In October 1996, Enova Corporation, the parent company of SDG&E, and Pacific Enterprises, the parent company of Southern California Gas Company (SoCalGas), jointly announced a plan of merger an agreement to combine their companies.

The principal utility subsidiaries of Sempra Energy include Pacific Enterprises and Enova Corporation, which are the parent companies of utility subsidiaries SoCalGas and SDG&E, respectively, which will continue to operate as independent utilities.

Electric power needed to meet the demands of SDG&E’s service territory is either (a) imported through SDG&E’s two transmission power links (i.e., the Southwest Power Link, which transports power from Arizona and the southwest, and the South-of-SONGS Path, which transports power from the San Onofre Nuclear Generating Station [SONGS]) and other sources in California and the northwest, or (b) generated at SDG&E’s Encina and South Bay Power Plants.

In addition to SDG&E’s power generating assets, qualifying facilities (QFs) on connected to SDG&E’s system add an additional 174 MW of power.²

As described in Section 1, Introduction, a series of events (namely implementation of the plan of merger that created Sempra Energy as the new corporate parent of Enova Corporation and Pacific Enterprisesthe merger of Enova Corporation, the parent company of SDG&E, and Pacific Enterprises into Sempra Energy) since the divestiture application was originally filed have resulted in the CPUC ordering the sale of SDG&E’s natural gas-fired generation assets.

... SDG&E’s ownership interest in SONGS and the long-term power supply contracts are intangible assets in that the primary discretionary operational control of these generating assets does not reside with SDG&E and in that SDG&E holds no ownership interest in the QFs or out-of-state utilities that produce electricity under the power supply contracts and only a passive ownership interest in SONGS. (SDG&E and the other SONGS co-owners sit on an owners committee that periodically meets for discussion and review of operational issues, but SDG&E and the Cities of Riverside and Anaheim are not involved in day-to-day decisions concerning SONGS operations.)...

The CPUC has discretionary approval authority over the general terms of the Asset Sale Agreement, the Operation and Maintenance (O&M) Agreement, and the Facilities Services Agreement, Bidding Contractand the auction process of each proposed sale.

The new owner would be required to take an assignment of assigned SDG&E’s "must-run" contracts with the ISO to ensure the availability of these generating facilities.

If the Port District does not elect to purchase the South Bay Power Plant under the terms of its agreement with SDG&E by November 14, 1998details of the negotiated sale are not finalized by November 30, 1998, 60 days after the signing of the agreement, then the agreement between SDG&E and the Port District will terminate and SDG&E would recommence the auction of the South Bay Power Plant as originally proposed in its divestiture application.

SDG&E would provide the buyer with a license to use a portion of these properties in connection with the buyer’s ownership and operation of the CTslong-term leases and related easements to these properties.

Where applicable, SDG&E is proposing a two-step process for its auctions, similar to the processes approved by the CPUC for recent divestiture applications from Edison (Application No. 96-11-046) and PG&E (Application Nos. 96-11-020 and 98-01-008). In the first step, SDG&E requests the CPUC to issue an interim decision approving SDG&E’s proposed auction process, proposed contracts, and proposed ratemaking. In the second part of the process, SDG&E would conduct the proposed auctions. SDG&E will receive and consider proposed contract changes from second round bidders prior to receipt of final bids from second round bidders. SDG&E will, at its sole discretion, adopt the final form of the contracts. Final bids will then be received. Upon selection of the winning bidder for each asset, If SDG&E will were to receive satisfactory bids for some or all of its generating assets being divested, it would then negotiate final contracts with the winning bidder(s) and submit the final executed contracts to the CPUC for approval.

Accordingly, the new owner(s) of such facilities would be assigned of SDG&E’s "must-run" contract with the ISO to ensure that electric power would be available when needed for reliability, to maintain transmission ratings, and to prevent price manipulation during times when market power exists, for as long as such facilities remain "must-run" facilities.

SDG&E agreed to prohibit the future placement of any gas- or steam-powered turbines, heat recovery steam generators, or electric generators on portions of the South Bay Power Plant located north of Telegraph Creek (see Figure 2.7 later in this section), but to eliminate any other deed restrictions on future land uses at the South Bay Power Plant site.

Decommissioning includes the decontamination, demolition, dismantlement and removal of any portions of the plant included among the assets being sold, and remediation of the soil and groundwater below the same as more fully described in the Asset Sales Agreement.

