New cogeneration and other non-utilitv P-f~865

power plants U

Ey Mona Reynolds, Special Projects Editor

Owners of cogeneration and independent power plants continue to choose natural gas a their primary fuel. Gas turbines hold a substantial lead as the type of prime mover chosen, used either in simple cycle or in a combined-cycle setup.

Other fuels are not out of the picture.

however. Coal is being used in conven- tional and fluidized bed boilers. Waste from coal-mining operations in Pennsyl- vania is being used, and its use is a double benefit. It serves as fuel to gener- ate electricity, and with time the acidic waste will be consumed and gone from the area.

A plant in Virginia has a symbiotic

Plant supplies steam to furniture plant, uses waste wood as fuel Altavista, Va. is the site of a 70-MW coal-fired cogeneration facility designed, constructed and operated by a joint venture between LG&E Power Systems Inc. and Westmoreland Energy, Inc.

Altavista’s site covers approximately 36 acres, bordered by a mix of industrial, commercial, and residential properties and the

relationship with a power plant supplies steam to the factory, and burns the factorv wood waste to nro- duce it.

Both cogen plants and independent power plants (producing electric power only) are getting bigger. Some of the latest include the Chesapeake plant, a gas/oil-fueled peaking plant that will pm- duce up to 375 MW destined for Virginia Electric Power; a cogen plant situated on the Exxon Bayway refinery site in New Jersey, billed as the “largest non-utility cogeneration plant in the United States,” producing 614 MW of power and more than 1 million Ib/hr of steam for refinery operations; and a natural gas-fired com- bined-cycle IPP system initially delivering 295 MW, the first phase in what will eventually be a 440-MW plant.

Following is a sampling of recently or soon-to-be completed cogeneration, small power, independent power, and other non-utility power plants.

Staunton (Roanoke) River. The facility has a 25-year power pur- chase and operating agreement with Virginia Power to sell energy and capacity to the utility.

The plant will sell steam for process and space-heating require- ments to The Lane Co. furniture manufacturing facility in Alta- vista. Lane has an agreement that requires the cogeneration plant to deliver up to 130,000 Whr of dry saturated steam at a pressure of 200 psig. In turn, the plant will purchase up to 100 tons per day of available waste wood from Lane, to be burned as supplemental fuel.

Major equipment at the Altavista plant includes two Babcock & Wilcox 280,000-lbhr steam coal-fired stoker boilers and a single

condensing steam turbine-generator manufac- tured by Mitsubishi Heavy Industries. Other key systems include coal unloading, storage and conveying facilities; lime and ash convey- or with storage facilities; water intake, pipe- line, cooling tower and water discharge facili- ties; scrubber and flyash baghouse equipment; Exxon thermal DeNO. system; switchyard; and steam lines to Lane. A standby gas-fired boiler large enough to meet contractual steam supply obligations to the Lane factory has been installed.

All potable water for the plant will be ob- tained from the town of Altavista, and non- potable process water requirements will be taken from the Staunton River. Sanitary sew- age will be discharged to the town’s sewer system. After required treatment, all site run- off and process water will be discharged into the river.

Westmoreland Energy, Inc. is a subsidiary of Westmoreland Coal Co. LG&E Power Sys- tems, Inc. is a subsidiary of LG&E Energy Systems Inc., whose parent company, LG&E Energy Corp., is also the parent company of Louisville Gas & Electric Co.

Virginia cogen plant burns wood waste as part of its fuel mix.

POWER ENGlNEERlNGlJULY I992 23

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Kegional waste-to-energy plant serves 14 towns Decemher 5 . 1991 marked the first pruces5ing oi WBIW hi the new American Rei-Fuel waste-to-energy facility i n Prestoii. Conn. 'lhc plant now accepts waste irom I I member tou'n, 01 the Southeastern Connecticut Regional Resourccb R c ~ ~ c r y Au- thorit) tSCKKRA) as well 8% thc communilie\ 01 G u i l f d . Madison Ind East Haddam. Negotiations are on-going m i t h other eastern Connecticut towns to fill the remaining csp;icity at the 622-tpd facility.

