ML060720127

Update of Alternate Cooling Water System Study for Oyster Creek Nuclear Generating Station, Volume 1 Technical and Economic Evaluation

ML060720127
Person / Time
Site:	Oyster Creek
Issue date:	08/31/1992
From:	Ebasco Services
To:	Office of Nuclear Reactor Regulation
References
2130-06-20281, TAC MC7625
Download: ML060720127 (87)

Text

- 2 INuclear Corporation H

I Update of Alternate Cooling I Water System Study I For Oyster Creek Nuclear I Generating Station II I. 'Volume 1 Technical and Economic Evaluation I

I August 1992 EI wco An ENSbERCJ EnginwUngandConsqructtonCompany

GPU NUCLEAR CORPORATION OYSTER CREEK NUCLEAR GENERATING STATION UPDATE OF ALTERNATE COOLING WATER SYSTEM STUDY VOLUME I TECHNICAL AND ECONOMIC EVALUATION EBASCO SERVICES INCORPORATED AUGUST 1992

TABLE OF CONTENTS 1.0

SUMMARY

. . . . . . . . . . . . . . . . .* * . . , . . . 4 1.1 Purpose . . . . . . . . . . . . . . . . . . . .a a . 4 1.2 Scopeu t . . . . * . . * . . . 6 a *

• a . . . . . . . . . 4 1.3 Resultsion . . . . . . . . . . . . . . . . . . . . . . . 5 1.4 Conclusions . . . . . . . . . . a . . . . . . . . . . . . 8 2.0 DISCUSSION . . . . . . . . . . . . . I . a

• P ..... . . . 1 0 2.1 Methodology . . . . * * * . . * . . * .. 4 . a * . . ... . . 10 2.2 Cooling Water System Description . . * . & * * . *. . . . . 0 11 2.2.1 Existing System . . . . . . . a . . .... . . . . . *1 1 2.2.2 Natural Draft Cooling Tower System . . . 12 2.2.3 Round Mechanical Draft Cooling Tower System . 16 2.3 Cooling System Optimization Input Data . . . . . . . . . 17 2.3.1 Cooling System Parameter Alternatives 17 2.3.2 Project Financial Criteria . . . 19 2.3.3 Intake Canal Water Conditions . . . . . . 22 2.3.4 Ambient Air Temperature Conditions . . . 22 2.3.5 Turbine Generator Unit Performance . . . . . . 23 2.3.6 Circulating Water System Layout . . . . . . 24 2.3.7 Cooling Tower Parameters . . . . . . . 24 2.3.8 Computer Pricing Information . . . . . . . . . 25 2.4 Cooling System Economic Optimization Results 26 2.4.1 Natural Draft Cooling Tower . . . . . . . . 27 2.4.2 Round Mechanical Draft Cooling Tower System 27 2.4.3 Economically Preferred Cooling Tower Spec. . 28 2.5 Cooling System Design, Operating and Cost Parameters . 28 2.5.1 Natural Draft Cooling Tower . . . . . . . 28 2.5.2 Round Mechanical Draft Cooling Tower System 30 REFERENCES . .. . . . . . . . . .. . . . . . . . . . 34 EXHIBITS APPENDICES 2

LIST OF EXHIBITS

1. Oyster Creek NGS Site & Vicinity

2. Existing Cooling Water System-.

3. Condensing System Performance Summary - Existing System

4. Natural Draft Cooling Tower General Arrangement

5. Natural Draft Cooling System Flow Diagram

6. Natural Draft Cooling System Layout

7. CWS Hydraulic Gradient - NDCT

8. One Line Diagram - NDCT Power Supply

9. Circulating Water Quality Analysis - NDCT

10. Water Treatment System Schematic

11. Round Mechanical Draft Cooling Tower General Arrangement

12. Round Mechanical Draft Cooling System Flow Diagram

13. Round Mechanical Draft Cooling System Layout

14. CWS Hydraulic Gradient - RMDCT

15. One Line Diagram - RMD)CT Power Supply

16. Circulating Water Quality Analysis - RMDCT

17. Levelized Energy & Demand Charge

18. Intake Water Average Monthly & Seasonal Temperatures

19. Ambient Air Temperatures

20. Turbine Cycle Heat Balances

a. Valves Wide Open Case

b. 100% Load

21. Exhaust Pressure Correction Curve

22. Natural Draft Cooling Tower Parametric Data

23. Round Mechanical Draft Cooling Tower Parametric Data

24. Cooling System Material and Installation Unit Costs

25. NDCT Investment, Comparable Annual and Capitalized Costs

26. NDCT Economic Evaluation Curve

27. RMDCT Investment, Comparable Annual and Capitalized Costs

28. RMDCT Economic Evaluation Curve

29. Condensing System Computer Printout - NDCT

30. Condensing System Computer Printout - RMDCT

31. NDCT and RMDCT Component Material and Installation Costs 3

1.0

SUMMARY

1.1 PURPOSE The Oyster Creek Nuclear Generating Station (OCNGS) utilizes an open cycle cooling system in which the main condenser cooling water is supplied via a man-made intake canal from Forked River and then discharged to Oyster Creek. Although the cooling system consistently meets pertinent environmental regulatory limits, there have been environmental impacts. To determine the benefits and costs of implementing a cooling system alternative to the existing condenser cooling system, Ebasco evaluated engineering, cost, licensing, and environmental factors, of sixteen (16) open cycle and closed cycle cooling water systems. The study, "Alternative Cooling Water System Study", November 1977 (Reference 1),

identified four "preferred" cooling systems: natural draft cooling tower, round mechanical draft cooling tower, fan assisted natural draft cooling tower and discharge canal to bay. Of these four, the study concluded that the natural draft cooling tower system is the optimum.

The purpose of this study is to update the technical, economic E and environmental findings of the original study with respect to the two (2) preferred cooling water alternatives, i.e. natural draft cooling tower (NDCT) and round mechanical draft cooling tower (RMDCT).

The technical and economic evaluations are presented in Volume

1. Environmental evaluations are presented separately in Volume 2.

1.2 SCOPE This study is performed in accord with the scope of work described in Ebasco' s proposal "Update of Alternate Cooling Water System Study for Oyster Creek Generating Station", December 1991.

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The two best closed cooling alternatives from the original study, the natural draft cooling tower.(NDCT) and round mechanical draft cooling tower systems (RHDCT), are evaluated. Detailed information contained in the original study was reviewed and the information updated for those technical, cost and environmental aspects that have been superseded based on current plant conditions, cooling system technology, environmental and regulatory criteria. For example, cooling system investment and operating costs are updated for today's equipment costs, GPUN's economic factors, remaining plant operating life, and forecasted replacement energy costs.

In this volume technical and economic aspects of the NDCT and RMDCT alternatives are evaluated in the following tasks:

1) Review the original study and confirm or update the criteria and assumptions consistent with current site characteristics, plant design, performance, environmental and regulatory requirements;

2) Update the technical design, including preliminary design, performance and cost information from a cooling tower vendor;

3) Update the Ebasco computer program "Economic Selection of Steam Condensing System" (CSIZE2011), including:

o site, plant and cooling system design features and performance o major equipment prices, e.g. cooling towers, pumps o balance of plant material and installation costs o GPUN economic factors 1.3 RESULTS Two arrangements of evaporative cooling towers are evaluated:

a single concrete, hyperbolic natural draft cooling tower (NDCT);

and two (2) 50% capacity round mechanical draft cooling towers. A 5

schematic flow diagram and layout drawing are given for the NDCT in Exhibits 5 and 6, respectively, and for the RMDCT in Exhibits 12 and 13, respectively. Condensing. system and plant overall performance, investment costs, and comparable annual costs including demand and energy charges for differential generation with respect to the existing system are given in Exhibits 29 and 30 for the NDCT and RMDCT, respectively.

NDCT and RMDCT design and performance parameters are:

NDCT RMDCT No. Towers 1 2 Flow rate, gpm 416,200 373,100 Range, F 20.2 22.6 Approach Temp, F 12 10 Cold Water Temp, F 86 84 Hot Water Temp, F 106.2 106.6 Base Diameter,ft 409 210 Height, ft 600 62 Pumping head, ft 42 38 Evaporation Loss, % 1.8 2.06 Drift Loss, % 0.001 0.001 No. Fans / Motor HP NA 12 per tower / 200 The proposed cooling tower(s) would be located on the north side of the plant. Cold water would be pumped by circulating water pumps through 12 ft (NDCT) or 11 ft (RMDCT) diameter reinforced concrete conduits to and from the existing circulating water intake and discharge tunnels. The conduits would be buried.

Circulating water system total head requirement is approximately 74.4 ft for the NDCT and 68.6 ft for the RMDCT. To satisfy the intake tunnel design pressure of 41 feet, the total pumping head is divided between four (4) 800 hp vertical type circulating water pumps located at the cooling tower and (4) 1500 6

hp horizontal type booster circulating water pumps located in the hot water return piping.

Circulating water'systen electric power requirements for pump, fan and miscellaneous equipment motors are provided using existing 4160 V 1A, 1B and dilution pump switchgear, new 4160 V switchgear and new 480 V power centers.

Intake water would be used for cooling tower makeup and would require pretreatment in a brine clarifier/reactivator to reduce the calcium hardness. Makeup flow would be approximately 15,000 gpm based on operating the circulating water at 2 to 2.5 cycles of concentration. Cooling tower blowdown is calculated to be a volume of about 7,500 gpm and would be piped to the discharge canal.

Clarifier sludge would be dewatered and compacted for offsite disposal.

Compared to the existing cooling system, the use of cooling towers will reduce plant net capacity and generation due to higher turbine exhaust pressure and higher auxiliary power demands. At design temperature conditions net capacity would decrease by about 15 MW for the NDCT and 19 MW for the RMDCT.

Parameter Existing NDCT Round MDQT Design WB Tempt F NA 74 74 Design CW Temp, F 82 86 84 Condenser Pressure, in Hga 2.66 3.18 3.24 TG Output, MW 616.8 605.8 604.5 BOP Aux. Pwr, MW 17.5 17.5 17.5 CWS Aux. Pwr, MW 3.2 7.6 10.3 Plant Net Output, MW 596.1 580.7 576.7 Differential, MW Base -15.4 -19.4 Net Generation, MWH/yr 4,039,400 3,939,100 3,923,200 Differential, NWH/yr Base -100,300 -116,200 7

where TG equals Turbine Generator, BOP equals Balance of Plant and CWS equals Circulating Water System.

NDCT and RMDCT total investment costs, comparable annual costs including demand and energy charges for differential net generation compared to the existing system, and comparable capitalized costs (based on a 23.42% levelized fixed charge rate) are:

Parameter (1995 $) NDCT Round MDCT Total Investment Cost, $ 98,550,000 91,100,000 Differential, $ Base -7,450,000 Comparable Levelized Cost, $/yr 33,200,000 33,500,000 Differential, S/yr Base +300,000 Comparable Capitalized Cost., $ 141,800,000 143,000,000 Differential, $ Base 1,200,000 Investment cost includes all costs to erect cooling tower and basin, pumps, piping, intake, and pump house structures, electrical, water treatment, etc. Comparable levelized cost includes investment fixed charge, 0&M, plus &djustment (energy/demand charge) for differential net generation compared to the existing condensing system. This cost is calculated on an annual basis for the 15 years from 1995 to 2009 when the plant's operating license expires.

Comparable capitalized costs = total comparable capitalized cost/levelized fixed charge rate.

1.4 CONCLUSION

S Incorporation of either cooling tower alternative appears technically feasible subject to more detailed engineering and cost studies of the cooling tower, circulating water pipe, water treatment equipment arrangements, electric power supply, circulating water pump total head and system operational 8

cooling l requirements with respect to limitations of the existing system (i.e. intake tunnel design pressure).

is high due to The economic impact of either the NDCT or RMDCT investment cost, and reduced net generation. Total l significant comparable costs are essentially equal.

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2.0 DISCUSSION 2.1 METHODOLOGY The original study evaluated and selected the natural draft and round mechanical draft cooling tower systems as "preferred" based on cost and environmental considerations. For this study, these cooling system alternatives are evaluated technically, economically and environmentally based on today's criteria.

Compared to the existing cooling system, incorporation of an alternative cooling system utilizing cooling towers will reduce plant net output. Cooling water temperature is warmer, resulting in higher condenser pressure and reduced generator output. Station auxiliary power consumption increases from greater circulating water pump power and cooling tower fans.

Each cooling system is technically and economically evaluated to identify the optimum design using Ebasco's computer program "Economic Selection of Steam. Condensing System" which was used in the original study. Program description is given in Appendix A.

Cooling system alternatives are evaluated in two levels of detail. In the first level of detail a cooling system economic optimization study is performed on a comparative basis to identify the technically acceptable and economically preferred NDCT and RMDCT system process specifications. The evaluation is based on cooling tower design, performance and cost parameters provided by a cooling tower vendor for alternative cold water and range temperature conditions. In the second level of detail, the cooling tower vendor provides refined design, performance, and cost data for the specific optimized cooling tower specifications. This data is used to perform more detailed engineering, economic and environmental evaluations.

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2.2 COOLING SYSTEM DESCRIPTION 2.2.1 EXISTING COOLING SYSTEM Exhibit 1 shows the Oyster Creek NGS site bounded by Barnegat Bay to the east, Forked River to the north and Oyster Creek on the south. The condenser cooling system, Exhibit 2, is an open-loop cooling system whereby the condenser heat load is ultimately discharged to Barnegat Bay via intake and discharge canals connecting Forked River and Oyster Creek, respectively. Four circulating water pumps convey the mixture of salt and fresh water from Barnegat Bay and Forked River through the intake canal and the condenser to the discharge canal. Circulating water pumps are located in the intake canal. A dam separates the intake and discharge canals.

The turbine exhaust steam condenser consists of three single-pass, single pressure shell.s manufactured by Worthington. The original tube material was replaced with titanium in the early 1970s. Condenser design parameters from References 2a and 2b are:

No. Shells 3 Surface Area per Shell 141,000 sq ft Cooling water flow per Shell 150,000 gpm No. Tubes per Shell 14,562 Tube Length 42.5 ft Tube Material Titanium Tube Diameter x Wall Thick. 7/8 in x 22 BWG Tube Cleanliness Factor 95%

The condenser is supplied by four (4) 115,000 gpm, 28.5 ft TDH, 1000 HP vertical type circulating water pumps located at the intake canal pump house. The intake canal also supplies three (3) 800 hp dilution pumps that may be used to regulate discharge canal water temperature.

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Cooling water is conveyed from the intake canal through the condenser to the discharge canal via 10.5 ft x 10.5 ft concrete intake and discharge tunnels. Tunnel, condenser pipe and valve arrangement facilitates condenser tube backwashing.

The circulating water system intake tunnel has a design pressure of 41 ft which restricts the maximum allowable circulating water pump discharge pressure, the number of pumps and condenser water boxes in service, and condenser backwash procedures (Reference 2c).

The performance of the existing condensing system, turbine generator output and plant net generation is calculated in Exhibit

3. At the average annual cold water temperature, the existing condensing system produces nominally 640 MW gross.In order to allow for comparability with the cooling tower alternatives, the existing condensing system was evaluated at an equivalent ambient temperature. This results in an 84 F cold water temperature.