The Port District would also be responsible for all existing and future hazardous material contamination and soil and groundwater contamination at the LNG site and the transmission property, except that the Port District may elect to have SDG&E remediate such property to meet industrial standards subject to the terms of the agreement between the Port District and SDG&E.

The South Bay Power Plant is located on a roughly 116-acre site located at 990 Bay Boulevard in the City of Chula Vista. In addition to the South Bay Power Plant site, SDG&E owns a roughly 33-acre site just south of the power plant that includes a now-decommissioned liquid natural gas (LNG) storage facility and a roughly 16-acre transmission corridor that runs north of the power plant and adjacent to a railroad right-of-way.

...of roughly 13.9 million gallons. The displacement oil stored at the refueling facility is was formerly used to fill the pipeline between residual fuel shipments to the power plant. The pipeline now is filled with nitrogen gas between shipments. This procedure is required because...

The new owner would acquire access to the site pursuant to SDG&E’s access agreement with the Navy.

SDG&E leases one additional above-ground tank at the site to Energy Factors, Inc.

The San Onofre Nuclear Generating Station (SONGS) is located on a roughly 90-acre site next to San Onofre State Beach on the Camp Pendleton U.S. Marine Corps Base in unincorporated San Diego County, just south of the City of San Clemente. SONGS has two active generating units (Units 2 and 3) and one retired generating unit (Unit 1)., with Units 2 and 3 have a combined net generating capacity of 2,150 MW, enough power to serve the needs of roughly 2.75 million households. Unit 2 has a net capacity of 1,070 MW, while Unit 3 has a net capacity of 1,080 MW. The net generating capacities of Units 2 and 3 reflect the rated outputs of those units. The maximum output from these units, which may be higher or lower than the said net generating capacities, on any given day varies due to ambient temperatures and other operating conditions. Units 2 and 3 were constructed were placed into commercial operation in 1983 and 1984, respectively. Combined, the two units occupy approximately 53 acres of the site. Unit 1 was constructed in 1967 and retired, after 25 years of service, on November 30, 1992. Unit 1 had a net generating capacity of 436 MW and has since been decommissioned. Edison and SDG&E are currently planning to submit a request in December 1998 to the Nuclear Regulatory Commission to commence the decommissioning of Unit 1. Unit 1 was a Westinghouse pressurized water reactor, while Units 2 and 3 are both Combustion Engineering pressurized water reactors of identical design. Under their current licenses, Units 2 and 3 are authorized to operate through 2013. When the units are eventually decommissioned, the underlying land must be returned to the government in an unrestricted use condition.

…other common areas. Moreover, SDG&E and Edison are tenants-in-common with respect to Unit 1.

Under the SONGS Agreements, Edison has been designated the Operating Agent. As such, Edison is primarily solely responsible for operating and maintaining the SONGS facility, for conducting required capital improvements, arranging for nuclear fuel, and refueling of the units. Edison’s responsibilities also include managing SONGS personnel, personnel training, procurement, quality assurance, ensuring that adequate support resources are available, and settling claims. The specific duties and responsibilities of Edison, as the Operating Agent, and the other co-owners, including SDG&E, are set forth in the SONGS Ownership Agreement, dated October 5, 1967, the San Onofre Units 2 and 3 Participation Agreement, dated November 1, 1997, and the Second Amended San Onofre Operating Agreement, dated February 26, 1987. SDG&E, as a co-owner, has certain responsibilities related to operating and maintaining the SONGS facility as described in the SONGS Agreements.

Edison, the City of Riverside, and the City of Anaheim each have contractual rights of first refusal to purchase SDG&E’s ownership interest in the SONGS Units 2 and 3 and associated units and facilities, while only Edison has a contractual right of first refusal to purchase SDG&E’s ownership interest in Unit 1.

Again, the sale of the power contracts and the interest in SONGS would not change the underlying operations of the electricity generating facilities involved since they would not be primarily controlled by the new owner

SDG&E does not now manage or control the daily operations of SONGS or of the electricity generating facilities that produce the power covered by the power supply contracts.

A new air emissions permit and different SDAPCD Rule 69 requirements rule changes may cause the new owners to make different decisions (e.g., accelerated installation of selected catalytic reduction (SCR) on units, or changes in the decision-making process for selecting the fuel type used at the Encina and South Bay plants) than SDG&E would if the plants continued under SDG&E’s ownership.

