ML20010J662
| ML20010J662 | |
| Person / Time | |
|---|---|
| Site: | Clinton  |
| Issue date: | 09/23/1981 |
| From: | Koch L ILLINOIS POWER CO. |
| To: | Harold Denton Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML20010J663 | List: |
| References | |
| L34-81(09-23)-L, L34-81(9-23)-L, U-0292, U-292, NUDOCS 8110060323 | |
| Download: ML20010J662 (1) | |
Text
_
U-0292 L34-81(09-23)-L ILLINO/57 POWER COMPANY i?h 500 SOUTH 27TH STREET, DECATUR, ILLINOIS 62525 September 23 g
- tfo, l
fe_
1 Mr. Harold R.
Denton, Director
~
R!
4(N'.N Office of Nuclear Reactor Regulation
'o U.S. Nuclear Regulatory Commission Washington, D.
C.
20555
'N
,,p-Oh -
3
Dear Mr. Denton:
Reference:
NRC (J. R. Miller) Letter 9/3/81 to IP (G. E. Wuller)
" Request for Additional Informatiot for the Environ-mental Review of Clinton Power Station, Units 1 and 2'-
Clinton Power Station Units 1 and 2 Docket Nos. 50-461 and 50-462 Environmental Report - Operating License Stage (ER-OLS)
Supplement No. 2 Tllinois Power Company hereby files Supplement No. 2 dated September, 1981, for the Clinton Power Station Environmental Report - Operating License Stage (ER-OLS).
This ER-OLS Supplement No. 2 provides additional information which was requested by NRC in the above-referenced letter.
Three (3) signed originals and fifty-seven (57) copies are furnished for amending the ER-OLS sets which were docketed on September 8,1980.
Respectfully submitted, ILLINOIS POWER COMPANY
/V
/j /L J. Koch Vice President Subscribed and sworn to before me this 23rd day of September, 1981.
Yor~,e u n bb d J A J
$ 0 Lavonne Bethard - Notary Public 8110060323 810923' PDR ADOCK 05000461 C
PDR J
U-0292 L34-81(09-23)-L ILL/N0lO POWER 00MPANY V-jf m 500 SOUTH 27TH STisEET, DECATUR, ILLINOIS 62525 September 23, 1981 Mr. Harold R. Denton, Director Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Washington, D. C.
20555
Dear Mr. Denton:
Refarence:
NRC (J. R. Miller) Letter 9/3/81 to IP (G. E. Wuller)
" Request for Additional Information for the Environ-mental Review of Clinton Power Station, Units 1 and 2" Clinton Power Station Units 1 and 2 Docket Nos. 50-461 and 50-462 Environmental Report - Operating License Stage (ER-OLS)
Supplement No. 2 Illinois Power Company hereby files Supplement No. 2 dated September, 1981, for the Clinton Power Station Environmental Report - Operating License Stage (ER-OLS).
This ER-OLS Supplement No. 2 provides additional information which was requested by NRC in thu sbove-referenced letter.
Three (3) signed originals and fifty-seven (57) copies are furnished for amending the ER-OLS sets which were docketed on September 8, 1980.
Respectfully submitted, ILLINOIS POWER COMPANY
/>l
/,-
gh/'L J. Koch Vice President Subscribed and sworn to before me this 23rd day of September, 1981.
kNe st u c /- Ybd>S-Lavonne Bethard - Notary Public
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981
()
INSTRUCTION FOR UPDATING YOUR ER To update your copy of the Clinton-Power Station - Units 1 and 2 Environmental Report -- Operating License Stage, please remove and destroy the following pages and figures and insert; the Supplement 2 pages and figures as indicated.
REMOVE INSERT VOLUME 1 General Table of Contents General Table of Contents Pages 1-i/1-11 and Pages 1-1/1-11 and 1-iii/1-iv 1-iii/1-iv Pages 1.1-1/1.1-2 through Pages 1.1-1/l.1-2 through 1.1-13/1.1-14 1.1-13/1.1-14 Page 1.1-21/1.1-22 Page 1.1-21/1.1-22 Page-1.1-27/1.1-28 Page 1.1-27/1.1-28 Figure 1.1-6 Figure 1.1-6 Pages 1.3-1/l.3-2 and Pages 1.3-1/3.3-2 and 1.3-3/1.3-4 1.3-3/1.3-4 Page 2-xxi/2-xxii Page 2-xxi/2-xxii Pane 2.1-7/2.1-8 Page 2.1-7/2.1-8 n(_/
Figure.2.1-15A Figure 2.1-15A Page 2.4-8a Page 2.4-8a Pages 2.4-15/2.4-16 and Pages 2.4-15/2.4-16 and 2.4-17/2.4-18 2.4-17/2.4-18 Following Figure 2.4-18 Figure 2,4-18A (do not remove) i i
VOLUME 2 General Table of Contents General Table of Contents Page 3-v/3-vi Page 3-v/3-vi Figure 3.3-1 Figure 3.3-1 l
Page 3.6-9/3.6-10 Page 3.6-9/3.6-10 Figure 3.6-2 Figure 3.6-2 Page'6.1-9/6.1-10 Page 6.1-9/6.1-10 Page.6.1-29/6.1-30 Page 6.1-29/6.1-30 Page 8.1-1/8.1-2 Page 8.1-1/8.1-2 Page S.1-55/S.1-56 Page S.1-55/S.1-56 3
i Following Page 5.1-69 Supplement 2 tab followed (do net remove) by Questions'and Responses for Supplement 2 i
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 CLINTON POWER STATION - UNITS 1 AND 2 x
s ENVIRONMENTAL REPORT - OPERATING LICENSE ___ STAGE GENERAL TABLE OF CONTENTS CHAPTER TITLE VOLUME J
l Purpose of the Proposed Facility and Associated Transmission 1
2 The Site and Environmental Interfaces 1
3 The Station 2
4 Environmental Effects of Site Prepara-tion, Station Construction, and Trans-mission Facilities Construction 2
5 Environmental Effects of Station l
Operation 2
6 Effluent and Environmental Measurements and Monitoring Programs 2
O
~'
7 Environmental Effects of Accidents 2
8 Economic and Social Effects of Station Construction and Operation 2
9 Alternative Energy Sources and Sites 2
10 Station Design Alternatives 2
11 Summary Cost-Benefit Analysis 2
12 Environmental Approvals and Consulta-tion 2
13 References 2
Supplement 1 2
Supplement 2 2
O
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 O
CHAPTER 1 - PURPOSE OF TH-: PROPOSED FACILITY AND ASSOCIATED TRANSMISSION TABLE OF CONTENTS PAGE 1.0 OBJECTIVES OF THE PROPOSED FACILITY **3D ASSOCIATED TRANSMISSION 1.0-1 1.1 SYSTEM DEMAND AND RELIABILITY 1.1-1 1.1.1 Load Characteristics 1.1-5 1.1.1.1 Load Analysis 1.1-5 1.1.1.1.1 Peak Demand and Energy Requirements 1.1-5 1.1.1.1.2 Load Factor 1.1-5 1.1.1.2 Energy and Demand Projections 1.1-5 1.1.1.3 Power Exchanges 1.1-10 1.1.2 System Capacity 1.1-10 1.1.3 Reserve Margins 1.1-11 1.1.4 External Supporting Studies 1.1-12 1.2 OTHER OBJECTIVES 1.2-1 1.3 CONSEQUENCES OF DELAY 1.3-1 l
1 1-1
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 h
CHAPTER 1 - PURPOSE OF THE PROPOSED FACILITY AND ASSOCIATED TRANSMISSION LIST OF TABLES NUMBER TITLE PAGE 1.1-1 Illinois Power Company Electric Operat-ing Statistics 1.1-14 1.1-2 Past Annual Peak Load Demand Excluding Interruptibles 1.1-15 1.1-3 Future Projected Annual Peak Load Demand Excluding Interruptibles 1.1-16 1.1-4 Past Annual Energy Requirements:
Net to Load 1.1-17 1.1-5 Future Projected Annual Energy Requirements:
Net to Load 1.1-18 1.1-6 Comparison of Past Forecasts with Actual Demand 1.1-19 1.1-7 Historical IP Total System Monthly Integrated Peak Demand 1.1-20 1.1-8 Illinois Power Company 1981-1990 Monthly Peak Forecast 1.1-21 1.1-9 Historical IP Past Monthly Energy gg)
Requirements from 1966 to 1980 1.1-22 1.1-10 Historic IP Capacity Entitlements and Commitments at Time of Summer Peak 1.1-23 1.1-11 Projected Capacity Entitlements and Commitments for MAIN, Ill t.o, and IP 1.1-24 1.1-12 Illinois Power Company Accredited Unit Capability Effective December 13, 1978 1.1-25 1.1-13 Illinois Power Company Unit Work Data for 1984 and 1995 1.1-26 1.1-14 Future Generation Installations from 1981 to 1999 for MAIN, Ill-Mo, and IP 1.1-27 1.1-15 Installed Generating Capacity during Summar, from 1970 to 1999 1.1-28 1.1-16 IP Lcad and Capability Summary for 1975 ta 1980 1.1-29 1.1-17 IP Projected Capacity and Demand at System Peak 1.1-30 1.1-18 Future Projected Demand and Capability Summary for MAIN, Ill-Mo, and IP from 1981 to 1999 1.1-31 1.3-1 Future Projected Load and Capability Summary without IP Clinton Unit 1 for MAIN, Ill-Mo, and IP from 1984 to 1987 1.3-4 1.3-2 Future Projected Load and Capability Summary without IP Clinton Unit 2 for MAIN, Ill-Mo, and IP from 1995 to 1998 1.3-5 1-il
1 CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 SUPPLEMENT 2 O./
SEPTEMBER 1981 s
[
LIST OF TABLES (Cont'd)
NUMBER TITLE PAGE 1.3-3 Production Cost Analysis for Official Load Forecast 1.3-6 1.3-4 Variable Costs for Official Load Forecast 1.3-7 2
1.3-5 Replacement Energy for. Official Load 1.3-6 Production Cost Analysis foc.
1.3-8 Forecast No y
Load Growth 1.3-9 1.3-7 Variable Costs for No Load Growth 1.3-10 1.3-8 Replacement Energy for No Load Growth 1.3-11 i
.i
- (:)
O 1-111
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 CHAPTER 1 - PURPOSE OF THE PROPOSED FACILITY AND ASSOCIATED TRANSMISSION LIST OF FIGURES NUMBER TITLE 1.1-1 National Electric Reliability Council Regions 1.1-2 Mid-America Interpool Network (MAIN) with Ill-Mo Pool, January 1978 1.1-3 Electric Utilities In Illinois, 1978 1.1-4 Electric Transmission Lines and Substations of Illinois Power Company, 1981 1.1-5 Typical IP Load Curve with 56% Load Factor 1.1-6 Illinois Power Company Comparison of Recent Forecasts 1.1-7 IP Flow Diagram of Peak Load Forecast Model for 1980-2000 Peak Load Forecast 1.1-8 Illinois Power Company Actual and Forecasted Annual Peak Load Demand, 1966-2000 1.1-9 Illinois Power Company Actual and Forecasted Annual Energy Requirements, 1966-2000 0
0 1-iv
_.-.-----------_________J
t CPS-ER(OLS)
SUPPLEMENT I I
JUNE 1981 1.1 SYSTEM DEMAND AND RELIABILITY The Illinois Power (IP) system is part of Mid-America Interpool-Network (MAIN), one of nine regional reliability councils that 4
l comprise the National Electric Reliability Council (NERC).
l Membership-in MAIN is voluntary and informal.. Members of "AIN provide electric service to loads in Illinois, Missouri, Michigan, and Wisconsin.
There are 12 member systems in MAIN.
l l
The MAIN response to Federal Power Commission (FPC) Order 383-3 (MAIN's Submittal on Coordinated Eulk Power Supply Program to the t
i Department of Energy, Code ERA-411,-April 1,
1981),-therefore, includes resource data from its 12 member systems, and in addition, includes data from associate members made up of small municipalities, cooperatives, and other systems, each with 25 MW or more of generating capacity.
In all, 21 interconnected l
systems within the MAIN region are included in the response to FPC Order 383-3.
Figure 1.1-1 shows the region included within MAIN and its relationship to other NERC regions.
l-IP is a participant in an Interconnection Agreement Between j
Central Illinois Public Service Company-(CIPS), Illinois Power
~
Company, and Union Electric Company (UE), February 18, 1972.
This more formal arrangement is known as the Ill-Mo Pool.
The Ill-Mo Pool through its member companies provides electric service to customers in portions of Illinois and Missouri.
()
Resource data for the Ill-Mo Pool is listed in the MAIN response j,
to FPC Order 383-3.
Figure 1.1-2 shows the region included i
within the-Ill-Mo Puol.
l The IP service territory comprises approximately 15,000 square i
miles in the southern two-thirds of Illinois, or approximately one-fourth of the state.
The largest cities served are Galesburg, Kewanee, LaSalle, Monmouth, and Ottawa in north 1 central Illinois; Bloomington, Champaign,-Danville, Decatur, Jacksonville, Normal, and Urbana in central Illinois; and Belleville, Centralia, Collinsville, Granite City, Mt. Vernon, and Wood River in southwest Illinois.
