exchange equipment. The cooling water temperature is reduced in the cooling towers by the evaporation of water and by the transfer of sensible heat to the atmosphere. The evaporation rates from the cooling towers varies with plant operation power level, ambient air temperature and humidity.

A small quantity of water is entrained in the air passing through the cooling tower and is lost from the system as

" drift". Drift eliminators are used in the cooling towers to minimize this loss, which will average about 285 gpm.

Dissolved and suspended solids, originally present in the river water, are concentrated in the cooling towers by the evaporation process. A small portion of the circulating water is withdrawn, by blowdown, to control the solids lev?1 as part of cooling water chemistry management. When operating at fullpower operation, it is expected that the cooling tower O

(_J 3.3-1

WNP-2 ER blowdown flow, returned to the Columbia River, will average 2580 gpm. A detailed discussion of the heat dissipation g

system is given in Section 3.4. Environmental effects are described in Section 5.1.

3.3.3 Process Water Treatment Systems Process water treatment systems prepare river water for station use, potable and sanitary water use, and miscellaneous water requirements. River water, which is used for potable water, sanitary water, and demineralized water, is first treated by filtration for the removal of suspended matter.

A maximum of 250 gpm of filtration capacity is provided. It is anticipated that the average operating demand for filtered water will be approximately 10 gpm.

The makeup water demineralizer provides high quality water for station use including filling and replacement of losses from the nuclear steam supply system, chemical control solution preparation, and the replacement of water lost in waste treatment processes. Virtually all liquid wastes from normal station operations are treated in the radioactive and

! chemical waste system and recovered to the extent possible l for reuse in the primary system. The makeup water demineralizer 1l has an operating capacity of 150 gpm but is expected to I operate at an average flow rate of about 6 gpm during normal l operation. At times of system fill and outages, the system I will operate near design capacity.

Filtered water will also be used in the potable water and danitary waste system. This facility has a capacity of 50 gpm but is expected to operate at an average daily rate of about 2,500 gal / day.

3.3.4 Chemical and Radwaste Systems Virtually all chemical waste from the station is processed through the radwaste system. Consumptive water use is approximately 100 gal / day. This represents the quantity of liquids lost through solid waste processes. Solidified wastes in sealed radioactive waste container 0 will be removed by a licensed contractor for storage at a licensed facility.

A detailed discussion of the radwaste system is given in Section 3.5.

3.3-2 Amendment 1 May 1973

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WNP-2 .

i 4 Maximum Power Operation Temporary Shutdown Re- Re-Con- turned Con- turned Total sumptive to Total sumptive to Flow Use River Flow Use River i

' (gpm) (gpm) (gpm) (gpm) (gpm) (gpm) l l A. Circulating Water  !

! Systems j

?

til i :o a) Evaporation 12,588 12,588 ---

368 368 ---  :

I b) Drift 285 285 ---

c) Blowdown 2,580 ---

2,580 i

B. Other Systems d) Process Water Treatment 10 4 6 10 4 6  ;

Chemical and Radwaste* 6 1 5 6 1 5 i i Potable and Sanitary

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l C. ' Total (a+b+c+d) 15,463 12,877 2,586 378 372 6  !

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WNP-2 ER

[mT 3.4 HEAT DISSIPATION SYSTEM V

Heat is dissipated from the WNP-2 turbine condensers by a mechanical draft cooling tower system. Thermal impacts on the Columbia River are avoided.

A description of the heat dissipation facilities for WNP-2 is provided in the following subsections. The environmentel effects due to the operation of the WNP-2 heat dissipation system are discussed in Section 5.1.

3.4.1 Mechanical Draft Cooling Towers 3.4.1.1 General A mechanical draft tower system utilizes evaporative cooling by contacting the warm water with air. The water is cooled both by sensible and by evaporative heat transfer. Intimate contact of water with air is accomplished by introducing the warm water at the top of the tower causing flow by gravity, through fill material, crosscurrent to the air. Air is in-troduced into the tower through louvered side panels, flows upward through the tower fill material, passes through the drift eliminators, through the fan stack (which houses the air moving equipment) and finally discharges to the atmos-phere. The cooled water is collected in basins at the base

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of the tower.

During this cooling process, a small percentage of the total water inventory is lost due to evaporation and drift. In addition, water is discharged from the system through system blowdown, required to limit the concentration of naturally

occurring river salts in the closed cycle as a result of the evaporation process. The water makeup system, which provides the necessary water to keep the system in equilibrium, is discussed in Subsection 3.4.2.1.

3.4.1.2 Design of the Mechanical Draft Cooling Towers In the design of the cooling tower system, the following features related to environmental matters were considered:

a. blowdown requ.' cements including outfall structures,

b. makeup requirements, l

c. meteorological effects,

d. hydrological effects, and

e. chemical and thermal effects on natural bodies of water.

(7 -)

3.4-1

y WNP-2 ER The heat dissipation system is designed to cool 570,000 gpm of cooling water, rejecting 7.88 x 109 BTU /hr to the environs.

The heat load for the WNP-2 cooling towers comes almost en-tirely from the 550,000 gpm circulating water system (with a travel time across the condenser of 15.17 seconds). The only major WNP-2 heat dissipation subsystem is the plant ser-vice water system. This system provides cooling water for most of the plants cooling coils, etc. and results in less than 4% of the heat load as provided by the circulating water system. The effect on the environment due to the added heat resulting from the plant service water system is insignifi-cant in comparison to the heat to be dissipated by the cir-culating water system. As shown in Figure 3.4-1, six towers are used, with each cooling tower approximately 60 feet to the top of the fan stacks and approximately 200 feet in diam-eter (see Figure 3.1-3). Each tower is provided with 6-200 hp, 30 foot diameter fans used to induce the draft required to operate the tower. The discharge velocity from the fan stacks will be approximately 33 fps. Figure 3.4-2 is a cut away view of one tower and Figure 2.1-4 shows the relation of the towers with the main plant structures.

Cooling water for the condensing of the turbine exhaust sys-tem is supplied to the tube side of the condenser by circu-lating water pumps located in the circulating water pump house. These pumps take suction from the tower basins and are designed with sufficient head to pump through the con-denser back to the cooling tower distribution system.

Design values for the cooling towers are:

Wet-bulb temperature 60 F Approach to wet bulb 16.3 F Range 28 F Cold-side temperature 76.3 F These numbers indicate that under design conditions, cooling water at 76.30F enters the condensers where it is heated 280F to 104.30F. From there this hot water is pumped to the cool-ing tower where, in air with a wet-bulb temperature of 600F, it is cooled to 76.30F, which is within 16.30F of the wet-bulb temperature. The 76.30F water is returned to the con-denser and the cycle is repeated. A cooling tower perform-ance curve is shown in Figure 3.4-3.

Although the individual towers are designed for a 60 F wet-bulb temperature, it is necessary to provide for plant oper-ation at less favorable conditions, so a conservative worst-case value of 700F wet-bulb temperature was chosen for plant capacity design calculations. This is reasonable in terms 3.4-2

WNP-2 ER

/, t of data shown in Table 2.3-22, which shows that the annual

\- # wet-bulb temperature for the WNP-2 site is such that a wet-bulb temperature between 600 and 650F would not prevail more than 6.68% of the year and one higher than 650F not more than 1.87% of the year.

3.4.2 Circulating Water System Balance Water is lost from the heat dissipation system by evaporation, drift, and blowdown. To balance these losses, makeup water from the Columbia River is required.

The design values used for blowdown are based on a dissolved solids concentration factor of about five (with a range of 3-10) in the cooling tower water as compared to river water.

The nominal blowdown rates calculated for normal operation vary from about 2000 to 4000 gpm. A higher rate, i.e., up to 6500 gpm, may be needed on occasion to lower the concentra-tion of dissolved solids in the circulating water system .

(The composition of the Columbia River and blowdown water is given in Table 3.6-1)

Expected values of evaporation rates, blowdown temperatures,'

normal river temperatures, and blowdown rates are given in Figure 3.4-4 as a function of time of year. These curves r' N each give an expected average over the month. Actually, a

( ,/ range of values above and below the curves would represent conditions from expected maxima to expected minima. For example, the average blowdown water temperature is shown to be about 750F in August. In August the range of blowdown tem-perature extends about 70F above the average, to a maximum of 820F. This is the maximum temperature expected at which water would be returned to the river. This maximum value is based on the assumption that heat transferred in the cooling towers is entirely by evaporation, with no transfer of sen-sible heat from the warm water, since in summer the ambient air dry-bulb temperature would be high.

The following table gives both maximum and annual average values for the heat dissipation system. Consumptive use is evaporation plus drift, where drift is taken as 0.05% of the circulating water system flow rate. Drift was determined through the use of em experimental data (1).pirical relationships Required makeup is determined evaporation from plus drift plus blowdown.

Maximum Annual Average Values, gym Values, gpm Consumptive use 16,500 12,873 m Blowdown 6,500 2,580 j Required makeup 23,000 15,453 3.4-3

WNP-2 ER The actual makeup water capacity for WNP-2 is 25,000 gpm (See Section 3.4.2.1) . See Figure 3.3-1 for a plant water balance chart.

3.4.2.1 Intake System Makeup water for WNP-2 is taken from the Columbia River via a river intake which is located approximately 3 miles due east of the plant site. The intake system is made up of three parts: two perforated pipe inlets supported offshore above the bed of the river and approximately parallel to tr e river flow, two 36 inch diameter steel lead-in pipes approximately 900 ft. long, and the pump structure embedded into the river bank with a major portion beluw grede. The intake system general plan is shown in Figure 2.4-6. Figure 3.4-5 is a detailed plan and profile of the intake system.

The pump structure contains three makeup water pumps, each having a capacity of 12,500 gpm. Two pumps with a combined pumping capacity of 25,000 gpm will supply maximum plant water requirements, the third pump will be a spare. Architec-tural elevations and an artist's conception of the pump struc-ture are shown in Figure 3.1-4 and 3.1-5. Plan and sections of the pump structure are shown in Figure 3.4-6. The pump house contains only the pumps, pump operating auxiliaries and flow control provisions. There are no screens or other water cleaning facilities in the structure.

Details of the "T" intake section and its connection to the two lead-in pipes are shown in Figure 3.4-7. Each "T" inlet is constructed of perforated steel pipes, with an outer 42-inch diameter pipe having 3/8-inch diameter holes covering about 40 percent of the area and an inner 36-inch diameter sleeve with 3/4-inch diameter holes covering about 7 percent of the area. The perforated pipe surface serves as the water cleaning facility. The outer sleeve is designed to prevent trash and fish entrainment and the inner sleeve is designed to provide uniform intake velocities through the outer sleeve perforations.

The inlet velocities are expected to be well below the accept-able limit required for suitable protection of small fish when water is being taken into the system. At the external screen surface under maximum operating conditions, with 12,500 gpm flowing through each "T", the velocity through the external screen openings is approximately 0.5 fps. At a distance of less than one third inch from the outer screen surface, the inlet approach velocity drops to less than 0.2 fps. Figure 3.4-8 shows the velocity profile of water approaching the inlet for two modes of circulation flow, as determined by hydraulic model testing (2). Figure 3.4-9, from the same model test series, shows the velocity distribution for 25,000 gpm h 3.4-4

WNP-2 ER

(~'% through one inlet at 3/8-inch distance from the screen surface (s / (abnormal or emergency condition). As shown in Figures 3.4-8 and 3.4-9, during normal or abnormal flow, flow velocities are low and flow distribution is even. During reduced flow, the perforated pipe intake velocity characteristics would be proportionately reduced.

Undersirable debris is not expected to pass through the outer perforations with these very low inlet velocities. A back-wash system has been provided to permit low velocity flow reversal through the perforations. The perforated sleeves have been designed to reduce the potential for debris collec-tion and to permit complete removal for periodic inspection, cleaning, repair and replacement. The frequency of backwash-ing and sleeve removal for the objective of minimizing bio-logical damage will be determined from a one year monitoring program including, but not limited to visual inspections of the intake and sampling to determine fish losses.

3.4.2.2 Discharge System The blowdown discharge system is a single pipe of varying diameter, running from the plant to the Columbia River. The layout of the discharge line is shown in Figure 2.4-6. It is buried underground and runs parallel to the makeup water line. The blowdown line in the river is located downstream of the intakes and is buried in the river bed. The exit point (73) is a rectangular slot (See Figure 3.4-10) and is located as shown in Figure 2.4-6, about 175 feet from the river low water line. Adequate riprap has been placed around the discharge to avoid any erosion to the river bed.

The line has been designed to accommodate a maximum blowdown 1 rate of 6,500 gpm. However, the average blowdown will be in the range of 2,000 - 4,000 gpm. Capability has been provided for greater discharge rates, should it become desirable.

Control of slimes and algae within the circulating water system is discussed in subsection 3.6.3. Removal of any algae and slimes will be via the blowdown. Discharge of blowdown to the river will not occur during chlorination.

3.4.3 Spray Ponds Two concrete basin spray ponds are provided for emergency cooling. In accordance with present requirements, the water inventory contained therein is adequate for emergency cooling for a period of thirty days. Each pond is 250 feet square with a combined surface area of 2.87 acres. Each pond is 15 feet deep, consisting of 14 feet of water and 1 foot of free

,_ board. Figure 2.1-4 shows the location of the spray ponds.

G 3.4-5

WMP-2 ER Slimes and algae in the spray ponds will be controlled with chlorine. Any discharges to the river would occur via trans-fer to and mixing with the cooling tower basin water.