Existing Condensing System Parameters Cold Water Temp, F 84 Condenser Pressure, in Hga 2.66 TG Output, MW 616.8 BOP Aux. Pwr, MW 17.5 CWS Aux. Pwr, MW .3.2 Plant Net Output, MW 596.1 Net Generation, MWH/yr 4,039,400 2.2.2 NATURAL DRAFT COOLING TOWER SYSTEM NDCT arrangement, system flow diagram and site layout are given in Exhibits 4, 5 and 6, respectively. A single cooling tower can handle the total condenser and auxiliary service water heat load and flow requirement.

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Major equipment includes:

o hyperbolic counterflow natural draft cooling tower and basin o horizontal and vertical circulating water pumps (8 total) o circulating water concrete conduit o circulating water pump house o electric switchgear, cables o makeup water pumps, piping o makeup water treatment system o water treatment sludge disposal system o blowdown water piping o condenser tube cleaning system Cooling Tower The natural draft or hyperbolic counter flow cooling tower relies on the structure's "chimney" effect to induce ambient air to flow upward through the tower "fill". Hot circulating water flows over the fill and is cooled by the air flow via evaporative and convective cooling.

One NDCT is required. Cooling tower design, performance and budget cost data for comparative analyses is shown in Exhibit 22.

Data are provided for towers with approach temperature from 12 to 16 F and range temperatures from 16 to 24 F. The economically optimized tower is approximately 600 ft tall and has a base diameter of 409 ft.

Circulating Water Conduit The cooling tower is assumed to be located at the north side of the plant. Reinforced concrete conduit convey the circulating water between the cooling tower and existing intake and discharge tunnels.

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The design pressure of the intake tunnel is 41 ft. This limits the allowable circulating water pump discharge pressure. For closed cooling alternatives utilizing cooling towers that have a high total head (for the NDCT system approximately 74 ft), the overall system pumping head requirement is minimized by the use of large diameter conduits. Furthermore, the intake tunnel pressure limitation requires that the total pumping head be shared between two sets of circulating water pumps. One set of four (4) CW pumps are located in the cooling tower basin and a set of four (4) booster CW pumps are located in the return piping to the cooling tower.

The TDH of each pump must be specified such that the following criteria are met:

a. cumulative pump head equals the sum of pipe friction, condenser friction and cooling tower pumping head;

b. the intake tunnel 41 ft pressure limit is not exceeded during all operating modes;

c. main and booster circulating pump NPSH requirements are met;

d. maximum siphon head is not exceeded (typically 25-26 ft).

A CWS hydraulic gra.de line given in Exhibit 7. For the optimized case, the circulating water flow rate is about 416,000 gpm and the reinforced concrete conduit diameter is 12 ft. Total conduit length is about 2.,900 ft. Vertical circulating water pump head is 26.4 ft and the horizontal booster circulating water pump head is 48 ft. Intake tunnel pressure is 39 ft and condenser siphon head is about 19.5 ft.

Electric Power Supply Cooling system electric power requirements for the circulating water pumps, makeup water pumps, water treatment equipment, valve motors and miscellaneous equipment will be supplied from existing 14

I 4160V buses lA, IB, and dilution plant switchgear, new 4160V switchgear, new 480V power centers and motor control centers.

A conceptual one line diagram of the major electrical

8. The components of the NDCT power supply is shown in Exhibit to supply existing 4160 V switchgear buses 1A and 1B will be used l the four (4) new 800 hp circulating water pumps. The. existing booster dilution pump 4160 V switchgear would feed two (2) 1500 hp center #1.

pumps, an 400 hp makeup water pump and a new 480 V power 4160 V A feed is provided from startup transformer SB to new water switchgear to supply the other two (2) booster pumps, makeup pump and new 480 V power center #2.

l Makeup Water Treatment l Intake canal water is used for cooling tower make-up. Intake 9.

water analysis from the original study is analyzed in Exhibit l Calcium hardness must be reduced by lime softening. The reduced 2 to 2.6 hardness will enable the cooling tower to operate between the cycles of concentration. At. the design wet bulb temperature is makeup water rate is approx:imatelfy 15,000 gpm. About 7,500 gpm lost to evaporation and 7,500 gpm is discharged to the discharge l canal. Makeup water is supplied by two (2) 50% capacity 400 HP CW pump pumps which would be located in the existing intake canal l house.

Water treatment schematic diagram is shown in Exhibit 10. Raw are water is pumped to the brine clarifier/reactor where chemicals added to enhance the removal of calcium hardness. The treated is effluent is discharged to the cooling tower. The excess sludge collected and discharged to a thickener where it is further concentrated before it is sent to a filter press to be dewatered to

- a truckable solid for offsite disposal.

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2.2. 3 ROUND MECHANICAL DRAFT COOLING TOWER SYSTEM Cooling tower arrangement, system flow diagram and layout for the Round Mechanical Draft Cooling Tower (RMDCT) system are given in Exhibits 11, 12 and 13. Major equipment is the same as for the NDCT except that two (2) RHDCT are required, and 2 additional new 480 V power centers are required to supply the cooling tower fans.

Cooling Tower The round mechanical draft cooling tower utilizes fans to induce the air to flow through the cooling tower. Cooling tower design, performance and cost data for comparative purposes are given in Exhibit 23. The two (2) cooling towers are assumed to be located north of the plant. Basin water flows to a common intake pump structure.

Circulating Water Conduit Conduit diameter would be 11 ft based on the optimized case flow of 373,000 gpm. Hydraulic gradient is shown in Exhibit 14.

Circulating water system total head is 68 ft, which is divided between the main circulating water pump (26.1 ft) and the booster pump (42.5 ft). Intake tunnel pressure is 39 ft and the condenser siphon head is 16.8 ft.

Electric power SUpRlR A conceptual one line diagram of the major components of the RMDCT power supply system is shown as Exhibit 15. Power supply from existing and new 4160 V switchgear for the four CWPs, four booster CWPs, two makeup water pumps and two 480 V power centers are the same as for the natural draft cooling tower. Two additional 480 V power centers are provided for the cooling tower fans.

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c If Makeup Water Treatment l The system is the same as for the NDOT. Circulating water analysis is shown in Exhibit 16. At the design wet bulb temperature the makeup water flow is 15,400 gpm based on an evaporation loss of 7,700 gpm and blowdown flow of 7,700 gpm.

2.3 COOLING SYSTEM OPTIMIZATION INPUT DATA 2.3.1 COOLING SYSTEM PARAMETER ALTERNATIVES I Condenser tube water velocity If The existing condenser design flow rate is 450,000 gpm and the condenser tube water velocity is 6.3 ft/s. The condenser tube lf velocity affects the cooling water temperature rise, flow rate, condenser pressure and generator power output. Higher tube velocity results in higher generator output due to better condenser heat transfer performance and reduced turbine exhaust pressure. But the higher flow rate increases the cooling tower cost, pump head and pump power. Lower tube velocity results in lower generator output, but also lower cooling system cost, pumping head and power.

Titanium condenser tubes may be expected to operate Df satisfactorily over a wide velocity range. For optimization of new cooling water systems the economically preferred titanium tube l design velocity is typically between 6 to 12 ft/s. However for this study, in which the existing condenser and circulating water conduits are fixed designs, the water velocity was evaluated over the range of 5.0 ft/s to 7.2 ft/s based on the following n considerations:

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o low velocity (high cooling water temperature range) to reduce cooling tower, pump and piping costs, pumping head, and satisfy the intake tunnel design pressure limitation; minimum velocity for the Amertapp tube cleaning system (for study purposes only) is 5 ft/s; o high velocity (low cooling water temperature range) to increase condenser performance and generator output.

Resulting condenser flow rate and water temperature rise versus tube water velocity, based on the full load condenser duty of 4110 million Btu/hr (at 1860 MWt), 3 shells and 14,562 tubes/shell (7/8 inch diameter, 22 BWG) are:

Condenser Tube Water Velocity. ft/s Condenser Flow. grp Temp. RiseF 5.0 359,000 23.6 6.27 450,000 (design) 18.8 7.2 517,000 16.4 where temperature rise Heat Duty/(Gpm x 500 x Cp x SG) ; assuming water equal to 1.5 normal sea water concentration or 50,000 ppm, Cp = 0.94 and SG = 64.4/62.4 = 1.03.

Cooling Tower Flow Rate Cooling tower flow equals the condenser flow plus 10,000 gpm auxiliary service cooling water (flow to the turbine building closed cooling water heat exchanger).

Cooling Tower Ranre Temperature Cooling tower water range temperature (i.e. hot water inlet temperature minus the cold water outlet temperature) is governed by the condenser and auxiliary service water system heat loads and 18

flow rates. For this study, the cooling tower range temperature is assumed equal to the condenser temperature rise.

Cooling Tower Approach Temperature Cooling tower cold water temperature performance is governed by the "approach temperature" to the ambient air wet bulb temperature. The ambient wet bulb temperature is the same as in the original study, 74 F. This equals the mean coincident wet bulb temperature corresponding to the 2.5% summer (June, July, August, September) frequency dry bulb temperature (89F) for Atlantic City as given in Reference 7.

From Ebasco's experience with numerous cooling tower economic evaluations, the economically preferred cooling tower will generally have a high range! temperature (to reduce the flow rate and capital cost) and low approach temperature (to lower the condenser pressure and increase generator output). For this study, the range temperatures described above and the following cooling tower approach temperatures are considered:

NDCT: 12; 14; 16 F RMDCT: 8; 10; 12 F 2.3.2 PROJECT FINANCIAL CRITERIA A. Material and installation cost escalation: 4.1 %/yr (reference 3c).

The escalation period is assumed to be three years based on system operation starting in 1995.

B. Sales/Use Taxes: 5% of direct material cost.

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I C. Indirect Construction Ccot: 15 % of total direct escalated cost.

Indirect Construction Cost has been estimated as a percentage of total direct escalated costs based upon Ebasco's in house data.

Indirect Construction Costs include architectural/engineering and related services such as design, engineering, purchasing, expediting, inspection, traffic, start-up services, construction management, locally hired non-manual employees (secretary, bookkeeper, surveyor), cars, pick-up trucks, site trailers and office expenses to support a construction management team at the site.

D. Contingencies: 14% of total direct and indirect escalated cost.

The contingency allowance has been estimated as a percentage of total direct and indirect escalated costs based upon Ebasco's experience. It covers the following items: conceptual quantities for earthwork, concrete, piping, and electrical; lack of firm pricing for major equipment; and the current phase of design (conceptual) for this study.

E. Interest During Construction: 10%/yr (reference 3a).

F. UtilitX's Expenses: 6% of total direct costs.

This is to cover GPUN's administrative, engineering and supervisory costs and taxes during construction, and is the same as used in the original study.

G. Levelized Maintenance Cost: natural draft cooling tower, 2% of total investment; round mechanical draft, 3% of total investment cost plus $3,800 per fan.

H. Leveliged Fixed-Charpe Rate: 23.42 % of the capital cost. This is the."carrying charge" need to cover expenses for return on weighted capital, book depreciation, income tax liability, property taxes and insurance. It is equal to the sum of the capital recovery factor (calculated at the rate of return, below) plus 9.7% from the original study for taxes and insurance. The economic evaluation period is 15 years from 1995 to 2009 when the plant's operating license expires.

I. Rate of Return: 10.78% (reference 3b). This is used to calculate the levelized replacement energy cost (see item L).

Capitalization Average Ubight Ratio Target Cost Return Long-Term Debt 45% 9.5% 4.28%

Preferred Stock 11% 8.7% 0.96%

Common Stock Equity 44X 12.6% 5,54%

100% 10.78%

J. Incremental Net Capabl-li t Charge: the demand charge is included in the replacement energy cost (item 1).

K. Nuclear Fuel Cost: this cost is not required since the fuel input is constant for all cases.

L. Levelized-Replacemen; Energy Cost: $77.71 / Mwh.

This is based on GPUN data (Reference 2d) for energy and demand charges, and is derived in Exhibit 17.

M. Levelized Makeup Watts: $19.23 per million gallons; chemical treatment, $50 per million gallons. Water cost is based on the makeup pump replacement power cost. Chemical treatment is escalated from the original study cost of treatment (e.g.

chlorine, etc.).

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N. Land Cost: No cost. Both alternatives examined would locate the cooling tower(s) on land currently owned by GPUN.

Additional land required to meet the noise regulations as discussed in Volume 2:, Section 7.2.3 - Noise Impacts, have been excluded from this study.

2.3.3 INTAKE CANAL WATER CONDITIONS Average monthly and seasonal cooling water temperatures used to determine the performance of the existing condenser system for comparison against cooling tower alternatives are given in Exhibit

18. Seasonal temperatures aore:

Ambient Condition CW Temperature. F Condenser design 82 F Average summer 76 F Average spring/fall 55 F Average winter 36 F 2.3.4 AMBIENT AIR TEMPERATURE CONDITIONS Average monthly ambient dew point and dry bulb temperatures from Atlantic City, NJ, 1/81 to 12/85 were used to determine the average monthly and seasonal wet bulb temperature conditions. See Exhibit 19.

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2.3.5 TURBINE GENERATOR UNIT PERFORMANCE & LOADING REGIMEN Turbine Cycle Heat Balance The turbine generator is a General Electric TC6F-38 LSB unit with Valves Wide Open (105%; flow) gross output and heat rate of 670,005 Kw and 9,797 Btu/Kwh at 1.0 in HgA exhaust pressure.

Reactor thermal output is 1930 MW. Throttle steam conditions are 6,834,590 lb/hr at 965 psia and 1191.2 Btu/lb. Condenser heat duty is 4,360 MMBtu/hr. Exhibits 20a and 20b illustrate the turbine cycle heat balances for the Valves Wide Open case and the 100% load case, respectively.

Generator output may be calculated for various exhaust pressures using exhaust pressure heat rate correction factors shown in Exhibit 21 and the following equation:

Change in Kw = (-X Change in Heat Rate)*100/(100-% Change in Heat Rate)

Plant Operation The plant is assumed for this study to operate (base loaded) equivalent to a 75% capacity factor. For study purposes, the turbine generator is assumed to operate at 100% guaranteed load gross output and heat rate of 640,757 Kw and 9,821 Btu/Kwh, respectively, at 1.0 in HgA exhaust pressure, for 0.75

• 8,760 hr/yr = 6,570 hr/yr. Reactor thermal output is 1860 MW. Throttle steam conditions are 6,509,130 lb/hr at 965 psia and 1191.2 Btu/lb.

Condenser heat duty is 4,110 MM Btu/hr.

The turbine cycle heat. balance for this case is shown in Exhibit 20b.

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2. 3.6 CIRCULATING WATER SYSTEM LAYOUT Piping layout is shown in Exhibits 6 and 13 for the NDCT and HDCT, respectively. The cooling tower is located on the north side of the plant for both layouts. New piping connects the cooling tower to the existing circulating water conduits. The new conduits are buried. Since ground water is close to the surface (less than 10 ft), pipe installation is assumed to require sheet piling.

Circulating water system TDH is calculated based on the following pipe arrangement:

No. Pipes Flow.X Avg Length. ft K-Factor Existing System + New CT Intake Main 1 10() 2,100 4.5 Branch 1 100 500 3 Branch 6 16.7 150 3 New Conduits Main - Supply 1 100 1345 .7 Main - Rtn 1 l0() 1540 1 Branch 4 25 38 1.5 2.3.7 COOLING TOWER PARAMETERS Preliminary NDCT and RMDCT design, performance and cost information was received from Marley Cooling Tower Company for the purpose of comparative evaluations. Cooling tower size, pump head, fan power, evaporation loss and budget price are given for NDCT and RMDCT alternatives in Exhibits 22 and 23, respectively.