Figure 1.1-3 shows the 1.
other Illinois utilities and'IP's relationship to them.
1 On January 1, 1 11, IP furnished electric service to 522,166 l
customers-in 422 communities.
The area served by IP has a i
population approaching 1,405,000.
Customers by service class l'
include:
466,546: residential, 54,546 commercial and small power, 359'large power, and 715 others.
Additionally, IP provided electric service to ten municipalities (two full requirement, 4
l eight partial requirement), nine electric cooperatives, and one privately owned distribution company.
Table 1.1-1 shows the breakdown of IP's customers for the years 1974 through 1980.
IP owns and operates electric generating facilities having a net summer capability of about 3,815 MW.
These facilitles include five steam generating stations with a net. summer capability of 3,626 MW.
IP owns other generating facilitiac with an aggregate I
1.1-1
,,-_.-,,,__m,,__,,,__--,____,_.,_,,_.,,-.,-,,_m_,._-_-,_m.,_.;--,.-,
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 4h capability of 189 MW, including one hydro stution and internal combustion and gas turbine peaking units at six locations.
In addition, the company has 55 MW of capacity available under contract from Electric Energy Inc. (EEI).
EEI is a corporation owned by Union Electric Company (40% ownership), Illinois Power Company (20%), Central Illinois Public Service Company (20%), and Kentucky Utilities Company (20%).
EEI operates the 1000 MW Joppa plant and supplies a portion of the Department of Energy (DOE) plant load near Paducah, Kentucky.
The generating stations owned and operated by IP are connected by an extensive transmission network to 775 substations.
As of January 1, 1981, there were 4,057 pole miles of transmission lines at all voltages, including 428 miles operating at 345 kV.
In addition, IP is interconnected with neighboring electric systems.
The major interconnections are with Central Illinois Light Company (CILCO), Central Illinois Public Service Company (CIPS), Commonwealth Edison Company (CECO), Indiana and Michigan Electric Company (IME), Iowa-Illinois Gas and Electric Company (IIG&E), Tennessee Valley Authority (TVA), and Union Electric Company (UE).
Customer load is distributed via an extensive distribution system that includes 872 distribution feeders.
Figure 1.1-4 shows major IP generation, transmission, and substation facilities as they existed on January 1, 1981, along with the proposed Clinton Power g
Station and its associated transmission ties.
Current IP expansion plans include the installation of two 950 MWe nuclear units at the Clinton Power Station.
Clinton Station Ownership Participation Agreement, August 19, 1976, between IP, Soyland Power Cooperative, Inc. (Soyland), and Western Illinois Power Cooperative (WIPCO) provides that the Clinton Power Station Unit 1 shall be owned by the participants as tenants in common, on an undivided basis, with IP owning 80%, Soyland owning 10.5%,
and WIPCO owning 9.5%.
The Ownership Agreement further stipulates that Soyland and WIPCO may participate in Clinton Power Station Unit 2 on an identical basis subject to the availability of financing.
Effective with the in-service date of Clinton Unit 1, IP will no longer serve wholesale cooperative load except for about 15 MW of WIPCO load.
Soyland will purchase unit deferral capacity (UDC) from IP untll 1988.
UDC will cover the needs of Soyland's member distribution cooperatives served from existing IP delivery points in excess of the amount served by Soyland's share,f Clinton Unit 1.
In addition, UDC includes Soyland's ;eserve ooligation for its share of Clinton Unit 1.
UDC will increase annually as a result of load growth until 1987, at which time it is scheduled to decrease because of capacity additions planned by Soyland.
IP has no obligation to provide UDC after May 31, 1988.
1.1-2
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981
)
It is expected that by l984 (the first year in which Clinton
~
Power Station Unit I will be in commercial service during the pea load season) IP's annual peak load will have increased 7.6%
sine-1980, to 3,390 MW; its energy requirements will have increased 6.5%, to 16,537 GWh; and its net usable owned capacity will have increased 20%, to 4,575 MW.
After adjusting the projected demand for scheduled firm purchases and sales, total capacity will exceed load responsibility by 1,104 MW in 1984.
IP's share of the 950 MW Clinton Unit i represents 100% of IP's capacity additions planned between 1981 and 1990 and 69% of its reserve capacity in 1984.
By 1984, it is anticipated that the net usable owned capability in the Ill-Mo Pool will have increased 21% since 1980 to 16,093 MW; its annual peak demand will have increased 6%, to 11,843 MW; and its energy requirements will have increased 7%, to 55,575 GWh.
After adjustments for scheduled imports and exports, total capability will exceed load responsibility by 3,770 MW in 1984.
Clinton Unit I represents 28% of the Ill-Mo Pool's projected capacity increase between 1981 and 1984 and 20% of its reserve margin at the time of the 1984 summer peak.
Similarly, by 1984 the annual peak demand for MAIN will have increased 13% since 1980, to 38,298 MW; its energy requirements will have increased 13%, to 187,253 GWh; and its net usable owned I'T cspacity will increase 8%, to 47,504 MW.
After adjustments total capability will exceed load responsibility by 9,238 MW in 1984.
\\~'
Clinton Unit I will represent 12% of MAIN's capacity increase between 1981 and 1984 and 8% of its reserve margin at the time of the 1984 summer peak.
It is expected that by 1995, when the second unit of the Clinton Power Station is scheduled to begin operation, IP's annual peak load will have increased 65% since 1980, to 5,21C MW; its energy regairements will have increcsed 75%, to 27,247 GWh; and its net usable owned capacity will have increased 66% to 6,317 MW.
Total adjusted capacity will exceed load responsibility oy 1,164 MW in 1995.
IP's share of the 950 MW Clinton Unit 2 represents 31% of IP's capacity additions planned between 1981 and 1995 and 65% of its reserve capacity in 1995.
Information for MAIN and L.C.
is not available for 1995.
l In the area of energy conservation and load management, IP has embarked on a number of programs involving advertising campaigns, innovative rate designs, load management techniques, and l
promotion of energy saving improvements.
The major objective of the load management effort is to shift demand to off-peak periodo, which results in more efficient use of generating capacity, and hence, lower per unit energy costs to the consumer.
The energy conservation program is designed to reduce demand and es
(_)
consumption by eliminating waste.
This savings can be used to 1.1-3 t
l
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 accommodate new customers and load growth without increasing IP's lll need for additional fuel and generating capacity.
IP has conducted " energy conservation audits" on the homes of residential customers requesting this service.
During these audits customers' homes are checked for energy efficiency.
Evaluations are made on excess heat loss or gain, attic ventilation, duct work insulation, and other factoco.
During the audit IP representatives may recommend energy saving improvements such as caulking, weatherstripping, adding insulation, or adding storm doors and windows.
In August 1977, Edison Electric I'tstitute (EEI) introduced a national program called " National Energy Watch."
Under this program, IP's energy-use personnel made free inspections of homes for energy efficiency and evaluate them according to guidelines approved by EEI.
Energy saving improvements are suggested to the customer.
Altogether, Illinois Power has cot' ducted over 79,000 residential audits as of April 1,
1981.
Part 1 of Title II of the National Energy Conservation Policy Act mandated the Residential Conservation Services (RCS) Program.
In compliance with rules promulgated by the Department of Energy (DOE) Illinois submitted a plan for RCS to DOE.
The Illinois Plar was approved by DOE on April 20, 1981.
Illinois Power Company helped develop the Illinois Plan, and IP is in compliance with the provisions of the plan.
IP advertises these services and other specific energy conservation information and suggestions for its residential customers.
The goal of these programs is to assist IP's customers to use energy wisely and efficiently and to personally contact all residential customars within 10 years.
Company representatives also perform " energy audits" to help commercial customers manage their electrical use more efficiently.
During these audits, the representative may recommend improvements such as load control devices, better ventilation, more efficient equipment, planned mair.tenance, different fuels, switching loads from on-peak to off-peak periods, or night setbacks for thermostats.
IP initiated an industrial load management program in 1975 to (1) improve system load factor and to control or direct the electric load on its system by voluntary and mutually beneficial customer actions and (2) to help industry utilize energy more efficiently.
IP representatives assist industrial customers to develop programs for more efficient energy utilization, conduct energy audits of industrial customers' plants, and introduce industrial customers to energy efficient equipment and processes.
IP also lll 1.1-4
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981
({}
sponsors courses on energy management and technical seminacs on load management techniques.
Other forms of load management are being used or experimented with.
These include seasonal rates, solar water and space heating, direct control of domestic water heaters and l
cogeneration opportunities.
1.1.1 Load Characteristics 1.1.1.1 Load Analysis i.1.1.1.1 Peak Demand and Energy Requirements The past annual peak load demands of IP, _11-Mo Pool, and MAIN are shown en Table 1.1-2 for the period from 1966 through 1980.
Forecasted annual peak Icad demands are shown in Table 1.1-3 for 1981 through 2000.
The past annual energy requirements for IP, Ill-Mo Po ~, and MAIN ace shown on Table 1.1-4 for the period 1966 through 1980.
Forecasted annual energy requirements are shown on Table 1.1-5 for the period 1981 through 2000.
1.1.1.1.2 Load Factor
()
Figure 1.1-5 shows IP's 1980 Load Duration Curve.
This curve yields an annual load factor of 56%, which is representative of the load factor expected in the mid 1980's following the start of commercial operation of Clinton 1.
1.1.1.2 Energy and Demand Proiections The model utilized for the current peak load forecast uses econometric techniques and disaggregated system peak into the 5 l
components shown below:
Large Industrial (customers with actual LI
=
demands over 500 kW during the summer months);
RCOB =
Residential, Commercial, and Other Base l
load (other consists of lighting, j
municipal service, and wholesale municipal);
RCOWS = Residential, Commercial and Other Weather-Sensitive load; COOP
= Wholesale (WIPCO and SOYLAND only); and j
Interconnected municipalities Load (Partial
(])
MUNI
=
Requirements Contracts) i i
1.1-5
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 Figure 1.1-7 contains a flow diagram of this forecasting model.
lll Power curves were adopted for LI, RCOB, and RCOWS models.
The COOP model is a growth rate applied to their historical load.
MUNI is projected to grow at the same rate as MCOB and RCOWS.
Ordinary least-squares regression analysis was used to determine l
the historical relationships on which the future was forecast.
Figure 1.1-7 is a flow diagram depicting IP's econometric model used for the 1980-2000 peak load forecast.
The model for large industrial peak load LI is as follows:
Suinmer : LI = EXP (-35.4 -
0.215 In IPE + 2.64 In INC)
(2.03)
(24.08)
Winter: LI = EXP (-35.5 0.160 In IPE + 2.65 In INC)
(1.55)
(26.34) where:
Large Industrial peak load (MW);
=
Large Industrial Real Price of Electricity (t/kWh); and INC
Total Personal Income (thcusands of dollars).
gg Statistics of Fit Item Value Summer Winter r2 0 980 0.984 F-Statistic 298 348 Durbin-Watson 1.56 1.52 t-Statistic Residential, Commercial, and Other Base load (RCOB) was modeled on a per residential customer basis.
Base load is then the product of number of residential customers and base load per residential customer.
The model for Residential, Commercial, and Other Base load is as tollows:
- t-Statistic are shown in parentheses below the equation lll coefficients.
1.1-6
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 SUPPLEMENT 2 i
' SEPTEMBER 1981
{
RCOB =
RC x BNC Summer: BNC =
EXP l-8.70 - 0.310 In (RPE)]
(6.57)
PCI 2
Winter BNC =
EXP l-8.58 - 0.297 In (RPE)]
(9.02)
PCI uhere:
1 RCOB =
Residential, Commercial, and Other Base load (HW);
RC
Number of Residential Customers; BNC
Base Load per Residential Customer (MW/ customer); and RPE
= Residential Average Annual Real Electricity Price (t/kWh)
PCI =
Real Per Capita Income ($).
Statistics of Fit O
Item Value Summer Winter ra 0.769 0.872 F-Statistic 43 81 Durbin-Watson 1.98 1.97 t-Statistic The model for summer weather-sensitive load is as follows:
RCOWS = AC x EXP (-4.76 - 0.811 in RSPE) 1 (5.01)
AC =
ACSAT x RC ACSAT = C/
[1 + EXP (+ 0.872 - 0.175 x Year)]
(25.1)
)
- t-Statistic are shown in parentheses below the equation coefficients.
1.1-7
.-,--.--.-.~.-.
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 SUPPLEMENT 2 SEPTEMBER 1981 where:
RCOWS = Reridential, Commercial, and Other Weather Sertsitive load (MW);
AC =
Number of Air Conditioners (central equivalents);
ACSAT = Residential Air Conditioning Saturation (decimal form)(3 window units equals 1 central unit);
RSPE
= Residential Summer real electricity price (t/kWh);
RC
= Number of Recidential Customers 2
C=
Ceiling of ACSAT central equivalents (=0.75)
Year =
1965 is Year 1.
Statistics of Fit (g)
Item Value r2 0 659 F-Statistic 25 Durbin-Watson 2.66 t-Statistic 1
The model for winter weather-sensitive load is as follows:
RCOWS = REHE x EXP (-18.5 - 1.63 In PCI)
(6.21) where:
RCOWS = Residential, Commercial and other winter weather-sensitive load REHE =
Number of Residential Electric Space Heat Equivalent Customers Real Per Capital Income ($)
PCI
=
llh
- t-Statistic are shown in parentheses below the equation coefficients.