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WNP-2 ER (O

_> 3.5 RADWASTE__ SYSTEMS AND SOURCE TERM 3.5.1 Source Term 3.5.1.1 General The source terms for both normal operation and anticipated operational occurrences are based on a noble gas release rate of 60,000 pCi/sec after 30 minutes decay as detailed in ANS Standard N237, " Source Term Specification. " (1)

Estimates of release rates to the environment followed the guidance in the Draft Regulatory Guide " Calculation of Releases of Radioactive Materials in Gaseous and Liquid Effluents from Boiling Water Reactors (BWR ' s ) . " ( 2 ) Where guidance is not provided (e.g., fuel pool concentrations) reliance is placed on reported measurements. Improved fuel cladding integrity may result in lower releases than those indicated by measure-ments on early plants.

ROference is made to other subsections of Section 3.5 and to the SAR where appropriate.

3.5.1.2 Noble Gas Leakage Rates From Fuel For normal operation, the average source terms for the environ-(A) mental release are based on a total noble gas leakage rate from the fuel of 60,000 pCi/sec (af ter 30 min decay) . This leakage rate is based on the recog( endations standard on source terms. ) Table in the proposed 3.5-1 ANS N-237 shows concentrations in units of pCi/g of steam at the reactor vessel steam nozzle, i.e., at decay time t = 0. Multiplication by the steam flow rate, 1.8 x 106 g/sec yields the release rate in pCi/sec.

l Table 3.5-2 lists the calculated radionuclide release rates l at t = 0 and t = 30 min decay. The latter is the rate at t = 0 multiplied by the decay factor e At at t = 30 min.

l l 3.5.1.3 Halogens I The equilibrium concentrations in the reactor water and steam at the reactor exit nozzles for computing average source terms are shown in Table 3.5-3. The iodine carryover fraction from reactor water to steam is taken as 0.02. (2) 3.5.1.4 other Fission Products and Corrosion Products The other fission product and corrosion product source terms are shown in Table 3.5-4 (fission products) and Table 3.5-5 (corrosion products). The carryover watertothesteamistakenas0.001.jgyctionfromreactor

({])

3.5-1

WMP-2 ER 3.5.1.5 Water Activation Products h The water activation products used in the source term calcu-lations are shown in Table 3.5-6.

3.5.1.6 Tritium In a BWR, tritum is formed from:

1. the fissioning of uranium within the fuel,

2. neutron reactions with boron in the control rods, and

3. activation of naturally-occuring deuterium in the primary coolant.

The tritium concentration in the reactor coolant is taken as 1 x 10-2 pCi/g of water or steam. (1)

The tritium released annually in liquid waste is estimated to be 0.01 pCi/ml from reference 2.

The tritium released through the building ventilation system is listed on Table 3.5-21. The principal sources are the equip-ment and valve leakages from the turbine and reactor buildings.

The sources of leakage from individual valves, pumps and other types of equipment are each too small to detect. Release estimates are therefore based on measurements made at opera-ting plants.

3.5.1.7 Source Terms for Fuel Pool The 376,000 gallon fuel pool is provided with a cooling and cleanup system to minimize the release of fission products, activation products and tritium to the reactor building envi-romment. The cleanup system, through filtration and ion exchange, removes fission and activation products from the coolant while the cooling systen minimizes evaporation of the tritum bearing water. Exposure of personnel to airborne radioactive material is further reduced by the placement of ventilation exhaust ducts around the periphery of the fuel pool and reactor well.

The fuel cooling and cleanup system consists of two circula-ting pumps, two heat exchangers, two filter demineralizers and two skimmer surge tanks together with the required piping, valves and instrumentation. The pumps circulate the pool water in a closed loop, taking suction from the surge tanks, circulating the water through the heat exchangers and filters, and discharging it through diffusers at the bottom of the fuel pool and reactor well. The water flows from the pool surface through scuppers and skimmer weirs to the surge tanks.

3.5-2

1 WNP-2 ER N

) 57e flow diagrams for the fuel pool cooling and cleanup

1. sistem and the fuel pool ventilation system are Figures 3.5-13 and 3.5-9 respectively.

The Bureau of Radiological Health reports concentrations measured at Dresden 1 for normal operating conditions. These results are listed in Table 3.5-7.

Data on air conditions above the pool are limited. Since the radionuclide concentration in the air above the fuel pool is speculative, the total releases from the reactor building are taken as a better value and include the contribution from the fuel pool.

3.5.1.8 Releases from Building Ventilation Systems Esthmr.tes of radioactive releases from ventilation systems are based on measurements of releases at operating boiling water reactors. The measurements and calculations used are those detailed in reference 2 and are summarized below.

3.5.1.8.1 Reactor and Containment Buildings Measurements at nine boiling water reactors indicated that the average Iodine-131 release rate during normal operation was 0.11 curies per year. Measurements of Iodine-131 released fi Ned from two of the plants during outages indicated an average ratio of Total I-131 released to I-131 released during normal operation of 3:1. The ratio (3 :1) of total release / operating release was multiplied by the average of operating release rates (0.11 Ci/yr) to obtain the expected total I-131 release rate. Iodine-133 releases were calculated using the ratio of I-133/I-131 in the reactor coolant.

The estimated noble gas release is the average of values

measured at two operating boiling water reactors.

Estimated releases of particulates are also based on measure-

! ments at operating boiling water reactors; however, the values are adjusted to reflect an 80% plant capacity factor.

Of the 20% downtime, 60 days are assumed to be long term outages (one week or more) while the remaining 13 days are short term shutdowns.

l Because of the differences in containment design between the measured plants and the WNP-2 design, the estimated releases were equally divided between the reactor building and contain-ment. Appropricte decontamination factors were then assigned to the containment releases to account for the effect of the standby gas treatment system.

lO I

3.5-3 L i

WNP-2 ER

'i Estimated releases from the reactor building and containmant h are listed in Table 3.5-8.

3.5.1.8.2 Turbine Building Releases of radioactive iodines, noble gases and particulates were estimated in the manner described for the reactor build-ing. Estimated values are contained in Table 3.5-9.

3.5.1.8.3 Radwaste Building Radwaste building releases were also based on measurements at operating plants and calculated in the manner described for the reactor building. Credit is taken, however, for HEPA filters located in the ventilation exhaust which considerably reduce the particulate releases from this source. Expected release rates are listed in Table 3.5-10.

3.5.1.9 Releases from Mechanical Vacuum Pump Estimates of radioactive releases via the mechanical vacuum pump are based on measurements made at two operating plants as detailed in reference 2. It is assumed that the mechani-cal vacuum pump is operated for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> during each of four shutdowns per year. 2xpected release rates are contained in Table 3.5-11.

3.5.1.10 Releases from Gland Seal Exhauster Because non-radioactive steam is used in the turbine gland seal system, it is expected that particulate and noble gas releases will be less than one curie per year and that iodine released will be less than 10-4 curies per year.

3.5.1.11 Answers to Appendix 3 Questions

1. a. Q: Plant capacity factor A: 80%

b. Q: Isotope release rates of noble gases to the reactor coolant and at 30 minutes decay, (pCi/sec)

A: See Table 3.5-2

c. Q: Concentration of fission products in the reactor coolant, p Ci/g .

A: See Table 3.5-4

d. Q: Concentrations of corrosion and water activa-tion products in the reactor coolant, pCi/g A: See Tables 3.5-5 and 3.5-6, respectively 3.5-4

WNP-2 ER

() e. Q:

A:

Tritium release rate Annual average taken as

.025 Ci/MWt x 3300 MWt = 2.6 pCi/sec 3.15 x 10 sec/yr

2. Q: The maximum core thermal power (MWt) evaluated for safety considerations in the SAR A: 3323 MWt

3. Q: The total steam flow, Ib/hr A: 1.43 x 107 lb/hr

4. Q: The mass (1bs) of primary coolant in the reactor vessel -

A: 5.53 x 105 lbs at normal water level.

5. a. Q: The average flow rate through the reactor coolant cleanup demineralizer A: 133,000 lb/hr at temperature = 533 F and enthalpy = 527.5 Btu /lb with both deminerali-zers in operation

b. Q: The type of resins used A: Powdex, strong base anion and strong acid y

cation

c. Q: The DF's used for the cleanup demineralizer A: Anion 10 Cs, Rb 2 Other 10

6. Q: The total mass (lb) of uranium and plutonium in an equilibrium core (metal weight)

A: For Uranium cycle, 15,000 MWD /T U = 136.4 Tonne Pu = 0.8 Tonne For Plutonium cycle U = 134.9 Tonne Pu = 1.4 Tonne l

7. Q: The percent enrichment of uranium in reload fuel A: Uranium cycle: 2.4 - 2.8%

Plutonium cycle: 2.4%

) 8. Q: The percent of fissile plutonium in reload fuel l A: Uranium cycle: 0.51%

Plutonium cycle: 0.62%

3.5-5

WNP-2 ER

9. a. Q: The regeneration frequency (days) for the h condensate demineralizers A: These are powder type demineralizers which are backwashed every 14 days

b. Q: The type of resins used A: Powdex

c. Q: The DF's used in the evaluation for the condensate demineralizer A: Anion 10; Cs, Rb 2; Other 10

10. Q: The flow rate (gpm) of water used to dilute liquid waste prior to discharge A: 2500 - 6500 cpm

11. Q: The input sources, average flow rates and activities of the wastes processed through the high purity waste system A: 18,380 GPD at 0.213 x Primary Coolant Activity

12. Q: Description of the system used to process the high purity waste. The process flow diagram for the high purity waste system, indicating all decon-tamination factors used in the evaluation A: See Section 3.5.2 for description and flow diagram:

DF for Iodine = 1000 DF for Cesium = 20 DF for other nuclides = 1000

13. Q: The high purity waste holdup times used in the evaluation and the fraction of the processed stream expected to be discharged over the life of the plant. The capacities (gal) of all tanks con-sidered in calculating the holdup time A: See Section 3.5.2 for tank capacities:

Collection time = 0.435 days Process time = 0.0617 days Fraction discharged = 0.01

14. Q: The input sources, average flow rates (gpd) and activities (fraction of Primary Coolant Activity) of wastes processed through the low purity waste system.

A: 5700 GPD at 0.132 x Primary Coolant Activity 9

3.5-6

WNP-2

, ER

)'

15. Q: Description of the system used to process the low purity waste. The process flow diagram for the low purity waste system, indicating all of the

, decontamination factors used in the evaluation A: See Section 3.5.2 for description and flow diagram:

DF for Iodine = 1000 DF for Cesium = 4 DF for other nuclides = 1000

16. Q: The low purity waste holdup times used in the evaluation and the fraction of the processed stream expected to be discharged over the life of the plant. The capacities (gal) of all tanks considered in calculating the holdup times A: See Section 3.5.2 for tank capacities:

Collection time = 1.403 days Process time = 0.0617 days Fraction discharged = 0.10

17. Q: The input sources, average flow rates (gpd) and activities (fraction of PCA) of water processed through the chemical waste system' A: 1400 GPD at 0.02 x Primary Coolant Activity

18. Q: Description of the system used to process the

- chemical waste. The process flow diagram for the (q^i) chemical waste system, indicating all decontamina-tion factors used in the evaluation A: See Section 3.5.2 for description and flow diagram:

DF for Iodine = 10,000 DF for Cesium = 10,000 DF for other nuclides = 10,000

19. Q: The chemical waste holdup times used in the evalua-tion and the fraction of the processed stream expected to be discharged over the life of the plant. The capacities (gal) of all tanks considered in calculating the holdup times A: See Section 3.5.2 for tank capacities:

Collection time = 8.571 days Process time = 0.833 days Fraction discharged = 0.10 1

20. Q: The stream leakage rate (lb/hr) to the turbine building considered in the evaluati0n. Descrip-tion of special design features used to reduce steam leakage and the fraction of iodine released.

If ventilation air is treated through charcoal adsorbers, the bed depth and the iodine decon-tamination factor used.

O 3.5-7

WNP-2 ER A: Steam leakage estimates were not used in evalua-tion of turbine building releases. Release estimates are based on measurements made at operat-ing plants as detailed in reference 2 There are no special treatment provisions for turbine building exhaust air.

21. Q: The steam flow (lb/hr) to the turbine gland seal and the source of the steam.

A: The total sealing steam flow to all turbines is 28,000 lb/hr of non-radioactive steam.

22. Q: The mass of steam (lb) in the reactor vessel A: 21,801 lbs during operation

23. Q: The design holdup time (hrs) for gases vented from the gland seal condenser, the iodine parti-tion factor for the condenser and the fraction of iodine released through the system vent. Descrip-tion of the treatment system used to reduce the iodine releases from the gland seal system A: There is no design holdup time for gases vented from the gland seal condenser. The gland seal steam is clean steam rather than process steam; see Question-Answer 21 above

24. Q: The primary coolant leakage rate (lb/ day) to the reactor building, the temperature of the coolant and the iodine partition factor used in calcu-lating releases from the reactor building in the evaluation A: Coolant leakage to the reactor building is not used in evaluation of reactor building releases. Release estimates are based on measurements made at operat-l ing plants given in reference 2 i

25. Q: Description of the treatment provided for the reactor building ventilation air to reduce iodine prior to discharge. The decontamination factor and the bed I

depth of the charcoal adsorber used in the evaluation A: See Section 3.5.3.3.2

26. Q: The holdup time (min) for off-gases for the main condenser air ejector prior to processing by the off-gas treatment system.

A: The holdup time is in excess of 10 minutes during normal operation i

1 3.5-8

WNP-2 ER

() 27. Q: Description and expected performance of the gaseous waste treatment system of the off-gases from the condenser air ejector. The expected air inleakage per condenser shell, the number of condenser shells and the iodine partition factor for the condenser.

A: There is one condenser shell which is divided into three chambers, each at its own pressure. The total expected air inleakage is 30 cfm for the entire system. See Section 3.5.3.2 for details

28. Q: The mass of charcoal in the charcoal delay system used to treat the off-gases from the main condenser air ejector, the operating temperature of the delay system and the dynamic adsorption coefficient for Xe and Kr, based on the system design used in calcu-lating the respective holdup times.