Waste is received six days a week. Facility tiperations t o process the waste and generate electricity continue 24 hours a day, seven days a week. About 10% of the electricity generat- ed from the 17-MW turhine-generator is used for plant operat. ing reqummenm: the balance is sold to Connecticut Light 8: Power.

The plant uses a roller grate technology licensed by American Ref-Fuel from Deutsche Babcock Anlagen of Germany.

For the southeastern Connecticut project, an American Ref- Fuel Darent comoanv. Brownine-Ferris Industries. Inc. (BFI) is

New 62-tpd waste-tosnergy plant serves municipalities in

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provibing interim landfill capacity for disposal of ash generated at the facility while the SCRRRA develops and obtains neces- sary permits for its own regional ash landfill.

American Ref-Fuel is a partnership formed by subsidiaries of BFl and Air Products and Chemicals, Inc. to design, construct, own and operate waste-to-energy plants.

Construction of the Sumas, Wash. zerodis- charge piant Is in its early stages. It will beoin ooeration in March 1993.

RO system, off-site demineralizer make zero-discharge plant feasible The Sumas Cogeneration Project, under construction in Sumas, Wash., is a conventional combined-cycle cogeneration facility that will produce approximately 125 MW of electric power for sale to Puget Sound Power & Light. It will also supply 25,000 Ibhr of low-pressure steam to an adjacent lumber dry kiln, which also is under construction.

The facility is owned by Sumas Cogeneration Co., a pannership of Calpine Corp. of San Jose, Calif. and NESCO of Redmond, Wash. It will use a General Electric gas turbine, a Vogt unfired heat recovery steam generator (HRSG), and a 36-MW GE steam turbine. Construction began in March 1992. and commercial oper- ation is scheduled for May 1993.

The plant is being constructed in a non-traditional owner-con- struct arrangement. The partnership has procured all of the major

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components, and Calpine is managing the con- struction of the project by supervising both the general contractor, a joint venture of lndustrial Power Corp. and Haskell Corp., and the engi- neer, Hipp Engineering of Vancouver, B.C.

Sumas Cogen has acquired I5 years' worth of natural gas reserves in northern British Co- lumbia and northwest Alberta to fuel the facili- ty. The gas will be transported to the Canada- U.S. border through the Westcoast natural gas pipeline. The project site is located near the border, and to avoid intrastate gas transporta- tion charges, a 3.5-mile natural gas pipeline is bekg ConStNCted to bring the gas from the border to the project site.

The gas turbine will be steam injected at 55,000 Ib/hr for NO, reduction, and the HRSG

will include a selective catalytic reduction (SCR) unit as well as a carbon monoxide converter. Both the SCR and CO converter are being supplied by Englehard.

To minimize the impact of the facility's wastewater on City of Sumas water treatment facilities, a zero-discharge water treatment system will be utilized. After evaluating several systems, the owners chose a Harris Engineering system because of low capital and operating costs and minimal operator interface. The Harris system consists of a cascading series of thermally driven evapora- tor modules followed by a filter press. The resulting non-hazardous waste will be trucked to a landfill.

To eliminate the zero-discharge salt volume associated with the waste from chemicals normally used in on-site demineralizer regeneration-and to eliminate the cost of these chemicals-two in-series reverse osmosis units were incorporated into the design of the boiler feedwater treatment system. The final stage of water treatment will be accomplished by a portable demineralizer that will be regenerated off-site.

24 POWER ENGINEERINGNULY 1992

Coal-fired plant will produce 18% of Oahu’s power Almost all of Hawaii’s electricity is presently supplied by oil- fueled power plants. The AES Barbers Point plant on Oahu will be the island state’s first large coal-fired power plant. It will supply approximately 18% of Oahu’s electric energy.