1.1-8
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981
(
Statistics of Fit Item Value r2 0.763 F-Statistic 39 Durbin-Watson 1.74 The model for system peak (SPEAK) is the sum of the three components shown above plus COOP and MUNI load.
SPEAK = RCOB + RCOWS + LI + COOP + MUNI where:
SPEAK = System Peak (MW); and COOP =
Wholesale (WIPCO and SOYLAND only)(MW).
The COOP load is forecast using growth rates supplied by each cooperative.
Forecasts of the exogenous variables used in the peak load forecast are as follows:
(])
IPE =
Increase at a rate of 3% per year 1981-1984; 2% per year 1985-1989; 1% per year 1990-1994; and 0.0% per year 1995-2000.
INC =
Increase 2.0% per year 1981-1984; 2.2% per year 1985-1989; 2.3% per year 1990-1994; and 2.2% per year 1995-2000.
Increase 2.0% per year 1981-1984; and at a RC
=
declining rate from 1985 down to 0.9% per year in 2000.
PCI =
Increase 1.7% per year 1981-2000.
0.75 C
=
RPE =
Increase 1.5% per year 198!-1984; 1.0% per year 1985-1989; 0.0% per year 1990-1994; and -1.0%
per year 1995-2000.
This econometric methodology is an extension of previous 4
forecasting methodologies.
Table 1.1-6 compares earlier forecasts with the actual loads experienced on the IP system.
Figure 1.1-6 provides a graphic comparison between earlier peak load forecasts and the current forecast.
()
Table 1.1-3 contains a tabulation of the peak load forecast using the econometric model.
i 1.1-9
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 llh It is anticipated that peak load growth rates will not return to their previous rates.
For the period from 1980 through 1995 IP's peak load, excluding cooperative load, is expected to increase at approximately 3.9% per year.
The forecast for the 1995-2000 period is approximately 4.8%.
The peak load growth rate experienced between 1966 and 1973 was 8.8S.
Figures 1.1-8 and 1.1-9 are plots that describe thase demana and energy growth rates from 1966 through 2000.
Historical IP monthly peak demands for the period from 1966 through 1980 are shown on Table 1.1-7.
Forecasted monthly peak demands are shown on Table 1.1-8.
The historical relationship of monthly to annual peaks was used to establish forecasted monthly peaks.
Monthly data showing actual IP energy consumption energy requirements are tabulat?d in Table 1.1-9.
1.1.1.3 E0ver Exchanges Historical IP capacity entitlements and commitments at the time of the annual system peak demand are shown on Table 1.1-10.
Economy and emergency transactions are not included.
Historical data show that, since 1966, the IP system power exchange has resulted in sizeable imports and exports.
The forecasted power exchanges show that a substantial net export is l
expected in future years.
(g)
Table 1.1-11 shows the projected capacity entitlements and commitments for Ill-Mo Pool, MAIN, and IP during the period l
1981-1999.
1.1.2 System Capacity Generation system expansion planniig at IP is affected through detailed analyses of environmenta and social considerations, economics, technical uncertaintius, and operating characteristics.
These analyses are then merged to yield the optimized or most desirable expansion plan that satisfies the desired capacity and reserve margin.
IP is bound by the Ill-Mo Pool agreement to maintain sufficient capacity for its own load plus a reserve of at least 15% of its adjusted demand or 50% of the capacity :f its largest generating source, whichever is greater.
These minimum reserve requirements may be modified from time to time by mutual agreement of the parties to the agreement.
Analyses by the MAIN Guide #6 Working Group have indicated that an adequate reserve level for the member companies in the early 1980's is about 15%.
Because of the characteristics of new units to be installed in the future and the greater magnitude of load forecast uncertainty, the IP P]anning Department utilizes a 15%
1.1-10
~.
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981
()
reserve margin until Clinton Unit 1 is installed and a 17%
reserve thereafter.
l The aforementioned " optimized" justification of expansion units is based solely on IP load growth.
However, depending on the factors involved, IP may arrange for capacity transactions with its neighbors during the years for which it expects to have either a surplus or deficiency of reserve capacity to adjust the timing of a new unit installation.
Although IP may be able to l
obtain periodic short-term capacity from other electric utilities, none of these utilities plans to be an esporter of power on a long-term basis.
Therefore, power cannot be purchased indefinitely as an alternative to installing new electric generation facilities.
The capabilities of e'xisting IP units are shown on Table 1.1-12.
Fuel types, duty cycles, and capacity factor estimates (1984 and 1995) for these units and Clinton Units 1 and 2 are shown on l
Table 1.1-13.
Capacity additions and retirements that are planned for IP, Ill-Mo Pool, and MAIN are shown on Table 1.1-14.
l IP capability, both existing and planned, and planned capacity for Ill-Mo Pool and MAIN at the time of annual peak demand are tabulated on Table 1.1-15.
(])
1.1.3 Reserve Marcin As noted in Subsection 1.1.2, IP's required reserve margin is 15%
of its adjusted demand prior to the installation of Clinton 1 and 17% thereafter.
These margins are baced on the Ill-Mo Pool Interconnection Agreement, MAIN recommendations, and in-house study.
The Ill-Mo Pool 15% reserve requirement is founded on actual operating experience and supplemented by probability studies made from time to time by Pool members.
Analyses by the MAIN Guide 46 Working Group have recommended a 15% reserve level for the member companies in the early 1980's.
This reserve level recognizes the value of the interconnected individual systems within MAIN and the assistance available from inter-tie with adjacent reliability councils.
At this time, MAIN 4
has not mandated a minimum reserve requirement for its members.
The MAIN analysis was made using the Probability of Positive Margin (POPM) approach.
This method relies on statistics to determine the reliability of MAIN's. generating system.
Increased attention is being paid to the level of reserve that is considered adequate.
Both IP and the MAIN Guide 46 are developing reliability. indices using the Loss of Load Probability (LOLP) method.
This approach uses statistics to calculate the number of occurrences of load exceeding capacity.
The results of s
l these studies are, as yet, unavailable.
i
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CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 Forced and scheduled unit outage rates are closely related to 4h overall IP system security and reserve margins.
The spring and fall months usually have the lowest monthly capacity requirements and are ideal for scheduling maintenance.
Thus, the scheduled maintenance of generation capacity closely follows seasonal fluctuations in load.
Generation maintenance is scheduled with the intent of levelizing reserve margins at a constant percentage of load responsibility each week during the maintenance season.
Unexpected forced outages may cause the maintenance schedule to be revised.
Many times, a forced outage on one unit will prevent others from coming off for scheduled maintenance because of reserve requirement limitations.
In some instances when a unit is forced out, maintenance work planned for later in the year is done ahead of schedule since the unit is down anyway.
Generatior, and transmission maintenance plans are coordinated extensively within the Ill-Mo Pool.
Maintenance is also coordinated with systems outside the Pool, and the effect of scheduled outages of major units and transmission lines in neighboring systems is considered in overall reliability planning.
Table 1.1-16 is a summary of IP actual load and capability data for the 1975 through 1980 period.
The actual reserve may exceed the minimum required reserve because of (1) mis.natches in annual growth rates and economical unit sizes and (2) differences g
between actual and forecasted loads.
Table 1.1-17 shows the adjustments to IP's load and capacity made to calculate the adjusted demand and eajusted capacity for the period from 1981 through 1999.
Table 1.1-18 is a summary of forecanted loads and capability for IP, Ill-Mo Pool, and MAIN during the 1981 through 1999 period.
These summaries indicate that in 1984 with the inclusion of Clinton Unit 1, IP will have reserves of 1,104 MW, Ill-Mo Pool will have reserves of 3,770 MW, and HAIN will have reser" 7 of 9,238 MW.
In 1995 with the inclusion of Clinton 2,
.e will i? ave reserves of 1,164 MW.
Information for MAIN and Ill-Mo is unavailable.
1.1.4 External Supporting Studies MAIN Guide 46, included in the Appendix to MAIN's response to FPC Order 383, adopts an adequacy criterion of a LOLP of 0.1 day per year.
Preliminary results utilizing the LOLP criterion generally correspond to the POPM criterion used by MAIN prior to LOLP.
Based on POPM, MAIN established that " current analysis and practices are consistent with an interim policy of maintaining a minimum reserve for MAIN as a whole of 15% each year for the next several years."
At the time this interim policy was established (1976), it was recognized that further investigations of the parameters that influence reserve requirements should be made a
prior to adoption of a firm policy.
This investigation is still W
under way.
1.1-12
j CPS-ER(OLS)
SUPPLEMENT I JUNE 1981 a
Item 3B of the aforementioned report concludes that the forecasted reserves for the Ill-Mo Pool are " adequate for the i
report period," (1981-1985).
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1.1-13 i
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TABLE 1.1-1 ILLINOIS POWER COMPANY ELECTRIC OPERATING STATISTICS Revised April 1981 1960 1979 1978 1977 1976 1975 19 74 Custemers At End of Year Resid.ntial 406,54; 461,966 455,014 445,130 435,611 426,062 419,742 Cmnercial cad Small Power 54,546 53,804 53,051a
'1,334 51,019 49,996 49,733
' arge Power nr.d Light 359 374 368a 1,305 1.340 1,309 1,273 ethet 715 714 699 692 694 689 692 Total 522,166 516,8To~
509,132 498,511 466,664' 478,056 471,490 Sales in Thousands of E!.lowatt liours Residential 4,003,563 3,737,245 3,770,703 3,632,898 3,211,719 3,277,664 2,935,760 f
cercre tal and Small Iowec 2,492,930 2,408,131 2,383,521 1,696,694 1,405. h 1,380,771 1,249,426 M
Large Fawer and Light 6,507,4e8 6,738,321 6,271,672 6,541,429 6,412,648 5,759,317 5,692,609 H
ither 290,851
^32,643 271M 260,263 24 7,2'A 222,S10 ml,400 g
i
- ale s-Ultimate consuners 13,294,612 13,166,545 12,697,949 12,131,4P4 11,331, % 4 10,f40,562 10,079,3's?
p F ural Coaperatives and Municipal Utilities 1,169,702 1,057,113 674,452 d17,334 736,034 633,026 619,h3 t/)
Other Electric Utilities 1,961
.l.,874 2h 2,035 1,836 1,650 1,446 2
Total 14,480,415 14,225,532 IJ,574,405 12,950,653 12,073,724 11,325,23d 10,i00,208 heclassification due to rate structure change.
C.4 CA CC Z 'O M 'O t*
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'J V,9 Table 1.1-8 ILLINOIS POWER COMPANY 1980-1990 MONTHLY PEAK FORECAST (All Values in Megawatts)
YEAR JAN FEB MAR APR MAY JtRJ JUL AUG SEPT OCT NOV DEC 1981 2715 2640 2470 2210 2585 2980 3250 3135 2945 2365 2690 2830 1982 2875 2795 2615 2325 2700 3110 3395 3275 3075 2485 2845 2990 1983 3040 2955 2765 2435 2795 3220 3515 3390 2970" 2415 2775 2920 1984 2965 2885 2695 2365 2695 3105 3390 3270 3070 2520 2925 3075 1985 3125 3040 2840 2470 2780 3205 3500 3375 3170 2630 3085 3245 g
7' 1986 3295 3205 2995 2580 2870 3310 3615 3485 3275 2745 3250 3415 Y
7 e,#
1987 3470 3375 3155 2690 2965 3415 3730 3595 3380 2865 3415 3590
^
Q w
1988 3650 3550 3320 2805 3060 3525 3850 3710 3490 2990 3600 3745 d
1989 3845 3740 3495 2930 3155 3635 3970 3830 3595 3120 3785 3980 1990 4045 3930 3675 3060 3265 3765 4110 3960 3725 3260 3985 4190 mmzm Sourae:
Illinois Power " Native Electric Peak Load Forecast 1980-2000."
The values QpMy include interruptibles except for July.
gg g
$$~$
aFirst month in which WIPCO and SOYLAND are excluded from IP native load.