A: The operating temperature is 0 0F. The mass of char-coal in the system is approximately 24.6 tons.

The dynamic adsorption coefficients used in calcu-lating holdup tbnes are 105 cm 3 /g for Kr and 2410 cm 3 /g for Xe

29. Q: Description of cryogenic distillation system, frac-tion of gases partitioned during distillation, holdup in system storage following distillation and expected system leakage Q(_/ A: Not applicable

30. Q: Inputs to the solid waste system: volumes, curie contents and sources of wastes. Principal radio-nuclides, on-site storage tbnes prior to shipment.

Description of solid waste processing systems A: See Section 3.5.4

31. Q: Sources, flow rates (gpa) and activities of deter-gent wastes. Description of treatment processes, volumes of holdup tanks and decontamination factors used in the evaluation A: See Section 3.5.4. Note: No on-site laundry

32. Q: Process and instrumentation diagrams for liquid, gaseous and solid radwaste systems and all other systems influencing the source term calculations.

A: See Figures 3.5-1 to 3.5-11.

33. Q: Process and instrumentation diagrams for fuel pool -

cooling and purification systems and for fuel pool ventilation system. Provide the volume of the fuel pool and refueling canals, identify the sources O

3.5-9

WNP-2 ER of makeup water and describe the management of h water inventories during refueling. Provide an analysis of the concentration of radioactive materials in the fuel pool water following refuel-ing and calculate the releases of radioactive materials in gaseous effluents due to evaporation from the surface of the fuel pool and refueling canals during refueling and during normal power operation. Provide the basis for the values used A: See Section 3.5.1.7 3.5.2 Liquid Radwaste System 3.5.2.1 General The liquid radwaste system is composed of a group of sub-systems designed to collect, control, process, handle, store, recycle and dispose of liquid radioactive wastes generated as a result of normal operation and anticipated operational occurrences. These subsystems and the classification of wastes that these systems process are as follows:

a. Equipment drains subsystem - processes high purity wastes. These wastes have a normal conductivity level less than 50 gmho/cm and a radioactivity level less than 10~ uCi/cc.

b. Floor drain subsystem - processes intermediate purity wastes. These wastes typically have a higher conductivity level than equipment drains but have a lower radioactivity level on the order of 10-7 to 10-3 pCi/cc.

c. Chemical waste subsystem - processes low purity wastes. These wastes are of such high conductivity so as to preclude treatment by ion exchange.

The radioactivity concentrations are variable and substantially affected by chemical cleaning and decontamination solutions.

These systems are discussed in Subsections 3.5.2.2 through 3.5.2.5, respectively.

The water that is generated from liquid waste processing is recycled for plant reuse to the maximum extent practical.

Excess water is discharged from the plant to maintain an overall plant water balance. Excess water is discharged to the cooling tower blowdown line which is, in turn, dis-charged to the river. Table 3.5-12 lists the estimated O

3.5-10

WNP-2 ER

(') radionuclide concentrations that are discharged to the river cooling tower blowdown line. The concentrations listed were estimated using the methods and parameters of the GALE Code detailed in reference 2. The parameters used in this evalua-tion are not necessarily the same values used for design.

Design basis values for the equipment decontamination factors

are listed in Table 3.5-13. These factors are defined as the l ratio of the input radioactivity concentration to the output i concentration.

The liquid radwaste system equipment is designed for a maximum of 150 psig 'and 1500F operation. Collection and storage tanks i

are vented to the radwaste building exhaust system. The mixed bed demineralizers, precoat filters and concentrators are con-tained within pressure vessels. The quality classification for the system is in accordance with Regulatory Guide 1.26.

The liquid radwaste system is essentially a manual-start, auto-matic stop process. Process and radiation instrumentation allows for the initiation of batch processing from the Radwaste Control Room area or local operation areas. Inputs to the various subsystems originate from both occasional unscheduled sources such as . sumps and from scheduled events such as process equipment flushing.

The portions of the radwaste and control building which are Seismic Category I are the radwaste area for El. 437'-0" to El. 467'-0" and the vertical portion of the building encompas-sing the area of the control room. The remainder of the l building is Seismic Category II.

A process flow diagram, Figure 3.5-1, together with process data, Table 3.5-14, shows the tank capacities, system flow rates, design capacities of components, holdup tbnes and total radionuclide inventories for the various radwaste subsystems.

Piping and instrumentation drawings of the subsystems with collection and discharge piping are shown in Figures 3.5-2 through 3.5-4.

3.5.2.2 Equipment Drain Subsystem Description The equipment drain subsystem collects and treats wastes from the following sources:

i

a. Drywell equipment drain sump i

b. Reactor building equipment drain sump 3.5-11

WNP-2 ER

c. Radwaste building equipment drain sump

d. Turbine building equipment drain sump

e. Reactor water cleanup system

f. Residual heat removal system

g. Cleanup phase separators (Decant water onl i)

h. Fuel pool seal rupture drains

i. Condensate phase separators (Decant water only)

Table 3.5-15 lists the quantity from each of the above sources that are processed in this system.

The wastes from these sources are pumped or drained into the waste collector tank. The waste collector tank contents are pumped through the wasto collector filter and waste deminerali-zer to the waste sample tanks where the liquid is monitored prior to release to the condensate tanks or the cooling tower blowdown line or recirculated for further processing.

(See Figure 3. 5-2)

In the event of a component malfunction within the equipment drain subsystem, sufficient crossties are provided to the floor drain collector subsystem to permit continued processing of the wastes. Sufficient capacity is provided in the equip-ment to handle such conditions.

3.5.2.3 Floor Drain Subsystem Description The floor drain subsystem collects and treats wastes from the following sources:

a. Drywell floor drain sump

b. Reactor building floor drain sumps

c. Radwaste building flocr drain sumps

d. Turbine building floor drain sumps

e. Waste sludge phase separator G

3.5-12 L

WNP-2 ER r

(j\ The wastes from these sources are pumped into the floor drain collector tank. Table 3.5-16 lists the quantity from each of the above sources that is processed by this system. The floor drain collector tank contents are pumped through the floor drain collector filter and the floor drain demineralizer to the floor drain sample tank. Here the fluid is sampled prior to discharge to the condensate storage tank or the cool-ing tower blowdown line. (See Figure 3.5-3)

Similar to the equipment drain subsystem, the floor drain sub-system normlly functions as an independent process string.

Intersystem crossties are provided with the equipment drain subsystem to allow continued processing of floor drain wastes.

3.5.2.4 Chemical Waste Subsystem Description The chemical waste subsystem collects and treats wastes from the following sources:

a. Detergent drains

b. Shop decontamination solutions

c. Reactor, turbine and radwaste building decontamina-tion draias

d. Low purity wastes from either the equipment or floor drain subsys,tems

e. Chemical cleaning solutions from filter deminerali-zer units

f. Battery room drains

g. Chemical system overflows and tank drains

h. Laboratory drains

i. Chemical waste sump (radt:aste building)

The quantities from the above sources are listed in Table 3.5-17. These wastes are collected in the chemical waste tank. The contents of this tank are recirculated through a mixing eductor in the tank. During recircula-tion, the fluid is sampled and a neutralizing solution is added as required from one of the chemical addition tanks, iQ l 3.5-13

WMP-2 ER Samples are taken and if a neutral solution is indicated, h the liquid is pumped to the decontamination solution con-I centrator. The concentrator bottoms are blown to one of the decontamination solution concentrated waste tanks.

From here, the concentrator bottoms are pumped to the decontamination solution concentrator waste measuring tank. This tank admits a pre-determined quantity of wastes for processing through the solidification system.

The concentrator distillate is condensed in the decontmnina-tion solution condenser and stored in the distillate tanks The distillate is sampled and if the radioactivity level and water quality is acceptable, the distillate is pumped to e the condensate storage tanks. If the radioactivity level or water quality is unacceptably high, the distillate is processed through the distillate polishing demineralizers or reprocessed through the decontamination solution concentrators.

It is resampled, and if acceptable, it is pumped to the condensate storage tanks. As with the other subsystems, when condensate storage is not available, the purified liquid is sent to the cooling tower blowdown line (See Figure 3. 5-4 for an illustration of this system).

Equipment reduncancy is provided in the chemical waste pro-cessing system to allow bypassing of any failed camponent.

Sufficient capacity is provided in the equipment to handle such conditions.

3.5.2.5 Detergent Wastes Detergent wastes are collected in the detergent drain tanks.

These wastes consist of primarily laboratory and decontam-ination solutions which contain detergent and laboratory wastes. Because of a tendency to foul ion exchange resins, these liquid radwastes are treated separately. They are filtered through the detergent drain filter prior to dis-charge to the chemical waste system for cleanup and recycling.

3.5.2.6 Sludges Expended filter demineralizer ion exchange resins are removed when necessary by backwashing. Condensate filter deminerali-zer resins are backwashed to the condensate backwash receiv-ing tank and pumped to the condensate phase separator tanks for processing. Reactor water cleanup system sludges are collected in the RWCU phase separators where excess backwash water is decanted to the waste collector tank. The remaining sludge is processed through the radwaste solids system.

O 3.5-14

l WNP-2 ER

() The fuel pool filter demineralizer, waste collector and floor drain filters are backwashed to the waste sludge phase separa-tor tank. The accumulated resins and sludges are processed through the solid radwaste system after a suitable decay period. The processing system for these sludges and resins is described in Section 3.5.4.

3.5.3 Gaseous Radwaste System 3.5.3.1 General The gaseous radwaste system is designed to process and control the release of gaseous radioactive effluents to the site environs so that the radiation dose to off-site persons is "as low as practicable" as defined in 10CFR50, Appendix I.

Gaseous effluents that are released to the off-site environs emanate from the following sources:

a. effluent released from the off-gas treatment system,

b. effluent released from the ventilation system in the various buildings, and

c. effluent released from the mechanical vacuum pump.

)

3.5.3.2 Off-Gas Treatment System 3.5.3.2.1 General The off-gas system can be divided into the following subsystems:

a. Recombiner subsystem

b. Condensing-moisture separator subsystem

c. Cooler condenser-glycol subsystem

d. Filter subsystem

e. Desiccant dryer regeneration system

f. Activated carbon refrigeration-adsorption subsystem

()

3.5-15

l WEP-2 ER Each of these are discussed in Subsections 3.5.3.2.2 to 3.5.3.2.7.

The source of radioactive gases is the steam jet air ejec-tors which remove main condenser noncondensible gases during plant operation. The condenser off-gas contains both fission product gases which leak through the reactor fuel element cladding as well as the coolant activation gases. The acti-vation gases result fro =. the irradiation of reactor coolant as it passes through the neutron field in the fuel portion of the core in the reactor vessel. The production of these gases is dependent upon the reactor power level rather than the amount of leakage in the fuel cladding. Condenser off-gas activity is principally due to N-16, 0-19 and N-13.

The N-16 and 0-19 have very short half-lives (secs) and decay rapidly, whereas N-13, with a ten (10) minute half-life, is only present in small amounts. The condenser off-gas contains radioactive no~ ole gases including daughter products of these nuclides. The concentration of noble gases depends on the amount of tramp uranium present and any fuel element defects which exist.

The source terms for the off-gac treatment system are based on the average noble gas release rate of 60,000 uCi/sec after 30 minutes decay (See Subsection 3.5.1). The system has a design basis of 100,000 pCi/sec with the capability of processing 300,000 pCi/sec of noble gases activity without affecting the delay time of the noble gases. Based on a condenser air inleakage of 30 scfm, the charcoal system will present a residence time delay for krypton of at least 46 hours5.324074e-4 days <br />0.0128 hours <br />7.60582e-5 weeks <br />1.7503e-5 months <br /> and a xenon residence delay time of at least 42 days.

The off-gas system's first processing function is to catalytically recombine radiolytically produced hydrogen and oxygen. The off-gas is then cooled to approximately 130 F to remove condensibles, and in the process, reduce the mass of gas per unit volume. The remaining non-condensible gas, which consists primarily of air plus trace concentrations of krypton-xenon, is delayed in the ten (10) m'.nute holdup system. The gas is cooled to 45 F and filtered through a high efficiency particulate air (IIEPA) filter. The gas is then pasged through a desiccant drygr that reduces its dewpoint to

-90 F and then is chilled to 0 F. Charcoal adsorption beds, operating in a refrigerated vault at about 0 F, selectively adsorb and delay the trace quantities of xenon and krypton in the bulk carrier gas. The refrigeration system of the O

3.5-16

WNP-2 ER

(T charcoal adsorber vault is designed with sufficient flexi-(_,) bility to maintain the vault temperature down to -400F.

After this delay, the gas is then passed through a HEPA filter and then discharged to the environment through the reactor building elevated release point.

Radioiodine is present in reactor steam and, to a small extent, carries over through the condensation and filtration stages of the off-gas system. Removal of off-gas train iodine, however, is virtually complete in passage of the process gas through granular activated carbon. Thus, the radioactive noble gases control the release rate of gaseous wastes from the off-gas system.

Figure 3.5-5 shows a schematic of the process flow diagram for the system. Table 3.5-18 lists the process data which apply to this system. The process and instrumentation diagrams are given in Figures 3.5-6 and 3.5-7.

The release rate of the noble gas isotopes into the atmosphere are listed in Table 3.5-20.

3.5.3.2.2 Recombiner Subsystem During plant operation, the steam jet air ejector removes the y non-condensible gases from the main condenser, provides the j motive pressure at the inlet to the off-gas system, and dilutes the hydrogen present in the off-gas with steam to maintain the maximum hydrogen concentration less than four percent by volume at all power levels. The actual hydrogen concentration in the effluent gas to and from the recombiner is much below the four percent level.