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2.3. 8 PRICING INFORMATION A. Pricing Data Stored On Computer Vertical circulating water pump and motor budgetary costs were obtained from Ingersoll Rand Pump Division (reference 5).

Pump Type Vertical, wet pit for salt water Pump Model 58 APMA Capacity, gpm 110,000 Total Head, ft 42 Efficiency, % 87 Motor HP/Volt/rpm 15,000/4000/400 Pump Price, $ 300,000 Motor Price, $ 225,000 The above pump and motor prices were used to determine a "discount factor" to adjust vertical pump, horizontal pump and motor price data contained in the computer program. The discount factor was derived to be equivalent to the combined cost of a "composite" vertical circulating water pump consisting of one vertical CW pump and one horizontal booster CW pump. This was necessary for the computer program to determine a cost equivalent to two circulating water pumps arranged in series.

Discount factors used for the "composite" vertical pump and motor were:

Vertical pump: -4.01 on 1968 price list (or a 5.01 multiplier on the computer price);

Motors: -1.36 on 1975 price list (or 2.36 multiplier) 25

B. Pricing Data Input Directly to Computer Current pricing data was quoted by vendors or estimated by Ebasco for major site development, circulating water intake structures, conduits, cooling towers, electrical equipment, power cables, local clearing, etc. Pricing data is listed in Exhibit 24. Land cost for noise abatement was excluded.

2.4 COOLING SYSTEM ECONOMIC OPTIMIZATION RESULTS The Ebasco computer program "Economic Selection of Steam Condensing System" was used to evaluate the design, performance, investment cost and comparable annual costs for NDCT and RMDCT.

Program description is given in Appendix A.

The computer analysis was performed for the following alternatives:

Condenser Tube Water Velocity. (ft/s) 5.0 - 7.2 ft/s in steps of 0.2 ft/s Cooling Water Approach Temperature (74 F wet bulb temperature)

NDCT: 12; 14; 16 F RMDCT: 8; 10; 12 F Natural draft and mechanical draft cooling tower technical, investment cost and annual cost computer results summary for each approach temperature are given in Appendix B. Investment cost includes all costs to erect cooling tower and basin, pumps, piping, intake and pump house structures, electrical, water treatment, etc.

Land costs to meet noise regulations have been excluded from this study. Annual cost (levelizeed) includes investment fixed charge, O&M, plus adjustment (energy/demand charge) for differential net 26

generation compared to the existing condensing system. Capitalized costs = total annual cost/levelized fixed charge rate (23.42%).

2.4.1 NATURAL DRAFT COOLING TOWER SYSTEM Total investment cost, comparable annual cost and capitalized annual cost, are given in Exhibit 25. Investment and capitalized costs are also graphically shown in Exhibit 26.

NDCT investment costs range from $85 to $116 million, depending on the tower type, cold water approach temperature, and tube water velocity (which sets the temperature range and flow rate). Capital cost increases as the cold water temperature decreases and the tube water velocity (or flow rate) increases.

Comparable capitalized costs varies from $143 million to $167 million.

2.4.2 ROUND MECHANICAL DRAFT COOLING TOWER SYSTEM Investment, levelized comparable annual and capitalized costs are presented in tabular and curve form in Exhibits 27 and 28.

Investment cost ranges from $86 to $118 million. Although these costs are nearly the same as for the NDCT, RMDCT specifications are more difficult since cold water approach temperatures are 4 F cooler (e.g 8 to 12 F vs 12 to 14 F for the NDCT).

Comparable capitalized cost ranges from $144 to $162 million which is from $5 million lower to $1 higher than the NDCT.

27

2.4 .3 ECONOMICALLY PREFERRED COOLING TOWER SPECIFICATION One the basis of low comparable cost, the economically preferred NDCT and RMDCT towers have the following specifications:

NDCT RMDCT Cold approach temperature, F 12 10 Condenser tube velocity, ft/s 5.8 5.2 Condenser range temp, F 20.2 22.6 Cooling Tower flow, gpm 416,200 373,100 Design, performance and cost data for these specific selections are given in the next section.

2.5 COOLING SYSTEM DESIGN, PERFORMANCE AND COST PARAMETERS Cooling tower economically optimized specifications were evaluated by Marley Cooling Tower Company who provided detailed design, performance and cost information (References 6b and 6c).

This information was analyzed to estimate condensing system performance, investment and evaluated costs parameters.

2.5.1 Natural Draft Cooling Tower System Computer printout of NDCT condensing system parameters is given in Exhibit 29. HydrauLic gradient and circulating water analyses are given in Exhibits 7 and 9.

Major technical, performance and cost data are summarized below:

28

A. Natural Draft Cooling Tower Design Conditions:

Approach to Twb = 74 F 12 Cooling Range,F 20.2 Circulating Water Flow, gpm 416,200 CW Temperature, F 86

Description:

Cooling Tower Type Counterflow, concre te No. Towers 1 Diameter, ft 409 Height, ft 600 Performance:

Pumping Head, ft 42 L/G Ratio 1.74 Evaporation Loss, % 1.8 Max. Drift Loss, % 0.001 Sound Power Level @ 50 ft 121 x 10A-12 R e Sound Pressure Level:

Hz 31.5 U 12& 250 500 1000 2000 4000 8000 Db 54 56 56 57 66 67 67 70 69 Budget Price (1992 $): $22,650,000 B. Circulating Water Pumps Type Vertical Number .4 Capacity, gpm 104,100 Total Head, ft 28.9 Motor Rating, hp 800 C. Booster Circulating Water Pumps Type Horizontal Number 4 Capacity, gpm 104,100 Total Head, ft 48 Motor Rating, hp 1500 29

D. Circulating Water Pipir, Type Reinforced Concrete Diameter 144 in Pipe Velocity 8.2 ft/s E. Station Performance Design CW Temp, F 86 Condenser Pressure, in Hga 3.18 TG Output, MW 605.8 BOP Aux. Pwr, MW 17.5 CWS Aux. Pwr1 MW 7.6 Plant Net Output, MW 580.7

• Differential, MW -15.4 Net Generation, MWH/yr 3,939,100

• Differential, MWH/yr -100,300

• Compared to existing cooling system (Exhibit 3)

F. Cooling System Investment and Comparable Costs (1995 t)

Total Investment Cost, $ 98,550,000 Comparable Levelized Cost, $/yr 33,200,000 Comparable Capitalized Cost, $ 141,800,000 2.5.2 Round Mechanical Draft Cooling Tower System Computer printout of RMDCT condensing system parameters is given in Exhibit 30. Hydraulic gradient and circulating water analyses are given in Exhibits 14 and 16.

Major technical, performance and cost data are summarized below:

30

A. Round Mechanical Draft Cooling Tower Design Conditions:

Approach to Twb = 74 F 12 Cooling Range, F 22.6 Circulating Water Flow, gpm 373,100 CW Temperatures F 84

Description:

Cooling Tower Type Counterflow, concrete No. Towers 2 Diameter, ft 210 Height, ft 62 Fan Deck Height, ft 48 No. Fans 12 No. Blades 8 Fan Diameter, ft 28 Full/Half Speed Rpm 137/68.5 BHP 200/25 Blade Pass. Freq, cpm 1096/548 Performance:

Pumping Head, ft 38 L/G Ratio 1.404 Evaporation Loss, % 2.06 Max. Drift Loss, % 0.001 Sound Power Level @ 50 ft 120 x 10^-12 Re Sound Pressure Level e Full and Half Speed, Db:

Hz 31.5 63 125 250 500 1Q.Q 2000 4000 8000 100% 81 82 78 72 70 70 68 70 70 50% 73 74 66 70 58 63 65 72 72 Budget Price (1992 $): $17,410,000 B. Circulating Water Pumps Type Vertical Number 4 Capacity, gpm 93,350 Total Head, ft 26.1 Motor Rating, hp 800 31

C. Booster Circulatini Water Pumps Type Horizontal Number 4 Capacity, gpm 93,350 Total Head, ft 42.5 Motor Rating, hp 1250 D. Circulating Water Pipisg Type Reinforced Concrete Diameter 132 in Pipe Velocity 8.8 ft/s E. Station Performance Design CW Temp, F 84 Condenser Pressure, in Hga 3.24 TG Output, MW 64.5 BOP Aux. Pwr, MW 17.5 CWS Aux. Pwr, MW 10.3 Plant Net Output, MW 576.7

• Differential, MW -19.4

• Net Generation, MWH/yr 3,923,200

• Differential, MWH/yr -116,200

• Compared to existing cooling system (Exhibit 3)

F. Investment and Comparable Costs (1995 $)

Total Investment Cost, $ 91,100,000 Comparable Levelized Cost, S/Yr 33,500,000 Comparable Capitalized Cost, $ 143,000,000 The seperate component material and installation differential costs from Exhibit 29 (NDCT} and Exhibit 30 (RMDCT) are shown in Exhibit 31.

32

LIST OF REFERENCES 33

LIST OF REFERENCES

1. Jersey Central Power and Light Oyster Creek NGS "Alternative Cooling Water System Study", Ebasco Services Inc., November 1977: Volume I Executive Summary; Volume II Study Text; Volume III Discussion of Alternative Cooling Water Systems; Volume IV Discussion of Preferred Cooling Water Systems.

2. Information from GPUN, 1'. Ruggiero (GPUN) to F. Kuo (ESI),

4/7/92:

a. Expected Condenser Performance Curves (for titanium retubing), Worthington, Doc. No. E-147920, 10/17/75 b.. Surface Condenser Engineering Data, Worthington, Doc. No.

1-604949-951, undated

c. GPUN System Design Basis Document Circulating Water System, Doc. No. SDBD-OC-535, Rev.O: Section 4.2 Process and/or Operational Requirements, pp 56-65; Section 4.3 Configuration and Essential Features, pp 65-70; Section 4.5 Structural Requirements, pp 81-86

d. Replacement Power Costs ($/MWeH), 1991 to 2009, dated 5/1/91 (energy value and PJM capacity charge rate)

e. General Electric Turbine Generator TC6F-38 LSB, 1800 rpm 640,700 Kw:

1) Heat Balance, GE Dwg. No. 332HB796, 5/4/64 (100%

load output 640,757 kw at 6,509,130 pph throttle steam, 1860 Mwt reactor heat)

2) Exhaust Pressure Correction Factors, GE Dwg. No.

452HB158, 10/213/76

3. GPUN Information, T. Ruggiero (GPUN) to F. Kuo (ESI), 5/6/92:

a. Interest during construction, 10%;

b. Weighted return requirement, 10.78%;

c. Long term inflation rate, 4.1%

d. 1976-1980 Annual and Monthly Mean Water Temperature (Table 2 Duncans Multiple Range Test)

4. Oyster Creek NGS Drawings:

a. Flow Diagram Circulating, HP Screen Wash, Service &

Emergency Service Water Systems, Dwg. No. BR2005, Rev. 6

b. Main One Line Diagram, Dwg. 3001, Rev. 9 34

c. Auxiliary One Line Diagram, Dwg. BR3002, Rev. 14

d. General Arrangement; Turbine Building As Built, Dwg 3E-151-02-001, -002, -. 007, -009, Rev. 0 (all)

e. Site Plan, Dwg. 19702, Rev. 11

f. Site Plan - Topographic Survey, Dwg 19701: Sheet 5, Rev.

2; Sheet 6, Rev. 6; Sheet 7, Rev. 6; Sheet 28, Rev. 1; Sheet 30, Rev. 2)

g. Plant Elect. Generation, Main One Line Diagram, BR3001:

Sheet 1, Rev. 3; Sheet 2, Rev. 0

h. 480 V System One Line Diagram, BR3002: Sheet 1, Rev. 4; Sheet 2, Rev. 3; Sheet 3, Rev. 4; Sheet 4, Rev. 2

5. Ingersoll Rand Pumps, Gene Mills (IR) to F. Kuo (ESI), 5/12/92 (circulating water pump budgetary technical and cost information)

6. Marley Cooling Tower Company (budgetary cooling tower information):

a. S. Assman (MCT) to F. Kuo (ESI), 5/5/92: natural draft and round mechanical draft CT parametric technical and cost information for comparative study;

b. T. Dwyer (MCT) to F. DeSiervi (ESI), 6/3/92: budgetary technical, cost, environmental data for selected NDCT and RMDCT cases

c. T. Dwyer (MCT) to F. Kuo (ESI), ND and Round MDCT Noise Data, 6/4/92 (noise data for selected cases)

d. J. Van Garsse (MCT) to F. Kuo (ESI), Salt Water and Geothermal (Experience) Lists, 6/8/92

7. Engineering Weather Data, Department of the Army, TM5-785, 1 July 1978 35

LIST OF EXHIBITS

1. Oyster Creek NGS Site & Vicinity

2. Existing Cooling Water System

3. Condensing System Performance Summary - Existing System

4. Natural Draft Cooling Tower General Arrangement

5. Natural Draft Cooling System Flow Diagram

6. Natural Draft Cooling System Layout

7. CWS Hydraulic Gradient - NDCT

8. One Line Diagram - NDCT Power Supply

9. Circulating Water Quality Analysis - NDCT

10. Water Treatment System Schematic

11. Round Mechanical Draft Cooling Tower General Arrangement

12. Round Mechanical Draft Cooling System Flow Diagram

13. Round Mechanical Draft Cooling System Layout

14. CWS Hydraulic Gradient - RMDCT

15. One Line Diagram - RMDOT Power Supply

16. Circulating Water Quality Analysis - RMDCT

17. Levelized Energy & Demand Charge

18. Intake Water Average Monthly & Seasonal Temperatures

19. Ambient Air Temperatures

20. Turbine Cycle Heat Balances

a. Valves Wide Open Case

b. 100% Load

21. Exhaust Pressure Correction Curve

22. Natural Draft Cooling 'rower Parametric Data

23. Round Mechanical Draft Cooling Tower Parametric Data

24. Cooling System Material and Installation Unit Costs

25. NDCT Investment, Comparable Annual and Capitalized Costs

26. NDCT Economic Evaluation Curve

27. RMDCT Investment, Comparable Annual and Capitalized Costs

28. RMDCT Economic Evaluation Curve

29. Condensing System Computer Printout - NDCT

30. Condensing System Computer Printout - RMDCT

31. NDCT and RMDCT Component Material and Installation Costs 36

I Exhibit [

I Oyster Creek NGS Site and Vicinity I

IX In I I

,7

- gm - F - - mm- am a = - cm 4.Ci~RcuT%.J~r WATER 82 PUMPS Oo~~BARNEGAT 04 5.O1tuTorlo Pumps t.Ac"~ tGa.000 s PM I BAY cn en

EXHIBIT 3 Condensing System Perrormance - Existing Cooling System SPICI8SCATIONS 101 CASE M. 1 9IZSTlK4 oAC! TSOeu90 COOLILS VATIC SSTEMI "Al tI A A JUSTO 06/15192 PAGl I IC Ituir *t1ZC1 ItEItRATUAl Cl) 32.00 PgIOAmACue ar , *0321 COS IIITZONSI kO. OF COOLING TOViINl-t 0 CsnEASI*tA tNPiSATUtAAI.1181 t CII tA P4t..t..TTP .. CNVI. _ - *16.81 . ,_ t atLu sFo CT TOBt ISAM1EIca (cINCNISIJAUGI 0.873122 ATYE41SN9312 FI P1U11 4hA.ACA 2.a4 CT mE3111 ArPiGA61 TaIN'it)" 0.002 TOTAL TUAS LIKST1 (Pt/IIILU 42.S0 TOTM Cl FAK ROTOR INPUT Kc no. 9ft TUBES PR1 21CLLIINALLS 143.TOTAL CO PP ,AINPOT. Si. 31641 No. Gs IuMt 10ASSSPRESS 1OItS II PIRtOFONNCE AI A At SU6AWi TRW IV A'W MOTORmATIN$ScaP$ 10co TOTAL 504FACt AtA CJa IT) 1210t0 To CAPAVZtLIl NMi) 410.1t CV STYTEM TIM (113 2J.53 CIRCULATZIN VATER FLOW YGPN *A 2.97 CO NASAM CONOMITS.bI CFT1 - so4s TUNE "L. AT A3018 CW ILO" CIS3) A.Z? MO* of Cis PUuS a AV8 SIAS0MAL :IV# PIIS Iza.a.tAJ1.07 1.30 2.27 T* CAPABL. O YA D.O. 'Inr) 0.0

.I1._ __L*..4~J .. L.......Z..N.Z. X.A.L..2.. ^ S.S..T.,.1.* I - C 1 s~ T -,t A0 IOOATY RATtfitL COST io &T3 INSTALLATION COST aSCALAT ii 1 0 00 CONE INITIO. ANTWIpENrI CesT ITETS UNIT TOTAL 10001 UN I TOTAL 1000 RATIRIAL IASTALLATIS3 RA4.10 SITE *VIVLIPININT . - ----- ~ *0 a....-

1.t1 'LOCAL IAtOUIWte 1t SJTS-cLIAiiQ= DSIACKC 0-2.1 LOCAL CMAOING 0.-O0JCv ct 0 0

_t__f~____ ot ro ___........

eotuItD___0__ 0°...

