SUNRISE AND POWER PROJECT
Note: This description was written before the project was approved by the Energy Commission.
Some information may be out-dated as the first part of the plant is now on line and producing electricity.
Sunrise and Power Company, LLC owned in equal parts by Edison Mission Energy and Texaco Power and Gasification Holdings, a subsidiary of Texaco.
The Sunrise Power Project is an operating simple-cycle, natural gas power plant with a capacity of 320 megawatts (nominal, MW). A second phase of the project will add a 265 MW combined cycle system.
Sunrise is located on approximately 16 acres in the south half of the southwest quarter of Section 23, Township 31 South, Range 22 East in western Kern County, California. The Sunrise site is approximatley 35 miles southwest of Bakersfield, 3 miles northwest of Fellows, and 2.5 miles south of Derby Acres. State Highway 33 running northwest-southeast is approximately 1.3 miles east of the site.
Texaco estimates the capital cost of Sunrise Phase 1 at approximately $175-195 million. The project will contribute to the local economy by employing about 255 workers during peak construction and about 24 permanent jobs during plant operations.
The California Energy Commission is responsible for permitting the proposed project. The Energy Commission will carefully examine public health and safety, environmental impacts and engineering aspects of the proposed power project including all related facilities such as electric transmission lines, natural gas pipelines, and water lines. The Energy Commission responsibilities are similar to those of a lead agency under the California Environmental Quality Act (CEQA).
The permitting process is open to the public and includes input from the public and all interested parties. The Energy Commission will be working in close consultation with local, state and federal agencies for their input and analysis of the potential impacts of the project. The review process was initiated on December 21, 1998, when Texaco submited an Application for Certification (AFC) for Sunrise to the Energy Commission. The Energy Commission's decision on the project is expected by February 2000.
If the project is approved, Texaco plans to begin construction in February 2000.
Texaco anticipates beginning commercial operation by May 2001.
Electrical energy produced from the proposed power plant will be sold in California's newly created electricity market. In addition, thermal energy from Sunrise will be provided to an adjacent thermal host, Texco North American Production (TNAP), for use in enhanced oil recovery operations.
Sunrise will be normally operated in a base load mode at the maximum continuous output for the forecasted ambient conditions. The plant will operate 24 hours per day, 7 days per week. The target annual capacity factor for Sunrise combustion turbine generators (CTGs) is 95 percent. It is possible that the turbines would be dispatched in the future to loads as low as 60 percent.
The applicant has proposed a combustion turbine generator (CTG) design with a nominal capacity of 320 MW. The facility will consist of two General Electric Frame 7FA CTGs equipped with dry low oxides of nitrogen (NOx) (DLN) combustors, with two heat recovery steam generators (HRSGs) equipped with an anhydrous ammonia-type selective catalytic reduction (SCR) emission control system and associated support equipment. Natural gas will be the only fuel used at the facility and will be supplied by the thermal host, Texaco North American Production (TNAP).
Each CTG system will consist of a stationary, heavy duty, industrial CTG capable of producing approximately 165 MW of electricity at site conditions. Power will be generated by the CTGs at 18 kilovolt (kV) and stepped up by two transformers to 230 kV in a new substation (the Sunrise Substation) directly east of the plant.
Exhaust gas from each CTG will flow directly through an unfired "single-pass" HRSG with an SCR, before passing through an exhaust stack. Each HRSG will be designed to produce steam at operating conditions of approximately 574° F and at 1,250 pounds per square inch gauge to TNAP steam injection wells in the vicinity of the project.
Electric Transmission Line
A new 15-mile 230 kV double circuit electric transmission line is proposed that will interconnect with existing California Department of Water Resources and Pacific Gas and Electric Company transmission lines. The new transmission line will run from a new Sunrise Substation at the power generation site to a new Valley Acres Substation.
Natural Gas Fuel Line
A new 60-foot natural gas supply pipeline will be built to interconnect with a TNAP gas pipeline.
NOx emissions from the combustion process will be reduced to 2.5 parts per million by volume dry (ppmvd), or less, at 15 percent oxygen, by utilizing dry low NOx combustion technology and a SCR system. The SCR system will use anhydrous ammonia for the reduction process.
The facility's consumptive fresh water requirements will be minimal, since the primary project water supply will be pretreated, produced water from the adjacent oilfield operations. A small quantity of potable water and service water will be required for domestic purposes and possibly evaporative cooler makeup. It is anticipated that the West Kern Water District will be the source of this fresh water.
Small quantities of non-hazardous waste water, comprised mainly of process drains and evaporative cooler blowdown will be directed to a new waste water line, approximately 600 feet west of the site to the TNAP main utility corridor and ultimately to the Valley Waste system. Valley Waste is a coopeeraative that handles waste water from area oilfield operations.
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