The off-gas effluent from the air ejectors is directed to the recombiner preheater, of these, there are two 100 percent capacity units, with one of the units on standby service.

I The recombiner preheater raises the off-gas temperature to l approximately 3500F to allow efficient catalytic recombiner l operation In the recombiner, the gas temperature increases l up to 8500F due to the heat of formation of water and this further improves recombiner ef ficiency. At the outlet of the recombiner, a hydrogen analyzer monitors the hydrogen concentration and inititates alarms at abnormal hydrogen levels.

1

! x_,/

(3 l 3.5-17 l

WNP-2 ER 3.5.3.2.3 Condensing Subsysten h

The off-gas condenser is utilized to cool and condense the recombiner effluent and reduce entrained water vapor from the off gas stream. The effluent noncondensible gases are then directed to the water separator where additional entrained water droplets are removed. From the water separator, the off-gas is routed to the holdup line, which is designed to provide lag storage of the off-gas for at least ten (10) minutes at the design flow rate. From here the off gas stream is routed to one of the two 100 percent capacity cooler condensers. The second unit remains on standby service. In the cooler condenser, the off-gas is further cooled to a lower dewpoint temperature to remove more condensibles. Upon leaving the cooler condenser, the off-gas stream is discharged to one of the moisture separators. There are two 100 percent units with one unit on standby service. In the moisture separator, additional entrained moisture is removed. From here the off-gas stream is routed to the filter-dryer subsystem.

3.5.3.2.4 Filter-Dryer Subsystem The off-gas stream effluent from the moisture separator is directed to one of the two 100 percent capacity HEPA pre-filters. These filters are of the high ef ficiency absolute type particulate filters which remove particulate form radio-nuclides. Based on DOP tests, the filter elements remove at least 99.97 percent of particles larger than 0.3 micron in diameter. Gas leaving the pref 11ter is directed through a disiccant dryer to further reduce the dewpoint level to reduce the competition of water for adsorption sites on the charcoal beds. There are four desiccant dryer units arranged in two independent trains as described in Subsection 3.5.3.2.7. Thus, while regeneration is being performed on one of the trains, the dryers in the second train are avail-able in the process system, one of which acts as a standby unit. Each of the four dryers is capable of drying the process gas stream to -900F dewpoint. From the dryer train, the off-gas stream is directed to the refrigerated adsorption subsystem.

3.5.3.2.5 Refrigerated Adsorption Subsystem Of f-gas ef fluent f rom the desiccant dryers under normal operation flows through one of the four off-gas coolers which are each designed to cool the process gas stream to 0 0 F. From the cooler the gas passes to one of the two banks of charcoal adsorbers. There are four adsorber O

1 3.5-18

WNP-2 ER I vessels in each of the banks. From two of the coolers, the

\-' gas stream is directed to the first vessel of each bank of adsorbers. The remaining two coolers are arranged so that one of the coolers feeding each bank of adsorbers can bypass the first adsorber in each bank in the event of the presence of excess moisture in that adsorber vessel. The gas stream effluent from the last unit of each bank is routed to one of the two afterfilters. Each of the afterfilters is capable of treating 100 percent of the normal process gas flow, thus one unit is in the standby condition. The afterfilters are of the HEPA high efficiency moisture resistant absolute particulate type. Particulate daughter products and charcoal fines are removed by the afterfilter before the gas is monitored for radiation level prior to being directed to the reactor building elevated release point and then is released to the atmosphere. This type of filter has better than 99 percent efficiency for particulates larger than 0.3 microns based on DOP tests.

The charcoal adsorbers provide selective adsorption of the xenon and krypton isotopes from the bulk gas (air) in the off-gas stream. Selective adsorption permits a major fraction of xenon and krypton isotopes to decay in place, thereby reducing activity releases to the atmosphere. The holdup time at design flow is in excess of 42 days for xenon and 46 hours5.324074e-4 days <br />0.0128 hours <br />7.60582e-5 weeks <br />1.7503e-5 months <br /> for

(~N krypton gases as mentioned earlier.

The Kr and Xe holdup time is closely approximated by the following equation:

t=K d

F Where:

t = holdup time of a given gas, (sec)

K dynamic adsorption coefficient for the given gas, d

! (cm3/sec)

M = weight of charcoal, (g)

F= flow rate, (cm /sec) l l

(3 V

3.5-19 m 4

WNP-2 ER Dynamic adsorption coefficient values for xenon and krypton have been reported by several authors, including Browning. (5)

The off-gas charcoal adsorber vault is maintained at 00F during normal plant operation by two independent, full capacity, closed loop, brine refrigeration systems. The re-frigeration system has been designed with sufficient flexi-bility to maintain the vault temperature down to -400F.

The off-gas charcoal adsorber vault refrigeration system is schematically shown in Figure 3.5-8.

During normal plant operation, one refrigeration system operates with the second system in standby mode. Each system consists of a rotary screw type liquid chiller, a centrifugal pump, two refrigeration fan coil units and associated piping, distribution ductwork and accessories.

3.5.3.2.6 Glycol subsystem This subsystem consists of three refrigeration machines through which a closed-type glycol system is fed. The cold glycol solution is pumped to the off-gas process stream's two cooler condensers described in Subsection 3.5.3.2.3 and the desiccant dryer's regenerative dryer chillers described in Subsection 3.5.3.2.7.

3.5.3.2.7 Desiccant Dryer Regeneration Subsystem This subsystem consists of four desiccant beds in two independent trains, each train having a full set of regenera-tion equipment. The regeneration cycle uses only captive air from the off-gas process stream which is cooled in the dryer chiller, circulated by the regenerative blower and heated and dried by the dryer heater before being directed through the desiccant dryer being regenerated. Under normal operating conditions, a desiccant unit can be regenerated in a 12-hour period including cooldown.

The desiccant dryer regeneration system is also piped to allow its use in supplying relatively dry (45 0F dowpoint) ,

heated (2500F) air at the rate of 250 cfm to be used in defrosting and drying the charcoal adsorber beds during the annual refueling outage, should gross moisture be present. Service air is utilized for this purpose and circulated through the regeneration system prior to being circulated through the charcoal adsorber beds.

O 3.5-20

WNP-2 ER

( 3.5.3.3 Building ventilation 3.5.3.3.1 General The Heating, Ventilation and Air Conditioning (HVAC) systems that service the reactor, radwaste and turbine building are designed to the following performance objectives:

a. To provide fresh air and maintain appropriate temperature and humidity conditions for plant personnel and eauipment.

b. Control and monitor all potentially radioactive airborne releases from the plant to within the objectives of 10CFR50, Appendix I.

c. Control and limit airborne contaminants within the plant structures by inducing air flow from areas of low radiation potential to areas of high radiation potential,

d. Maintain.the various buildings at a negative pres-sure with respect to the atmosphere. This prevents the exfiltration of radioactive material.

O Details of the HVAC system used in each building are discussed in the following paragraphs.

i 3.5.3.3.2 Reactor Building The reactor building heating and ventilating system is l schematically shown in Figure 3.5-9.

i The system is basically a push-pull heating and ventilation system providing once-through air flow with no recirculation.

{' It consists of the following subsystems which can potentially

! release radioactive effluents.

Supply Air System The supply air system consists of a ventilation unit, air distribution ductwork, two isolation butterfly dampers on the fresh air intake and the associated controls. During normal plant operation and shutdown, the supply air system isolation dampers are open and the ventilation system operates continuously. This provides 100% outdoor air throughout the building.

O l 3.5-21

_a

WNP-2 ER The reactor building supply air system also provides makeup air to the primary containment during a primary containment purge. During purging, isolation valves in the supply purge duct to the primary containment are opened, and air is blown from the supply air system into the primary containment.

In the event of a reactor building isolation signal, the supply system ventilating unit stops and the two isolation dampers on the fresh air intake close. The signals which cause reactor building isolation are as follows:

a. reactor vessel low water level,

b. high drywell pressure, and

c. high radiation level in the reactor building exhaust ventilation system.

Exhaust Air System The reactor building exhaust system draws air from all areas with radiation contamination potential and discharges it to the elevated release point. The elevated release point is located on the roof of the reactor building.

In the event of a primary containment purge, the exhaust air h is discharged through the reactor building exhaust system or through the standby gas treatment system. Ducts connect the primary containment drywell and wetwell with reactor building exhaust system and standby gas treatment system. The reactor building exhaust system is normally used.

The standby gas treatment system is used to process building exhaust during an accident to maintain reactor building under negative pressure. It consists of two independent, full-size systems. Each system contains a denister which removes excess moisture, a prefilter which removes particulate matter present in the effluent, and electric heating coil to reduce i

the relative humidity of the air, a high efficiency particu-late air filter (HEPA) which is capable of removing 99.97%

of all particulate matter which is 0.3 micron or larger in size, two activated charcoal iodine filters which remove 99%

of the iodine and an afterfilter. This equipment is listed in the order of air treatment. See Subsection 6.5 of the FSAR for further details.

O 3.5-22

WNP-2 ER

) Sump Vent Exhaust Filter System All potentially radioactive liquid leaks and/or spills in the reactor building are channeled to the eugipment er floor drain system. In order to minimize the release of radio-active contaminants from the building, the drain system. sumps and drain headers are maintained at a negative pressure and are vented-through a filter system. The sump vent exhaust system is composed of two full-capacity, 1000 cfm filter units, each consisting of moisture separator, electric heater, HEPA filter, charcoal filter and fan. The units which draw air from the sumps and drain headers pass it through filters and

discharge it into the main reactor building exhaust system upstream of the radiation monitoring instruments.

3.5.3.3.3 Radwaste Building J

The radwaste building heating and ventilating system is j schematically shown in Figure 3.5-10. The main system is a push-pull heating and ventilating system providing once-i through air flow with no recirculation. In addition, indi-vidual air conditioning units are provided for all rooms which personnel will normally occupy for extended periods of time.

^

The main radwaste building supply air system consists of a

supply ventilation unit and distributfon ductwork. During normal plant operation, the supply unit operates continuously.

This provides fresh air throughout the building via the

supply duct distribution system.

The radwaste building exhaust system is composed of three 50%

capacity exhaust filter units. Only two of these units are

! in operation at any one time. Each exhaust unit fan is pro-l vided with an automatic air operated inlet vane for volume control. The inlet vanes are controlled by differential pressure controllers set to maintain the tank enclosures in

~

the lower level of the radwaste building at a negative pres-sure with respect to the atmostphere.

! All radwaste building exhaust air is processed by the exhaust l units and monitored by radiation detectors prior to discharge.

The release point for the ventilation exhaust is located on the roof of the radwaste building. All exhaust air is passed l through HEPA filters prior to discharge, thus minimizing the release of radioactive particulates.

O 3.5-23

WNP-2 ER 3.5.3.3.4 Turbine Generator Building The heating and ventilation systems of the turbine generator building are schematically shown in vigure 3.5-11. The pri-mary system is a push-pull heating and ventilating system.

It consists of the following subsystems which can potentially release radioactive effluent.

Main Supply System The turbine generator building supply air system is composed of four supply ventilation units and distribution ductwork.

The units are operated in pairs, with one pair discharging into a common supply duct system servicing the west side of the building. The other pair supplies the east side of the building.

Each ventilation unit contains a centrifugal fan. This fan is furnished with automatic inlet vanes for fan capacity and control. These are used to control the air flow and to main-tain the turbine building at a negative pressure with respect to the atmosphere.

Automatic dampers are provided on the intake of each ventila-tion unit that permit the unit to draw either 100% outdoor air or 100% recirculation air from the turbine building. Recircu-lation is only performed in the event of a plant outage, when airborne contamination potential does not exist, to reduce building heating requirements.

Main Exhaust System The main exhaust system consists of four roof-mounted cen-trifugal fans, all of which draw air from a central exhaust duct system. Three of the exhaust fans normally operate continuously with one fan as standby. Air flow through the operating fans is maintained at a constant rate by automatic volume dampers on the fan discharges.

Almost all exhaust air is drawn from the shielded areas of the turbine building where the potential for airbornt radio-active contamination is highest. This induces flow from the cleaner areas. All exhaust air is monitored for radioactive contamination prior to discharge.

In the event that supply air to the turbine generator building is reduced, as during a plant outage, only one or two exhaust fans may be operated. Motor operated shut-of f dampers are provided in all main branches of the exhaust duct system so that exhaust can be stopped on an area-by-area basis. Auto-matic volume dampers are provided in the exhaust system so 3.5-24

l WNP-2 ER i

() that full exhaust flow can be drawn from the shielded equip-ment vaults on the lower level of the turbine building when the exhaust system is operating at full capacity. These vaults house equipment with higher contamination potential such as the air ejectors and the off-gas system hydrogen recombiners.

3.5.3.3.5 Effluent Released from Building Ventilation Flow rate, elevation, heat content and description of the three release points are listed on Table 3.5-19.

1 Reactor Building The reactor building ventilation system supolies fresh air to the reactor building and exhausts air through the elevated release point. Table 3.5-21 lists the radionuclide concentra-tion in the reactor building effluent; basis for these values are discussed in 3.5.1.1.1.

The reactor building suinps are vented through a bank of HEPA and activated charcoal filters; however, no credit is taken for this sump vent treatment system when calculating releases.

Turbine Building O

s- l The turbine building ventilation system supplies fresh air to the various building arean and exhausts air to the atmos-phere. Table 3.5-21 lists the radionuclide concentration in the turbine building effluent. These values are based on measurements at operating plants as discussed in 3.5.1.8.2.

The turbine building sumps are vented through the ventila-tion system directly to the atmosphere. The contribution to the total building ventilation effluent is included in Table 3.5-21 values.