Construction started in late March, 1990. The project is currently about two months ahead of schedule. Steam blows were completed in early April of this year, and commercial

Emissions limits for Barbers Point are lower than federal new source performance standards (NSPS). Barbers Point emission IimitsforSO,, NO,anddustare0.3,0.11, andO.OlSib/MMBtu respectively. NSPS standards are 0 .6 ,0 .6. and 0.3 for the same emissions:

Currently, there are no emissions limits for carbon dioxide, However, recognizing that CO, may contribute to global warm- ing, AES-BP is contributing to the purchase of a 143,000-acre nature reserve in Paraguay. The CO, saved by preserving this forest will he approximately equal to the CO, which will be emitted over the life of the plant.

Barbers Point will use a salt-water cooling tower for condens- er cooling, selected because it reduces the plant’s fresh water requirements by about 90%. The salt water is supplied from on-

operation is expected this month. The plant will produce 180 MW

of electricity for sale to the Hawai- ian Electric Co. (HECO) under a 30-year contract. The plant will be base loaded with some dispatch, primarily at night. Dispatching will be under HECO control. Minimum dispatch will be 63 MW. Barbers Point will produce about 30,000 lh/hr of 45 psig, 345 F steam for export to the nearby Chevron oil refinery under a 20-year extendable contract.

Coal will be burned in two circu- lating fluidized bed (CFB) boilers. Local limestone is added to the coal. The limestone is calcined in- side the boiler, and reacts with the sulfur in the boiler gases to form gypsum.

At its 180-MW rate output, the plant will use approximately 90 tph of coal. The coal, being supplied from Indonesian Borneo, will be unloaded at Barbers Point Harbor by a bulk cargo unloader. The AES Barbers Point project provided the quantity of bulk cargo shipments needed to finance the installation of the bulk cargo unloader. The un- loader will provide low-cost un- loading of other bulk cargoes on oahu.

The coal will be carried from the harbor to the plant in a pipe con- veyor. This conveyor is unique in that its belt folds over on itself to form a pipe which completely en- closes the coal. The pipe conveyor eliminates windblown coal dust while maintaining a slim profile.

T h e pipe system can make sweeps as small as 800-ft radius. This capability eliminated the need for an intermediate coal transfer point. When completed, the system will be the longest and largest capacity overland pipe conveyor operating in the world.

The circulating fluidized boilers operate at relatively low temperatures, which significantly reduces the production of nitrogen oxides when compared to conventional boiler opera- tion. In addition, the boilers are provided with ammonia and Steam injection to further reduce the nitrogen oxides. The am- monia reacts with the nitrogen oxides to form nitrogen and water vapor.

The Barbers Point plant is Hawaii’s first large coal-fired power plant.

site shallow wells, The plant is being built under a turnkey contract with Multi-

power Associates, a joint venture of National Power Develop- ment Corp., Pyropower, and the Pritchard Corp. NPDI is a subsidiary of Marubeni. Pyropower is a subsidiary of Ahlstrom. The prime construction contractor is Hawaiian Dredge and Construction. Construction management is by Black 81 Veatch.

POWER ENGlNEERlNGlJULV 1992 25

Combined-cycle plant uses new low-emissions combustor An $87-million cogeneration facility, built by Ebasco Construc- tors, Inc., went into commercial operation in May within the city limits of Buffalo, N.Y., five months ahead of schedule.

The General Electric Frame 6-powered combined-cycle facili- ty produces 62 MW, and is one of the first to use GE's dry low nitrogen oxide combustor to reduce emissions.

Ehasco designed, engineered and constructed the plant under a contract with Encogen Four Partners, L.P., whose managing general partner is EDC Four Inc. Ebasco and EDC Four are wholly owned subsidiaries of Enserch Corp., Dallas, Tex.

Lone Star Energy Co., another Enserch unit, will operate the facility.

Construction was complicated by the site itself. It lies within the city limits of Buffalo, and is approximately 100 ft wide and 1000 ft long. A rail line lies along one side; the distance between the center of the nearest track and the nearest wall of the new facility is 8 ft.

Electric power produced by the new plant will he purchased by Niagara Mohawk Power Corp. Thermal energy will be sold to Outokumpu American Brass, Inc., a copper and copper alloy manufacturer adjacent to the power plant.

In addition to the GE gas turbine, major components include a Deltak heat recovery steam boiler, GE steam turbine, and Ha- mon cooling towers.