3.5* zwr~cE zrauCtusi 0.001/cu IF 0 O.CSJCU it 0 a 0 3.2 CIRCULATINg VATIR CONSUtt: MAIN OSIIU IT 0 O.oos1Ltu PT O a 0 Aell _ 0D~LI t °- OOoI I .t~rr_ -. Q- ,_ -- -- o

-P.

7.32 *ISCHARSE STtOCTURI 0.*0D Cl FT 0 0:.o$cu i a a a A

3.41 OOLSN TOWtI SASIt 0.005S/1 tl 0 0.001130 It a a 0 3.44 . COOLIJS TOWSA t t 5urt .... r., C ... t..'.' . ' OS/lAC-- - --. o.... D° 5.1 TS BUULDINS 9611iSA(TIAL) SIFT? ii 0 01/1r NT 0 0 0--

4.15 Ts PCOSSIAL (SIrPRtETIAL) OWI/T Ut a 01FT kT a 0 0 7.1 TS I ACCESSONIS ClIfIgIAtSAISL. .T.SOSIVA a 0.OcSf/TA . 05 a

10.315 COMP1k11 sHE$1LL 0)/ACK a Os/lACM I a a 10.213 CONOENSESTUeS (TITANS 000001/pT 0 0.00001/FT I a a

_te.121 ... CIACVLAT:VG-VA~t1ArzP? OX^Kt____JICet.

13.2 Uc3 uAtZNS ID.UA tu/r rttoA OSttACHt#. a /IACH D O . O 14.1 INSltUACKTATION t CoNTROt 0.00J1tACK t O.O1I/4ACU 0 a o t5.11 StA3T-UP 9 3TAUNDY TAlNJPOINI .CPJ tA) . OrVA . 0 osr"VA. .. D, _,.O a.

13.12 UNIT AUZILJAMT T*ANStOINIt lSZPMAXIIA&1. USIAVA 0IRVA CVA 0-V e0 0o 11.21 CAIIULATIK WATL1 XMITC1S4AM USIPUMP 0 011P~v 0 0 0

.13.4 VINING FOR CSICUI.ATINS WATgX.STSIN.-- _ . AIRA ... S list/A . 0 .

51. UNIT SAIN POVKK TNAASF02NEO CBMII*I*NTIAL3 S 0* 1D,4 o0 a 13.23 FAN Noro5 rovia ((MIEns ~ I.-& spaItA IUEN01loTE C)SCA11 V0, 3citrCE a a TOTAL -. --. o0 @. --.-- 0 .e 00 - o TOTAL OINCCr ISCALASII COST9.ATCISAL.PLUS - 3SALESIVSCt TAX PLUS IMSTALLAUION - i ustIANCT C0IIITRUCtIIM COST INCLUSING PRAOFI9StIAL SItvICUS 0 COSSTTItNtC M1A.CK1 JI OItECT PLUS iaitatcr COST) 0 UTILITYS EIPENSCS. INTIRlST. WRINA COUSTOINCTI4S. I LANb 0 TOTAL ESTtRATIO INVOSTNtNT COST 10081 0 1 s T t a A I I I C 0 N P A t A I L I I i V 8 3 T rJ tE AT I A N N L A . C 0 1 T i IOOOIJTI KILLS/IN UOly NEK CAPASIL. VIStfISI (kV) 421.5 411.9 403.1 3 S1. CO SWTITC PUlL COST 1EAS VALUE) 0 I...0 1FISCRATIL. UNIT A1T CAPAOLtTr Bm .. G._01 o o._ ANIIUAL.lAJN CbAAItS CAT BAlI 0.2Z251e.

• VAiTR COS tA7 O.SAILLIUN SALOMS *- CXiNICALS) a

• IWT NIT AbwUAL &CANEATIZON ("WINT*/ 40"42129 RA1NT9N4C1 I 0.001 of TOTAL IRV

• 9I1AR) e WATER CONSUAPTION (NILLION ALLONITr3 O TOTAL AkkAL UNIT i;#L COST

.- . - ..... ......~....AbJITNIlZI~.OZPI~lb~hLCAPL3ILITY*

ANJUSTNItNT t0NtIPI rtAt InAL KIT ANNUAL

'; '- *O *-'0 CAT D.0000SINALLION OT0) (10DOJS 0 TRIAL CONPANABLf ANNUAL CStl INCLUItOA APJONIstCTS

-. TOAL.COIIPANALI. IWIvSTMIAT. COST.....- 1%.AUL41 IAIA.~hIL~tl O C.M1A SAITIN .. P.....- .--

SWCtUAlas CAPASIL3TV ADJUSTAINT ONPAA I PIAOIt T/01 (005 IP XCL. AOJI2INETS 0.000 39

EXHIBIT 4 Natural Draft Cooling Tower General Arrangement Ebow SpedficatIn 54- 79 Nabm Daft Cooing Tower (Comunrnow iype - Typical)

FOUNOATION SING FOOTING U1-6 40

- - - - - m - - - - - - - - - - - - -

vqAkVT

4. Ctlru TII4Cx LA.b SOOSTEZe PUMPS II

-A--

EMSTIG COOEN,5eS c eXIST ILU~t~J XIST.U PUMPS TURDINE 11_

bitocG'. CLO11,9 coo-Ima' WAXF-FSY FEM

I I EXHIBIT 6 Natural Draft Cooling System Layout I

I I N I-Iv I

I.

I I

I-I I~. . 5agsl I

1 I 42 I

EXHIBIT 7 CWS Hydraulic Gradient - NDCT 43

EXHIBIT 8 One Line Diagram - NDCT Power Supp1V 34V kV SDyo ASWv 3jqgJ xS a.t A .A LJAM.D5 SAA EXISTI04& L,4 tcI AN Aflo *tic§ K t"^ .o oAes )00 )#s^e CW4p I c'Vz c W3 c-6.JT.

-~~~~V -N-E W--

526A l }t i ^4sS-v taocA 7

&4UP caP icu A4 P . eC (e l' 1) 1

• 66 4 6So r^ 6 6 Bow CWP kwp WA M*.v Tr or*M tult 6v ;

or 4 W4 e, Cr d MZA5 fiJy OVO) ?i ( trwA) 44

EXHIBIT 9 Circulating Water Quality Analysis - NDCT COOLING TOWER CALCULATION Calons Raw Water Conce Racic Wtr Cancan Sal~s la CaC= in Ions asCaC0S AMSENT CONDITION 8g V*

ppm ppM ppm ppm CalkIum 150 448.18 360 897.76 RECRCULATION RATE 418,200 GPM Magnesiun 375 1543.21 750 3086.42 INLET TEMP T1 86 'F '

Pobtsumn 256 327.37 512 654.73 OUTLETTEMPT2 106.2'F '

Sodim 8033.62 17464.39 16067.24 34928.78 TEMP DFF. 20.2 F WETB" TEMP 74 'F TO tatlons 6844.62 19783.84 17688124 39567.69 EVAPORATION RATE 7.491.60 CPM CYCLES OF CONCEN 2 DRIFT 4.16 GPM Blkarbonate 42.7 35.00 70 57.38 BLOWDOWO 7.47.44 GPM Carbonate 0 0.00 0 0.00 MAt(EUP 14,98320 GPM Sufate 1816 1889.70 3544.12 3792.01 Chloride 12680 17859.15 25360 3571831 Flrade 0 0.00 0 0.00 Nitrate 0 0.00 0 0DI Total anions 145387 19753.85 29074.12 39587.69 SNkcppm 18a 14.94 35 29.88 hIn. ppm 0. 1.07 1.20 2.15 Manganese, ppm 0.01 0.02 0.02 0.04 Cabon Dioxide. ppM 7.84 8.93 2.00 2.28 Alumrnwn. ppb 0.000 0.000 Cadmknn. ppb 0.000 0.000 Copperw ppb 0.000 0.00 Chrornlnu, ppb 0.000 0.000 Fluorine, ppb 0.000 0.000 Nick, ppb 0.000 0.000 Vanadirn. ppb 0.000 0.000 Zinc. ppb 0.000 0.000 T degres F 65 106.2 TdegressC 18.33 4122 M alfaiaity (CaC03) 35.00 5738 pH measured 6.95 7.66 Netral pH 7.11 5.75 TDS. ppm 23409.768 4W80258 Langlier idex -1.39 0.48 Ryvnr Index 9.73 6.73 Ushing the LI.Ths water Is Corrosive Scala Fotng Concntradotfn aor 11.01 5.1 1 Conductivilyomicrohiskm1 29630.65 99251.04 Cycles of Concentration 2 SulutIcacidd frqWed 1191.53 LBS/DAY 81.08 GALSIDAY Sodium for balance 8033.62 45

EXHIBIT 10 Water Treatment. System Schematic Diagram NDCT and RMDCT 46

EXHIBIT 11 Round Mechanical Draft Cooling Tower General Arrangement Th~ Sp~ifimiam MLwoichs Draft Ceo1ng Tow" 1comnudrlow Type - Typkal Round Corau)

"LVAWZLO STEE ALL AROUND PiC3( di

~I I WI~I-Hi I

0 AJCESS HATcH m 7AM Dact oOfs-l

_=- I (0 IO - I I.mRn a---

ACCIS AWT FAN DMC FAMSNO....

TO FAXtC - i f ee. I HALF ELtVATIO HALF SECTION n-10 47

_' _ _, _ - - _ _ _ _ e _- _-

TOTALt VAPORATtON R

RR R R R VO U NP taFrT t~ t fi4k)4 COOc 1CG %C&L Towlts 0

/ I /)I my{ _-

P 0D I0 n

CIRCuLA.tHI4 WhMEt PumFs g1:

Cu m on-btj

~-

1.1-imt .-

ch EXIST VILUTIO'4 PUMPS -L,_

EXHIBIT 13 Round Mechanical Draft Cooling System Layout I

I I.

I I

I I

I I

.Ii I-I II 49 I

EXHIBIT 14 CWS Hydraulic Gradient - RMDCT UPI Im 1BCyl Kipilf f j ipig I'4i7 EL. DC.wP Tra CTh*

70 _

WApb

~

lo_.

to -

0 -

_to -

eI14r a

-artst[I I 50

1I EXHIBIT 15 I One Line Diagram - RMDCT Power Supply I

I 34S W Si -3'4. V0 54A t

I t V- *4 UA. t^"A , s P4.%

XFiPi xS I I It R5S'T~

4ri 41A _l JX I 14V s 1n )

z4. _ . _ iT;~ .I ____.

II .4T cA:

I4P C~Z

-3 -oA C..P~CJ~

c osz A;I1-st a e I

126oA I ~i .ILwvre VI, SWCA . 4, tbo6P :St-I V266A I A I) I I)-

2boo WA kt .BC 4Cwp 2Mb0 WA 14 *. %L L S 4 I_&OsAl

.fly31$

qGV.o 2 1 wo.a 1 -

4." or

-OY/a

41. 'I . I 4 IJ CM%

I 2 eovZ":lI Ih I w - ML I I I I qS64 #*a%?

1, I) I) 1) I)

II 6 n0P MOYp (T)

-ff1t I6 ISTOZ&I 6 I O rcoP "wV S P're)l C7vT(7VtS (Tyv 0 0 it* v 0-la cmT 460V IM.A CMt'

)

I)~ 1 4zoa cr WP) C1' Pyi CT(

c.

('ryp ) t lry!) (Tvf )

51

]EXHIBIT 16 Circulating Water Quality Analysis - RHDCT COOLING TOWER CALCULATK C nomRfc V tr Concen CZk awar Us CoOW asais as Cac3 AMBIENT CONDtTJON . 9 .F CRWC PPm wn ppn ppm 373,100 GPM CRIutm 18 44688 360 897.78 RECIRCULATION RATE 375 154321 750 306&42 INLETTEMPtI 34 -F mapflsJkrt potasshm 258 327.? 512 6573 OUTLET TEMP n2 10b.5 'F S adbxn B5.52 1748438 i6067.24 3492078 TEMP DIF 22.65'F WET UL TEMP 74 'F Total c s 844.62 19783.4 17689.24 39567.69 EVAPORATION RATE 7,685 3PM CYCLES OF CONCe4 2 DRFF 3.73 GPM BJCa8bxnalk 427 310 D 70 57.38 BLOWOWN 7.6813 GPM Carborgi* 0 a 0 a(km MAKEUP 15371.72 GPM Sdta m181 tS71!5

' 3844.12 3792.01 Chbade 12a80 2530 35718.31 Fkwde 0 3 0 0.00 Ntrd 0 0.0 ToUa amI' 14538.7 197am 5 29074.12 35567.59 s$c ppm la 14.1 4 36 29L68 Iron. ppm 0.8 t.O,7 1.2 2.15 Mm~gnewo ppm 0.01 CO; n 0.02 0.04 Carbon doxlde. ppm 7.84 3 2.00 2.28 m*WM ppb 0.000 0.000 Cadm. ppb .. 000 0.000 aLooo Copp. ppb 0.000 Cv*Wm^ pqb QCOO Fkuodne. pPb Qmo 1ca ppb (lOw 0,000 QOX V bwkmXpb 0.000 Zhe, ppb 0 000 o om T degrm F 85 108.6 r dore" C 18.33 41.44 M kflt (A= 35W.w 57.38 pHwead a8.9 7.68 Nevtfl DP 7.11 6.75 TOSM ppm 23409766 4U02.5 LaoeWkW= -1.39 Q47 RyzM kW= 9.73 6an2 UmknVW LI-Tis wmWI Coaro" Scain Fanning ConcwaIanktdor MO.1 5.11 Comydtlaoim alafl 2963065 9#24.09 Cyckm or Conbon 2 Suwt a dirwd 12m.43 L 83.1 oGALSDAY Sodkm foabac 603.62 52

EXHIBIT 17 Levelized Energy and Demand Charge Rate of Return: 10.78%

Energy Capacity Present Year Value Charge Total Wrth Fct Value 1991 28.00 7.25 35.25 1992 28.90 7.63 36.53.