Radwaste Building

! Sources of gaseous radioactivity in the radwaste building include:

a. Air ejector off-gas system leakage

b. Liquid leakage to the radwaste building

c. Hydropneumatic transfer of resins O

3.5-25

WNP-2 ER Leakage of radioactive gases from the off-gas treatment h system is Ibnited by the use of welded piping connections where possible and bellows stem seals or equivalent for valving. The system operates at a maximum of 7 psig during startup and less than 2 psig during normal operation so that the differential pressure to cause leakage is small.

Liquid leakage, which is at ambient temperature, is retained in trenches, cells and concrete rooms and returned to the system for additional processing.

Any radioactivity displaced from filter precoats and bed resins during processing is routed to the building ventila-tion exhaust system and high efficiency filters.

Estimated radioactive material releases from the radwaste building ventilation exhaust are listed in Table 3.5-21.

3.5.4 Solid Radwaste System 3.5.4.1 General The solid radwaste system collects, monitors, processes, packages and provides temporary storage facilities for radioactive solid wastes for off-site shipment and perma-nent disposal. The following describes the design basis for the solid radwaste system.

a. The solid radwaste system is designed such that the solid radwaste collected and prepared for off-site shipment does not result in radiation exposure in excess of the limits set in 10CFR20.

b. The solid radwaste system is designed to package radioactive solid wastes for off-aite shipment and burial in accordance with applicable regula-tions including 49CFR170-178,

c. The solid radwaste system is designed to prevent the release of significant quantities of radio-active materials to the environs so as to restrict the overall exposure to the public within the limits of 10CFR50, Appendix I.

d. Shielded casks are provided as necessary which conform to applicable federal regulations.

O 3.5-26 l

WNP-2 ER

( The solid waste processing system processes both wet and dry solid wastes. Wet solid wastes include backwash sludge and spent resins from the reactor water cleanup system, the condensate filter demineralizer system, the fuel pool filter demineralizers, the floor drain filter, the waste collector filter, the floor drain demineralizer, the waste deminerali-zer, the decontamination solution concentrator and the distil-late polishing demineralizer. Dry solids wastes include rags, paper, small equipment parts, solid laboratory wastes, etc.

The processing of these wastes is discussed in subsections 3.5.4.4 and 3.5.4.5.

The input of the various radioactive solid waste inputs are shown on the radwaste process diagram, Figure 3.5-1.

The expected frequency of solid waste input, the quantities of solids generated and the radioactivity level in the solids after accumulation are listed on Table 3.5-22. Figure 3.5-12 shows the waste packaging portion of the solid radwaste system.

The radionuclide inventory in the streams that serve as input into the radwaste is listed in Table 3.5-23.

3.5.4.2 Radwaste Disposal System Descriptions

() 3.5.4.2.1 Radwaste Disposal System for Reactor Water Cleanup Sludge The purpose of the radwaste system for cleanup sludge is to process the highly radioactive backwash waste which is dis-charged from the reactor water cleanup system.

The reactor water cleanup system includes two filter-demin-eralizer units, each of which are precoated with powdered ion exchange resin (powdex), which is retained on a permanent stainless steel septum. These filter demineralizer units remove, by filtration and ion exchange, the suspended and dissolved solids from the recirculating primary reactor coolant. These solids consist of radioactive and stable elements. Upon exhaustion of either its filtration or ion exchange capability, the cleanup filter demineralizer is taken out of service. Then it is backwashed and precoated.

The backwash waste discharged from a cleanup demineralizer consists of a slurry which has a suspended solids content of about 0.5% by weight. This slurry is accumulated in one of the two cleanup phase separators.

Each backwash batch received by the working phase separator l is allowed to settle and the resulting decantate is pumped to to the waste collector tank. The bottoms, or sludge, is

(

3.5-27 l

WNP-2 ER stored in the phase separator, and when sufficient sludge has accumulated, the working phase separator is isolated for a period of one to two months to permit additional time for radionuclide decay. At the end of this decay period, water is added to the sludge until about 5% solids content by weight is reached and it is then pumped to the centri-fuges for dewatering. See Subsection 3.5.4.4 for a descrip-tion of the centrifuges.

3.5.4.2.2 Radwaste Disposal System for Condensate Demineralizer Sludge The purpose of this system is to process the radioactive backwash waste which is discharged from the condensate filter demineralizer system.

The condensate filter demineralizer system consists of six filter demineralizer units which are precoated with powdered ion exchange resin (powdex). Five of these are in continuous operation and one is in a standby mode. These filter demin-eralizer units remove, by filtration and ien exchange, the suspended and dissolved solids from the reactor steam condensate. These solids consist primarily of corrosion products and trace radionuclides. Upon exhaustion of either its filter or ion exchange capability, the exhausted demin-eralizer ic taken out of service and is backwashed and pre-coated.

The backwash waste discharged from a condensate demineralizer consists of a slurry which has a suspended solids content of aoubt 0.5% by weight. This discharge is collected in the condensate backwash receiving tank. After collection, the waste is transferred by pumping to one of the two condensate phase separators for processing.

Operation of the condensate phase separators is similar to that for the cleanup phase separators (See Subsecticn 3.5.4.2.1). Backwash sludge is received by the phase separators at a suspended sludge concentration of 0.5% by weight. The slurry is retained to allow setting and is then decanted to the waste collector. The sludge fraction is routed to the centrifuges for dewatering and solid waste packaging.

O 3.5-28

WNP-2 ER s

() 3.5.4.2.3 Radwaste Disposal System for Fuel Pool, Floor Drain and Waste Collector Filter Sludge The purpose of this system is to collect backwash sludge wastes from the floor drain filter, waste collector filter and fuel pool filter demineralizers. These wastes, which have a solids content of about 0.5% by weight, are drained by gravity to the waste sludge phase separator. The waste sludge phase separator decants the wastes to a solids content of 5% by weight. The resulting decantate is pumped to the floor drain collector tank.

When a predetermined quantity of waste sludge has been accumulated, water is added to it until a solids content of 5% by weight is reached. Then the sludge la pumped to the centrifuges for dewatering.

3.5.4.2.4 Radwaste bisposal System for Spent Resin The purpose of this system is to collect spent resin from the floor drain, waste collector and distillate polishing demineralizers. These wastes are hydropneumatically trans-ferred to the spent resin tank. The spent resin tank is designed to accept one batch of resins from any of the aforementioned demineralizers plus resin transfer water f plus free board. Each batch of the spent resin is trans-(

ferred, in slurry, to the centrifuges for dewatering.

3.5.4.3 Radwaste Disposal System for Concentrated Solutions The purpose of this system is to process wastes from the decontamination solution concentrators which are discharged to the concentrator waste tanks. These wastes consist of radioactive chemical wastes, detergent wastes and excess inventory floor drain wastes whose chemical content is too high to permit economical purification by ion exchange.

These wastes are concentrated in the decontamination j solution concentrator.

The waste solution from the decontamination solution concen-trator is blown down with steam to one of two decontamination solution concentrated waste tanks. Each concentrated waste tank is sized to handle half of a batch of concentrated l waste solution from each concentrator.

l From the concentrated waste tank, the concentrated solution is pumped to the decontamination solution concentrator waste measuring tank. From here, the solution is fed into the solids waste processing system for solidification and dis-

, posal. Note that these wastes are not pumped to the centri-l fuges prior to disposal.

3.5-29

WNP-2 ER 3.5.4.4 Radwaste Solids Handling System The purpose of this system is to process the waste sludge slurries from the cleanup phase separators, the condensate phase separators, the waste sludge phase separators, the spent resin tank and the concentrated solutions from the decontamination solution concentrator waste measuring tank.

The system dewaters the bulk volume of the solid water slurries and prepares the dewatered concentrated waste for off-site shipment in disposable containers. The system also reclaims the water from the wet solid wastes for reuse within the plant. Concentrator waste solutions can be solidified in disposable containers for off-site shipment.

In addition, the system has the capability for solidifying all dewatered solid wastes in disposable containers com-patible for off-site shipment.

Two processing trains are provided for processing the solid waste slurries. Each processing train consists of a centri-fuge, hopper, controls and piping to dewater and concentrate the solid waste slurries. In addition, one processing train contains equipment for solidifying the dewatered solid wastes.

This equipment consists of a vaste processing pump, static mixer and associated polymer storage tanks, polymer day tank, catalyst tanks and pumps to deliver predetermined amounts of polymer and catalyst for solidification.

Sludge and resin wastes are pumped from the cleanup phase separators, the condensate phase separators, the waste sludge phase separator or the spent resin tank and are reduced in volume by dewatering in either one of the two centrifuges.

Water effluent from the centrifuges is transferred to the waste sludge phase separator tank for decanting, reprocessing and reuse in the station. The dewatered solid wastes are I discharged from the centrifuges by gravity into their re-spective hoppers, which are used for filling 50 cubic foot containers for disposal.

If solidification is required, the solidification processing train is used and the hopper is filled to a predetermined level with dewatered solids from the centrifuge. The.re-quired amount of water is then added to each hooper.

l An empty disposable container is placed on the transfer dolly and the transfer dolly and container are then moved to the filling station underneath the hopper. The hopper discharge valve is opened, which permits the flow of wastes to the waste processing pump. A set of hopper augers forces the wastes into the discharge bin and a conveyor transports the 3.5-30

WNP-2 ER waste to the throat of the pump. The speed of the waste processing pump, polymer processing pump and the amount of catalyst are set to achieve the proper ratio of solids, polymer and catalyst required for proper solidification of the mixture. The processing pumps are started and pump the mixture through the static mixer where the solids, catalyst and polymers are well mixed. Then, the mixture is dis-charged into a disposable container from the static mixer.

An identical process to the above is used to solidify de-contamination solution concentrator wastes. The concentrator waste measuring tank discharges directly to the waste proces-sing pump. The speed of the waste processing pump, polymer processing pump and catalyst processing pump are set to achieve the proper ratio of concentrate, polymer and catalyst i'

required for solidification of the mixture. The processing pumps are started and pump the mixture into the static mixer where mixing occurs; then the mixture is discharged into a disposable container.

i

{ Dewatered solid wastes are packaged in 50 cu. ft. disposable containers that meet the requirements established in 49CF2170-178. The containers are brought into the processing i area and loaded on the dolly and the dolly is moved to the l filling station where dewatered waste is added. The quantity i of wastes packaged in the container is measured by a level indicator.

l The filled container is moved to the container capping sta-l tion where it is remotely capped by the operator. After l capping, the container is moved to the smear and washdown rtation and decontaminated prior to being sent to the storage l area station.

i The storage area is capable of storing up to seventy-two 50 cubic foot containers. High radioactivity containers can 1 be stored for periods of up to, and in excess of, six months to allow for additional decay prior to shipment.

3.5.4.5 Miscellaneous Solid Waste System Dry waste consists of air filter media, miscellaneous paper, j rags, etc. from contaminated areas. It also consists of contaminated clothing, tools and equipment parts which cannot i be effectively decontaminated, and solid laboratory wastes.

The radioactivity level of much of the waste is low enough to permit direct handling by personnel. These wastes are collected in containers located in appropriate zones around the plant as dictated by the volumes of wastes generated

!O i

3.5-31 l

i

WNP-2 ER during operation and maintenance. The filled containers are sealed and moved to a controlled access area for temporary storage. Compressible wastes are compacted into 55 gallon steel drums in a hydraulf'c press-baling machine to reduce their volume.

The compressed solid wastes are stored temporarily near the truck loading area in the radwaste building. Non-campressible solid wastes are packaged manually in similar 55 gallon steel drums. Because of its low radioactivity level, this waste can be stored until enough is accumulated to permit eco-nomical transportation to an off-site burial ground for final disposal.

3.5.5 Process and Effluent Monitoring The locations and elevations of all radioactive release points are shown in Figure 3.1-6.

Table 3.5-24 lists all radioactive effluent monitoring and control points. Indicated are those monitors that auto-matically terminate effluent discharges upon alarm or those monitors, upon alarm, which automatically actuate standby or alternative treatment systems or which automatically divert streams to holdup tanks.

O O

3.5-32

WNP-2 ER TABLE 3.5-1 NOBLE GAS CONCENTRATION IN THE REACTOR STEAM NUMERICAL VALUES - CONCENTRATIONS IN PRINCIPAL FLUID (uci/gm)

ISOTOPE REACTOR STEAM a)

Kr 83 m 1.1 E-3 Kr 85 m 1.9 E-3 Kr 85 6.0 E-6 Kr 87 6.6 E-3 Kr 83 6.6 E-3 Kr 89 4.1 E-2 Kr 90 9.0 E-2 Kr 91 1.1 E-1 Kr 92 1.1 E-1 Kr 93 2.9 E-2 Kr 94 7.2 E-3 Kr 95 6.6 E-4 Kr 97 4.4 E-6 Xe 131 m 4.7 E-6 O Xe 133 m Xe 133 Xe 135 m 9.0 2.6 8.4 E-5 E-3 E-4 Xe 133 7.2 E-3

Xe 137 4.7 E-2 Xe 138 2.8 E-2 Xe 139 9.0 E-2 l Xe 140 9.6 E-2 Xe 141 7.8 E-2

.: n 142 2.3 E-2 l Xe 143 3.8 E-3 l Xe 144 1.8 E-4 (a) The reactor steam concentration is specified at the nozzle where reactor water leaves the reactor vessel; similarly, the reactor steam concentration is specified at time 0.

These values are ANSI N237 Table V values multiplied by 0.6 to convert from the 100,000 pCi/sec - 30 minute mixture design basis case to the 60,000 pCi/sec normal operating basis suggested by ANSI N237 and subsequently by NRC Regulatory Guide 1.70.27 references.