8 8
gw N
TABLE 1.1-9 HISTORICAL IP PAST MONTHLY ENEPGY REQUIREMENTS FROM 196ti TO 1980 (All Values in Kilowatt Hours)
Y F.AR J A.VJ ARY FF B PC A RY PARCM APR11 MAY JUNE JULY 1966 556,760,358 500,793,546 539,559,680 500,052,856 506,781,017 546,566,713 847,257,377 196' 563,174,523 542,629,949 572,457,299 520,111,960 545,907,526 600,165,468 612,049,640 1968 668,914,'26 620,084,342 626,991,265 547,164 324 61%,464,223 694[285,923 742,233,153
- 969 715,914,707 633,610,331 689,956,390 644,073,677 684,521,934 720,375,g87 372,021,705 1970 777,123,914 6e7,244.645 730,909.775 696,610,219 742,406,015 776,988,265 972,465.433 1971 796,026,240 729,065,945 781,*.5.559 712,986.815 725,C54,683 953,549,938 000,819,313 1972 846,634.'35 006,2i',229 523,326,722 761,033,831 843,539.243 897,059,429 981,056,264 1973 928,353.434 936,1?7,116 979,164,866 326,769,365 959,999,275 1,000,689,370 1,128,195,i's O
t 1974 960,275,013 B53,053,320 903,461,675 542,977,273 599,t20,'15 917.36*,300
.,214,670,174 g)
Fd 1975 1,015.141,693 899,007.126 991,693,693 686,956,723 934,587,399 1.C69,450,925 1,168,921,40' g
1976 1,116,513,645 993.814,518 1,025,107,789 950,019,9?2 971,332,394 1,100,194.793 1,2?9,314,356 UO ff, 1977 1,261,044,861 1,051.658,010 1,090,391,189 99?,988,055 1,152,1C4,033 1,176,133,995 1,416,180,474 bJ 1978 1,243,?99,764 1.118,709,323 1,l'9.879,729 1,031,555,490 1,139,544,494 1,255,816,465 1,384,139,814
()
h3 1979 1,391,230,814 1,242.636,546 1,242,244,460 1,114,575,~49 A,156,612,810 1,292 i43,150 1,372.142,210 Ed ff, 1950 1,350,124,960 1,285,297,160 1,286,779,190 4,124,324,710
,,133,004,630 1,243,524,370 1,589,682.0c2 Y EA g AUCCST SFPTFRBER OCTOBER ItWEM B E R DECEM&ZR AMtAL 1966 570,394,224 521,732,9I6 542,414,407 551,243,271 591,305.024 6,574,152,519 196 7 619.246,199 563,757,433 404,104,327 622.171,251 442,787,127 7,047,903,900 1969 767,330,656 639,731,250 649,102,031 432,089,934 696,096,393 7,900,365 230 1963 918,687,904 704,067,043 724,774,332 695,140,365 746,854,609 3,653,989,660 1970 852,893,300 712,451,200 737,179,447
- 19,930.9/6 775,701.00'?
9.156,104,347 1971 893.743,427 872,044,335 763,2.4,028 750,790,562 Oc5,257,59R 9,659,106,940 1*?2 1,011.236,*04 895,631,061 849,164,923 954,764,662 914.178,333 10,493,610,613 1973 1,143,s55,451 951,042,532 922,440,740 891,307,200 928,450,0C9 11,295,885,729 1974 1, C 8 0,7 3 5,186 906,780,240 9s
250 921,922,310 972,562,710 11.429,029,141
{
1975
,,233,204,259 973,667,564 996 4 533 950,?29,655 1,044,326,956 12.115,798.520 1976 1,165,000,197 1,050,942,739 1.099,641,434 1,109,879,049 1,180,449,151 13,033,020,638 gg 93 1977 1.262,145,943 1,137,624,532 1,069,!39,515 1,114,344,155 1,103,974,*43 13,934,938,595 EU "O 1978 1,371,023,6:4 1.275,701,167 1,l',5,030,590 1,160,417,499 1,258,202,204 14,550,294,644 19?9 1,445,729,132 1.237,247,840 1,251,293.300 1.241,496,695 1,268,529,717 15.226,362,343 yg gg 1990 1,552,171,047 1,269,505,370 1,209.054,130 1,177,560,519 1,310,764,905 15,524,962,984 CD b1 Fd EdH Fd O
O O
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 SUPPLEMENT 2 SEPTEMBER 1981
(,,)
TABLE 1.1-14 FUTURE GENERATION INSTALLATIONS FROM 1981 TO 1999 FOR MAIN, ILL-MO, IP YEAR MAIN ILL-MO IP 1981 71 81 0
1982 1433 85 0
1983 2509 1670 0
1984 2457 870 760*
1985 1730 0
0 1986 1090 0
0 1987 1977 0
0 1988 (10) 0 0
1989 643 0
0 1990 1095 1150 0
1991 450 O
V 1992 0
1993 450 1994 0
1995 760 1996 0
1997 600 1998 0
2 1999 600
(/
'N' t
- Installed August '983.
Source:
MAIN (1981).
1.1-27
CPS-ER(OLS)
SUPPLEMENT *1 JUNE 1981 TABLE 1.1-15 INSTALLED GENERATING CAPACITY DURING SLAMER_FROM 1970 TO 1999, (All Values in Megawatts)
YEAR MAIN _
ILL-MO"
_ II [
1970 2,199 1971 2,199 1972 2,191 1973 2,796 1974 2,813 1975 3,388 1976 3,412 1977 3,412 1978 3,839 1979 3,839 1980 3,815 1981 41,106 13,468 3,815 1982 42,539 13,553 3,815 1983 45,048 15,223 3,815 1984 47,504 16,093 4,575 1985 49,234 16,093 4,575 1986 50,724 16,093 4,575 lll 1987 52,301 16,093 4,575 1988 53,441 17,243 4,575 1989 54,084 17,243 4,575 1990 54,084 17,243 4,575 1991 5,107c 1992 5,107 1993 5,557 1994 5,557 1995 6,317 1996 6,317 1997 6,917 1998 6,917 1999 7,517
" Source:
MAIN Appendices to Yearly Reports (MAIN 1970-1978, 1981).
Source:
IP Historical and Forecasted System Data.
Does not include IP's share of EEI capability or 20 percent other company ownership cf Clinton - Units 1 and 2.
l c Includes 82 MW increase in system capability due to use
'nter ratings.
O 1.1-28
SUPPLEMENT 1 JUNE 1981 SUPPLEMENT 2 SEPTEMBER 1981 9.000 -
j
/
3.000 -
/
c' /i/p/
j c
7.000 -
0 O
/
/
6.000 -
/
8 6560 n
2 l
p 5.000 -
o 4995
<I O
d 4,000 -
4:10 M
<I
{
3 515 3.000 -
1980 ACTUAL PEAK LOAD F-r M
(D i O 2.000 -
f fi/
1.0 0 0 1970 1975 1980 1985 19'9 0 1995 YEARS c
LEGEND C ) cArc or rope est roaccAst
- - ACTUAL CLINTON POWER STATION LI:ilT S 1 A N D 2 E NV IRO NM E NTAL M6 PORT O PE R AT I NG L.,1C E NSE S T A ti E.
O ricuRE i.i-s ILLIN0IS POWER COMPANY COMPARIS0N 0F RECENT FORECASTS
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981
()
1.3 CONSEQUENCES OF DELAY IP, under existing state and federal laws, has the legal responsibility and obligation to supply electricity to meet the demand in its service area, and must, therefore, plan to satisfy the forecasted demand.
The effects of delays in the commercial operation of Clinton Unit 1 on reserve margins are shown on Table 1.3-1.
The reserve margins of IP, Ill-Mo Pool, and MAIN that result from delays of 1, 2, 3, and 4 years are also shown.
For IP, Table 1.3-1 shows that delays of 1, 2,
3, and 4 years in the commercial operation of Clinton Unit I will reduce IP reserve margins to 9.8% in 1984, 4.4% in 1985, 0.8% in 1986, and 1.4% in 1987.
All reserve margins are reduced below the planned 15%.
Even with a delay of only 1 year, the failure of any one of tre three Baldwin 600 MW units, Havana unit 6, or Wood River Unit 5 will lower IP capacity below peak demand.
Similarly, delays of 1, 2, 3, and 4 years in the commercial operation of Clinton Unit I will reduce Ill-Mo reserve margins to 25.5% in 1984, 19.9% in 1985, 16.2% in 1926, and 15.9% in 1987.
These delays will reduce the MAIN reserve margins to 21.7% in 1984, 22.1% in 1985, 22.8% in 1986, and 23.0% in 1987.
Delays of 1,
2, 3, and 4 years in the commercial operation of
(])
Clinton Unit 2, as shown in Table 1.3-1, will reduce IP reserve margins to 7.8% in 1995, 2.5% in 1996, 8.4% in 1997, and 3.5% in 1998.
These reserve margins are substantially below the planned 17%.
Furthermore, these delays will reduce Ill-Mo Fool and MAIN reserve margins.
In addition to jeopardizir.g reliability, delays in the commercial operation of Clinton Unit 1 and Clinton Unit 2 will increase IP's reliance on oil and other fossil fuels.
Additional burning of these fuels will increase dependence on oil; increase emissions to tea environment; and increase the overall electric energy cost to the customer.
Customer costs will also increase because of the effects of escalation and interest charges for funds used during construction.
Table 1.3-3 shows how the variable production costs change if the Clinton Power Station is delayed or unavailable.
Without U: t t 1, the annual production costs increase by $21.4 million in 19's, o
$96.5 million in 1984, $215.1 million in 1985, $290.8 million in 1986, $294.4 million in 1987, $334.5 million in 1988.
Without Unit 2, the annual production costs increase by $429.2 million in 1995, $527.3 million in 1996, $345.i million in 1997, 5473.4 million in 1998, and $394.0 million in 1999.
Also shown on Table 1.3-3 are the projected annual Clinton Power Station capacity factors.
Table 1.3-4 shows the cost of replacement energy by fuel category (i.e., coal, oil, etc.) on the IP system if Clinton
()3 Power Station is delayed.
Table 1.3-5 shows how the replacement
(
energy was distributed among the other fuel categories.
Tables 1.3-1
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 SUPPLEMENT 2 SEPTEMBER 1981 ggg 1.3-3 through 1.3-5 were developed using a probabilistic production cost computer program.
This program uses a generation model and a load model to determine che expected cost (including fuel and variable O&M) for future years.
The system was modeled with Units 1 and 2 installed in 1983 and 1995, respectively.
Each unit was then delayed five years so that the distribution and cost of the replacement energy could be determined.
The results reflect the operation of 100% of Clinton Power Station (i.e., two 950 MW units).
All costs are in current year dollars.
Tables 1.3-3 through 1.3-5 are based upon an analysis which includes the expected IP load growth.
Tables 1.3 1.3-8 are similar, except that a cero load growth rate was assumed.
The following costs are expected for the first year of operation of Clinton Unit 1 (commercial operation beginning August 31, 1983):
Millions of Dollars Mills /kWh 1
Fixed Charges 371.2 70.3 Fuels /
60.7 11.5 llk C&M 7.6 1.4 TOTAL 439.5 83.2 2/The estimated fuel load date for Unit 1 is January 1983.
The estimated date of criticality is February 1983.
The estimated date of commercial operation is August 1983.
These costs are for Illinois Power's 80% share of the Clinton Unit.
The cost estimates shown are exclusive of nuclear-related 2
liability insurance.
In the event of non-operation of Clinton Unit 1, the following costs would be expected:
llk 1.3-2
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 SUPPLEMENT 2 SEPTEMBER 1981
({}
Costs in Millions of Dollars i984 1985 Replacement Power Cost 77.2 172.1 Interest on Capital 118.0 127.3 Fuel Carrying Charges 6.9 7.5 TOTAL 202.1 306.9 The above costs are for IP's 80% share of the Clinton Unit.
The I
total cost of a delay would be even greater because of costs to the owners of the remaining 20% of the unit.
The installed costs of IP's 80% share of Clinton Unit 1 is estimated to be $1,455,537,000.
This cost includes AFUDC and assumes a commercial operation date of August 31, 1983.
The fuel car ing charges are only for the initial core.
Since a delay could a2so affect subsequent batches of fuel, the total
] ( ')
impact may be much greater than that shown above.
O 1.3-3
CPS-ER ( OLS )
SUPPLEMENT i JUNE 1981 TABLE 1.3-1 O
FUTURE PROJECTED LOAD AND CAPABILITY
SUMMARY
WITIIOUT IP CLINTON - UNIT 1 FOR MAIN, ILL-MO AND IP FROM 1984 TO 1987 YEAR PARAMETER MAIN ILL-MO IP 1984 Adjusted Capability (MW) 46,448 14,823 3,872 Adjusted Demand (MW) 38,160 11,813 3,528 Reserve (MW) 8,288 3,010 344 Reserve (%)
21.7 25.5 9.8 1985 Adjusted Copability (;MW) 47,956 14,580 3,872 Adjusten DLmand (;MW) 39,265 12,161 3,710 Reserve (MW) 8,691 2,419 lb2 Reserve (%)
22.1 19.9 4.4
(, W) 49,615 14,534 3,872 1986 Adjusted Capability M
Adjusted Demand (MW) 40,397 12,513 3,841 Reserve (MW) 9,218 2,021 3 ",
Reserve (%)
22.8 16.2 0.8 1987 Adjusted Capability (MW) 51,194 14,709 3,872 g
Adjusted Demand (MW) 41,637 12,688 3,818 W
Reserve (MW) 9,557 2,021 54 Reserve (3) 23.0 15.9 1.4 Note:
Derived from Table 1.1-10 by removing 760 MW capability from I? system and Ill-Mo and 950 MW (Soyland included) from MAIN.