1993 32.30 8.02 40.32 1994 32.90 8.44 41.34 1995 38.20 8.89 47.09 1.0000 47.09 1996 42.40 9.41 51.81 0 . 9027 46.77 1997 46.20 9.96 56.16 0.8148 45. 76 1998 50.00 10.66 60.56 0.7356 44.55 1999 55.50 11.21 66.71 0.6640 44

• 29 2000 60.60 11.90 72.50. 0.5994 43.45 2001 57.30 12.65 69.95 0.5410 37.85 2002 71.00 13.46 84.45 0.4884 41. 24 2003 78.50 14.30 92.80 0.4409 40.91 2004 88.20 15.20 103.40 0.3980 41. 15 2005 96.30 16.15 112.45 0.3592 40.40 2006 103.50 17.19 120.69 0.3243 39.14 2007 113.00 18.31 131.31 0.2927 38.44 2008 117.50 19.50 137.00 0.2642 36.20 2009 144.40 20..74 165.14 0.2385 39.39 Sum 8.0637 626.63 Levelized Replacement Power Cost = $ 626.63 Mweh / 8.0637

= $ 77.71 / Mweh Reference #2d: Informatiom from GPUN, T. Ruggiero (GPUN) to F. Kuo (ESI) on 4/7/92. Replacement Power Costs ($/Mweh), 1991 to 2009, dated 5/1/91.

53

EXHIBIT 18 Intake Water Average Monthly & Seasonal Temperatures hven Year 1976 IlZ7 1978 1979 '76-80 Annual Mean TemP. F 57.9 67.4 56.3 58.5 56.5 57.3 Monthly Average Temp. F January 33.1 32.2 34.9 37.0 35.4 34.5 February 39.4 35.8 34.5 34.5 33.3 35 . 5 March 48.2 47.3 41.7 47.7 39.9 45.0 April 57.9 57.4 53.2 54.3 53. 6 55. 3 May 68.0 65.1 60.3 66.4 62.8 64.5 June 78.4 70.5 73.2 74.8 70.9 73. 6 July 80.1 78.4 77.0 77.7 79.2 78.5 August 79.9 79.5 78.8 79.0 79.7 79.4 September 73.9 72.5 69.4 73.2 75.6 72. 9 October 58.8 58.1 59.5 61.2 60.6 59.6 November 44.2 51. 1 51.1 52.9 46.2 49.1 December 32.2 39.2 40.3 40.6 38.3 38.1 Seasonal Average Temperature. F Summer 78.1 75.3 74.7 76.2 76.4 76.1 (JJ,A,S)

Spring 55.5 55. 8 53.2 56.5 52.7 54.7

/Fall (MA,MON)

Winter 34.8 35. 7 36.6 37.5 35.7 36.1 (DJF)

Reference:

The Ichthyofauna of Barnegat Bay, New Jersey -

Relationships between Long Term Temperature Fluctuations and the Population Dynamics and Life History of Temperature Estuarine Fishes During a Five Year Period, 1976-1980 by James J Vouglitois Thesis submitted to The Graduate School of Rutgers, The State University of New Jersey, January 1983.

54

I EXHIBIT 19 Ambient Air Temperatures Dew Point Dry Bulb Wet Bulb (F) (F) (F)

January 20.2 28.1 25.0 February 28.4 36.7 33.5 March 29.9 41.2 36.7 April 39.5 51.3 45.0 May 50.3 61.3 55.0 June 59.6 71.0 63* 5 July 64.7 76.8 68.5 August 64.1 74.2 67.5 September 57.5 66.8 61.0 October 49.3 57.1 52.5 November 39.7 47.5 43.2 December 29.2 37.5 34.0 Cooling tower design and average seasonal wet bulb temperatures used in determining circulating water temperatures are:

Amli n t Cond +i tio n Wet Bulb Temp. F Cooling tower design 74 F Average summer (Jun, Jul. Aug, Sep) 65 F Average spring/fall (Mar, Apr, May, Oct. Nov) 47 F Average winter (Dec, Jan, Feb) 31 F

Reference:

National Climatic Data Center in Asheville, NC CD-144 Format 1981 to 1985 for Atlantic City, NJ Airport 55

MMmm -, mm- i-1111111 - -I-F 1 -

CALCULATED DATA

• NEOT GUAtAWMr D S6L Ult tit ZttbIA* Ratlng w %araStandl to 1* 5,s07. 10!pit. with aeteea! &

Plow el £t,917.771Hwr. at inlet eam eanditeas of 110 PSIA 0.ZUV M. To sent*`.

that two turbin, wMI pass this flows Cnsidlering vautation. otaflow coffleleetsfrom 1

, ,SA #I"& saw 419.44- expeted4 vales, whop leferance oi drawisg areas ate, which may afloct the rlew0 1191.t1 no.2%M

_t__ tbrhie toI betimn designed for & Design Flow ofittting Flow *S') 6,S134,11001r.

0

_________________ & .oerr s~pen~ln Ctcl Flow etf, 254, 005 11/r.

R P '.Flow. *:I C D t "A*fr.

H Sepaa2 s M. H 2SF Tvaper 4--e IZ79 1V1 H - P t&4, '

b.4

~ i *ew, U>/Hr.

P

• Pressure, PSIA I I R 0 er a.9 ITIV

• 513.0 r a Temperalstoe r d*amp**

v-

1. . .

_CI ..

cowdsAne P 4s0.2 r 33.4 110 . . .

'4 *4

. 0 .9

_;- Cenerator Output 410 005 KW M 0,$s 1impi Pr -

a V. 0 CW 0 . O

. De 0 .oo^* Al - . .*...0 J 45 PSIC HI Ptess3 S.! p .

0 o00. 0.0 J ~~ *0-

" 0 11720 XW4N 4eck. Losa os F . . U -_ -- -in - 0 P. .* 7173 KW.C 5n. Laa a OI I.. _ 'a U

I 6*j_

C1 4,442,1 tn _ 22,7409 1043.5 N ICLEP a u 3H 0 M '1.3H4 7, 259,0009 0 0a 0 lol

• (

D 8 ST TO EO e- S Ceo o-pi

) p4 r9 -- _

• V. ^

C1

,a .

C r-C0 0a -v v

~ t . iI C- .9t Z 4.

1. -

p.. l 0,

.9 11.d 20OCM _  ;

-1 F. 210 it.

I F I 1 I 7.*219,009 4 g,

_______ .ItVP .3'.P.

315. t F_

2IV.3 h

,14. F h 2 oS 1 3 l 5.9 D I r43.92 ~ colol,64Duives 1s.1h132.t h 5K.S 1 tis*O .4CAT ItA IM1 *.!.t 4 .kO I_ U - flM.)1 10.0O0 i. . .91197 BTUIXW.Hn

mM l _- M_ mm- - - - - -

M

_ at, qV.& *&a w * &to &fl

'In__ N . 121M 1101 tet.I. 5 T ie.

&70 Twsis.

as* or 3g 1~~ M~tsiCRIA Reho1erSP H . pv4u1jir I

41I I---- P~a.~P~sr. "0P .I 60 .01 Generamto Omilptl

£40,151 Kw 0.933 jimp.1 P7 44 PS10 HI Pues.:

P.. ; JH . A5 o -d P.O

.3 I.. 1720 Kw4.1gcb. Leff 7£73 XW-Coii. Laos

'LI .1

.4

.1 .- 1 A

1 xp- vu~. i 0 Zion*a f32'"of r P,.

. . . ! b A A Oa '-I LLR0 O0 01

.4 a I01 240 2Rk0 "

II

• 0.

I 4 .8TO

• • a

.I . a 11.0-X I t sm ri .l521.T11 te i.12.7701 ta.I .,r V14.IPRIP. . 4409p izaot2r&.7 s53,r

,secret RoA Drives GROSS JeCAT PATC. 4,97, n 11i91.2 - 3S3.7)

• 10,000 IZ61.9 - 4i.9l) a 1331 BTUJXWI-HI 640,117 .

EXHIBIT 21 Exhaust Pressure Correction Curve 6Sl.70 KIu I.() IN. HO. pBS. 0 PCT M TC5F-38 IN. LS8 I800 RPM 950 PSIG 1191.2 H 0.28 1

_: -t- s 4

,..a._

8. _:r.

.4 44.  !;< & i

.t. ,., __ ^ _ ... i

_^I r . ____ I' -

sw US 6509130 LBS/M

~sj 1. .i .4~. r1.(.,* I .  !'-l** z..

. ..z.:. 6635WLD-b_,@ , . * ._ _

.. .  ! 1./ -- _s...1 H-.

,_ s r i:_*:

a US tl , j L  :-§s L LI::i :': ylla t~  ::'Sl St SXl~..,.<

Z

_e  !  !- -*

I@5t1g141 L!-!t' tilg~ l'J'@@@

l}t. -

,;~IiA

I:i: Id. ::s -: l:;,.: V1: :! - ,i:'I

'i- .l1.

:.:l '1-:t!,lt'i'll_ ..

0.00 3.00 2. 00 1.00 EO 5 . 00 EXfHAUST PRESSIURE- IN. HG. AS .

HET1H OF USING CURVE FLOWS NEAR CURVES PRE THROTTLE FLOWS AT 950 PSIG 1191.2 M TKESE CORRECTION FACTORS ASSUME CONSTANT CONTSOL VALVE OPENING APPLY CORDECTIONS TO HER.T FATES'SNO KW LORMS AT 1.0 IN. RG. R8S. SNO 0 FCT HU THE PERCENT CHAtGE IN KV LGOAFOR VARIOUS EXHAUST PRESSURES IS EOUPI TO (MINUS PCT INCREASE IN HEAT RATEI 1O,/(10

• tCT INCREASE IN HEAT RSTE) a THESE CORRECTION FACTORES ARE NOT GURRANTEEO GENERAL ELECTRIC COWPNi'. SCHiNECTFOT. NEW TOM 57

EXHIBIT 22 Cooling Tower Parametric Data - NDCT Heat Duty, lOE6 Btu/hr 4300 Design Wet Bulb, 74 F Cooling Water Seawater Range, F 16 16 16 16 Approach, F 10 12 14 16 CW Flow, gpm 554.,100 554,100 564,100 554,100 Harley Model No.

Number of Towers Diameter, ft Too difficult for natural draft cooling tower Height, ft Pumping Head, ft L/G Ration Evaporation Loss, x Price, $ million Range, F 20 20 20 20 Approach, F 10 12 14 16 CW Flow, gpm 443,200 443,200 443,200 443,200 Harley Model No. 8600237 8550232 8550222

-5.5-410 -5. 0-406 -4.5-369 Number of Towers 1 1 I Diameter, ft Too 415 411 374 Height, ft difficult 600 550 550 Pumping Head, ft for 42 42 38 L/G Ratio NDCT 1.803 1.87 2.04 Evaporation Loss,  % 1.8 1.8 1.8 Price, $ million 23.11 22.25 19.61 Range, F 24 24 24 24 Approach, F 10 12 14 16 CW Flow, gpm 369,400 369,400 369,400 369,400 Harley Model No. 8570237 8550237 8550227 8500212

-5.0-410 -4.6-393 -4.5-352 -4.5-3xx Number of Towers 1 1 1 1 Diameter, ft 415 398 356 338 Height, ft 570 550 550 500 Pumping Head, ft 44 43 40 38 L/G Ratio 1.46 1.52 1 .69 1.89 Evaporation Loss, X 2.2 2.2 2.1 2.1 Price, $ million 22.725 21.215 18.48 16.56 Reference 6a: Marley Cooling Tower Company, S. Assman (MCT) to F.

Kuo (ESI) on, 5/5/92 - Natural Draft and Round Mechanical Draft CT Parametric Technical and Cost Information For Comparative Study 58

I :EXHIBIT 23 Cooling Tower Parametric Data - RMDCT Heat Duty, lOE6 Btu/hr 4300 Design Wet Bulb, 74 F Cooling Water Seawater Range, F 16 16 16 16 Approach, F 8 10 12 14 CW Flow, gpm 554, 100 554,100 554,100 554,100 Harley Model No. 8294 8262 8242 8242

-6.0-16 -6.0-16 -6.0-16 -6.0-12 Number of Towers 2 2 2 2 Diameter, ft 260( 234 219 219 Height, ft 67 64 61 60 Pumping Head, ft 43 40 37 36 No. Fans/Fan BHP 16,193 16/193 16/192 12/193 L/G Ratio 1 .367 1.592 1.824 2.066 Evaporation Loss, % 1

• 5) 1.5 1.5 1.5 Price, $ million 26..55 21.51 19.01 18.8 Range, F 20 20 20 20 Approach, F 8 10 12 14 CW Flow, gpm 443,200 443,200 443,200 443,200 Harley Model No. 82633 8233 8214 8216

-6. 0-16 -6.0-16 -6.0-16 -6.0-12 Number of Towers 2 2 2 2 Diameter, ft 235 212 197 199 Height, ft 66 62 69 59 Pumping Head, ft 41 38 36 35 No. Fans/Fan BHP 16/ 192 16/192 16/192 16/192 L/G Ratio 1.247 1.46 1.669 1. 887 Evaporation Loss, % 1.*9 1.8 1.8 1.8 Price, $ million 21.9 17.65 15. 916 15.49 Range, F 24 24 24 24 Approach, F 10 12 14 16 CW Flow, gpm 369,400 369,400 369,400 369,400 Marley Model No. 8233 8209 8210 8194

-6. 0-16 -6.0-16 -6.0-12 -6. 0-12 Number of Towers 2 2 2 2 Diameter, ft 212 193 194 181 Height, ft 63 60 59 57 Pumping Head, ft 39 36 35 34 No. Fans/Fan BHP 16(192 16/192 12/192 12/192 L/G Ratio 1. 174 1.373 1. 569 1. 768 Evaporation Loss, X 2.1 2.2 2.1 2.1 Price, $ million 17. 65 15.41 14. 78 13. 3 Reference 6a: Marley Cooling Tower Company, S. Assman (MCT) to F.

Kuo (ESI) on 5/5/92 - Natural Draft and Round Mechanical Draft CT Parametric Technical and Cost Information For Comparative Study 69

EXHIBIT 24 Sheet 1 of 2 Cooling System Material and Installation Unit Costs

1. Major Site Development Units Material Installation

a. NDCT $1000 12,600 5,900

b. RMDCT $1000 12,800 6,200 Includes capital cost for general clearing and grading, maintenance roads, lighting, cathodic protection, condenser tube cleaning system, valving facilities, power wiring to pUpMS, instrumentation wiring and controls, and water treatment facilities (e.g. make-up water clarification and blowdown sludge removal).