A new6BMW cogen plant occupies a 100-fi-wide space between a manufacturing plant and a rail line.

Florida plant constructs 570-acre lake for use as cooling pond Construction will he completed this fall on a 295-MW indepen- dent power plant in Hardee County, Fla., as the first phase of what eventually will he a 440-MW facility. The plant owner is Hardee Power Partners, an affiliate of TECO Power Services, which is the wholesale power producing arm of TECO Energy, Tampa.

Long-range plans call for two General Electric combined-

uted control system is from Bailey Controls. Metric Construc- tors, an affiliate of the J.A. Jones Group of Charlotte, N.C., is providing construction services and balance-of-plant equip- ment. Metric also is providing detailed design services through Black & Veatch.

Power from the plant will be sold to Seminole Electric Coop- erative and Tampa Electric Co.

Construction began in January, 1991. One highlight of the project was the construction of a 570-acre lake to be used as a cooling pond in place of cooling towers. The power block site is adjacent to a reclaimed phosphate mining area; reclaiming the mined area as a cooling pond was considered a positive enhance- ment to the land. Because it is less energy-intensive, the cooling pond also is more efficient than cooling towers. - - .

cycle systems. each rated at 220 MW. IO he in\talled at the site. 'The first unit. featuring two gas turhincs and an 80-MW steam turbine. is scheduled to begin commercial operation in January IYY3. In addition. a third gas turbine will hegtn simple-cycle operation at the same time. That uni t eventually wil l become part of the second combined-cycle block. planned for commercial opera- tion i n 2003.

I n the initial configuration-one combined-cycle unit plus the \Imple-cycle gas turhine-plant output will he approximstely 295 MW fcir site suninier conditions. Natural gas u ill be the priinary fuel for the gas turhincr, u,ith distillate oil as n hackup.

GE Porer Gencrxtion. the turnkey C O I I I ~ ~ L ' I O ~ for the $IM)-niillionpro~ect, is providingthesteani turbines and gcneratori. along wi th thr gas turbines. The heat recov- ery steam generator is iroiii Vogt and the plant's d i h h -

Florida independent power plant will use 570-acre lake (upper left of photo) a s a coollng pond.

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The CFB technology uses pulverized limestone to removi more than 90% of the waste coal’s sulfur dioxide emissions- better than government-mandated levels. The suspension in ail (fluidization) of the coal, ash and limestone allows recycling o: Pennsvlvania cogen dant fires

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unhurncd karhon hack 10 [he comburtion chamher and &c~lll&* the capturcof SO.. uhich eitnunales the nced for ddditlonal SO waste enhances environment

A new 85-MW coal refuse-fired cogeneration facility at Ebens- burg, Cambria County, Pa. is providing 85 MW of electric power to Pennsylvania Electric Co. and an effective solution to one of the area’s most persistent environmental concerns. The $190-million facility is the first to use waste from bituminous coal as fuel.

A 35-year supply of fuel to operate the Cambria facility is taken from two sources: a 30-million-ton waste coal pile adja- cent to the plant site, and another smaller waste coal pile near Carrolltown, Pa. During the first three years of operation, fuel will come from the remote source, During the subsequent 30 + years the facility will consume approximately 1,200,000 tpy from the coal refuse pile adjacent to the facility.

Effectively disposing of waste coal, a by-product of the coal mining process, has been an environmental concern throughout Pennsylvania and other coal-mining regions.

At the plant’s dedication, Mark Singel, Pennsylvania lieuten- ant governor, said, “This project has moved our state one step closer to its goal of a cleaner, healthier environment. At the same time, the project supports economic growth and energy independence from foreign oil through the innovative use of a

abatement equipment. Lower combustion temperatures mini. mize thermal nitrous oxide formation and ash fouling and slag ging caused by coal deformation.

The plant’s continuous emission monitoring system allow! ongoing checking of air quality levels, and ensures compliancc with pollution control standards.

The plant contains unusual features, including dual fuel s u p ply, redundancy of critical components, and technology to c o n trol fuel moisture levels to minimize interruptions in its operations.