O

WNP-2 ER TABLE 3.5-2 AVERAGE NOBLE GAS RELEASE ^

RATES FROM FUEL LEAKAGE RATE LEAKAGE RATE AT t = 0 AT t = 30m ISOTOPE HALF-LIFE (uCi/s) (UCi/s)

Kr 83 m 1.86 h 2.0 E3 1.7 E3 Kr 85 m 4.4 h 3.4 E3 3.1 E3 Kr 85 10.74 y 1.1 El 1.1 El Kr 87 76. m 1.2 E4 9.1 E3 Kr 88 2.79 h 1.2 E4 1.1 E4 .

Kr 89 3.18 m 7.4 E4 7.4 El Kr 90 32.3 s 1.6 ES -

Kr 91 8.6 s 2.0 E5 -

Kr 92 1.84 s 2.0 E5 -

Kr 93 1.29 s 5.2 E5 -

Kr 94 1.0 s 1.3 E4 -

Kr 95 0.5 s 1.2 E3 -

Kr 97 1. s 7.9 EO -

Xe 131 m 11.96 d 8.5 EO 8.4 EO Xe 133 m 2.26 d 1.6 E2 1.6 E2 Xe 133 5.27 d 4.7 E3 4.7 E3 Xe 135 m 15.7 m 1.5 E3 4.0 E2 Xe 135 9.16 h 1.3 E4 1.3 E4 Xe 137 3.82 m 8.5 E4 3.4 E2 Xe 138 14.2 m 5.0 E4 1.2 E4 Xe 139 4.0 s 1.6 ES -

Xe 140 13.6 s 1.7 E5 -

Xe 141 1.72 s 1.4 E5 -

Xe 142 1.22 s 4.1 E4 -

Xe 143 .96 s 6.8 E3 -

Xe 144 9. s 3.2 E2 -

TOTALS 1.4 E6 5.6 E4 (a) NRC Draft Reg. Guide (Ref. 2) 0

WNP-2 ER

,r .

( TABLE 3.5-3 CONCENTRATIONS OF HALOGENS IN REACTOR COOLANT AT REACTOR VESSEL EXIT NOZZLES (uCi/gm) ("

ISOTOPE REACTOR WATER REACTOR STEAM Br 83 3 E-3 6 E-5 Br 84 5 E-3 1 E-4 Br 85 3 E-3 6 E-5 I 131 5 E-3 1 E-4 I 132 3 E-2 6 E-4 I 133 2 E-2 4 E-4 I 134 7 E-2 1 E-4 I 135 2 E-2 4 E-4 (a) Values from ANSI N237 Table 5 O

WNP-2 ER TABLE 3.5-4 CONCENTRATIONS OF FISSION PRODUCTS IN REACTOR COOLANT AT REACTOR VESSEL EXIT NOZZLES (uCi/gm) "

ISOTOPE REACTOR WATER REACTOR STEAM Rb 89 5 E-3 5 E-6 Sr 89 1 E-4 1 E-7 Sr 90 6 E-6 6 E-9 Sr 91 4 E-3 4 E-6 Sr 92 1 E-2 1 E-5 Y 91 4 E-5 4 E-8 Y 92 6 E-3 6 E-6 Y 93 7 E-6 7 E-9 Zr 95 7 E-6 7 E-9 Zr 97 5 E-6 5 E-9 Nb 95 7 E-6 7 E-9 Nb 98 4 E-3 4 E-6 Mo 99 2 E-3 4 E-6 Tc 99 m 2 E-2 2 E-5 Tc 101 9 E-2 9 E-5 Tc 104 8 E-2 8 E-5 Ru 103 2 E-5 2 E-8 Ru 105 2 E-3 2 E-6 Ru 106 3 E-6 3 E-9 Ag 110 m 1 E-6 1 E-9 Te 129 m 4 E-5 4 E-8 Te 131 m 1 E-4 1 E-7 Te 132 1 E-5 1 E-8 Cs 134 3 E-5 3 E-8 Cs 136 2 E-5 2 E-8 Cs 137 7 E-5 7 E-8 Cs 138 1 E-2 1 E-5 Ba 139 1 E-2 1 E-5 Ba 140 4 E-4 4 E-7 Ba 141 1 E-2 1 E-5 Ba 142 6 E-3 6 E-6 La 142 5 E-3 5 E-6 Ce 141 3 E-5 3 E-8 Ce 143 3 E-5 3 E-8 Ce 144 3 E-6 3 E-9 Pr 143 4 E-5 4 E-8 Nd 147 3 E-6 3 E-9 W 187 3 E-4 3 E-7 Np 239 7 E-3 7 E-6 (a) Values from ANSI N237 Table 5

WNP-2 ER p---

(_,/ TABLE 3.5-5 CONCENTRATIONS OF CORROSION PRODUCTS IN REACTOR COOLANT AT REACTOR VESSEL EXIT NOZZLES (uCi/gm)

ISOTOPE REACTOR WATER REACTOR STEAM Na 24 9 E-3 9 E-6 P 32 2 E-4 2 E-7 Cr 51 5 E-3 5 E-6 Mn 54 6 E-5 6 E-8 Mn 56 5 E-2 5 F-5 Fe 55 1 E-3 1 E-6 Fe 59 3 E-5 3 E-8 Co 58 2 E-4 2 E-7 Co 60 4 E-4 4 E-7 Ni 63 1 E-6 1 E-9 Ni 65 3 E-4 3 E-7 7-s

( ,) Cu 64 3 E-2 3 E-5 Zn 65 2 E-4 2 E-7 Zn 69 m 2 E-3 2 E-6 (a) Values from ANSI N237 Table 5 3

WNP-2 ER TABLE 3.5-6 CONCENTRATIONS OF WATER ACTIVATION PRODUCTS IN REACTOR COOLANT AT REACTOR VESSEL EXIT NOZZLES (u Ci/qm) ^

ISOTOPE REACTOR WATER REACTOR STEAM N 13 5 E-2 7 E-3 N 16 6 E-1 5 E-1 N 17 9 E-3 2 E-2 0 19 7 E-1 2 E-l F 18 4 E-3 4 E-3 (a) Values from ANSI N237 Table 5 0

O l

l l

WNP-2 ER TABLE 3.5-7 RADIONUCLIDE CONCENTRATIONS IN FUEL POOL ^

RADIONUCLIDE RADIONUCLIDE CONCENTRATION UCi/mL

-6 I 131 <1 x 10

~4 H 3 8.8 x 10

-6 Mn 54 6 x 10

-5 Co 58 1.8 x 10

-5 Co 60 7.4 x 10

-6 Sr 89 2.0 x 10

-5 Sr 90 1.8 x 10

~4 Cs 134 3.1 x 10

~4 Cs 137 7.6 x 10

-5 Ba 140 1.5 x 10 (a) Radiological Surveillance Studies at a Boiling Water Nuclear Power Reactor, BRH/ DER 70-1, February 1971.

l t

d'

l WNP-2 ER TABLE 3.5-8 ESTIMATED RELEASES FROM DRYWELL AND REACTOR BUILDING VENTILATION SYSTEMS REACTOR BUILDING CONTAINMENT BUILDING Ci/yr Ci/yr Kr 85 m 3 3 Kr 87 3 3 Kr 88 3 3 Xe 133 66 66 Xe 135 m 46 46 Xe 135 34 34 Xe 138 70 70

-2 I 131 0.17 1.7 x 10

-2 I 133 0.68 6.8 x 10

-4 -6 Cr 51 3 x 10 3 x 10

-3 -5 Mn 54 3 x 10 3 x '.0

-4 -6 Fe 59 4 x 10 4 x 10

-4 -6 Co 58 6 x 10 6 x 10

-4 Co 60 1 x 10- 1 x 10

-3 -5 Zn 65 2 x 10 2 x 10

-5 Sr 89 3 x 10 9 x 10-

-6 -8 Sr 90 5 x 10 5 x 10

-4 -6 Zr 95 4- 10 4 x 10

-4 -6 Sb 124 2 :: 10 2 x 10

-5 Cs 134 4 x 10- 4 x 10

-4 -6 Cs 136 3 x 10 3 x 10

-3 5 x 10

-5 Cs 137 5 x 10

-4 -6 Ba 140 4 x 10 4 x 10

-4 -6 Ce 141 1 x 10 1 x 10 (a) Based on NRC GALE Code (Ref. 2) 9

---

l

I WNP-2 ER TABLE 3.5-9 ESTIMATED RELEASES FROM TURBINE BUILDING VENTILATION (a)

Ci/yr Kr 85 m 68 Kr 87 190 Kr 88 230 Xe 133 280 Xe 135 m 650 Xe 135 630 Xe 138 1400 I 131 0.19 I 133 0.76

-2 Cr 51 1.3 x 10

-4 Mn 54 6 x 10

~4 Fe 59 5 x 10

() Co Co 58 60 6 x 10 2 x 10

-4

~4 Zn 65 2 x 10

-3 Sr 89 6 x 10

-5 Sr 90 2 x 10

-4 Zr 95 1 x 10

-4 Sb 124 3 x 10

-4 Cs 134 3 x 10

-5 Cs 136 5 x 10

-4 L Cs 137 6 x 10

-2 Ba 140 1.1 x 10

~4 Ce 141 6 x 10 (a) Based on NRC GALE Code (Ref. 2)

O ,

WNP-2 ER TABLE 3.5-10 ESTIMATED RELEASES FROM RADWASTE BUILDING "

Ci/yr Xe 133 10 Xe 135 45 <.

-2 I 131 5.0 x 10

-1 I 133 1.8 x 10

-5 Cr 51 9.0 x 10

-4 Mn 54 4.5 x 10

-4 Fe 59 1.5 x 10

-5 Co 58 4.5 x 10

-4 Co 60 9.0 x 10

-5 Zn 65 1.5 x 10

-6 Sr 89 4.5 x 10

-6 Sr 90 3.0 x 10 Zr 95 5.0 x 10-Sb 124 5.0 x 10 Cs 134 4.5 x 10-

-6 Cs 136 4.5 x 10

-5 Cs 137 9.0 x 10

-6 Ba 140 1.0 x 10 Ce 141 6.0 x 10-(a) Based on NRC GALE Code (Ref. 2)

O

WNP-2 ER O TABLE 3.5-11 ESTIMATED RELEASES FROM MECHANICAL VACUUM PUMP "

Ci/yr Xe 133 2300 Xe 135 350

-2 I 131 3 x 10

-6 Cs 134 3 x 10

-6 Cs 136 2 x 10

~

Cs 137 1 x 10

-5 Ba 140 1.1 x 10 (a) Based on NRC GALE Code (Ref. 2)

O O

WNP-2 ER l

TABLE 3.5-12 l ANNUAL RELRASES OF RADIOACTIVE MATERTAL AS LIOUID l

CONCENTRATION )

IN PRIMARY - - - - - - - - - - - - - - - - - - - - - - - ADJUSTED l

!!ALF-LIFE COOLANT IIIGli PURITY LOW PURITY TOTAL LWS TOTAL TOTAL i NUCLIDE (DAYS) (MICRO CI/ML) (CURIES) (CURIES) (CURIES) (CI/YR) * (CI/YR)

CORROSION AND ACTIVATION PRODUCTS l

NA 24 6.25E-01 8.38E-03 0.00034 0.00041 0.00075 0.00656 0.00660 l P 32 1.43E 01 1.96E-04 0.00001 0.00002 0.00003 0.00026 0.00026 l 1 CR 51 2.78E 01 4.90E-03 0.00026 0.00050 0.00077 0.00671 0.00670 MN 54 3.03E 02 5.89E-05 0.00000 0.00001 0.00001 0.00008 0.00008 MN 56 1.07E-01 4.08E-02 0.00050 0.00032 0.00081 0.00712 0.00710 FE 55 9.50E 02 9.82E-04 0.00005 0.00010 0.00016 0.00136 0.00140 l 1

FE 59 4.50E 01 2.94E-05 0.00000 0.00000 0.00000 0.00004 0.00004 l CO 58 7.13E 01 1.96E-04 0.00001 0.00002 0.00003 0.00027 0.00027 CO 60 1.92E 03 3.93C-04 0.60002 0.00004 0.00006 0.00055 0.00055 NI 65 1.07E-01 2.45E-04 0.00000 0.00000 0.00000 0.00004 0.00004 CU 64 5.33E-01 2.77E-02 0.00106 0.00122 0.00220 0.02000 0.02000 1l ZN 65 2.45E 02 1.96E-04 0.00001 0.00002 0.00003 0.00027 0.00027 ZN 69M 5.75E-01 1.85E-01 0.00007 0.00009 0.00016 0.00139 0.00140

, ZN 69 3.96E-02 0.0 0.00008 0.00009 0.00017 0.00146 0.00150 l U 187 9.9EE-01 2.84E-04 0.00001 0.00002 0.00003 0.00027 0.00027 NP 239 2.35E-00 6.77E-03 0.00034 0.00057 0.00090 0.00792 0.00790 FISSION PRODUCTS NO BR 83 1.00E-01 2.31E-03 0.00003 0.00002 0.00004 0.00037 0.00037 g, $ BR 84 2.21E-02 3.50E-03 0.00000 0.00000 0.00000 0.00003 0.00003 ea RB 89 1. 0 7 F.-0 2 3.43E-03 0.00001 0.00002 0.00002 0.00021 0.00021 4G^l SR 89 5.291 01 9.81E-05 0.00001 0.00001 0.00002 0.00014 0.00014

"$ SR 91 Y 91M 4.027 -01 3.47E-02 3.64E-03 0.0 0.00012 0.00008 0.00013 0.00008 0.00025 0.00016 0.00222 0.00139 0.00220 0.00140 Fil Y 91 5.88E 01 3.93E-05 0.00000 0.00001 0.00001 0.00007 0.00007 SR 92 1.13E-01 8.20E-03 0.00011 0.00007 0.00017 0.00152 0.00150 0 0 0

O LR AY T/

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WNP-2 ER TABLE 3.5-12 (Con t ' d)

CONCENTRATION -- ADJUSTED HALF-LIFE IN PRIMARY -llIGli COOLANT - - PURITY

- - - - - - -LOW

- - -PbRITY

- - - - - -TOTAL

- LWS TOTAL TOTAL (MICRO CI/ML) (CURIES) (CURIES) (CURIES) (CI/YR) * (CI/YR)

NUCLIDE (DAYS) 3.89E-03 0.00003 0.00002 0.00004 0.00036 0.00036 LA142 6.39E-02 0.00000 0.00003 0.00003 CE143 1.38E 00 2.87E-05 0.00000 0.00000 1 0.00000 0.00001 0.00005 0.00005 l PR143 1.37E 01 3.92E-05 0.00000 0.00007 0.00007 1.32E-02 0.00000 0.00000 0.00001 ALL OTIIERS TOTAL 0.01931 0.16931 0.17000 (L'XCEPT TRITIUM) 4.llE-01 0.00685 0.01246 TRITIUM RELEASE - - - 12 Curies per year - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

• Adjusted total includes an additional 0.15 ci/yr with the same isotopic distribution as the calculated source term to account for ariticipated occurrences such as operator errors resulting in unplanned releases.