…such as the Regional Water Quality Control Board for an NPDES permit the USFWS for a FESA Section 10(a) permit. The process of re-applying for these permits could also cause the new owners to make different operational and maintenance decisions that than would SDG&E if it continued to own the plants.

However, the general characteristics of the buyers of the plants previously divested by Pacific Gas and Electric Company (PG&E) and Southern California Edison Company (Edison) are known.

The project site includes generation facilities (five steam turbines and a combustion turbine), fuel tanks, a switchyard, a machine shop, and related facilities on approximately 95 acres south of the Agua Hedionda Lagoon. Agua Hedionda Lagoon, which is part of the project site, encompasses approximately 265 acres of water and offers opportunities for a variety of recreational activities. The lagoon consists of three basins known as the outer, middle, and inner basins. A sea bass fish hatchery operated by the Hubbs-Seaworld Research Institute (which leases approximately 10 acres on the north shore) and a mussel farm are located in the outer basin. A YMCA camp is present in the middle basin. The middle basin is open to boating and jet skiing. The Snugg Harbor Marina which rents equipment for jetskiing, sailboarding and waterskiing, is located in the inner basin, which is otherwise generally open to boating and jetskiing. located on the north shore of the middle basin, rents equipment for jetskiing, sailboarding, and waterskiing. The approximately 200 acres of wetlands at the east end of the inner basin are attractive to hikers and bird watchers. Also included in the project site is the 6.6-acre site of the Hubbs-Seaworld Research Institute (which leases the property from SDG&E) on the north shore of the outer basin of the lagoon, and a roughly 20-acre section of beach west of Carlsbad Boulevard.

Cannon Park, a small neighborhood park at the corner of Carlsbad Boulevard and Cannon Road, was given leased to the City of Carlsbad by SDG&E in 1963 (Sempra Energy, 1998).

The South Bay Power Plant is located on an approximately 116-acre site at 990 Bay Boulevard within the City of Chula Vista.

SDG&E’s contract with the Navy for the use of the land on which these two CTs are located expired on September 28, 1998 was recently extended for a term of 30 months and is currently being extended on a month-to-month basis.

Figure 4.1.1 shows the City of Carlsbad General Plan (1994) land use designations for the project site and surrounding lands. The land use designations for the project site are U (Public Utilities), covering the majority of the dry land, and OS (Open Space), covering the Agua Hedionda Lagoon and Cannon Park. The Public Utilities designation allows such uses as "the generation of electrical energy, treatment of waste water, public agency maintenance, storage, and operating facilities, and other primary utility functions designed to serve all or a substantial portion of the community" (City of Carlsbad, 1994). The Open Space designation covering the Agua Hedionda Lagoon and Cannon Park serves to preserve natural resources, aesthetics, and recreational resources. The project would not involve new construction, and any projected changes in operation (such as increased generation) would continue to be consistent with General Plan designations.

As shown in Figure 4.1.2, the City of Carlsbad zoning designations for the SDG&E property proposed to be divested are P-U (Public Utility), and OS (Open Space Zone [Water]), and R-A-10 (Residential Agricultural) (City of Carlsbad, 1997). The Public Utility zone covers the majority of the dry land, and the Open Space zone covers the waters of the Agua Hedionda Lagoon, and the Residential Agricultural zone covers a small portion of the dry land between the east and west lagoons. The generation and transmission of electrical energy is a permitted land use in the P-U zone; other permitted uses include energy transmission facilities; the processing, use, and storage of natural gas; and the use and storage of fuel oils. The facilities on site will continue to be used for electrical generation and transmission purposes. The Encina Power Plant is, and would continue to be under divestiture, consistent with City of Carlsbad zoning designations. Uses within the areas zoned OS would not be expected to change.

A portion of SDG&E property located between the middle and outer lagoons, The land zoned R-A-10 (Residential Agricultural), is not proposed for sale. This property is currently leased to the Hubbs-Seaworld Research Institute. Aquaculture is permitted under zoning designation R-A-10 with a Conditional Use Permit (CUP) (Carlsbad Municipal Code 21.42.010(1)(L)). The City of Carlsbad has issued a CUP for the Hubbs-Seaworld. SDG&E’s lease with Hubbs-Seaworld Research would continue under the project. The existing lease would be transferred to the new owner, and future leases of the site would be subject to negotiation with the new owner. There is no reason to believe that a significant change of land use at this site would result from the project. The R-A-10 is a "Residential Agricultural" zone. It does not appear that the existing use conforms with this zoning designation. However, the sale would not increase or exacerbate that inconsistency.