2. Circulating Water Pump Intake Structure Units Material Installation

a. NDCT $/cu ft 7.72 20.25

b. RMDCT $/cu ft 7.72 20.25

3. Reinforced Concrete Pipe Units Material Installation

a. Pipe Dia: 72" S/ft 206 403

b. 84" S/ft 276 459

c. 132" g/ft 458 696

d. 144" $/ft 521 733

e. 150" S/ft 553 752

4. *CW Pump Installation 10% of material cost

5. CW Pump Motor Installation Cost 4% of material cost

6. Cooling Tower Basin Excavation Grading & Backfilling Units Material.Yslat

a. NDCT S/cu ft 5.95 36.54

b. RMDCT S/cu ft 7.79 44.21

7. Unit Auxiliary Transformer Units

a. Material $/MVA 12,619

b. Installation $/MVA 2,260 60

EXHIBIT 24 Sheet 2 of 2 Cooling System Material and Installation Unit Costs

8. Power Cable Ma' teerial Installation

'MVA/ft) ($/MVA/ft)

a. HV Cable to Intake Switchgear * *

b. Cable from Intake Swgr to a CWP * *

c. Cable from Power Center to a Fan 140 234.7

• Included in major site development

9. Control Wiring Units Ma1.terial Installation

a. Circ Water Pump $/pump/ft

b. MDCT Fan $/fan/ft 2.25 10

• Included in major site development

10. Instrumentation & Control Units Mal Lerial Installation

a. CW Pumps $/pump 9,400 4,600

b. CT Fans $/fan 2,600 1,900

11. CWP Switchgear Included in major site development.

12. Fan Power Center

'Units

a. Material $/Cntr 291,000

b. Installation $/Cntr 19,000 Nine fans per power center. Includes transformer, breaker and required switchgear.

61

EXHIBIT 25 NDCT Investment, Comparable Annual and Capitalized Costs Cooling Water Condenser Tube Investment Annual Cost Capitalized Approach Water Velocity Cost w/Adjustment Cost F _ _ ftlsec S1E6 $1000 S1E6 12 5.00 95.29 34230 146.16 5.20 96.49 33921 .144.84 5.40 97.44 33694 143. 87 5.60 98.72 33622 143.56 5.80 99.56 33493 143.01 6.00 103. 33 34173 145.91 6.20 105.27 34439 147.05 6.40 107.08 34721 148.25 6.60 109.30 35146 150.07 6.80 110. 92 35515 151.64 7.00 113.06 36082 154.06 7.20 115.72 36810 157.17 14 5.00 89.10 34435 147.03 5.20 91. 69 34486 147.25 5.40 93. 66 34443 147.07

5. 60 95.89 34536 147.46 5.80 97. 62 34608 147. 77 6.00 101, 83 35400 151 .15 6.20 104.01 35721 152.52 6.40 106.04 36057 153.96 6.60 108.46 36533 155.99 6.80 110. 86 37047 158.19 7.00 112.93 37515 160.18 7.20 115.41 38124 162.78 16 5.80 91.58 35100 149.87 5.60 90.06 35164 150.15 5.40 88.46 35269 150.59 5.20 86.44 35351 150.94 5.00 84.84 35618 152.08

6. 00 95.23 35642 152.19 6.20 98.47 36117 154.21

6. 40 101.68 36647 156.48 6.60 104.22 37066 158.27 6.80 107.10 37654 160.78 7.00 109.37 38125 162.79 7.20 113.31 39060 166.78 Note: 1995 dollars;for computer printout see Appendix B Sheets 1-3.

62

- - w--- - - -

EXHIBIT 28 NDCT ECONOMIC EVALUATION CURVE 180 170 160 4-.

0 (i 150

-o N

0 140 a.:,

En

_ 0 C

130 I-4-A 120 C

E u) 0 110 0)

C 100 90 80 5 5.4 5.8 6.2 6.6 7 Condenser Tube Velocity, ft/s U1 invest S - 12A + Invest $ - 14A ° Invest $ - 16A A TCopz$- 12A X T Capz - 14A V T Capz t - 16A

EXHIBIT 27 RMDCT Investment, Comparable Annual and Capitalized Costs Cooling Water Condenser Tube Investment Annual Cost Capitalized Approach Water Velocity Cost w/Adjustment Cost F ft/sec _ -IE6 $1000 $1E6 8 5.00 94.26 33735 144. 04 5.20 96.49 33921 144.84 5.40 98.60 34279 146.37

5. 60 100.94 34753 148.39

5. 80 103.00 35189 150.25

6. 00 106.13 35994 153. 69

6. 20 108.25 36571 156. 15 6.40 110.38 37184 158. 77

6. 60 111.84 37654 160. 78 6.80 113.56 38227 163.22 7.00 115.07 38774 165.56 7.20 118.04 39735 169.66 10 5.00 88.51 33876 144. 65

5. 20 90.23 33879 144 .66 5.40 91.37 33797 144 .31

5. 60 92.83 33870 144.62 5.80 94.54 34063 145.44 6.00 97.27 34692 148.13 6.20 98.63 35011 149.49 6.40 100.41 35472 151 .46 6.60 102.22 35980 153 .63 6.80 103.73 36470 155 .72 7.00 104.83 36894 157.53 7.20 107.80 37841 161 .58 12 5. 00 85.64 34373 146.77 5.20 86.95 34334 146.60 5.40 87.86 34296 146.44 5.60 89.24 34440 147.05

5. 80 90.49 34602 147 .75 6.00 93.28 35141 150.05

6. 20 94.42 35258 150.55 6.40 95. 99 35538 151.74 6.60 97.62 35879 153.20 6.80 98.59 36179 154.48 7.00 99.88 36590 156. 23 7.20 101.62 37154 158.64 Note: 1995 dollars;for computer printout see Appendix B Sheets 4-6.

64

- - - - -m - - - - - - - -

EXHIBIT 28 RMDCT ECONOMIC EVALUATION CURVE 180 170 160 4-.

(n 0

o 150 N

4-0 140

. _i 0->

o_ = 130 O.-

0_, 120 E 110 100 90 80 5 5.4 5.8 6.2 6.6 7 Condenser Tube Velocity, ft/s 0 Invest S - BA + Invest $ - 10A ° Invest $ - 12A A T Capz S - 8A X T Copz $ - 10A V T Copz $ - 12A

EXHIBIT 29 Condensing System Computer Printout- NDCT SPICICATIONS, FerttCAIl nO. 'I NTNIAL HIT5 CsO1S1c TiMID -AStIV RIBOTI MAE AIPT A J 1,SIO esJ1019Z PaSA 7 CV ItCiT *t11 TIfIPSMAtE (S) 86.20 PFAIRANACt Al MtISS C0JtNTIGMu3 fe. OF CIOIIS 71tIc-?t I COaksWINS& 1[NPSRAT 9*RIS 31 1) . 29.23...7.CAPSLT.(V. A05 79.* ., .  ?-O.jPffjLk Pin el 0 TUBA BIAMTCS (INC115s1GAIM4 0.81s 22 Avg c. a'514113t swS * -l°S 3.11 CT A7Pr TblefI.r0cr serAc tIt LtKtM CFTISNCLAL) 42.50 rernt CT FAA rorou INrcT XV a NP...O)JUISP1SNLUSSLS.- 'ui--~-- -- _.97JALNLq j.EjJYLV tC. aft 1.S PaSIIIPuI3SS 20415 III NWFOSRANCI AT NAE u SW F coo pump 10 SATNST (ISPAl 2no)

T4TAL1V35ACE AtXA ISO FT) 423000 It CAPAuILITT awR) 605.73 tv S5TrE1 lAo III) 74.S0 CtIjC9LAIIII WATS F4LOW (SPITZ ,. ,*,1a2 LV. *CtO3j1S Ia P1S1S3I (iN.",X, 3.1S eV RSita (0339I1 11t *A tt1°.0

• uot YSL. AT A60VE CV FLOW LIMSP S.30 me. 0f Cs pumpSs AVE3[AIBRAL CROmP(t1S (1w.k"C) 1.84 2.19 2.I. l1 CPASIL. 3

• 30.41 (tNW 0.0 a* 1 aJ A , t..,l, .1 I AL . I Ir r t S r A I a 7 C 9. J ACCOUNT9 TODA1S MATERIAL COST TO*AI'J INSTALAlIISI COSt 15CtLATIOI 1003O cost INITIAL INVIXfktkf COST 1795S 'I I01AL roo0* UNIT TOtAL 10001 RATtkl(L ISSTALLAIrsO MA410 SITE %VT99L`fO T 12400 -- 59O0 J *5 1.11 LOCAL INPRSOVCMAnT T SltAmC lt C e-------- m CSAC*S a 0 2.1 LOCAL 614A1o5 - - - O.OOSICw 1* 0 0 3.421 INTAXE STRUCTUQI - if FT1( -6 0 . O.O2stic 11 07 ais 3.2 cISUtLATIN WiTlE COMNrTI S"AIR OSILIN fIT O.CSOILIW FT 0 0 0 3.3..35 3*A7F? .... 14.1 . -482.S"LIN FT r_2103 - SO? ?70.

-3.2 SSCtiAiSi STRUCTURS 0.00sitU FT a e.0otsrc Jr 0 0 - a J.4t COOLING ToCs4 BASIN s.nS/44 IT n 40 S4.S4s1/4 Ft 5M2 I10 477 3.44 COOLING TOQVt%SUPIITSUtTUIC .. ............ jO1?2S40SICATN....._51.t0 .12j54,SjtACp. .245a 1304 5.1 Ts OWIL§IME cAIurtscuIIats MIT VT a OsIrT NT a 'G-4.18 Tn PtrtTAL CSIFMIVIAW¶IL)T 0 mSyIT CIT Mt O 7.1 T6 a ACCISSO*IEI (lmirTjt .3..0.00514VA . 0 . D.OOajVA _0 a 10_211 CONAS11SSIASILL OI114CM a 64.015Ci 0. .0 0 10.213 CONIeISInTuld (TITAN) 0.OO00lFT 0 0.0000SPIT a o .0 0

_ 0.221..CZ*U~TULYZ 15.1 CIRSULATING

~t3III UTPJU__

PNP Mclaw U2_lpy!ttfi

_J___ alRet1_

II0......ACN CATN 144 ~ AlSS EM 15 AS 1 14.1 IlVTOUREMI'AtMVA A COATIOL 9409.00SICACM 38 4400.0as0tA4C 1A I 2 15.11 START-UP A STAMSNI TRAUSIOSNE.K, CSI.14INTIu.) OoJMV . 0 . a 0 U.12 AUSZLZANT TA OMIT 1ANSFOOMEN ltIfftCleTLL IZAIISIIVA to, 124@$itV 19 - 1'.

• 15.21 CIRCULATINO VATER SVITtTIlMAN OAIP9%P 0 OSlAT 0 0- 0

.. 1.SING FOB aIRCULTI 0 13.1 UNIT MAIN POVES 5A4NS1511A( 489PF91I4ItAL)I 0BJAVA 0 05144 0 0 Cl 1.253 FAM NlYONPOWtS CMIES * *teSeINI *tfsts 1 0LCEIta a CtCS 0Ca 0 TOTA ... . . . .

jusIStEc CONITRUCTra CoST IwCl(U*INS PR@V(SsZUAL S*f (CI l0er COMIINGENCT 114.00 Of er tAC PLUS IMBIAM (ISI 1011 UTILITV.0 COS11uCTIOW LAPX$SISTILST.lu8Iwt N S . . -.

T014A. ISIIUIMTIS 14VISIET COST 10001 9VSS3 t I 7 I RA t I I C e 4

• A

• A;8 L t ai 9 i i 11a i T a A r "UA; tO ;VVIt I~i UlI1T NT CAPASIL. gjSttSlP (AtJ 509.0 60Z.4 585.1 I40.7 IV SYSIT FUEL COST ttASt VALU1) 0

• 1twitaCTIA1. UNI7 MCT CAPARIMT NIS). 9 .O2 ANNUAL PIN* CM41TS495A1 RATO 0.23422 21011

-ATE* COST dAf 19t.i/ILLIOE SALLONS

• CMINICACS) 331 UNIT MET AUWUALGINIIATAIOA MUIVII 3119117 MAINATSANCC I 2.00S Of TOTAL 11*"IlM INt

• 1915

• IPFtSLITIAL UNIT 55t( GSICIATION (MVh/tl _ _1(C512 SUNTOTA@ACvAL C"C " - --

CT? PIOAUCTION COST **L44 WATAS IONIUAPTON CrItLION CALLONSIT&I 4774 T i£uAL "li LTALT Fnti COST A___.__---VJUSStlII fo StIAL AlT ANNUAL 6"NCOATIew *'

tAT *.0100AesJLLSON 5152 4100031 0 TOTAL C.KDAISELI ANNUAL C05l INCLUOIDS ASJOSTAICTS TOTAL 1"PA15ttt IMVKtSMIIT CAST . S UaLISIS CAPABILITY4 . MIT LlANA. SIPNATISN_ 31113 IN(LVY0M08 tCAPA5I.TV AJUIDSAIS? (240w3h 114553 C1OASAULI. NT? ASSIUCTrON CISF JNCa. 4.JStIQNITS 66

EXHIBIT 30 Condensing System Computer Printout - RMDCT SOCCZIFCAtIONs Foe CASt ao. I NCS. RAiFT COOtING TIMES -RAIL2T 05014 aa ARl T A e 965ST0OAtlOn2 PAG4 r IV IlftT at510 ?IRPIEATUEI (13 $4.00 POallovAeCe All 011360 CONSITIONSI NO. 40 C&lLING 189112-C a

_CN060N310 T(HPgEAIUEt RISE IFl 2.5 T f*AP4ALl!T (CNW) 44tS51 ' i. Of CELLS FIX CT 12 TUef OZANETiiB~CINcES)3GAVC d. SANi PiN24-4 d~tFV9rt5WfMtd..1IA) -. 3z4* f£11rrdf-~p~~8 TOTAL 7Ue0 LENGTN CITTSKILL.) 42.S0 TOTAL C? t eAm IMOTOI 251 XE 3970 Ot OtPASELISEL NO iV ____ TT. P5960Th[PyTy pi 6 NO.t8 tI0 PASEi/sO4sE ZES IJI 1'1 PAIOUI4ADIC AIZ V P Ian NATI t37) 20Pi?

TOTAL ZUEFACO AI4A tSO FT) 21T000 TS CAPAOtlh!T CAN) 400.66 CV 3Y7151 [FT) 48.43

_CIRCUAT3MI 551tU FLOW I&FPA3 .-.

........ VJk - gN.!!---UN.A........ -

7501 "L. At AIONS IN FLOW IFPS) 3.20 me. or INtm~s AVG ISANOAL (:ONt PR0S1 ()N.W9A) 1.7n 2.17 2.81 TO CAPASIL. 0 VS 30.1f (SW) 0.0 coc InTITIAL imntVETt cCst 5t71S UNIT TOTM. 1000S UPI0T TOTAL 10005 tlATERIAL INSALLATSI MAJOR SITE S(VILOP"RERT ff060 OO79'

.LCALttt ,AovAnt To S1_iit-TrATIR 1-.'-- - . - _

2. LOCAL *5AUINO O.O0Z1/U To 0 0

_ _ __ _ _ _ _ _ _ _ _ ?0O ... 4 T L F a pOR j Fv a a 0

,.&Tt-TAKE nic-3'T IIBUCTA ,T *ir ' r g '-0 O?