O 1.3-4 l
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 LIST OF FIGURES (Cont'd)
NUMBER TITLE 2.3 3 Composite February Onsite Wind Rose for 10-Meter Level 2.3-4 Composite March Onsite Wind Rose for 10-Meter Level 2.3-5 Composite April Onsite Wind Rose for 10-Meter Level 2.3-6 Composite May Onsite Wind Rose for 10-Meter Level 2.3-7 Composite June Onsite Wind Rose for 10-Meter Level 2.3-8 Composite July Onsite Wind Rose for 10-Meter Level 2.3-9 Composite August Onsite Wind Rose for 10-Meter Level 2.3-10 Composite September Onsite Wind Rose for 10-Meter Level 2.3-11 Composite October Onsite Wind Rose for 10-Meter Level 2.3-12 Composite Ncvember Onsite Wind Rose for 10-Meter Level 2.3-13 Composite December Onsite Wind Rose for 10-Meter Level 2.3-14 Topographic Map of the Area within 50 Miles of the Clinton Power Station Site 2.3-16 Topographical Cross Section as a Function of the Distance from the Clinton Power Station site 2.4-1 Plant Location Plan
()
2.4-2 Hydrologic Network:
Sangamon River Basin 2.4-3 Peak Flood Magnitudes and Frequencies for Salt Creek at Rowell 2.4-4 Low-Flow Magnitudes and Frequencies for Salt Creek at Rowell 2.4-5 Plan of Lake Showing Bottom Contours 2.4-6 Lake Elevation - Area Capacity Curves 2.4-7 Plan of Main Dam, Spillways, and Outlet Works 2.4-8 Area-Capacity of Submerged Ultimate Heat Sink 2.4-9 Water Surface Profiles:
Salt Creek 2.4-10 Water Surface Profiles:
North Fork 2.4-10A Preconstruction Flood Prone Area 2.4-10B Preconstruction Flood Prone Area and Property Line 2.4-10C Flood Prone Area with Dam in Place 2.4-11 Discharge and Turbidity Frequency Curves:
Salt Creek Near Rowell 2.4-12 Man-Made Lakes Used in Sedimentation Analysis (Numbers 1-6) 2.4-13 Sediment Deposition in Lake Clinton After 50 Years 2.4-14 Lake Area Capacity Curves Before and After 50 Years of Sedimentation 2.4-15 Water Quality Frequency Curves:
Salt Creek Near Rowell 2.4-16 Non-Private Water Wells within 15 Miles of Site 2.4-17 Water Wells within 5 Miles of Site
/~N 2.4-18 Location of Piezometers, CPS Test Well, and Water k/
Table in Site Vicinity 2-xxi
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 LIST OF FIGURES (Cont'd) ggg NUMBER TITLE 2.4-18A Location of Piezometer; in Main Plant Vicinity 2.4-19 Typical Installation Details for OW-Series Piezometers 2.4-20 Water Level Observations:
Station Site 2.4-21 Water Level Observations:
Dam Sites 2 4-22 Water Level Observations:
Borings E-1B to E-7 2.4-23 Ground-Water Levels and Daily Precipitation 2.4-24 Ground-Water Levels and Daily Precipitation 2.4-25 Ground-Water ' 7vels and Daily Precipitation 2,4-26 Ground-Water Levels and Daily Precipitation l
2.4-27 Ground-Water Levels and Daily Precipitation 2.5-1 Site Stratigraphic Column 2.5-2 Conparison of Terminology Used for the CPS-ER, PSAR and boring Logs 2.5-3 Agricultural Soil Associations 2.7-1 Noise Monitoring Locations 2.7-2 Noise Levels - Location 1 Daytime without Construction 2.7-3 Noise Levels - Location 1 Daytime with Construction 2.7-4 Noise Levels - L~ at ion 1 Nighti.ime without Construction 2.7-5 Noise Levels - Location 2 Daytime without Construction llh 2.7-6 Noise Levels - Location 2 Daytime with Construction 2.7-7 Noise Levels - Location 2 Nighttime without Construction 2.7-8 Noise Levels - Location 3 Daytime without Construction 2.7-9 Noise Levels - Location 3 Daytime with Construction 2.7-10 Noise Levels - Location 3 Nighttime without Construction 2.7-11 Noise Levels - Location 4 Daytime without Construction 2.7-12 Noise Levels - Location 4 Daytime with Construction 2.7-13 Noise Levels - Location 4 Nighttime without Construction 2.7-14 Noise Levels - Location 5 Daytime without Construction 2.7-15 Noise Levels - Location 5 Daytime with Construction 2.7-16 Noise Levels - Location 5 Nighttime without l
Construction l
2.7-17 Noice Levels - Location 6 Daytime without
(
Construction 2.7-18 Noise Levels - Location 6 Daytime with Construction 2.7-19 Noise Levels - Location 6 Nighttime without Construction 2.7-20 Noise Levels - Location 7 Daytime without Construction ggg 2-xxii
-CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 The nearest industry is located in the Clinton Industrial Park,
(])
about 6 miles west of.the plant.
The industries located in this park have approximately 125 employees.
Most of these employees reside locally and are not considered transients.
Discussions with the administration offices of local schools indicate that most of the staff and students reside locally and thus are considered as permanent population (Nernuh 1977, and Administration Center of Wapella'C.U. School District 1977).
Besides the schools, the only other public facilities are the John Warner Hospital, with a 52-bed capacity and a staff of 119, and three nursing homes.
All four facilities are located in Clinton.
The nursing homes are Crestview Nursing ifome, with 95 residents and 65 staff; DeWitt County nursing home; with 72 residents and 41 staff; and the DeWitt County Mental Health Center, with 10 to 50 catpatients per day and a staff of 15.
The only rer sational facility within 5 miles of the station is Lake Clintt Figure 2.1-15 shows the recreational development of the lake, and Table 2.1-5 lists the planned recreational facilities.
Lake Clinton, which is managed by the Illinois Department of Conservation, was opened to the public on August 22, 1979, for boating, fishing, and water skiing.
The estimated number of users on opening day was 10,300, and the lake has averaged 1,000 C3 users per weekday and 5,000 to 6,000 users per weekend day.
The recreational facilities will be used year round, since snow-mobiling is offered in addition to boating, fishing, water skiing, picniching, camping, hiking, and hunting.
2.1. 3 Uses of Adjacent Lands and Waters The Clinton Power Station site occupies approximately 14,092 acres of land and water and is approximately 6 miles east of Clinton, Illinois, in DeWitt County.
The station property lines and exclusion area boundary are discussed in Subsection 2.1.1.2 and shown in Figurcs 2.1-5 and 2.1-6.
The distances from the con. mon station HVAC vent to the nearest site boundary, for each of the 16 sectors, are given in Table 2.1-6.
The site boundary nearest to the common station HVAC vent is directly east, at a distance of 3,800 feet.
2.1.3.1 Land Use 2.1.3.1.1 Land Use within 5 Miles As shown in Figure 2.1-16, the area within a 5-mile radius of the station along with the remainder of DeWitt Ccunty is predominantly agricultural.
According to the U.S. Department of j
Commerce (1974) farm statistics, approximately 95.2% of DeWitt County is farmland.
In addition, approximately 80.0% of the total county land was under cultivation in 1974 (see T-ble s
2.1-7).
1 I
2.1-7
CPF-ER(OLS)
The major crops in DeWitt County are corn and soybeans.
- Wheat, llI oats, and hay are also grown in the area.
Table 2.1-8 gives the 1975 and 1976 acreage, yield, and production of these crops for DeWitt County and for the state of Illinois.
In general, DeWitt County was more productive in 1975 than the state average, with the exception of hay yield, which was slightly less than the
- r. tate avarego.
The number of acres devoted to corn and wheat in Debitt County increased between 1975 and 1976, while the number of acres devoted to soybeans, oats, and hay decreased.
The major livestock raised in DeWitt County are cattle and hogs (Illinois Cooperr cive Crop Reporting Service 1977).
Table 2.1-9 lists the numbe' of head of livestock in the county for 1975 and 1976.
There
-r<
ao milk cows or milk goats within 5 miles of the station.
The area within 5 miles of the station is not industrialized.
The nearest industries are located in Clinton, Illinois, approximately 6 miles west of the station.
Table 2.1-10 lists all industries within 10 miles of the site along with their products and approximate number of employees.
There are only two communities within 5 miles of the station.
Table 2.1-11 lists the nearest residence and garden in each of 16 directions from the site.
Since most nearby residences are farms, it was assumed that the nearest garden in each direction 3
was the same as the nearest residence.
The nearest residence and W
garden are located approximately 0.7 mile northwest of the station.
There are no schools within 5 miles of the station.
The nearest school is located in Weldon, approximate 1.y 5. 3 mil es east-southeast of the station.
Table 2.1-12 lists all schools within 10 miles of the station along with their location and number of students and staff.
There are no hospitals with'n 5 miles of the station.
The neare.t. hospital is located in Clinton, Illinois, approximately 6 miles west of the station.
The major transportation routes within 5 miles of the Clinton Poaer Station include the highways and railroads shown in Figure
?.1-17.
The nearest highways to the station are Illinois State Routes 54, 10, and 48.
Illinois State acute 54 traverses Illinois Power's property approximately 1 mile north of the power station.
Illinois Sta te Route 10 is adjacent to the station's southern boundary, and Illinois State Route 48 is approximately 4.5 miles east of the station and also traverses the site property.
Figure 2.1-17 shows these highways and their 1978 traffic volumes.
State Routes 10 and 54 are moderately well traveled, averaging approximately 1,750 to 2,900 cars per day within 5 miles of the station.
State Route 48 is less traveled, having a 24-hour annual average of 750 cars within 5 miles of the statitn.
U.S.
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CPS-ER(OLS) b]PPLEMENT I JUNE 1981 SUPPLEMENT 2 SEPTEMBER 1981 O
highway bridges, a marina, and seven boat ramps.
Again, there were no feasible locations for these structures outside of the flood prone a: na.
Construction of these structures is complete, and their presence will not cause any alteration in flood levels 1
that would extend beyond the site property lines.
There will be no effect on downstream facilities of debris generated from the site during floods.
2.4.1.4.4 Effects of Droucht A design drought with a recurrence interval of 100 years was used in the determination of minimum water level in the cooling lake.
The once-in-100-year drought runoff data with a duration up to 60 months are given in Table 2.4-8.
Net lake evaporation values for a 100-year recurrence interval are given in Table 2.4-9.
The average monthly forced evaporation data are given in Table 2
2.4-10.
Lake drawdown analyses were made starting at a normal pool elevation of 690 feet, using a minimum reservoir release of 5 cubic feet per second and assuming a seepage loss of 0.5% of the lake capacity per month.
The minimum water level obtained for the once-in-100-year drought is elevation 681.1 feet based on 2
forced evaporation data and load factors given in Table 2.4-10.
(])
The plant will be able to withstand the effect of the once-in-100-year drought without interruption of normal operations.
Similtrly, the effect of the historic drought on the lake was analyzed using precipitation and evaporation values obtained from the U.S. Department of Commerce (U.S. Department of Commerce 1943-1977).
The water level in the lake for a historic drought condition is elevation 684.1 feet.
In the event of a drought more severe than the once-in-100-year drought that will lower the lake level to elevation 677 feet, the ultimate heat sink will supply water for the emergency core cooling system.
2.4.1.4.5 Lake Sedimentation i
Studies were made on sediment distribution and deposition in the lake to determine the effect on the lake capacity, depth, and shoreline area.
On Salt Creek near Rowell, an average turbidity of 16 parts per million and a discharge of 0.35 cubic feet per second per square mile were observed from 1950 to 1956 (see l
O 2.4-8a
CPS-ER(OLS)
Public water supplies in the regional area are derived exclusively from groundwater sources.
Approximately 65 percent
(_/c) of tre total public groundwater supply is pumped from ths Mahomet Sand.
Except for the alluvial wells at Heyworth, the remaining public water supplies are pumped from wells in the Wisconsinan, Illinoian, and Kansan glacial deposits.
Bedrock aquifers are not used in any public water supply system.
There are at least 137 private wells for domestic use and for livestock watering within 5 miles of the site (see Figure 2.4-17 and Table 2.4-21) and 36 known active and inactive wells on the station property.
Production exceeds 10 gallons per minute in only a few cases.
With all the recorded wells operating and pumping continuously, the estimated total pumpage capacity on the station property is 600 gallons per minute.
However, pumpage in these small domestic wells is intermittent, and the total daily production, computed on a 24-hour continuous basis, is probably less than 300 gallons per minute.
Most wells are less than 150 feet deep and produce from sand lenses in the upper glacial tills rather than from the deeper Mahomet Bedrock Valley aquifer.
With the exception of wells used by tenant farmers or for monitoring, private wells on the site property were abandoned and sealed in accordance with applicable state requirements during plant construction.
2.4.2.3 Site Hydrogeologic Conditions
(~/;
2.4.2.3.1 Ultimate Heat Sink Area
\\v At the ultimate heat sink area, fine-grained floodplain deposits (Henry Formation) overlie coarse-grained glacial outwash, which in turn overlies Illinoian till.
Floodplain deposits include up to 23 feet (9 feet average) of silt with fine sand and clay.
Sand and gravel characterize the glacial outwash deposite which also contain variable amounts of silt and clay.
Although no laboratory or field permeability tests were performed on the outwash material, the coefficient of permeability can be estimated from grain-size analyses to be roughly 10-8 cm/sec to 10-2 cm/sec.
Outwash deposits average about 9 feet thick and are thickest (about 41 feet) over an apparent terrace on the north side of the heat sink.
The outwash deposits are continuous in the foundation excavation for the heat sink dam.
2.4.2.3.2 Power Block Area The glacial drift thickness at the station power block area ranges from approximately 230 feet to 250 feet and averages 237 feet.