Although that it does not appear that the lack of an…

As described in detail in the Section 2, Project Description, SDG&E proposes to sell five of the seven parcels located west of Interstate 5. However, SDG&E would reserve an exclusive easement from the buyer for continued SDG&E use and occupancy of land containing the North Coast Construction and Operations Center, as well as a mostly vacant storage area located south of the tank farm. SDG&E would also reserve to itself the right to purchase these SDG&E easement lands at a nominal cost if and when the necessary lot line adjustments are implemented. In addition, SDG&E would grant the buyer an easement to use, dredge, and otherwise maintain the inner and outer lagoon basins located east of Interstate 5 for purposes of electric generation at the Encina Power Plant. SDG&E would grant to the buyer the right to purchase, at nominal cost, the inner basin if and when the required lot line adjustments that accommodate such purchase are approved. Since any such lot line adjustments would occur subsequent to the sale of the plant and are not necessary for the sale to occur, they are not considered to be part of the project.

SDG&E proposes to reparcelize the lands on which the Encina Power Plant is located in order to separate the power generation assets from the power transmission and distribution assets. This action would involve a modification of lot lines through a lot line adjustment process. The lot line adjustment process would relocate existing property lines, but would not create new lots (SDG&E, 1997). SDG&E has stated that the lot line adjustments would conform to all applicable jurisdictional zoning requirements, including development standards for street frontage, minimum lot area, and width (Dodson, 1998).

The San Diego Unified Port District (Port) maintains jurisdiction of land and water located west of the historic mean high tide line. The South Bay Power Plant is located within the Chula Vista Bayfront - Planning District 7 of the Port Master Plan. There is a small upland parcel within the west portion of the South Bay Power Plant leased by the Port to SDG&E which is designated as "Marine Related Industrial." In addition, SDG&E leases water area from the Port for purposes of the cool water intake and warm water outfall channels. A SDG&E dike, used to separate these channels and provide access to the Chula Vista Wildlife Reserve, is also leased from the Port. The reserve, dike and surrounding water areas are designated in the Port Master Plan as "Conservation" areas, with the intent to preserve, maintain and enhance natural habitat areas. As part of the sale of the plant, SDG&E would assign the lease of the upland, water and dike areas to the new owner (unless if the Port were the new owner, in which case the title for the plant property would be merged with the lease holdings) (Dodson, 1998b). Since no changes in land use are expected from the project, the plant would be continue to be consistent with the Port Master Plan.

The new owner of the CT will be entitled to access to and continued use of the site in accordance with SDG&E’s access agreement with the Navywould be required to enter into a lease agreement with the federal government to continue to use the property.

The new owner of the CT will be entitled to access to and continued use of the site in accordance with SDG&E’s access agreement with the Navywould be required to enter into a lease agreement with the federal government to continue to use the property.

The new owner of the CT will be entitled to access to and continued use of the site in accordance with SDG&E’s access agreement with the would be required to enter into a lease agreement with the Navy for the continued use of this site.

The Encina Power Plant is located in an established community and has been a local feature along on the coast since 1954.

The South Bay Power Plant is located in southwestern San Diego County, in the City of Chula Vista. The population of Chula Vista in 1997 was 156,148, a 16 percent increase from its 1990 population of 135,163 (SANDAG, 1998c). The estimated population in 2015 is 173,001 239,144 (SANDAG, Series & Regional Growth Forecast). The housing stock in Chula Vista in 1997 was 55,258 units and is anticipated to increase to 61,047 82,221 units in 2015. The vacancy rate currently is in 1997 was 4.1 4.06 percent and had remained unchanged since 1990. Population per household in Chula Vista as of 1997 1998 was 2.92 2.975.

SDG&E has permits from the California Coastal Commission, the RWQCB, the State Lands Commission, the State Department of Parks and Recreation, and the U.S. Army Corps of Engineers for the removal by dredging of specific quantities of sand.

The beneficial uses are identified in the Regional Board’s Water Quality Control Plan: San Diego Basin (often referred to as the "Basin Plan") and the state’s Water Quality Control Plan: Ocean Waters of California (referred to as the "Ocean Plan").