.2 CIRCULATINI WATER CONOIRTt AIl as/A..u Ft 0 O.0o41LIN sT 0 0 0

3. .*aJAC ( * .ItOL FI.t...1i...... 1 5t FT 2167 161 z78

3. CTFT 0 .oic 1 - --- a--_

3.41 COOLIMS T7051 BAlTA 7.19SISO FT 625 44.21/10 FT 3547 to 454 COLZ OTOER 4p77 AgeA 'L7& 0L -227 5.7 yr. SUItORN 2FT NT OSIIFVITAL a 915 FT Vat t - - 0 0.

4.13 TY PEDESTAL CSZFFR*RINTAL) OS/FT lT a cs9FT PT 0 0 0

4. -T6. ACCessoUls tolfraIENTIAL) . - . .OOS/EVA .0. 0.041/%VA 0 00 0.211 LONDSINSR SWILL OlAIN N OUCACW o e. e 10.213 .COoKSlCA TUNE CTITAN) 2.-0000/FT o.0051?T 8 o 0 0

.. :...iO22..CILCI.uA-yATS tIu-_ q27A$/OtCN _ 221,jO07j!O!1A re 40 32 _2

15.3 CIRULAtZ P ATIPA rVMP M TeO 27-I6 9t A I'l 2 IEAs I 2JJISC 9 14.1 2SS1SUNTzatIoN

• CONTtL 33S1 .4ttIIACY' 100 2253.7tISICHc 04 1A a

1. 11 tSlT-UP I* STAJISV TRANSODR9 (02 tF4PEST2M.)_ os'n"A o OS/ C .o 0 0 15*.2 UNEIT XUIL AS TRANIFORNIR 11S9:ANVA IIIIFIIIST1'L) 144 226Cs/avs 24 s 3 15.21 CIRCULATI1 WAVItt SWITCOCIAR 0S/6RW. a OltIMP a 0 a

• S-... . 51219 FOX . IRCUtATINS *sIao-A

.1711957( .IvA3.. t1SJIWS. - . _12T8 _..j6..M _- .

15.1 UNIT MAIN P*Vtl ITAUNSfOSNII 3Z1jII(N7AL0 0SI/VA 0 ESlIVA 0 0 o 15.23 FAN ROTOR FOVIE lE NT1 *S4'b S1t6

• FMlIR 29100011CNT7S1 7S7 ¶boosIc(ATue 5? IzI 7 TST *. -*- * ** - .--

.5024 -- 3204.

TOTAL StIECT IEC:.ALA 1oSj:.PAsllZAL.AL.rLUS .OOZ SAtISIUSOtAX PLUS INTIALLASIO . .1773.

1"SIICT cosNTactIOA COST INCLUDING rOetn1so1AL 11tfVIC3 129s IINIINSt"CY (14.001 of 01a2t1 PLUS INDI1ZEr COST) 5,45 UTTLITTYS 1196E551. £uTt(lOT 9USIN4 CONST1OCTI@, * $.AN lD1010 TOTAL 1l71IMATtO £MwtSTO(RT1 COST MO05020

• T I* , A T I S C i0e Ji P A *S L t I U V I S I 1T it A*A A V 0 A L C 0 5 I S 1oooIE AILLOOKUS "MIT at? CAPrSlL. v/sI/S/p IMW3 607.0 600.2 526.0 70.9 IV ElsTh PUlL COST 10AS VALSII 0 111EI1101AL VAIlT AfT CAPASILIT? MIN _16.hl *01UAL FIXlE CXAIG1S (AT A1l 3.2342 2MST3 VS4tI COST tST 19.SNILLIOW GALLO'S

• INRIiALI) - '

UNIT MIT ANNUAL, CINtATION INNAIT61 3923212 PAIATIAAOCc I 3.001 or TOTAL 11W

• MS6t7N) 2r24

_IIflt BTZAL.TVIT. NT_ GIN(SATIOW_ J L J S217.S AANUALC,7j.-- - - --.-  ;.

SIT a aOUCTON CST .3 WAltE COASUKPTSS" (MILLION 9ALLONSITIS 454?

- .. ** .....- ..... A049UITI(T.J.0 03MIACK1lI&. (AFASILITI..

TITAL ANZISAV 1,0T FULL C01T A JV51Mt1l IDOA*IjFFNEt A, NOT ANSOAL SSIVIR13S8M 9031 4AT *.ONOSAIT.LION ITU) (10001) a ItAt T. PARASLC ASNUALCtO INCLOUSX APJ4JSTXIEIS TOTAL CONPAOIOA4t INVtIEIINT COST . . 0 FOR EOU4A1LO.CAPASITT 9 WIT ANL. AO..1350? .

SNCLVOSSC CAP03ILITT AIJVSIXlNT MtOO1 lfC4 C0oPARASB lilT FROSCITon COST INCL. AJUSAIXtTNS .2NT 67

EXHIBIT 31 RMDCT and NDCT Component Material and Installation Differential Costs RMDCT NDCT Material Installation Material Installation 1000.Q$ 100$_ 1000$ 1000S Ma.ior Site Development 12800 6200 12600 5900 Intake Structure 617 1618 666 1747 Circulating Water Conduit 1414 2167 1481 2105 Coolinz Tower Basin 625 3547 860 5282 Cooling Tower Superstructure 7835 9576 10193 12458 Circulating Water Pump 2121 403 2289 435 Circulating Water Pump Motor 1117 89 1483 115 Instrumentation and Control 100 64 38 18 Unit Auxiliary Transformer 144 26 107 19 Wiring for Circulating Water System 673 1278 0 0 Fan Motor Power Center & Required Switchgear and Feeder 873 57 0 0 68

I I LIST OF APPENDICES I Appendix A Computer Program for Cooling Water System Sizing and Economic Evaluation Appendix B Computer Printout Summary Data Sheet 1 NDCT - 12 F Approach Sheet 2 NDCT - 14 F Approach Sheet 3 NDCT - 16 F Approach Sheet 4 RHDCT - 8 F Approach Sheet 5 RMflCT - 10 F Approach Sheet 6 RMDCT - 12 F Approach 69

APPENDIX A Computer Program for Cooling Water System Sizing and Economic Evaluation 70

APPENDIX A COMPUTER PIOGRAM FOR COOLING VATEP SYSTEM SIZING AND ECONOMIC EVALTION

A. INTRODUCTION The input data to the computeizLed optimization program for the selection of a steam condensing system based on costs to comprised of the equipment dosign variables, the heat ratme, layout information, and system load# as well as equipment, material and labor pricing information. The program, utilizing theee inputs together with mathematical, theoretical and design assumptions, selects and develops cooling system features and components including concrete or earth structures (such as intake structures or cool-ing tower basins), circulating water main and branch conduits, circulating water pwnps and motors (and condenser shells and tubes, If necessary). The cost Impact of the differential unit transformers' (main, auxiliary and startup) size, which depends an the cooling water system power requirements, ts also considered.

3S COMIUTER PROGRAM The program selects, analyzes and prices all the system components as follows:

(1) The size of the circulating water pumps, motors and condensers (if necessary) is determined from design formulas and the cost*

calculated based or, the latest pricing lists available assuming reasonable discounts.

(2) The Intake structurt size Is calculated from general de6ign relation-ships and priced volumetrically ($/cu ft of structure).

(3) Cooling cover data is calculated as a function of approach to the vet bulb temperature and the cooling range based on the input data.

(4) The optimuw size o. the circulating vater conduits is selected based on a cost analysis of fixed and annual charges (investment and fuel cost)

(5) The auxiliary power demand and annual energy consumption for the cooling water system are determined from the units loading schedule, circulating water jpump and cooling tower fan design and mode of operation data.

A-1

I (6) Makeup water consumption and vater treatment chemical cost ts Cal-culated as a function of evaporation rate, drift losses and cycles of concentration in the circulating water circuit.

For each case the economic analysis includes the determination of initial in-vestment cost and annual systemt cost (fixed charges on the investment cost plus the annual operating and maintenance costs). These costs include items I related to condenser cooling systems only and do not represent total plant costs,

1. Investment Coate The total investment coat consists of estimated major site development cost associated with each alternative cooling system plus computerized variable costs. The major site development cost, Included in the overall computerized optimization program for each of the alternative cooling systems, is estima-ted based an information shown, on plot plans and the specific quantities required for the following:

Clearing - general area, Grading - general area, M¢akeup, blowdown system and water treatment -

equipment, piping, structures, Maintenance roads, Condenser tube cleaning system, and Cathodic protection and lighting.

For the cooling pond and spray canal systems, the total civil work cost was included In major site development cost.

Computerized variable Investeent costs are developed by the computer to make up the remaining Investment cost Items which are added to the major site de-velopment cost for the total direct cost of material and installation.

Included in the computerized variable costs are:

Local improvement to sire-clearing, Local grading, Circulating water intakc structure, Spray cooling modules, Circulating water pumps and rotors, Circulating water main and branch water conduits, A-2

I Coaling tower basin and superatructure, condenser shells and condenser tubes (if necessary),

I Instrumentation and control for circulating water pumps, Unit main power transformer (differential),

Unit auxiliary transformer (differential),

Start-up and stand-by transformer (differential),

Circulating water system svitchgear, and Wiring for circulating water system.

The size and coat of turbine *,nerstor equipment, pedestal and building for an existing plant is assumed ified for ail cases considered.

2. Comparable Annual Cists The estimated "Comparable Annual Costs" is developed using the computerized program and the results are recorded in the following manner:

Description of Cooling !ystem Type of Cooling System - A controlled variable Identify-Ing the specific type of Cool-ing Water System.

Maximum Cooling Water Tempera- - Cooling water temperature enter-ture ing condenser at maximum meteorological conditions is used for unit capability calcu-lation at adverse conditions.

Degrees of Approach at tiesign - A controlled variable within Conditions the typical range of values for the type of cooling water system.

Plant Net Capability at Max-Imum Meteorological, Design and Average Seasonal Con-ditions (1) Iuroine Generator - Energy generated operating at condenser pressure coincident with the appropriate meteoro-logical conditions.

A-3

I .

I Description of Coolint Svnstem Cozment_

t I

I (2) Estimated Plant Aux- - A set of constant values for iliary Power Eic- each of the various loads com-eluding Cooling I Water System, W mun to all cooling water sys-tem alternatives studied.

(3) CW System Auxiliary Calculation and S -ation-of pover, kW circulating water putp motor and cooling tower fan motor or of spray module motor input power.

(4) Plant Net Capability - These calculation values re-at Various Condi- flect the restraint or limit tions, kW in plant capability at various conditions. The value at aver-age seasonal conditions Is the basiS for monetary evaluation of differential net capability.

Plant Not Annual Generation - Integrate (Net Plant Capacity x kWhlyr Period Hours) for three (3) periods per year and three (3) values of turbine generator loads.

Differential Plant Nat Cap- - Base value is the maximum de-ability, kW pendable plant net output of 620 M. Any value smaller is penalized for this loss of capabilit ts instructed by JCP&Ljlarger values were not credited.

Differential Plant Net Gen- - Base value is a preselected eration, kih/yr specified value.. Any value smaller is penalized for this loss of kilowatt hours genera-tion. A value larger is credited on the same basis.

A-4

I.

I I -

Description of Cooling Sastem Plant Vet Generation with the I existing tooling system was used as base value.

Annual Fixed Charges, $/yr The total Estimated Investment Cost has been defiued. 7his cost multiplied by an Annual Fixed Charge Rate Is equal to the Annual Fixed CMargeo.

Annual Plant end cooling It is assumed that the Nuclear Water System Fuel Coats, Reactor annual fuel consumption

$/yr and hence the thermal output is the same for all alternative cooling vater systems. The total plant annual fuel cost tS calculated based on the inte-gral of three (3) periods per year, the percent loading regi-men per period, the thermal rating of the nrIlear reactor and a specified fuel cost.

This cost is the sae for all alternatives. A variable ts the fuel cost related to the cooling water system. This cost is calculated based on circulating water pump motor and cooling tower fan rotor energy requirements (kWh/yr) and to included In the.com-parable annual system costs.

A-3

Description of Cooling S-sutem Water Consumption - Evaporation plus DrIft Loss plus blowdown equals makeup.

Water Costs, #/yr - Hakeup x Unit Cost of water treatment.

Haintenance, $/yr - A Calculated Cost as a percentage of Investment Cost. For mchani-cal draft towers$ a maintenance charge per fan is added.

Subtotal Annual Cost, $/yr - A st~ation of above costs.

Vet Unit Production Cost, - This cost is based on the above mills kWh annual costs divided by net annual generation.

Adjustment for Differential - This differential capability cost Plant Net Capability, O/yr is calculated at a rate of incre-mental net capability levelized cost times the levelized Fixed Annual Charge Rate times the differential net capability (see next cornt).

Adjustment for Differential - This differential generation cost Plant N~et Annual Genera- adjustment it calculated assuming tion, $/yr a fixed levelized charge per kWh timS the differential plant net annual generation.

Total Comparable Annual Cost - A S-ms tion of Subtotal Annual Including Adjustment for Cost and Adjustment.

Equalized Capability and Generation, 4/yr Comparable Net Unit Produc- - This cost is based on Total Com-tion Cost, mills/kWh parable Annual Cost Including Adjustments for Equalized Cap-ability and Generation divided by base net generation, A-6

I l The above computation Is repested for each condensing system using various values for the water velocity in condenser tubes and cooling tower approach (the latter is defined as the difference between the circulating water temp-erature entering the condenser and the ambient vet bulb temperature). Then all the cooling system costs are sorted and results printed In ascending order of annual cost with capability and generation adjustment,, the least costly being first on the lint.

I A-7

I I

I I

I APPENDIX B l Cooling System Alternatives - Computer Printout Summary Data Sheet 1 NDCT - 12 F Approach Sheet 2 NDCT - 14 F Approach Sheet 3 NDCT - 16 F Approach Sheet 4 RMDCT - 8 F Approach Sheet 5 RHDCT - 10 F Approach Sheet 6 RMDCT - 12 F Approach 71

Natural Draft Cooling Tower, LZ2F A~aprouch Temperature SORT IN ASCENDINfG ORDER Of ANNUAL COST INCLUDING CAPABILITT t GENERATION ADJUSTMENTS PAGE 6 NNE DEPT 'A J NUSTO 06102192 IAPEFRANCIE fl~~APERIRMANE ATPEtFORMANCE AT ATPEAK LOAD CONOITION qp

• CONuIrIONS SURFACE CONDENSER AND CCNUSESER TUSE S WATER TEMP

- - - - - - - -- - - - - - - - - -e--- - - - -- - - - - - -

'1AMNUAL SYSTEM COSTS INVESTMENT COSTS AVG TOTAL TEIIP AVG

---

4 TO SACI SUIACE RISE TOTAL TUBE TUME

'I CASE ~ZiMOUT'1C" bS 1 XIIA .APADIL. PRESS AREA ACROSS FLOW VELOC LsTN liUi!

P14K UNIT NET CAPABIL.

OACK PRESS NO- AbJUSTRUYS'ADSUSTRONTSI# ESCAL' TOTAL ENV) . IN MG6 (SR FT) COND 1000 PMt WSF) (FT) UIN) (NV) IN NG '

17 343 716 9560d605.79' 3.18' 4Z3008 202 '416.2 5.80 3' 2 25462 33622 68941 43 0.875 510.26 3.18 98719 604.22 3.25 423000 21.0 401.8 5.60 43 0.875 579.14 3.25

.3__.. .25138.. 33694 66050. 97436 602.53 -333 '

423000 21.7 387.5 5.40 43 0.875 577.88 3.33 4 24897 33921 65400 96485 600.66 3.&f 421000 '22.6 373.1 5.20 26632 43 0.875 576.43 3.41 34173: 70163 103325 607.23 3.11 423000 19.6 430.5 6.00 43 0.875 581.20 6479 S293. 59.3 3.11 "

.1 473000 33.5 -338.8 5.00 43 0.175 574.80 3.51

'1 7 27125 3443? 71498 i05263 i408.57 3.05 423000- 118.9 444.9. 6.70 B"i 27517 34721 43' 0.875 582.03 3.05 72747 107084 609.79 3.00 423000 18.3 459.2 6.40 43 0.875 532.72

- 9 _..231 ~1_.__35146 3.00 .