Designed with two fuel sources, the facility has two coal crushers, two reclaiming systems and two refuse Crushers tc ensure uninterrupted flow of the waste coal. The ability 01 cogeneration plants to keep fuel flowing has been identified as a key factor in operation success. The plant design alsc features a dual system for removing ash from the combustion process.

The plant requires roughly 2500 tons of waste coal daily ta operate. One 25-ton truckload of bituminous Coal refuse is delivered to the plant approximately every 5 minutes on a 10-hour-per-day. 6-day-per-week schedule. It is dumped onto the receiving hopper from which it is moved by enclosed con-

Coal-minina waste for Dlant in Cambria Countv. Pa. is moved bv for start-uos and flame s enclosed c&eyor to a storage dome, where ii is stacked out by stackerlreclaimer.

coal mining by-product.” The Cambria County facility is owned by the Cambria Cogen

Co., a Pennsylvania partnership consisting of Air Products and Chemicals, Inc. as general partner and Energy Investors Fund, L.P. and Allstate Insurance Co. as limited partners. It was built and is being operated by Air Products and Chemicals, Inc., and employs two circulating fluidized bed (CFB) boilers to produce 820,000 Ib/hr of 1550 psig, 955 F steam. The steam drives a single turbine-generator train to produce approximately 98 MW of electricity. About 13 MW are consumed by the facility, and approximately 85 MW are exported to Penelec. An average of 12,900 lb/hr of low-pressure steam are supplied to a nearby nursing home for space heating,

veyor to the first screening unit, which rejects any material larger than foul inches in diameter.

The material is then transferred by conveyor to the refuse storage dome (which can contain up to 20,500 tons). where it is stacked out by the stacked reclaimer. Next. the material moves by conveyor to the fuel handling build- ing where it is deposited on a vibrating screen which rejects any pieces larger than 2 inches.

The remaining material moves to the crusher, which crushes and screens it in size to 114 in. or smaller. The crusher is equipped with circulating heated air to remove moisture as need- ed. Then the material is transferred by a 620-ft conveyor to the refuse boiler fuel bunker and is ready for use by the combustors.

The plant also uses run-of-mine coal as a backup supply of fuel as well as

tahilization. It is ourchased on the soot market as’needed.

The run-of-mine coal also is delivered to the plant in 25-ton trucks and stored in a covered pile. The handling system for this fuel is served by two separate crushers and a separate conveyor from the fuel handling building to the run-of-mine fuel bunker in the boiler building.

Another unusual feature of the installation is the moisture control built into the fuel processing system, a factor that can affect material flow rates significantly. Once the waste coal is received by truck, it is handled by a series of enclosed conveyors and structures and is never exposed to outdoor elements.

Ash produced during the combustion process is returned to waste coal piles to help neutralize their acidic nature and aid in their reclamation.

According to Air Products and Chemicals, the plant has achieved an availability rate of over 95% in its first year of operation.

POWER ENGlNEERlNGNULY 1992 27

Wood-waste-burning power plant pipes wastewater to local town’s lagoon system, reducing town’s groundwater dlscharge.

Wastewater discharge plan benefits local water system The fuels to be used at the Grayling generating plant at Grayling, Mich. dictated the design. The plant is located adjacent to an existing sawmill and utilizes sawmill wastes such as sawdust and planer mill fines in addition to wood lot forestry operations wastes and some whole tree chips as fuel.

The most difficult of the fuels are the sawdust and planer mill fines. The plant is designed to burn up to 40% heat input from this type of fuel, which required careful attention to both the fuel

Peaking plant has dual-fuel capability A peaking power plant recently completed in Chesapeake, Va. by the Commonwealth Atlantic Limited Partnership utilizes simple- cvcle combustion turbines ourchased from Westinnhouse Electric Corp. on a turnkey basis.

The facility consists of three combustion turbines rated at 312 MW on natural gas in the summer and 375 MW on No. 2 distillate oil in the winter. Water injection will be used to reduce the NO, to 25 ppmvd on gas and 42 ppmvd on distillate oil.