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%J O 00 3 6

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WNP-2 ER TABLE 3.5-13_

RADWASTE OPERATING EQUIPMENT DESIGN BASIS DESIGN BASIS DECONTAMINATION FACTOR EQUIPMENT Deep Bed Demineralizers ,

Conductivity . . . . . . . . . . . . . . . . . . . . . . 20 Radioactivity . . . . . . . . . . . . . . . . . . . . . Soluble 100 Insoluble 50 Precoat Filters Equipment Drains 20 Suspended Solids . . . . . . . . . . . . . . . . . . . .

Floor Drains 100 .

1 Radioactivity . . . . . . . . . . . . . . . . . . . . . Soluble Insoluble 2 Evaporators Concentration . . . . . . . . . . . . . . . . . . . . . 2/25 (Input / Bottom)

Radioactivity . . . . . . . . . . . . . . . . . . . . . 1000

WMP-2 ER TABLE 3.5-14 RADWASTE SYSTEM PROCESS FLOW DIAGRAM DATA (sheet 1 of 11)

EQUIPMENT DRAIN SUBSYSTEM Flow Path 1 2 3 4 5 6

/ i Batches / Day (Normal) 8.5 4.1 1.1 6.3 1.0/3.4 4.0/7.4 Batches / Day (Maximum) 63.4 15.8 1.1 6.3 1.0 4.0/2.0 Volume / Batch (gal) 455 909 909 909 2430 13,500 Normal Daily Volume (gal) 3,860 3,755 1,000 5,725 - -

Normal Activity (uCi/cc) 4.92E-2 1.24E-2 6.84E-b 1.82E-5 1.52E-2 6.84E-6 Max. Daily Volume (gal) 28,800 14,400 1,000 5,725 2,430 27,000 Max. Activity (uCi/cc) 1.72E-0 4.32E-1 2.39E-3 1.26E-2 5.32E-1 3.59E-4 Flow Rate (gal / min) 50 50 50 50 50 450 Daily Activity (uCi/ day)

Normal 7.19E5 1.76E5 2.59E2 3.94E2 - -

Maximum 2.51E7 6.14E6 9.05E3 2.73E5 4.89E6 3.67E4 See page 9 of Table for notes, definitions and explanation of entries.

O O O

O O O WNP-2 ER TABLE 3.5-14 (sheet 2 of 11)

EQUIPMENT DRAIN SUBSYSTEM (Cont.)

Flow Path 8 9 33 12 14 Batches / Day (Normal) 1.0/30.0 1.0 1.0 1.0 1.0 Batches / Day (Maximum) 1.0/30.0 7.0 7.0 7.0 7.0 Volume / Batch (gal) 11,250 15,000 15,000 15,000 15,000 Normal Daily Volume (gal) -

15,000 15,000 15,000 15,000 -

Normal Activity (uCi/cc) 8.79E-7 1.llE-2 5.54E-3 1.llE-4 1.llE-4 Max. Daily Volume (gal) 11,250 104,825 104,825 104,825 104,825 Max. pctivity (uci/cc) 3.08E-5 3.59E-1 3.53E-1 3.53E-3 3.53E-3 Flow Rate (gal / min) Batch 190 190 190 190 Daily Activity (uCi/ day)

Normal -

6.28E5 3.12E5 6.28E3 6.28E3 Maximum 1.31E3 4.9E7 4.82E7 4.82E5 4.82E5

WNP-2 ER TABLE 3.5-14 (sheet 3 of 11)

FLOOR DRAIN SUBSYSTEM Flow Path /\ 17 18 19 20 21 Batches / Day (Normal) 1.5 2.2 1.1 2.2 .3 Batches / Day (Maximum) 63.4 16.5 1.1 2.2 1.3 Volume / Batch (gal) 455 909 909 909 19,305 Normal Daily Volume (gal) 700 2,000 1,000 2,000 6,615 Normal Activity (uCi/cc) 6.84E-6 1.00E-6 1.37E-5 6.84E-7 9.53E-5 Maximum Daily Volume (gal) 28,800 12,000 1,000 2,000 52,062 Maximum Activity (uCi/cc) 6.84E-2 1.00E-3 4.78E-4 2.39E-5 1.08E-2 Flow Rate (gal / min) 50 100 50 50 190 Daily Activity (uCi/ Day)

Normal 1.81El 7.57E0 5.18El 5.18E0 2.39E3 Maximum 1.81E5 7.57E3 1.61E3 1.81E3 5.40E5 O O O

l 4

O 0 0 i

4 q WNP-2 ,

ER l

TABLE 3.5-14 '

(sheet 4 of 11)

I l FLOOR DRAIN SUBSYSTEM (Cont.)

! Flow Path 23 107 108 l Batches / Day (Normal) .3 .3 .3 i

i Batches / Day (Maximum) 1.3 1.3 1.3 i Volume / Batch (gal) 19,305 19,305 19,305 Normal Daily Volume (gal) 6,615 6,615 6,615 2

Normal Activity-(uCi/cc) 4.76E-5 9.53E-7 9.53E-7

, Maximum Daily Volume (gal) 52,062 52,062 52,062

! Maximum Activity (uci/cc) 1.08E-2 1.08E-4 1.08E-4 Flow Rate (gal / min) 190 190 190 l

Daily Activity (uCi/ Day) 1 i Normal 1.19E3 2.39El 2.34El l Maximum 5.40E5 5.40E3 5.40E3 l

i i

i i

k

WNP-2 ER TABLE 3.5-14 (sheet 5 of 11)

WASTE SURGE SUBSYSTEM Flow Path 104 37 Batches / Day (Normal) 1.0/yr 1.0/yr Batches / Day (Maximum) 1.0 1.0 Volume / Batch (gal) 56,720 56,720 Normal Daily Volume (gal) - -

Normal Activity (uCi/cc) 6.84E-6 6.84E-6 Maximum Daily Volume (gal) 56,720 56,720 Maximum Activity (uCi/cc) 3,59E-4 3.59E-4 Flow Rate (gal / min) Batch 190 0 0 0

O O O i

1 WNP-2

$ ER 4

. TABLE 3.5-14 i

! (sheet 6 of 11) i CHEMICAL WASTE SUBSYSTEM Flow Path 27 109 120 121 122 f

j Batches / Day (Normal) 1.0 - - - -

j Batches / Day (Maximum) 2.0 1.0 1.0 1.0 3.0 Volume / Batch (gal) 1,000 24,305 24,305 760 230 f Normal Daily Volume (gal) 1,000 - - - -

t Normal Activity (uCi/cc) 1.0E-5 2.63E-3 2.58E-3 1.'45E-2 1.45E-2 Maximum Daily volume (gal) 2,000 24,305 24,305 760 760 l

i

! Maximum Activity (uCi/cc) 1.0E-5 2.67E-3 1.50E-2 1.50E-2

! Flow Rate (gal / min) 25 190 10 Batch 30 1

i i

i i

i I

i 1

i 4

WNP-2 ER TABLE 3.5-15 (sheet 7 of 11)

WASTE SLUDGE SUBSYSTEM (Condensate Backwash)

Flow Path /h 56 58 60 6 Batches / Day (Normal) 4.0/7.4 4.0/7.4 1/18.5 4/7.4 Batches / Day (Maximum) 4.0 4.0 1 4.0 Volume / Batch Solids (lbs) 330 330 3300 -

Liquids (gal) 13,500 13,500 7527 13,500 Normal Daily Volume (gal) 13,500 13,500 Normal Activity Solids (uCi/ Batch) 2.10E6 2.10E6 1.20E7 -

Liquids (uCi/cc) 6.84E-6 6.84E-6 6.84E-6 6.84E-6 Maximum Daily Volume (gal) 54,000 54,000 7527 27,000 Maximum Activity Solids (uCi/ Batch) 5.26E7 5.26E7 2.67E7 Liquids (uCi/cc) 3.59E-4 3.59E-4 3.59E-4 3.59E-4 Flow Rate (gal / min) 2,500 450 20 450 0 0 0

O O O WNP-2 ER TABLE 3.5-14 (sheet 8 of 11)

WASTE SLUDGE SUBSYSTEM (Radwaste lilter Backwash) 61 63 C2 7 65 Flow Path / s Batches / Day (Normal) 1.0 1.0/3.4 1.0/5.2 -

1.0/3.4 Batches / Day (Maximum) 2.9 1.0 1.0/5.2 1.0 1.1 41.36 41.36 59.4 -

219 Volume / Batch Solids (lbs) 1692 1692 2430 28,800 527 Liquids (gal)

Normal Daily Volume (gal) 1692 - -

3.I5E4 8.03El' l.40E4 4.64E4 Normal Activity Solids (uCi/ Batch) 6.84E-6 l Liquids (uC1/cc) 6.L4E-6 6.84E-6 6.84E-6 varies i

l 4906 1692 - 28,800 527 l Maximum Daily Volume (gal) 3.15E4 8.03El 1.41E6 - 7.33E5 Maximum Activity Solids (uCi/ Batch) 3.59E-4 varies '9.88E-4

< Liquids (uCi/cc) 3.59E-4 3.59E-4 376 376 540 20 20 Flow Rate (gal / min) l 1

1 i.......w-2_a..,.

WNP-2 ER TABLE 3.5-14 (sheet 9 of 11)

WASTE SLUDGE SUBSYSTEM (Cleanup Backwash)

Flow Path 54 59 5 Batches / Day (Normal) 2.0/3.4 1.0/60 2.0/3.4 Batches / Day (Maximum) 2.0 1.0/60 2.0 Volume / Batch Solids (lbs). 29.7 1048 -

Liquids (gal) 1215 2391 -

Normal Daily Volume (gal) 1215 1215 Solids (uCi/ Batch) 2.43E7 2.25E8 Mormal Activity 1.52E-2 1.52E-2 1.52E-2 Maximum Daily Volume (gal) 2430 2391 2430 Maximum Activity Solids (uCi/ Batch) 7.68E8 3.59E8 Liquids (uCi/ gal) 5.33E-1 5.53E-1 5.33E-1 Flow Rate (gal / min) 270 20 53 9 G e

WNP-2 ER TABLE 3.5-14 ,

(sheet 10 of 11)

WASTE SLUDGE SUBSYSTEM (Spent Resin)

Flow Path 64 119 69- 71 Batches / Day (Normal) 1.0/66 1.0/67 1.0/25 Batches / Day (Maximum) 1.0/29 1.0/49 1.0/22 Volume / Batch Solids (lbs) 1539 1539 1863 1539 Liquids (gal) 746 746 930 3210 Normal Activity Solids (uCi/ Batch) 2.28E6 5.86E3 1.56E2 -

Liquids (uCi/ gal) 6.84E-6 6.84E-6 6.84E-6 6.84E-6 Maximum Activity Solids (uCi/ Batch) 2.74E7 2.34E5 1.72E2 -

Liquids (uCi/ gal) 3.59E-4 3.59E-4 3.59E-4 3.59E-4 Flow Rate (gal / min) 37 37 47 20

WNP-2 ER TABLE 3.5-14 (sheet 11 of 11)

NOTES:

a. The following definitions are used for this data:

Normal Volume - Expected flow during steady state normal operation.

Maximum Volume - Maximum expected flow during unsteady state operation such as startup, shutdown, etc.

Normal Activity - Activity level expected during operation with no fuel leaks and corrosion product reactor water activity concentration of 0.1 uCi/cc.

Maximum Activity - Activity level expected during operation with fuel leak rate equivalent to reactor water activity concentration of 2.3 uCi/cc and total noble gas stock release rate of 100,000 uCi/sec (corrosion and fission products present).

Maximum volume and maximum activity are not necessarily concurrent.

1

b. For Accivity Values: E-1 = number x 10_14; El = number x 10 4 E-4 = number x 10  ; E4 = number x 10

c. Fractional values on tables denote the number of items per occurrence divided by the nunber of days between each occurrence (i.e., 1/30 batches / day means one batch processed every 30 days) .

d. Waste system input activities are based on a reactor water-to-steam decontamination factor of 1.OE-3.

O O O - -

WNP-2 ER TABLE 3.5-15 f's ))

EQUIPMENT DRAIN SUBSYSTEM SOURCES Startup Regular Irregular Maximum Flows Daily Flows Flows Flows Source (GPD) (GPD) (GPD) (GPD)

Equipment Drains Drywell 3,800 3,800 28,800 Reactor Bldg. 3,800 3,800 14,400 Turbine Bldg. 5,700 5,700 5,700 Radwaste Bldg. 1,000 1,000 1,000 Reactor Hydrotest

& Thermal Expansion Water 56,700 0 0 Suppression Pool Drain 11,300 0 11,300 (4) 0 RHR System Flush Water 4,000 (5) 0 O' Condensate Demin.