Several geologic units are exposed in the power block excavation:
the Wisconsinan-age Richland Loess, Wedron Formation, and Robein Silt, and the Illinoian-age Glasford Formation.
Lacustrine deposits and Kansan-age till were encountered in deep borings below the level of the power block excavation.
7,V 2.4-15
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 Several discontinuous sand lenses, ranging in thickness from several inches to 22 feet, occur between elevations 650 and 730 feet MSL.
Some of these sand lenses were penetrated by the power block excavation which has a floor elevation of 680 feet MSL.
Some sand lenses occur near the weathered-unweathered Glasford Formation Contact.
Only one nearly continuous sand layer occurs near the power block.
In the Wedron Formation a 2-to 16-foot layer of fine sand slopes from elevation 723 feet at the western limit of the excavation to clevation 716 feet on the slope above the cooling lake.
2.4.2.3.3 Groundwater Levels The water table ir the vicinity of the station occurs as a ridge-like mound in the kisconsinan till between Salt Creek and the North Fork of Salt Creek (see Figure 2.4-18).
The position of the groundwater ridge marks a recharge area from which groundwater flows to the southeast toward Salt Creek and to the northwest, across the station site, toward the North Fork of Salt Creek.
The magnitude of the hydraulic gradient at the station site is approximately 0.086, or 454 ft/mi.
This value is based upon a maximum head loss of 55 feet over a minimum distance of 640 feet from the station site to the floodplain of the North ll)
Fork of Salt Creek.
Prior to impoundment of the cooling lake, the North Fork of Salt Creek served as the local base level for groundwater flow from the station arec to the floodplain.
Impoundment of the cooling lake has raised the base level to elevation 690 feet MSL, causing the groundwater-surface water interface to shift to the southeast toward the station; Assuming no change in the height of the water table at the station, establishment of a new base level higher and closer to the station will eventually result in a decrease in the hydraulic gradient to about 0.068, or 359 ft/mi.
In the station area, piezometers were installed in the Wisconsinan, Illinoian, and Kansan deposits.
Some of the piezometers are no longar functional, having been dccLroyed by construction activities.
A summary of the installation dates, tested intervals, and status of all piezometers is presented in Table 2.4-22 and FSAR Table 2.4-31.
Locations of piezometers other than the P-series (main plant) and OW-9 through OW-24 (below dam) are shown on Figure 2.4-18; locations of piezometers installed in P-series borings are shown on Figure 2.5-16 of the FSAR; locations of OW-9 through OW-24 are shown on Figure 2.4-1CA.
Installation details for the l
piezometers installed during the PSAR-stage investigation are given on their respective boring logs.
A typical OW-series a
piezometer is shown on Figure 2.4-19.
Groundwater levels W
l measured in the piezometers are shown on Figures 2.4-20 through 2.4-16
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981
()
2.4-27 Groundwater levels are listed in Table 2.4-23 for those piezometers not included on these figures.
A discussion of the piezometers and groundwater levels is provided in Subsection 2.4.13.2.3 of the FSAP..
Groundwater levels in the Wisconsinan till were as high as 729 feet MSL, the highest in the plant area.
In the seven piezameters installed in Illinoita deposits: groundwater levels range..
n elevation from 675 to 717 feet MSL.
In the two 4
piezotsters installed in Kansan deposits, the potentiometric level coincided with the base of the main station excavation at elevation 680 feet MSL.
Despite the high groundwater levels, seepage into the excavation was minor and was controlled by a system of drainage ditches and sumps.
The low volume of seepage was due to the low overall permeability of the tills and the limited size of the discontinuous sand layers and lenses within the tills.
The head relationships between the Wisconsinan, Illinoian, and Kansan aquifers indicate that the glacial drift aquifers are recharged by vertical seepage from the overlying drift under a net downward hydraulic gradient.
2.4.2.3.4 Permeability Laboratory falling-head and conctant-head permeability tests were performed on representative samples of Salt Creek alluvium and
(])
the Illinoian and Wisconsinan deposits.
The results of these tests are summarized in Tables 2.4-24 and 2.4-25.
Average coefficient of vertical permeability values of t he Illinoign till at the dam site range from 3.8x10 5 cm/sec to 1.0x10-cm/sec.
At the station site, average coefficient of vertical permeability values of the Illinoian till range from 9.5x10-8 cm/see to 2.3x10 7 cm/sec.
Soil from the interglacial zone at the dam site has an average vertical permeability of 2.1x10 3 cm/sec, ranging from 1.8x10 " cm/sec to 4.7x10-8 cm/sec.
A sample of fine-grained deposits from the Henry Formation (Salt Creek Alluvium) near the dam site has a vertical coefficient of permeability of 1.8x10-e cm/sec.
Field permeability tests were conducted on Illinoian and Wisconsinan till.
Average coefficient of horizontal permeability values obtained from field tests were consistently higher than values obtained from laboratory tests.
The average coefficient of horizontal permeability of Illinoian till ranges from 1.4x10-5 cm/sec to 6.1x10-5 cm/sec.
The results of these tests are summarized in Table 2.4-26.
()
2.4-17 e-n-
--,---n.
w-
CPS-ER(OLS)
TABLE 2.4-1 qgg DRAINAGE CHARACTERISTICS OF SALT CREEK AND ITS TRIBUTARIES AVERAGE DRAINAGE MAXIMUM ANNUAL" LENGTH AREA RELIEF RUNOFF C REEK (mi)
(sq mi)
(ft)
(in)
North Fork 26 128 270 9.73 Lake Fork 40 280 210 8.88 Kickapoo Creek 55 330 380 8.91 Sugar Creek 55 480 380 8.63 Salt Creek 92 1860 440 9.17
^O aDerived from U.S.
Geological Survey 1962-1977.
2.4-18
. -_ ~-..-. _.... -.. _ _ _
CPS-ER(OLS)
SUPPLEMENT 2
~
SEPTEMBER 1981 TABLE 2.4-10 i
CALCULATED AVERAGE MONTHLY FORCED LAKE EVAPORATION DATA LOAD "ORCED FACTOR EVAVOPATION MONTH
(%)
(cfs)
January 80 20.4 February 70 15.6 March 70 18.2 April 70 16.1 I
May 70 21.8 i
June 92 33.4 July 92 44.8 August 92 53.2 O
Segeember 80 41.2 October 70 37.1 November 70 26.9 s
December 80 20.3 4
i r-O 2.4-27 4
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TABLE 2.4-11
SUMMARY
OF CAPACITIES AND DEPTHS AT LAKE CLINTON BEFORE AND AFTER DEPOSITION OF SEDIMENT SALT CREEK NORTil FORK CREEK LAKE CLINTON REDUCTION ORIGINAL S EDItiENT AVAIIABLE ORIGINAL SEDIITNT AVAIIABLE ORIGINAL SEDIMENT AVAIIABLE IN DEPTH INTERVAL r \\PACITY VOLUME CAPACITY CAPACITY VOT.UME CAPACITY CAPACITY VOLUME CAPACITY AT THE DAM (yrs)
Jacre-ft) (acre-ft)
(acre-f t) (acre-f t) (acre-ft) (acre-ft) (acre-ft) (acre-ft) (acre-ft)
(ft.)
10 Years
- 9,360 840 58,520 14,840 640 14,200 74,'!00 1,480 72,720 7. 26 20 Years Sv,360 l',680 57,680 14,840 1,290 13,500 74,200 2,970 71,230 7.8i 30 Years 59,360 2,520 56,a40 14,840 1,930 12,910 74,200 4,45i 69,750 8.2 40 Years 59,360 3,7,50 56,000 14,840 2,57 0 12,270 74,200 5,930 68,270 9.0 h
w 50 Yeart 59,360 4,500 55,160 14,840 3,410 11,430 74,200 7,610 66,590 9.4 s
3 9
O O
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SEPTEMBER 1981
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690 FOOT E-2 CONTOUR S
IMILE 22 23 COOLING
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O EXISTIN9 PtEZOMETER PIEZOMETER Dt'STROYFD BY CONSTRUCTION g ACTIVITIES CLINTON POWER STATION
' ^ "
NOTES E NV IRO NM E NTAL R E PORT-OPE HATING l.lC E NSE STAGE I. PIEZOMETRIC INSTALL ATION OATA p
ARE GIVEN IN TABLE 2.4-22.
d
- 2. GROUND WATER LEVELS ARE SHOWN FIGURE 2.4-18A ON FIGURES 2.4-20 THROUGH 2.4-27 AND IN TABLE 2.4-23.
LOCATIONS OF PIEZ0 METERS IN f1AIN PLANT VICIflITY
CPS-ER (OLS )
SUPPLEMENT 2 SEPTEMBER 1981 CLINTON POWER STATION - UNITS 1 AND 2
(']
v ENVIRONMENTAL REPORT - OPERATING LICENSE STAGE GENERAL TABLE OF CONTENTS e
VOLUME CHAPTER TITLE 1
Purpose of the Proposed Facility and Associated Transmission 1
2 The Site and Environmental Interfaces 1
3 The Station 2
4 Environmental Effects of Site Prepara-tion, Station Construction, and Trans-mission Facilitics Construction 2
5 Environmental Effects of Station Operation 2
6 Effluent and Environmental Measurements and Monitoring Programs 2
~s
-Q 7
Environmental Effects of Accidents 2
8 Economic and Social Effects of Station Construction and Operation 2
9 Alternative Energy Sources and Sites 2
10 Station Design Alternatives 2
11 Summary Cost-Benefit Analysis 2
12 Environmental Approvals and Consulta-tion 2
13 References 2
1 Supplement 1 2
Supplement 2 2
O
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 CHAPTER 3 - THE STATION LIST OF FIGURES s
NUMBER TITLE 3.1-1 Architectural Rendering 3.1-2 X, Y Coordinates of Liquid and Gaseous Release Points 3.2-1 Simplified Boiling Water Reactor Flow Diagram 3.2-2 Net Plant Heat Rate as a Function of Exhaust Pressure 3.3-1 Water Usage Flow Diagram 3.4-1 Diagram of Heat Dissipation System 3.4-2 Anticipated Monthly Distribution of Plant Load 3.4-3 Location of Intake Structure 3.4-4 Location of Intake Structure (Screenhouse) 3.4-5 circulating Water Screenhouse General Arrangement 3.4-6 Calculated Water Velocities Within Screenhouse for Normal and Low Water Levels 3.4-7 Discharge Flume l
3.4-8 Diagram of Discharge Structure 3.4-9 System Layout for Spray Modules in Discharge Canal 3.4-10 Canal Discharge Temperature to Lake Clinton Units 1 & 2, 92% Plant Load Factor, 1964 Summer Months,
(])
232 Spray Modules in Discharge Canal 3.4-11 Canal Discharge Temperature to Lake Clinton Units 1 & 2, 92% Plant Load Factor, 1962 Summer Months, 232 Spray Modules in Discharge Canal 3.5-1 Liquid Radwaste System Simplified Flow Diagram 3.5-2 Gaseous Radwaste System Simplified Flow Diagram 3.5-3 Station Roof Plan i
3.5-4 Solid Radwaste System Simplified Flow Diagram 3.6-1 Flow Diagram for Wastewater Treatment System 3.6-2 Flow Diagram of Wastewater Effluent Treatment Facility for One Unit Only 3.9-1 Proposed Transnission Line Routes (I. F-G and H) and Field Intensity Check Points (1 through 5) 3.9-2 Radio Influence Voltage for 345 kV Unshielded Insulator - Hardware Assemblies 3.9-3 Type HV-IB 345 kV Tangent Structure l
3.9-4 Type HV-2B 345 kV Angle Structure 3.9-5 Type HV-3B 345 kV Angle Structure 3.9-6 Type HV-4B 345 kV Angle Structure 3.9-7 Type HV-5B 345 kV Angle Structure 3.9-8 Type HV-6B 345 kV Angle Structure 3.9-9 345 kV Double Circuit Tangent Structure Clinton Power Station to Line 4571 3.9-10 345-kV Double Circuit Light Guyed Angle Structure Clinton Power Station to Line 4571 0
3-v
CPS-ER(OLS)
CHAPTER 3 - THE STATION ggg LIST OF FIGURES (Cont'd.)
NUMBER TITLE 3.9-11 345 kV Double Circuit Light Unguyed Angle Structure Clinton Power Station to Line 4571 3.9-12 345 kV Double Circuit Medium Guyed Angle Structure Clinton Power Station to Line 4571 3.9-13 345 kV Double Circuit Tap Structure in Line 4571 Clinton Power Station to Line 4571 3.9-14 345 kV Double Circuit Tangent Structure Line 4571 to Oreana Substation 3.9-15 345 kV Double Circuit Light Angle Structure Line 4571 to Oreana Substation 3.9-16A 345 kV Single Circuit Tangent Deed End Structure Clinton Power Station to Line l,571 3.9-16B 345 kV Single Circuit Tangent Dead End Structure Clinien Power Station to Line 4571 3.9-17 345 kV Single Circuit Guyed Dead End Structure Line 4571 to Oreana Substation
-g 3-vi
W" Q
StORw DRAINS 9
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DISC H A R GE TO SALT CREER (2250 GPM. MIN a il di j(
20.160 G PD 47,520,000 GPD h
EHutDOWN IF WIS C S E R vlC E DR AIN S AND O
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qr PRE TRE A T WE N T S E W A G F.