The plant discharges the cooling water through a discharge canal located to the south of the plant. The discharge is regulated by the RWQCB through NPDES Permit No. CA0001368. The NPDES permit establishes the upper thermal limits, which are based on the plant’s maximum generation capacity. At full capacity, the plant is permitted to discharges 601 mgd of cooling water and 1 mgd of metal cleaning wastes and low-volume wastes (RWQCB, 1996). However, according to SDG&E, the metal cleaning wastes are related to the boiler cleanings and typically occur only once per year per unit. Low volume wastes are typically discharged at a rate of 100,000 gallons per day but may fluctuate significantly on a day-to-day basis. The metal cleaning wastes and low-volume wastes are from essentially the same plant processes as described above for the Encina Power Plant.

SDG&E regularly adds chlorine to the cooling water to remove marine biological growth in the plant’s condenser tubes and associated pipes. Accumulated growth restricts the flow of cooling water and increases the volume of cooling water needed to maintain constant condenser temperatures. Cooling water volumes can be increased by increasing the speed of variable speed pumps or by adding additional pumps. However, once all the pumps are running at full speed, volume can no longer be increased and condenser temperatures will begin to rise, thus significantly reducing the generating efficiency of the plant and eventually damaging equipment. Each unit is equipped with two cooling water pumps. Cooling water volumes and discharge temperatures are adjusted by turning these pumps on or off (Sempra Energy, 1998).

To reduce biological growth, a sodium hypochlorite solution is injected into the cooling water immediately upstream of the cooling water pumps for each unit. The injection is conducted intermittently throughout the day on each unit that is operating on an as-needed basis. The quantity of sodium hypochlorite use depends on the rate of slime and algae formation. More treatments are needed in the summer than in the winter (RWQCB, 1996). Residual amounts of chlorine are discharged with the cooling water, and the concentration and mass loading are regulated by the plant’s NPDES permit. Chlorine decays to non-toxic chloride ions when it reacts with other constituents, such as ammonia and organic compounds. During the chlorine treatment, the cooling water from the unit being treated is blended with the cooling water from the other operating units, resulting in an average four-fold dilution even before discharge to the bay (Lauer, 1996).

The allowable chlorine residual final limit for the cooling water effluent was substantially reduced in the 1996 NPDES permit compared to prior permits due to a decision by the RWQCB to use the California Ocean Plan as the basis for the permit limit. The final limit is scheduled to replace the interim limit on December 15, 1999. However, SDG&E and the RWQCB have revisited the applicability of the stricter limit. SDG&E and the Regional Board staff, with concurrence from the Deputy Attorney General and Counsel of the Regional Board, have reached resolution on the issue. The Regional Board is scheduled to adopt an amended permit with reasonably implementable limits and in October 1998, the RWQCBand public notice of the proposed amendment has been issued Addendum No. 3 to the NPDES Permit (RWQCB, 1998). This Addendum establishes a chlorine effluent limit based on a calculated receiving water limitation determined by a statistical analysis of the discharge and water quality monitoring data.

Metal cleaning wastes are generated from chemical cleaning operations within the power plant, including boiler fireside washes, air preheater washes, and boiler waterside acid and chelant cleanings. Wastes are collected in aboveground tanks. The effluent from the impoundments and portions of the low-volume wastes are sent to the chemical treatment facility. The treated wastewaters are collected in tanks for testing and verification of the NPDES permit limits prior to discharge to the intake basin. Sediment that accumulates in the tanks is periodically removed and disposed of as a hazardous waste (Woodward-Clyde, 1988).

Low-volume wastes include boiler blowdown and wastes from floor drains, the water softener, and the reverse osmosis brine. The low-volume wastes are conveyed to the on-site treatment plant. The power plant also maintains an Industrial Waste Permit (No. 13-0019) from the Cities of Chula Vista and San Diego, which allows discharges to the sewer system of industrial wastes of up to 100,000 gallons per day meeting certain quality requirements (SDG&E, 1997). Since December 1997, all low volume and metal cleaning wastes are discharged to the municipal sewer system (Sempra Energy, 1998).

The discharge specifications of the permit contain numeric effluent limitations for settleable solids, turbidity, pH, and acute toxicity, as well as toxic materials. Limitations are also provided specific to the low-volume wastes and metal cleaning wastes. Limits on many constituents are based on both concentration (e.g., grams/liter) and mass emissions (e.g., lbs/day).