Backwash 27,000 13,500 (1) 40,500 (3)

Cleanup Demin.

Backwash 2,400 2,400 (2)

Water Inleakage to Condenser 0 0 14,400 111,700 14,300 104,800 I

4

1. Under normal operating conditions, one condensate filter demineralizer would be precoated every four days.

2. Under normal operating conditions, each cleanup demineralizer would be precoated every 3.4 days.

3. The maximum daily flow is based on a condenser inleakage of 10 gpm, which corresponds to two condensate demineralizer precoats daily and maximum leak and drain inflows. Higher condenser inleakage rates can be accommodated up to a maximum of 36 gpm. This requires precoating of one condensate de-mineralizer every three hours. This leakage rate would result in overloading the equipment drain subsystem but could be tolerated for short periods of time during location and repair

{s,)'s of the leak.

WNP-2 ER TABLE 3.5-15 (Cont'd)

4. Once every thirty days during testing of reactor emergency core coolant systems.

5. Occurs every shutdown prior to placing the RHR system in operation for shutdown cooling.

O O

WNP-2 ER TABLE 3. 5-16 FLOOR DRAIN SUBSYSTEM SOURCES Regular Irregular Maximum Daily Flows Flows Daily Flows Source (GPD) (GPD) (GPD)

Floor Drains Drywell 700 7,200 Reactor Building 2,000 12,000 l Radwaste Building 1,000 1,000 '

Turbine Building _ 2,000 2,000 Waste Sludge Phase Separator Decant 0 8,400(y) 8,400 5,700 8,400 31,200 (1) Under normal operating conditions, the waste sludge phase separator tank is decanted every 3.4 days.

O O

WNP-2 ER TABLE 3.5-17 CHEMICAL WASTE SUBSYSTEM SOURCES Regular Irregular Maximum Daily Flows Flows Daily Flows Source ___ (GPD) (GPD) (GFD)

Detergent Drains / Shop Decontamination Solutions 1,000 2,000 Laboratory Drains 400 400 Decontamination Drains Reactor &

Turbine Buildings 1,000 1,000 From Floor Drain or Equipment Drain Subsystem 20,000 20,000 Filter Demineralizer Chemical Cleaning Infrequent 2,000 Solutions 2,000 Battery Room Drains Infrequent 100 100 Chemical System Overflow Infrequent

& Tank Drains 1,400 25,000 0

i WNP-2 ER I

I TABLE 3.5-18 i OFF-GAS SYSTEM PROCESS DATA l

The information contained in this table is proprietary and will be transmitted separately with other FSAR proprietary information as Sheet 761E918AD.

O l

l O

WNP-2 ER TABLE 3.5-19 RELEASE POINT DATA Reactor Bldg Radwaste Bldg Turbine Bldg Height of release point above grade 230'-8" 65' 107' Annual average total air flow from release point 95,000 82,000 261,000 cfm Annual average heat content flow from release point 15.09 x 10 6

41.46 x 10 6 13.02 x 106BTbfHr Type and size of DUCT 3 LOUVER HOUSES 4 DUCTS release point 45" x 120" 54" x 96" x 30" 57" x 79" O

_ - - - - _ _ _ . _ l

WNP-2 ER O TABLE 3.5-20 NOBLE GAS RELEASE RATE INTO ATMOSPHERE FROM OFF-GAS SYSTEM Avg. Release Rate Isotope (Ci/yr)

Kr 85 m 2 Kr 85 270 Xe 131 m 5 Xe 133 22 Total 299 0

O

_ _ _ . _ _ . - _ _ _ . . . _ _ _ ~ _ . - - _ _ _ - _ _ _ . - . _ - _ - _ , - _ _ _ _ - _ _ _ . __--._ _ ,._ _ _ . ___ _.__.___. -,_. . _ _ .

WNP-2 ER TABLE 3.5-21 ESTIMATED ANNUAL AVERAGE RELEASES OF RADIOACTIVE MATERIALS FROM BUILDING VENTILATION SYSTEMS, GLAND SEAL AND MECHANICAL VACUUM PUMPS GASEOUS RELEASE RATE (CURIES PER YEAR)

COOLANT CONC. TURBINE REACTOR RADWASTE GLAND MECH VAC l' NUCLIDE (MICROCURIES/G) DRYWELL BLDG BLDG BLDG SEAL PUMP Kr 83 m 1.100E-03 0.0 0.0 0.0 0.0 0.0 0.0 Kr 85 m 1.900E-03 3.0E 00 6.8E 01 3.0E 00 0.0 0.0 0.0 Kr 85 6.000E-06 0.0 0.0 0.0 0.0 0.0 0.0 l Kr 87 6.600E-03 3.0E 00 1.9E 02 3.0E 00 0.0 0.0 0.0 Kr 88 6.600E-03 3.0E 00 2.3E 02 3.0E 00 0.0 0.0 0.0 Kr 89 4.100E-02 0.0 0.0 0.0 0.0 0.0 0.0 Xe 131 m 4.700E-06 0.0 0.0 0.0 0.0 0.0 0.0 l 0.0 0.0 Xe 133 m 9.000E-05 0.0 0.0 0.0 0.0 Xe 133 2.600E-03 6.6E 01 2.8E 02 6.6E 01 . 1.0E 01 0.0 2.3E 03 Xe 135 m 8.400E-04 4.6E 01 6.5E 02 4.6E 01 0.0 0.0 0.0 Xe 135 7.200E-03 3.4E 01 6.3E 02 3.4E 01 4.5E 01 0.0 3.5E 02 Xe 137 4.700E-02 0.0 0.0 0.0 0.0 0.0 0.0 Xe 138 2.800E-02 7.0E 00 1.4E 03 7.0E 00 0.0 0.0 0.0 Total Noble Gases I 131 3.449E-03 1.7E-02 1.9E-01 1.7E-01 5.0E-02 0.0 3.0E-02 I 133 1.477E-02 6.8E-02 7.6E-01 6.8E-01 1.8E-01 0.0 0.0 68 Curies /Yr Tritium Gaseous Release "0.0" Appearing in the table indicates release is less than 1.0 Ci/Yr for noble gas and less than 0.0001 Ci/Yr for Iodine.

O O O _ _ _

O O O WNP-2 ER TABLE 3.5-21 (Cont'd)

ESTIMATED ANNUAL ~ AVERAGE RELEASES OF RADIOACTIVE MATERIALS FROM BUILDING VENTILATION SYSTEMS, GLAND SEAL AND MECHANICAL VACUUM PUMPS AIRBORNE PARTICULATE RELEASE RATE )j (CURIES PER YEAR)

CONTAINMENT TURBINE REACTOR RADWASTE MECH VAC BLDG BLDG BLDG BLDG PUMP NUCLIDE 3.0E-06 1.3E-02 3.0E-04 9.0E-05 0.0 Cr 51 3.0E-05 6.0E-04 3.0E-03 4.5E-04 0.0 Mn 54 Fe 59 4.0E-06 5.0E-04 4.0E-04 1.5E-04 0.0 Co 58 6.0E-06 6.0E-04 6.0E-04 4.5E-05 0.0 60 1.0E-04 2.0E-03 1.0E-02 9.0E-04 0.0 Co 65 2.0E-05 2.0E-04 2.0E-03 1.5E-05 0.0 Zn 9.0E-07 6.0E-03 9.0E-05 4.5E-06 0.0 Sr 89 5.0E-08 2.0E-05 5.0E-06 3.0E-06 0.0 Sr 90 4.0E-06 1.0E-04 4.0E-04 5.0E-07 0.0 Zr 95 2.0E-06 3.0E-04 2.0E-04 5.0E-07 0.0 Sb 124 3.0E-06 Cs 134 4.0E-05 3.0E-04 4.0E-03 4.5E-05 Cs 136 3.0E-06 5.0E-05 3.0E-04 4.5E-06 2.0E-06 Cs 137 5.5E-05 6.0E-04 5.5E-03 9.0E-05 1.0E-05 Ba 140 4.0E-06 1.lE-02 4.0E-04 1.0E-06 1.lE-05 1.0E-06 6.0E-04 1.0E-04 6.0E-05 0.0 Ce 141 l

WNP-2 ER TABLE 3.5-22 EXPECTED ANNUAL PRODUCTION OF SOLIDS Normal Maximum 3

50 Ft Activity Activity

• Containers /yr pCi/ Container pCi/ Container 8 0 Cleanup Filcer Demineralizer Sludge 10 1.39 x 10 2.23 x 10 6 6 Condensate Filter Demineralizer Sludge 100 2.47 x 10 5.5 x 10 Waste, Floor Drain & Fuel Pool Filter 5 6 Demineralizer Sludge 36 1.37 X 10 2.16 x 10 2 2 Distillate Den.ineralizer Resin 26 .96 x 10 1. 05 x 10 6 7 Waste Demineralizer Resin 7 1.78 x 10 2.14 x 10 3 5 Floor Drain Demineralizer Resin 7 4.56 x 10 1.82 x 10 4 4 Ccncentrated Waste Solution 11 2.05 x 10 2.12 x 10

• 50 cubic foot containers O O O

j' p'% ,y

( \

\~  %.)

}'

WNP-2 ER

[ -

TABLE 3.5-23 I SIGNIFICANT ISOTOPE ACTIVITY ON WET SOLIDS AFTER PROCESSING Clean Up Waste Distillate Waste Floor Drain Condensate Concentrated Stream Sludge Sludge Resin Resin Resin Sludge Waste Batch Solid 1048 lbs/ 219 lbs/ 1863 lbs/ 1539 lbs/ 1539 lbs/ 3300 lbs/ 690 lbs/

Production 60 days 3.4 days 25 days 66 days 67 days 18.5 days 3 days Isotopes Ci/50 Cubic Foot Container

-6 -3 -3 Mo 99 ---- 0.3 5.3 x 10 1.07 9.1 x 10 ---- 1.3 x 10

-2 -3

Sr 89 40 0.15 1.1 x 10 -5 2.14 1.8 x 10 1.16 1.1 x 10

-6 -3 -5 l Sr 90 11 0.015 1.1 x 10 0.21 1.8 x 10 0.11 8.5 x 10

-7 -4 6.4 x 10-Cs 134 6.7 0.006 5.3 x 10 0.11 9.1 x 10 0.11

-6 8. 5 x 10-l Cs 137 11 0.015 1.1 x 10 0.21 1.8 x 10- 0.17

-b -2 -3 Da 140 4.5 0.35 1.1 x 10 2.14 1.8 x 10 0.66 2.3 x 10

-5 -2 -2 Np 239 ---- ---- 5.1 x 10 10.3 8.7 x 20 ---- 1.1 x 10

-5 -3 I 131 0.67 0.76 1.1 x 10 2.14 1.8 x 10- 0.44 2.5 x 10

-6 -3 I 133 ---- 0.39 3.2 x 10 0.64 5.5 x 10 ____ ____

-5 -2 -3 Co 58 116 0.15 1.6 x 10 2.14 1. 8 x 10 2.26 1.9 x 10 j

-3 -4 Co 60 29 0.015 1.6 x 10 -6 0.21 1.8 x 10 0.44 2.1 x 10 Cr 51 4.5 0.015 1.6 x 10

-6 0.11 9.1 x 10

-4 0.17 2.1 x 10-l I

1 i

l

WNP-2 ER TABLE 3.5-24

SUMMARY

OF RADIOACTIVE EFFLUENT MONITORING AND CONTROL POINTS LOCATION OF RELEASE POINT DETECTOR OR ALARM OR SHUTDOWN AS SHOWN ON RELEASE POINT SAMPLE PROBE TYPE OF MONITOR FUNCTION FIG 3.1-6 REMARKS Reactor Bldg.

Vrtnt Stack Probe at Elev. 650' Continuous Noble Gas Detector High Radiation Alarm

([) Effluent Monitor In Stack (G amma ) , Iodine and Particulate Sampler Cartridge Probe in Off- Dual Continuous High Radiation Process Gas Line from Noble Gas Detector Alarm Automatically Monitor Outlet of GM Tubes 03mmma), Isolates Off-Gas D17-50ll

' Charcoal Ad- Iodine and Partic- from Vent Stack sorbers to ulate Sampler Car-Reactor Bldg. tridge Vent Stack Detector in Continuous GM Tube High Radiation Process Line from 0 Gamma) Detector Alarm, Automatically Monitor (Condenser) Shuts Down Vacuum RE-21 Mechanical Pumps and Gland Vacuum Pumps Seal Exhauster to Vent Stack Four (4) De- Continuous GM Tube High Radiation HVAC Monitor tectors in (Ganma) Detector Alarm, Automatically D17-N009A, Reactor Bldg. Trips Valves to Isolate B, C, D Ventilation HVAC Exhaust froO Exhaust Plenum Vent Stack, Closes (Discharge to Containment Vent Valves Vent Stack) and Initiates Standby Gas Treatment System O O O

O O WNP-2 1

ER TABLE 3.5-24 (Cont'd) i

SUMMARY

OF RADIOACTIVE EPPLUENT l

MONITORING AND cot; TROL POINTS e

LOCATION OF RELEASE POINT DETECTOR OR ALARM OR SilUTDOWN AS SIIOWN Otl HELEASE POINT SAMPLE PROBE TYPE OP !!ONITOR FilNCTION FIG 3.1-6 REMARKS i

Turbine Bldg.

ilVAC Exhaust Probe at

, Elev. 551' Continuous Noble Gas Detector liigh Radiation Alann hhhh Effluent