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g sySTEu SYSTEM DE uiNE R A L ilE F 216,000 G PD
.6 II 1r CIRC UL A TING WATER CONDE NS A 7E SYSTEM IC ONDE NSE N) gyggggg 2 31.600 G P D 1r f ueElkt GINf 8 A TOR 4L LOW CRu0 f A N et CONDE NS A TE l
CHE ulC A L afACTOs WAS E TANK POttSHE R l
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(
SEPTEMBER 1981 Mant-up FRou (AKE C11NION SALT CRIER 84895 ACREI AND NOR TH FORM Of Salt Celt s &
dl C ML ORIN a tsON Sit P A GE $
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e SEDeutNT A YsON eACmwASM WAStt r
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NOTE-
- 1. FLOWS INDIC A TED ARE FOR 1 t' NIT OPE R A TIO N ONL Y.
- 2. 4 FLOW R ATE S ARE V ARIABLE.
CLINTON POWER STATION
(
UNITS 1 AND 2 l
r uv enonut stat. ac ront.ogr narino t.mr war : act FIGURE 3.3-1 I
WATER USAGE FLOW r)lAGRAM 1
l 1
=
CPS-ER(OLS)
O TABLE 3.6-4 SLUDGE RATE ENTERING SETTLING POND i
1 l
LB/ DAY CONETITUENT i
5664
- 1. CACO Sludge 3
233
- 2. Mg (OH) 2 Sludge 1200
- 3. TSG Removed from Raw Water 28
- 4. Al (OH)3 Sludge 237 1
- 5. Inerts from Lime 7362 TOTAL
}
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1 f
,V.
Figures reflect pretreatment flow rate design capacity Note of 500 gpm, once a day backwashing of sand filters i
and carbon purifiers, and an average regeneration of one primary demineralizer train per day.
r O
3.6-9
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TABLE 3.6-5 ESTIMATED COMPOSJ,. TION OF WASTE STREAM LEAVING THE SETTLING POND AND APPLICABLE LIMITATIONS NPDES EFFLiiETi STATE EFFLUENT LIMITATIONS LIMITATIONS St.4TE WAITR CCAL. LIMIT PARAMETER SETTLING PCMD EFFLLT*:T (Prrn)
(rpm) f rrm)
Flow (gal / day) 92,423 9al Calcium (as Ca) 162 ppm Phosphorus (as P) 1.0 1.0 0,05" C
Magnesium (as Mg) 182 ppm Sodium (as Na) 457 ppm (as CACO )3) 30fi ppm M.0. Alkalinity (as CACO 10 ppm Q
P. Alkalinity 3
Chloride (as Cl) 300 pp::
500 W
Sulfate (as 50 )
1,564 ppm 500 u) 4 h
Nitrate (as N) 27 10 (Drinking Water ty)
I pp.,
)
Silica (r.s Sio2) 36 ppm
]
H TSS 20 to Sob ppm 15 Maximum 15 m
C BOD-5 4 Average 30 0
TDS 2,800 ppm 3500; A750 1,000
{
pH 7-8 6-9 5-10 6.5-9.0 except for Natural causes Oil and Crease 15 rpm 15 Maximum 75 Maximum None Visible 30 Daily Average 15 Monthly Average Iron, Total (as Fe) 1.0 2.0 1.0 Copper, Total (as Cu) 1.0 1.0 0.02 Zinc. Total (as Zn) 1.0 1.0 1.0 Note: Values are for one-unit operation; concentrations will not change with two-unit operation.
- Figures reflect pretreatment flow rate at design capacity of 500 gptc. cnce a day backwashing of sand filters and carbon purifiers, and U1 U1 an average regeneration of one prinary dumineralizer train per day.
M@
y L
dT Approximated values, since no data are available to permit calculation of these values. Settling pond effluent will be routed to a MM waste filter house fr.r further reduction of TSS to ensure compliance with applicable liritations.
MM cWater quality limit in lakes and streams at point of entry into lakes: effluent limitations on 1erge discharge to lakes and tributarles WZ thereto.
d g
ou CD H
h O
O O
SUPPLEMENT 2 SEPTEMBER 1981 LWE DEMINER ALIZER PIPE CARBON FILTER SOFTENER PUR!FIER REGENERANT FLUSHING BACNWASH SLUDGE BACKWASH WATER ACTIVITY BLOWDOWN l
M Ap. AND AVG.
MAX. AND AVG.
MAX. FLOW MAX. FLOW FLOW 7 0.055 MGD FLOW 0.02 uGD 0.03 MGD 7 0.08 MGD AVG. FLOW AVG. FLOW 7 0.025 MGD
~ 0.03 MGD If lf if if l
5 i
^
LAXZ WATER SAMPLING POINT LAKE RECYCLE MANHOLE CLINTON FILTER (IFpH DOES NOT TREATMENT MEET EFFLUENT HOUSE STANDA7D OF 37 6 TO 9 )
MAX. FLOW Y 3.143 MGD
( pH AND.
g IF NEEDED.
COAGULANT )
AVG. FLOW 2 0.05 MGD FOR q
11/2 YEARS. ZERO THEREAFTER (AVG. FLOW = 0.7 MG PER CLEANING. EACH CONSISTING OF SEVERAL BATCHES. THERE POND WILL BE AN ESTIMATED 40 SUCh CLEANINGS OVER APPROXIMATELY 11/2 YEARS )
i l
> OISCHARGE CANAL g
OVERFLOW PCND EMERGENCY CLINTON POWER STATION OVERFLOW UNITS 1 AND 2 (FLOW =0)
E NV IRONM E NTAL RE PORT =O PE R AT ING LICE NSE STAGE i
EFFLUENT l
' S A MPLING FIGURE 3.6-2 V
PolNT J
FLOW DIAGRAM 0F WASTEWATER EFFLUEf1T TREATf1EtiT FACILITY f
FOR ONE UNIT ONLY s
.4
..n
CPS-ER(OLS) consultant for enumeration and identification.
It is anti-(~)
cipated that IP personnel will perform these functions in V
the near future.
6.1.1.2.5 Fisheries Fish were collected quarterly at Locations 1, 2, 3, 4, 5, and 7 beginning in May 1974.
The dam was closed in October 1977; Location 2 was flooded and part of the lake during the November 1977 sampling.
Locations 2 and 4 were part of the lake during the April 1978 sampling, and the laka reached nor-mal pool in mid-May 1978.
Methods of sampling were adapted to the site conditions at the time of campling.
Sampling for fish at each location was accomplished by the use of one or more of the following meth-ods:
seining, gill netting, winged hoop netting, and electro-shocking.
Two to four seine hauls were made using a minnow seine 25 feet long and 6 feet deep, with 0.25-inch ace mesh net.
The hoop nets used were 2.5 and 3 feet in diameter, with two 6-foot leads and made up of 1 inch square mesh.
A boat-mounted boom shocker powered by a 230 volt a-c three-phase generator wam used for electroshocking.
The gill nets were 150 feet long and 6 feet deep, with six 25-foot panels of
- 0. 5, 1, 1. 5, 2, 2. 5, and 3-inch bar mesh.
Fish that were collected were identified in the field whenever s
!_)
possible.
Others were preserved in formalin and returned to s
the laboratory, where they were identified using various taxonomic keys (Becker and Johnson 1970; dubbs and Lagler 1970; Smith 1972; Eddy 1974; Pflieger 1975) and assigned scientific and common names in accordance with Baily (1970).
All indi-viduals were identified to species, and their total length was measured.
In addition, sport and commercial fish were individually weighed.
The relative abundance and size distri-bution of species were recorded.
The species composition and relative abundance of species for each sampling date and loca-tion were determined.
Stomach samples were taken from selected game fish to provide information on food habits.
The relative importance of food items found in fish stomachs was estimated by reporting empir-ical numbers of food items in the stomach, percentage of occurrence, volume in milliliters, and percentage of total volume.
Beginning in the summer of 1978, IP personnel conducted the
~
, quarterly fish sampling at Locations 1, 2, 4, 4.5, 5, 7, 8, 16, and 17.
The two stream locations (1 and 7) are sampled with winged hoop nets or trap nets set for about 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and with 1
seine hauls from pool and riffle habitats.
The seven lake locatiens are sampled by electroffshing for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> (four 15-ndnute Deviods), using winged hoop nets or trap nets set for
-()
- about 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, and using experimental gill nets 1'
6.1-9
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981
!.11 individuals are identified to species and total lengths taken.
Weights are obtained for all sport and commercial ll!
species.
Stomach samples are taken from representative game species from two different areas of the lake.
These stomachs are examined for the type and number of forage organisms present.
Scale samples are taken annually from representative sport fish.
Edible portions of selected game fish are analyzed for pesticides and heavy metal.
6.1.1.2.6 Summary of Dreoperational Munitoring Program Table 6.1-7 presents a surmary of the preoperational ecological and water chemistry monitoring program schedule from May 1974 through December 1980.
This summary schedule includes the terrestrial monitoring described in Subsection 6.1.4.3.
6.1.2 Groundwater 6.1.2.1 Physical and Chemical _ Parameters The groundwater study performed on the site area and sur-rounding 1egion was described in the CPS-ER and that de-scription is not repeated here.
Since the CPS-ER has been submitted, two additional areas have been investigated.
a.
We1.1 testing was conducted to adequately document that the Mahomet Aquifer could yield the 500 gpm required for station operation without adversely affecting the aquifer or c cher users.
This issue has now become moot since lake water will be used as the source of potable plant water.
This switch in sources was nade because of the concern of possible methane build-up in water storage tanks if water from the aquifer was used.
b.
Semiannual monitoring of four farm wells and wells in or near four communities peripheral to the lake was begun in February 1978.
The monitoring was performed to determine whether Lake Clinton water was affecting regional groundwater quality, i.e.,
intruding into groundwater supplice.
The following wells are being sampled:
1.
private residence / farm (Weldon), Section 6 Township 19N Range 4 East; 2.
tenant farm (R.
R.
2, Farmer City), Section 14 Township 20N Range 4 East (this land is owned by IP);
O 6.1-10
.~
PS-ER(OLS)-
C
.( )
This proposed change has.the following rationale:
a.
The terrestrial monitoring program was designed to assess the impacts of constructing the plant and associated facilities.
The major impacts that'-
uere expected on the terrestrial environment had to do with lake bed clearing and clearing and grad-ing of the power block area.
The impacts on adj a-cent land have been in ignificant, and the major activities that would.be expected to cause these impacts are now complete.
Thus, it is felt that terrestrial monitoring can now be ended since continued monitoring would be of questionable value.
6.1.6.8 Summary of noniporing,Pgggram With Proposed Changes The following subsections present a sumuary of the preopera-i tional monitoring program as it-would be conducted with the proposed changes given in 6.1.6.1 through 6.1.6.7.
6.1.6.8.1 Water Chemistry a.
Monthly samples shall be taken at the following
~
locatibas:
1, 2, 3, 4, 5, 6, 7, 8, 9, and 16.
b.
Each month a different station shall be sampled in duplicate for all parameters, c.
Analyses shall be performed for the following para-
~
meters:
Dissolved Oxygen
' Fecal Coliform Oxygen Saturation Fecal Streptococci Biochemical Oxygen Demand Specific Conductance i
pH Ammonia Total Dissolved Solids Nitrate Total Susoended Solids Total Organic Nitrogen Turbidity Total Organic Carbon j
Total Alkalinity Total Phosphorus Soluble Orthophosphate Soluble Silica Copper Lead.
j d.
When thermostratification occurs at Locations 2, 4, 8, and 16, each layer (epilimnion, metalimnior., and hypolimnion) shall be sampled and treated as a sepa-rate location.
I f) e.
Vertical profiles at 1 meter intervals shall be per-formed at Locations 2, 4, 8, and 16 for dissolved oxy-(_ '
gen, temperature, pH, and conductivity.
6.1-2)
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1931 f.
Chlorine analysis shall be performed at the time of collection at the following locations:
lll 1) preoperation phase at Location 3, and 2) operational p'.ase at Locations 2, 8, and 4.
g.
Additional temperature profiles anall be taken monthly at 1-meter intervals at Locations 12, 13, 14, and 15.
l 6.1.6.8.2 Periphyton a.
Quarterly samples shall be taken from a given area of natural substrate at Locations 1 and 7.
b.
Analysis of the sample shall be for chlorophyll a and density of diatoms and non-diatoms.
6.1.6.8.3 Benthos a.
Quarterly samples shall be taken with a ponar dredge from Locations 1, 2, 4, 13, 16, and 7.
1)
At lake locations (2, 4, 13, and 16) two replicate dredge samples shall be collected per station.
g 2)
At stream locations (1 and 7), tuo samples shall be collected per station, one representa-tive of a pool area arl one representative of a riffle area.
b.
Analysis of the sample shall be for identification and density of those organisms retained by a 30 meth screen.
6.1.6.8.4
[nytoplankton a.
Quarterly samples shall se collected from Locations 1, 2, 3, 4, 4.5, 5, 7, 8, and 16.
b.
Analysis shall be for density, identification, and chlorophyll a.