Each of the power plants is regulated by the San Diego RWQCB by NPDES permits for both direct discharge to receiving waters and for stormwater runoff. The NPDES permits for each of the plants allow for discharges up to the amount of water required to operate the plant at design capacity. Cooling water discharges from the power plants are the predominant sources of thermal loading to San Diego Bay and to the marine environment in the vicinity of the Encina Power Plant, although natural processes also tend to elevate the temperature of the shallow back bay in the vicinity of the South Bay plant.

The production of the low-volume and metal cleaning waste streams occurs as part of scheduled maintenance. For example, each boiler at the Encina plant normally undergoes boiler cleaning once every four years. However, the volume of metal cleaning wastes produced on an annual basis is dependent on plant operations (RWQCB, 1994). With higher production rates, maintenance may be conducted at more frequent intervals. Therefore, the project may result in the increased production of low-volume waste or metal cleaning wastes., but the However, the amount of discharge of these wastes at the Encina plant would continue to be regulated by the NPDES permit limitations, and at the South Bay plant, these wastes are discharged to the sewer.

The project could result in additional generation of energy and, therefore, require additional water for cooling. Cooling water, however, is controlled at the plants by the use of variable-speed drive multiple pumps that operate at different levels are turned on or off depending on the level of generation at the plant., or the use of multiple pumps, some of which turn off when not operating at maximum capacity. Therefore, the amount of thermal discharge from the plants has some relationship to the level of electricity being generated at the plants. If a unit is completely off, some or all of the unit’s circulation pumps are typically off, although at times a volume of water that is less than full-operation volume is kept circulating for various process needs. Therefore, additional energy generation would likely require additional time when the pumps are in full operation. The pumps would extract and subsequently discharge additional water. The additional amount of water would not correlate directly with the increase in generation, but, in general, higher generation rates would result in higher volumes of intake water and higher volumes of heated discharge water. However, these discharges would have to comply with the existing NPDES permit conditions for flow quantity, thermal limits, and effluent constituent limits.

Toluene Benzene is a trace contaminant, but it can be detected in stack emissions where natural gas is burned.

The Encina Power Plant also includes a gasoline dispensing facility.

According to SDG&E, most of the NOVs were dismissed by the issuing agency without further action and no NOVs are outstanding.

The results of the 1992 HRA were adjusted to reflect current (1996) emissions estimates to provide a basis for updating the estimated health risks associated with the Encina Power Plant. The current estimated cancer risk for a maximum exposed individual (MEI) at the location of highest impact and caused by existing plant emissions is lower than one in a million (0.09 0.96 in a million). The major contributing pollutant (99% 91% of the total risk) was from methylene chloride and perchloroethylene from painting and cleaning operations gasoline vapor which is associated with the gasoline dispensing facility. Other contributing pollutants were methylene chloride and perchloroethylene from painting and cleaning operations, metals from fuel oil combustion by the boilers, and formaldehyde from natural gas combustion by the boilers.

According to SDG&E, many of these NOVs were dismissed by the issuing agency without further action and no NOVs are outstanding.

They have historically been used as peaking units and, as such, operated less than 100 hours per year; however, following the commencement of the restructured electricity market in March 1998, the dispatch requirements from the ISO have required that the CTs run at higher levels are peaking units operated generally less than 50 hours per year.

Health risk assessments were performed in 1992 for three CT sites (Naval Station, Naval Training Center, and North Island). For these 1992 assessments, the SCREEN dispersion model was used to estimate ambient concentrations of TACs surrounding the facilities. These concentrations were in turn used to derive a conservative estimate of health risks. The 1992 health risk assessments were based on estimated emissions provided in SDG&E’s 1989 AB 2588 Toxic Air Contamination Report. Beginning in 1990, emissions from the combustion turbines declined substantially relative to prior years because the units began to function nearly exclusively as peaking electric power generators. In 1990, the units on average operated 3% of the total hours operated during 1989. Between 1991 and 1997, the use of the units decreased even further, but during 1998, use of the units has increased again to levels similar to those that occurred in 1990. Therefore, the emissions and calculated risks from based on the decreased use of the combustion turbines are currently about less than 3% of the reported risks in the 1992 HRAs. The referenced assessments are discussed below along with a discussion of sensitive receptors in the vicinities of the CT sites.

The 1992 HRA estimated cancer risk for the MEI, which was has found to be located approximately 400 feet from the CT.

The 1992 HRA estimated cancer risk for the MEI, which was has found to be located approximately 400 feet from the CT.