74288 *109302 *.610.92 -. 2.94 423000 77.8 473.6 6.60 43 0.875 583.2? 2.96 20 8562 35515 7?5401- 1I10921 611.9$ 2.39 423000 '17.3 487.9 6.80 43 iI 29106 36082 76886 0.875 583.73 2.89 113039 612.93 2.85 423000 16.8 SOZ.3 7.00 43 0.875 584.10 2.85 S.

1 .273 -36I10~. - .718752 11M2 613.84 2.80 423000 16.3 516.6 7.20 43 0.875 584.37 2.30 IN

Natural Draft Cooling Tower, 14F Approach Temperature SCKT IN ASCENDING ORDER OF ANNUAL COST ItCLUDOIN CAPABILITY S GENERATION ADJUSTMENTS PACE 6 NNE DEPT A J MUSTO 06102192 Mb 19A APERFORMANCE AT PERFORMANCE AT DESIGN PfAX LACAD COMDTICN CoMoMrIoAS SURFACE CONDENStR AND CCNDENSER TUBES WATER TEhP

_____,___ Z- ___ _, -____________ ---- ----- --------- __._ _____________._____

ANNUAL SYSTEM cOsTs INVESTrENiT :osrs AVC TOTAL TEMP AVG

_u_____*_ ___*______

____ TG BACK SURFACE RISE TOTAL TUEL TUBE TUBE UNIT MIT BACK

CASt WITHOUT INCLUDSES INITIAL CAPaSIL. PRESS AREA ACROSS FLOW VELOC LGTK DIAN CAPABIL. PRESS No ADJUSTANtS ADJUSTANTS + ISCAL TOTAL (MW) lo NG (so ET) COub 1000 CPR (FfS) (FT) (AV) in HG (IN) 1 23017 .34i5 , 60344 j9100 594.70 3.70 423000 Z3.5 2 24175 3s8.S 5.00 43 0.875 S75.04 3.51 34443 63469 93656 598.58 3.51 423000 21.7 3t7.5 5.40 43 0.875 3 3Z676 34486 578.01 3.33

.62129 91 692 596.72 3.60 423000 22.6 373.1 5.20 43 0.575 576.61 4 24742 34536 65004 3.41 95885 600.34 3.43 423000 21.0 401 .8 S.60 43 0.875 579.22 5 25183 34608 66159 97622 3.25 601 .98 3.35 423000 20.2 4t6.2 So.1 43 0.875 580.28 3.18

.. 6 26254. 33400 69140 101833 603.48 3.29 423000 19.6 430.3 7 26806 6.00 43 0.875 581.18 3.11 35721 70634 104005 604.88 3.2Z 423000 1a.9 444.9 6.20 43 0.875 581.97 3.05 8 27322 36057 72029 106035 606.16 3.16 423000 15.3 459.2 1 _ 9 27937 6.40 43 0.875 $82.62 3.00 36533 .. 73?10 108456 607.37 3.11 423000 17.8 473.6 6.60 43 0 .75 s53.14 2.94 10 28548 37047 753?? 110857 608.48 3.06 423000 17.3 487.9 I . 11 29075 6.30 43 0.875 583.56 2.89 K ...- I2 . 29?06.

37515 38124 76815 78344 112933 115414 609.54 610.49 3.01 2.96 423CO0 423000 16.8 16.3 502.3 51 6.6 7.00 7.20 43 43 0.875 0.J75 583.

584.1 3 89  ?.85 2.80 I.... .

to

.J

-i

P- - - 1- m - - - - --

-v --  ;- 3 .-

Natural Draft Cooling Tower, 16F Approach Temperature SRI IN4 ASCENDING ORDER Of ANNUAL COST IhCLuDOIN CAPABILITY & GE1EIA11O0 AOJIJST"EWTS PAGE 6

?NE DEPT A J MUsIC C6102192 PERFORMANCE AT PERFORMANCE AT OESt c PEAK LCAS C4PITOtO C04RITIOkS SURFACE CONDENSER AND ctNalESER TUBES WATER TEn?

AMNUAL SYSTEX COSTS INVESTMENT CCBSTS AVG TOTAL TENP IS BiA SURFACE OISE TOTAL TUIE TUBE TUBE UNIT MET BACK CASE 4ITNOUT INCLUDES INITIAL CAPARIL, PRESS AREA ACROSS FLON VELOC LGTM DIAN CAPASIL. PRESS NO ADJUSTRtTS ADJUSYNNTS

• ESCAL TOTAL (XV) IN OS tS5 IT) CORO lD00 1PM t(PS) (1) CII) (KW) IN He I}

4, I 236S) 3S100 62065 91580 398.02 3.54 423000 20.2 416.2 5.80 43 2 23264 0.575 580.68 3.18 35164 61021 90061 395.39 3.62 423000 21.0 401.3 5.60 43 0.8?5 579.5? 3.25 3 22854 35269 S9917 38455 394.61 3.70 423000 2147 387.5 5.40 43 0.875 578.32 3.33 A 22340 35351 58522 16439 592.6 30.79 423000 22.6 373.1 5.20 43 0.8?S 5 21933 35618 576.87 3.41 57430 64841 590.5? 3.90 423000 23.5 358.8 5.00 43 0.875 575.24 3.51 6 _ 24579 .35642. 64607 95231 599.5S 3.47 423000 19.6 430.5 6.00 4*3 0.75 581.64 3.11 T Z5403 36tl? 66347 91471 401.01 3.40 423C00 18.9 444.9 6.20 43 0.3?5 582.47 3.05 8 26219 36647 69068 101680 602.35 3.34 423000 *8.3 459.2 6.40 43 0.875 S53.13 3.00 9 - v Z6865 37066 70817 104224 603.61 3.28 4.23000 17.8 473.6 6.60 1a 27597 43 0.5175 583.75 2.94 37654 72111 107101 604.71 3.23 423000 57.3 ,S7.9 6.80 43 0.875 584.22 2.89 ti 28174 3812S 743?3 109n32 603.5S 3.18 423000 16.8 s02.3 7.00 43 0.875 584.65 2.85 12 29175 39060 77131 113311 606.90 2.13 423000 16.3 516.6  ?.20 43 0.875 584.S9 2.80 tzj I

-' 'i W

"., I ..

-'., I .. . 5 ._ - . -I . . .. . .

.,, t:

I.....

_ L . .. .. ._ . - . __. _.- _ _ . _. . . . . .. .

- -v, -m ONN-F- - V - - _

R~ound Mechnnical Draft Cooling Tower, 8F Approach Temperature SORT IN ASCENOINGo OlDIE 0f ANNUAL COST I&CLUDIN6 CAPA81ITV I GENE4AIJON ADJUSTMENTS PAGE a PRE 0EFT A J RUSTO 06104192

'aAPERFORMANCE AT kiiRPIQ APICI AT DESIGN PEAK LOAD CONOZIZON CONDITIONS SURFACE CONDENSER AND CONDENISER IUBES WATER TERP ANNUAL SYSTEM COSTS INVESTMENT COSTS AVG TOTAL TEMP AVG

--- T4 SACK SUPC IS OA lUIE TUBE TUBE UNIT NET BACK

• CASE WIlTMCUT INCLUDES INIIIAL. CAPADIL. PRESS AREA ACROSS fLOV NO ADJUSYIINTS ADJUSIRNNS

• ESCAL VELOC L6TN DIAR CAPABIL.. PRESS TOTM (RV) IN G9 CSH FT) CORDS 1000 6PM WFs) (FT) (IN) (NV) iN NS 1 25372 33735 63956 ii2i' 606."30 3.16 423000' 3. 5 358,1" 5.0O 23961 33921 4 0.87 569.57 .1

-2 65494 86492 608.17 3My 423000 22.6 373.1 5.20 43 0.875 571.09 3 259 329 691 3.41 98598 409.88 -.2.99 423000 .21.i 38. . .0 43 0.87 S572.43 3*.3.3.

4 27152 34753 68561 100940 411.39 2.92 423000 20.9 401.8 5.60 5 27702 4.3 0.675 573.51 5.25 35189 69966 103002 612.79 2.85 423000 20.2 416.2 5.80 43 6 za527. - 0.875 574.57 3.16

. 35994 *..7167.1612.. 14.0? .-2.79 ... 4230001.-l9.6 7 2908? 000 63.5 - 3 J0.875 _575ft41 3Mt.

36571 73638 108252 615.24 2.74 423000 18.9 444.9 6.20 43 a 29646 0.875 510.12 3.05 37184 75109 1103?6 616.33 2.69 423000 18.3 459.2 6,40 43 0.875 576.69 9 30030 37654 3.00.

76107.__ .. 111835~. 617.3Aj 2.64...423000 *¶7.8. 473.6 6.60..43 87S577.13--..Z.94 10 30485 38227 77300 113560 618.33 2.59 423000 17.3 487.9 11 6406 43 0.8?5 577.46 2.89 30383 31774 78341 1107 619.2? 2.55 423000 16.8 502.3 7.00 12 43 0.875 577.69 2.85-

.31666 39735 B80424 116040 .620.05..2.51 423000I 16.3- 516.6 7.20 43.. Q.875 577.83 2.80..

.j.

- - - - - Tempe-rature-Round Mechanical. Draft Cooling Tower, lOF Approach Te prtr SORT in ASCEbINGI4 ORDER Of ANSNUAL COST INCLUbING CAPAS1LITY I SCUEIATIOII ADJUSTMENTS PAGE MN( DIFT A J MUSTO 06101,192 MT b ERfb4RAMLtEAT PE*PO*XANCE AT .

DESIGNM PEAK LOAD CONSITION

.. . .CONDITIONS SURFACE CONbENSER APIS CONDENSER JUBES WALTER TeMP ANNUAL SYSTEM COSTS INVESTMENT COSTS AVG TOTAL TEKP AVG

~ - ~-~~ TG SACK SURFACE RIMSE TOTAL TUBE TUBE TUBE UNIT MET BACK CASE VIT66UT INCLUDES INITIAL CAPABIL. PRESS AMIA ACROSS FLOU VELOC LCTH DEAR' tAPA.BIL. PRESS

• NO A0JPITANMTS ADJUSTNINTS I, ESCAL TOTAL (RV) IN NGE CII FT) CONS 1000 GPM (FPS) (Mr (N)l (Inv) in He

. 2423 439 1'990 9.3T2 606.30 3.16 4235000-2. 57T.3 5.0 4 0.875 574.73 3.33 2 25007 33570 63004 92834 60?.92 3.06 423000 21.0 401.8 5.60 43 0.875 573.88 3.23 3 23871 33876 .- 60315 505602.56 . .3 123000 23.5 358.8 5.00 43 0.3?5 569.31. 3.51 .

4 24324 33379 '61209 90228 604.51' 3.24 '423000 22Z.6" 373.1 5.20 -43 '0.875 571.37 '3.3.1 S 55 403 616 94544 609.42 3.01 423000 20.2 416.2 5.80 ~ .7 7.9 31 6 2617& .. 34692~.. . 660 *927.17.25.A3. 19.6.. 30.5 6.00 43 0.875 57S.73 3.11 7 26538 MIT1 67036 93632 _.612.01 .. 2.89 423000 18.9 '444.9 -6.20 43 0.575 S74.-4f5 3.05 a 27009 35472 68268 10040? 613.15 2.84 423000 1 8.3 459.2 6.40 43 0.875 577.04 3.00

• - 9 ..--27490 35?80. I6928

• 12224 614.23_ 2. 79_ 4 23000.. -1. 4 73. 6 - ..

60*O.875_577.49~ 2.9#6 10b' 27839 364.70 70570 10037Z 615.22 2.74 423000 17.3 487.9 6.80 43 0.875 57.8 z.89 .

11 28181 36894 71325 104831 616.16 2.70 423000 16.8 502.3 7.00 43 0.875 578J.07 2.35

• 12 ... 2AV66 -..3784.1 733.14. 10l9..617.02 *2.65 42300Q. 16.3 . ....56.6 7.20 ... *43 .0.8?5 .579.22  ?.0.

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Round Mechanical Draft Cooling Tower, 12F Approach Temperature SCRT IN ASCENDIN6 ORDER OF ANNUAL COST IACLUbtZG CAPAaILITT I GENERATION ADJUSTAEMTS pACE 6 RNE DEPT A J MUMTO 06104192 PERFOMNANCt At

• PENFORANCIE AT SESTGk PEAK LOA* CONDITION toAIlatoks

c. SURFACE CONbENSER AND CODENSER TUBES VATER *IENP

_4 - _ - _._ _ _ ________

ANNUAL SISTEM COSTS INVESTFENT COSTS AVG TOTAL TEiP AVG Tc . ACK SURFACE RISE TOTAL TUEE TUBE TUBE UNIT NET 9ACK CASE WITHOUT INCLUDES IIITIAL CAPAIIL. PRESS AREA ACROSS FLOY VELOC LGTH bIAN CAPABIL. PRESS NO ADJUSTMXTS ADJUSTANTS - ESCAL TOTAL (NV) IN Ha ($2 FT) COND 1000 GPN (FPS) (FT) (Cm) (NW) IN HC 1 23681 34296 59574 8786060Z.53 3.33 4230OQ i1.7 2 23430 Xii.5 i .40 43 0.7... 573.43 3.33 34334 58944 88945 600.66 3.41 423000 22.6 373.1 5.20 3 23084 34373 43 0.675 S72.32 3.41 58036 85644 s98.63 3.S1 423000 23.5 338.8 5 .00 43 0.875 571.05 3.51 4 24054 34440 63537 89235 604.22 3.25 423000 21.0 401.8 5 24394 S.60 43 0. 875 574.37 3.25 3460Z 61415 90490 605.79 3.18 423000 20.2 416 2 43 0.875 0 S.80 575.17 3.18 6 251 3t 35141 63373 93275.. 607.Z3.., 3.l1o. .423000 *...19.6 .430.5 .6.00 7 25435 £3 0.3O75 575.946 3.11 35258 64153 54422 608.57 3.05 423000 15.9 444.9 6.20 43 0.875 570.71 3.05

_ *- a 25851 35538 65250 95994 609.t9 3.C0 421000 13.3 459.2 6.40 43 0.875 577.32 3.00 9 26281 35179 66319. 76.1. 610092. 2.94 ... 4Z3000 ... 17.3 10 26539 473.6 6.60 43 . 0.875 577.79 .2.94 _

36179 67044 98591 611.95 2.89 423000 17.3 487.9 6.10 43 0.875 2.t9 11 26879 578.1 6 36590 67935 99876 612.93 2.85 423000 16.8 502.3 7.00 43 0.875 578.43 12 27339 2.85 37154 69151 10161? 613.84., 2.80 *,423000.* 16.3.t6 516.6  ?.20 . 43 0.875 ts8.60. 2.80 t;j I

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