O 6.1-30
SUPPLEMENT 1 CPS-ER(OLS)
JUNE 1981 SUPPLEMENT 2 SEPTEMBER 1981 e
CHAPTFR 8 - ECONOMIC AND SOCIAL EFFFCTS OF km)
STATION CONSTRUCTION AND OPERATION Most information on the economic and social effects'of station construction and operation is included in Chapter 8 of the Clinton Power Station - Units 1 and 2:
Environmental Report -
Construction Permit Stage (CPS-ER). and in. Sections 4.4 and 5.6 of the Clinton Final Environmental Statement (FES) published by the U.S.
Atomic Energy Commission in October 1974.
Only 2
additional information is included in this chapter.
8.1 EFFECT OF CLINTON POWFR STATION OPERATING STAFF ON SURROUNDING COMMUNITIES The presently authorized plant staffing level for one unit operation is 221.
Of this total 38% are involved in operations activities and 37% are involved in mainterance activities.
This number. (221) does not include security guards, who should number about 80.
The size of the staff may increase somewhat as minor adjustments are made before fuel loading.
The two unit-staff is estimated to be 50% larger than the one-unit 1
staff, and the contractor personnel required during outages will be consistent with the present industry use of contractor
()
personnel during outages.
The estimated annual payroll for the first full year of operation for each unit is as follows:
1982 Dollars Unit 1-1984
$9,490,000 Unit 2-1996 5,160,000 These values represent the cost of 1sbor if purchase' in 1982.
8.1.1 Anticipated Impacts on Affected Communities from Workers' Residences Approximately 60% of the operating staff for the Clinton Power Station is already at the site.
It is expected that the current residential pattern of these workers will be the typical pattern for the total operating staff.
The residential location of preser.t operating employees is as follows:
4 8.1-1
CPS-ER(OLS}
SUPPLEMENT 1 JUNE 1981 Clinton Power g
Station Employees Community Number Percent Decatur 57 42.5 Clinton 18 13.4 Maroa 9
6.7 Champaign-Urbana 8
6.0 Farmer City 6
4.5 Warrensburg 6
4.5 Other Communities 30 22.4 lith the exception of Bloomington, "Other Communities" include small towns and villages within a 25-mile radius of the Clinton Power Station.
Only from one to four employees reside in any one of these small communities.
Bloomington, which has three operating personnel residing there, is an SMSA located approximately 23 miles northwest of the station.
Assuming that the preceding residentia'. pattern proves typical of the total operating staff, approximately 40% of the staff is expected to reside in Decatur.
Thus the number of additional workers expected to relocate to Decatur is about 30.
Decatur is an SMSA located approximately 23 miles southwest of the station, with a 1980 population of 94,081.
The additional workers and their families are not expected to have any significant impact on the city's services (gg and facilities.
Similarly the small number of additional workers expected to relocate to Chamoaign-Urbana (which had a population of 94,111 in 1980) and Bloomington-Normal (which had a population of 79,861 in 1980) should have insignificant impact ; on those cities services.
The town of Clinton (8,014 in 1980) is the only community near the station in which a significant percentage of the Clinton Power Station workers are expected to reside:
about 13%.
The additional residents should amount to approximately 10 workers and their families.
The additional residents should not require any addition to community services and facilities.
In 1980 Clinton had a total of 3,354 housing units (a 16% increase over 1970) of which 2,214 were owner occupied.
Of the 1,140 rental units 28% were single family units.
Between 1975 and 1979 DeWitt County (excluding Clinton) granted 235 permits for new single family homes, and 142 permits for mobile homes.
In the town of Clinton, between 1975 and 1979, permits were granted for 133 single family units and 91 multi-family units.
It is not exoected that there will be a shortage of available housing in DeWitt County or the town of Clinton.
Educational and health facilities in Clinton and the other nearby snall communities should experience little impact from the Clinton Power Station staff and their families.
There are three school districts O
8.1-2
CPS-ER(OLS)
SUPPLEMENT 1 JUNE 1981 Question 320.1
^'
k-)
/
Tables 1.1-1 thru 1.1-6 should be revised to show actual 1979 and 1980 data on peak load and enurgy consumption.
If the fore-casts for years thru 1990 require revision as a result of the differenceF.- Detween actual and fGreCast for 1979 and 1980, these forecast revisions should also be made.
Response
The revised Tables 1.1-1 thru 1.1-6 are included.
Other parts of Chapter 1 have also been updated to reflect current data.
(G'1 9
j V
S.1-55
CPS-ER(OLS)
SUPPLEMEMT 1 JUNE 1981 SUPPLEMENT 2 Question 320.2 lh What will the first year of commercial operation costs (fixed charges, fuel, O&M) be, in mills /kWh and dollars of the year in question?
Break out these costs by unit, indi-cating in what year each unit will be commercially operating.
Response
The following costs are expected for the first full year of operation of Clinton Unit 1 (commercia' operation beginning August 31, 1983):
Millions of Dollars Mills /kWh Fixed Charges 371.2 70.30 Fuel 60.7 11.50 O&M 10.6 2.01 2
TOTAL 442.4 83.80 For planning purposes, the scheduled completion of Unit 2 is shown as 1995.
The following costs are expected for the lll first year of operation:
Millions of Dollars Mills /kWh Fixed Charges Undetermined Undetermined Fuel 101.3 19.12 O&M 15.1 2.35 2
Those costs are for Illinois Power's 80%. hare of the Clinton units.
The cost estimates shown are exclusive of nuclear-related liability insurance.
O S.1-56
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 I)
NRC REQUEST FOR ADDITIONAL INFORMATION QUESTIONS AND RESPONSES This'section contains the NRC requests for additional in-formation based on J. R. Miller's letter of September 3, 1981, to G.-E. Wuller, followed by the response'to each question.
Where appropriate, the. response includes a ref-erence to the applicable updated sections of the text.
O O
S.2-1
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981
{~}
Question 240.10 s/
In Section 6.1.6.8.1 it is stated that an automatic tempera-ture recorder will be installed at Location 10 to obtain monthly temperature samples.
Please indicate the water depth of the proposed sampling.
Response
This statament is in error; no automatic temperature re-corder is planned for this location.
The temperature profiles taken at Locatiens 2, 4,
8, and 16 (as per Sub-section 6.1.6.8.1 e) and those to be initiated during the operational phase at Locations 12, 13, 14, and 15 (as per Subsection 6.1.6.8.1 g) will provide adequate coverage since thermal data will be available from locations throughout the cooling loop.
The text has been modified to reflect the planned sampling set.eme.
This response is incorporated into the text on page 6.1-30.
O 1-S.2-1
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 ggg Question 240.11 The coefficients of permeability (10-3 to 10-cm/sec) for the sediments underlying the UHS cited in Section 2.4.2.3.1 are significant, and if correct, would result in substantial water losses due to infiltration.
Please provide evidence that these va]ues have been verified and, in addition, provide evidence that increased permeability due to higher temperature water has been included in the analysis.
Response
The coefficients of permeability (10-to 10-2 cm/sec) cited in Subsection 2.4.2.3.1 for the outwash sediments underlying the Ultimate Hcat Sink (UUS) are based on only the particle size analyses shown in FSAR Figures 2.4-33 and 2.4-34.
The UHS is submerged within the cooling lake; therefore, seepage from the UHS will be a factor only if the cooling lake is lost and the lake water level drops below the level of the submerged UHS dam.
If this occurs, the prevailing hydraulic gradient upstream of the UHS dam will be directed towards the UHS as discussed in FSAR Subsection 2.4.11.6, thereby preventing seepage from the UHS upstream of the UHS dam.
UHS water losses due to infiltration (seepage under and h
through the UHS dam) will be insignificant during the 30-day shutdown period when the UHS is operational as discussed in FSAR Subsection 2.5.6.6.1.
1 S.2-2
CPS-ER (OLS)
SUPPLEMENT 2 SEPTEMBER 1981 1
Ouestion 240.12 a.
Analysis of groundwater flow, based on the availability of wells and water level measurements,.is difficult to determine in the region of the purported groundwater-divide.
Plcase provide the evidence used to construct J.
Figure 2.4-18.
b.
The hydrographs provided, Figure 2.4-20, show a lack of 3
i response to hydrologic events (precipitation, flooding, etc).
This lack of response can be attributed to several possible causes including:
- 1) low vertical.
and horizontal permeability; 2) poor piezometer placement; i
or 3) inadequate design and' construction of piezometers.
Plecse. provide and discuss details on piezometer design, j
installation and development with regard to the above.
t It is absolutely essential that hydrostatigraphically l
c.
equivalent units be used in constructing maps of the
{
piezometric surface.
Please provide evidence that this condition has been met.
4
Response
9 a.
Figure 2.4-18 shows the locatior.s of piezometers,
'Clinton Power Station test well, and inferred water
'( )
table in the Wisconsinan deposits in the site vicinity.
The water table contours are inferred on the basis of i
surface topography and three piezometers (E-1B, P-37, P-40) completed in Wisconsin glacial till.
The piezometers indicate that the local water table is generally 8 to 16 feet below the ground surface (see l
Figure 2.4-22, Tables 2.4-22 and 2.4-23).
The generalized depth of the water table below the ground surface was used to construct the inferred water table shown in Figure 2.4-18.
b.
A lack of response of groundwater levels to discrete I
hydrologic events such as precipitation or flooding is not unexpected in piezometers installed in low permeability materials or in zones that are hydrologically disconnected from the ground surface where the l
hydrologic events are manifested.
The low permeabilities of onsite soil materials are discussed in Subsection 2.4.2.3.4.
Geologic. cross sections showing the stratigraphic relationships of~ geologic materials at the site are shown in FSAR Figures 2.5-275 throu'gh 2.5-280.
Details on piezometer design and installation are provided in the FSAR and ER.
Installation dates, ground-l surface elevations, depths and elevations of tested V'T intervals, and stratigraphic units open to the piezometers
\\/
are tabulated in ER Table 2.4-22.
The " tested interval" S.2-3 i
k
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 refers to the piezometer granular filter pack zone.
lh Addi' tonal design and construction details, including piezometers OW-1 through OW-8 is r,huwn in ER Figure 2.4-19.
Piezemeter design is discussed in Subsection 2.5.4.3 of the FSAR.
Piezometers were developed by bicwing them out with compressed air after construction, a
c.
The only potentiometric (piezometric) surface map provided in the Environmental Report is the sketch of the inferred water table shown in Figure 2.4-18.
As discussed in the Response to Question 240.12a, the three piezometers (E-1B, P-37, P-40) used in constructing the inferred water table were completed in a single hydrostratigraphic unit, Wisconsin glacial till.
e e
f S.2-4
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 Cj')
Groundwater conditions appear to be well defined at the dam site through an extensive drilling and testing program.
However, at the Power Block Area, these hydrogeologic factors are not well documented.
Please provide reasonable scale maps showing the location of piezometers and monitoring wells in the Power Block Area.
Response
A map showing the location of piezometers in the Pcver Block Area is provided on Figure 2.4-18A.
Existing and destroyed piezometers are indicated.
Construction aetails for the piezometers are provided in Table 2.4-22 and on the individual boring logs.
Water levels for the piezometers shown are given in Figures 2.4-20, 2.4-22, 2.4-26, and 2.4-27.
This response is incorporated into the text on page 2.4-16.
<T
'% )
i i
\\_)
i S.2-5
t CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981 h
Quef; tion 240.14 It is stated in Section 6.1.2.1 that three areas of groundwater studies have been investigated since the CP-ER was submitted.
Two of the three areas, well testing and semi-annual well monitoring, are discussed in the text.
Please describe the third area investigated.
1 l
Response
l Two areas of groundwater studies were investigated since the CP-ER was submitted, not three areas.
The ER will be I
changed to reflect this fact.
This response is incorporated into the text on page 6.1-10.
o a
e O
S.2m6
CPS-ER(OLS)
SUPPLEMENT 2 SEPTEMBER 1981
(~T Question 240.15 L)
Please provide copies of the following references sited in Section 2.4.1.4.4:
- Roberts, W.
J.,
and Stall, J.
B.,
1967.
Lake Evaporation in Illinois.
Report of Investigation 57, Illinois State Water Survey, Urbana, Illinois.
- Stall, J.
B.,
1964.
Low Flows of Illinois Streams for Impoundino Reservoir Desien.
Bulletin 51, Illinois State Water Survey, Urbana, Illinois.
Response
One copy of each report has been sent to the NRC.
('r kw n/
A._
S.2-7
CPS-ER(OLS)
SUPPLEMENT ^
SEPTEMBER 1981 h
Question 240.16 a.
Please discuss and justify the use of a 70% load factor for computing the minimum water level of Lake Clinton during a once-in-100-year drought as stated in Section 2.4.1.4.4.
b.
Please compare the computed minimum water level of Lake Clinton for the once-in-100-year drought using the monthly load factors presented in Section 3.4.1 with that presented in Section 2.4.1.4.4 using a 70% load factor.
Response
The drought period referred to in Subsection 2.4.1.4.4 extends over a period of 5 years.
The use of a 70% load factor was based on the expected average load factor over the 5-year period including periods of scheduled maintenance outages.
The computed minimum water level of Lake Clinton for the once-in-100-year drought is 681.1 feet based on the load factors presented in Subsection 3.4.1, as compared to 682.3 feet based on a 70% load factor.
Ihh This response is incorporated into the text on page 2.4-8a.
l l
S.2-8 1
L