A leased mobile water treatment system will provide demineralized water for NO, injec- tion. The water will he stored in a 1-million- gallon storage tank, which is sufficient for 30 hours of operation.

Westinghouse is responsible for the total turnkey project; it has subcontracted with Black & Veatch for the balance of plant engi- neering, BOP procurement, and construction. B&V has subcontracted to Metric Constructors

The Chesapeake plant will deliver up to 375 MW to the Vlrglnla Power grid.

handling system and the boiler. Initially, 100% of the energy produced will be sold as electric

power on a long-term power sales agreement with Consumers Power Co. The design of the plant allows for the future uses of process steam to support a planned lumber drying kiln at the sawmill.

The Grayling project is scheduled for commercial operation during the third quarter of 1992. Black & Veatch Power Devel- opment Corp., a subsidiary of Black & Veatch, is the turnkey contractor. Construction is being managed by TBC, a joint venture of Townsend & Bottum Inc. and the Christman Co.

In its design of the project, Black & Veatch utilized approach- es developed for much larger utility power designs, including 3-D computer modeling, This project is the first time these types of design tools were applied to a small power producer. They resulted in a well documented design in which the owner could see the modeled layout of the plsnt before it was built. This approach also reduced the potential for interferences in the field, which is a benefit on a fixed price project with a tight schedule.

The project also has a unique service watedwastewater sys- tem. It is interconnected with the water treatment lagoon system for the town of Grayling, which is approximately three miles from the power plant. An overland piping system has been designed which carries power plant wastewaters and blowdown to the town’s lagoon system. In return. a portion of the power plant’s makeup water is taken from the tertiary section of the lagoon system. This arrangement avoids the need for a separate discharge to the area groundwater system from the power plant. It also reduces the town’s groundwater discharge since the plant uses and evaporates more water than it discharges to the town’s lagoons.

for construction of the plant. Site construction began in February 1991; turbine-generators

were delivered in July. Interconnection was made to the Virginia Power 230-kV line’in February 1992, and commercial operation was scheduled for this spring.

The Limited panners of Commonwealth Atlantic L.P. are Hano- ver Energy Co. and Chickahominy River Energy Corp. Hanover is a wholly owned subsidiary of Mission Energy Co. and Chickahom- iny is a wholly owned subsidian, of Long Lake Energy Corp.

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46-MW cogen plant delivers steam for oil recovery Because much of the energy reserves remaining in the western United States are in the form of heavy crude oil, many producers have turned to thermally enhanced oil recovery to aid in extract- ing this oil. By injecting steam into existing wells, oil viscosity can be lowered enough to allow economical recovery.

The Live Oak cogeneration plant near Bakersfield, Calif. supplies steam under pressure for this purpose. It delivers up to 40,000 Ib/hr of steam to the nearby thermally enhanced oil recovery project operated by Texaco, Inc. It also supplies 46 MW of electric power to Pacific Gas and Electric Co.

Destec Energy, Inc. and its subsidiaries were responsible for all aspects of the development of the project, from feasibility studies to operation and management of the finished plant. The partnership formed to own Live Oak has long-term contracts with PG&E for electric power sales and a contract with Texaco Inc. for steam sales. The facility purchases natural gas from PG&E.

Live Oak cogen began opera- tion in March of this year. It uti- lizes a steam-injected natural gas- fired aero-derivative General Electric turbine, packaged by Stewart & Stevenson Services, to generate electric power, and a

Deltak waste heat recovery boiler and a steam turbine for steam generation. Demineralized water is provided by an Aquatec treatment system.

A distributed control system from Westinghouse monitors and controls plant functions.

The project utilizes the latest emission control technologies to achieve stringent clean air standards. These include a snperheat- ed steam injection system to reduce nitrous oxide emissions, a selective catalytic regenerator in the heat recovery steam genera- tor to further reduce NO, emissions. and a catalytic converter to reduce carbon monoxide emissions from the boiler.

Prior to development of the cogeneration project, oil and gas producers in the area had utilized steam produced at the site by a conventional steam generator. By efficiently producing both electricity and steam, Live Oak cogen provides improved pro- duction and profitability because the steam required for oil recovery is readily available at a substantially lower cost.

Compared to expenses incurred when conventional steam generators were used, Live Oak cogen provides its steam host overall energy savings equivalent to approximately 200,000 barrels of oil a year.

Process steam from 46-MW Cali- fornia cogen unlt alds in crude 011 recovery.

process steam. It also powers, simultaneously, a GE automatic- extraction condensing steam turbine.

Cogen plant design ~

To comply with environmental concerns, the plant's design factors in stringent sound and NO, control requirements. Steam is

overcomes site obstacles The Fort Orange cogeneration project, on line since February 1992, provides 60 MW of power to Niagara Mohawk Power Co. It also provides process steam for operations at the adjacent Fort Orange paper mill.

The site's conditions presented some challenges to design. Located over soil that contains compressible pockets of peat, the two-acre site was covered with up to 7% ft of a compacted fill material to keep all Structures above the 100-year flood plain elevation. All structures were supported on steel H-piles to counter a soil settlement of seven to nine inches. The piles were coated with visco-elastic asphalt material to reduce the downdrag caused by the friction of the settling soil.

The combined-cycle plant was engineered by Parsons Main for C.N.F. Constructors, Inc., the turnkey contractor. It was devel- oped and is owned by Cogeu Engineering Technology, Inc. (CETI).

A General Electric Frame 6 combustion turbine is the core of the plant. Fueled by natural gas or distillate oil, the turbine exhausts into a Deltak heat recovery steam generator, which provides the

injected into the turbine to limit NO, emissions

Remediation of the site was requlred before the Fort Orange cogen unlt was constructed.

DWER ENGlNEERlNQNULY 1892

Ccgeneratlon plant in New Jersey, sald to be the US.’ largest, will dellvar 614 MW.

U.S.’ largest non-utility cogen plant to start up in New Jersey According to Cogen Technologies, its plant at Linden, N.J. is the largest non-utility cogeneration plant in the United States. Con- struction began in January, 1991, and commercial operation is scheduled for this month.

The $500-million combined-cycle plant will he capable of pro- ducing up to 614 MW of electric power and more than 1 million Ibhr of steam. The power will be purchased by Consolidated Edison under a 25-year contract. Low, medium, and high pressure steam has been contracted for by Exxon for refinery operations. The plant lies on an 8%-acre site within the confines of Exxon’s Bayway refinery

The plant will operate on natural gas as fuel to power five turbines. During 15 days each winter, natural gas normally con- sumed by the Linden plant will be provided to Public Service Electric & Gas for public distribution. On these occasions, the plant will operate with butane as a backup fuel, without degrada- tion of emission standards.

The five gas and three steam turbines in the plant were supplied by General Electric: the gas turbines are the GE 7EA model. The supplementary-fired waste heat boilers are from Nootermriksen. Duct burners were provided by John Zink Co. Ebasco developed the plant under a turnkey contract.

The plant includes an air-cooled condenser system supplied by GEA Power Cooling Systems. According to GEA, the system, consisting of three condensers, is considered to be the largest of its kind in North America, and one of the largest in the world.

The original steam host, a textile mill. experienced financial difficulties, and the steam contract was set aside.

In looking for a replacement steam customer, the company offered to provide low-cost energy in exchange for the cus- tomer’s current emissions. Negotiations were begun with

The DuPont site was located adjacent to the city-county line. The county was seeking industrial development, but a citizen’s group campaigned against the plant. The city of Richmond, however, was receptive, and the plant site was moved across the line, still adjacent to the DuPont plant.

Stoker coal for the plant will be provided by rail. All ash will be commercially re-used by Reuse Technology, an affiliate of Cogentrix.

Developer switches site to accommodate new plant DuPont.

This summer, Cogentrix will place its ninth and largest coal-fired plant in operation. The standard 220-MW cogeneration facility, in Richmond, Va., will consist of four of the cogen developer’s standard 55-MW modules.

Each module will consist of two 292,000 Ibhr, 1525 psig. 955 F ABB Combustion Engineering boilers and one General Electric controlled extraction turbine-generator. The T-G consists of a