ATTACHMENT A Lompoc Wind Energy Project Description 1.0

Project Overview

The proposed project is a commercial wind farm, the first such project in Santa Barbara County. The applicant is Pacific Renewable Energy Generation LLC. Pacific Renewable Energy Generation is a project subsidiary of Acciona Wind Energy USA LLC formed specifically to develop, construct and operate the Lompoc Wind Energy Project. The proposed project requires a Major Conditional Use Permit, pursuant to the County’s Inland Zoning Ordinance (Section 35-300). The application was found complete on June 1, 2006. The Project Description, Environmental Setting and Analysis; and Biological Resources Survey included in the application contain numerous applicant proposed mitigation measures to reduce potential environmental impacts during construction and operation of the project. The project would be located on approximately 2,950 acres of rural, agriculturally zoned land on coastal ridges south of Lompoc. The applicant has entered into long-term leases with the six property owners. The wind farm would have a maximum electrical generating capacity of 80-120 megawatts (MW), some of which would be sold to PG&E under a long-term power purchase agreement and delivered to the transmission grid. According to the project application, the proposed wind farm could generate up to 350 million kilowatt hours of electricity annually. The major project components include 60-80 wind turbines, new access roads and road improvements, a communication system, meteorological towers, an operations and maintenance (“O&M”) facility, onsite electrical collection and distribution lines, an onsite electrical substation, and a new 115kV PG&E power line to the Lompoc area to interconnect with the PG&E electric grid. In addition to the wind farm, the project includes a proposed amendment to the County’s Inland Zoning Ordinance to provide an exception to the existing height restriction. Project construction would occur in 2007-2008. The major part of the work would take approximately 6-10 months to complete. The anticipated operational life of the project is approximately 30 years. Future decisions would be made on lease renewals and possible repowering of the wind farm with advanced wind turbines, or decommissioning the project and restoring the land. 2.0

Location and Setting

The proposed project is located in a rural area of the County on ridges of the Santa Ynez Mountains along the coast between Jalama Beach and Point Arguello. The project is entirely in the inland zone of the County. The southern project boundary abuts the coastal zone. The project area is bounded by Vandenberg Air Force Base (VAFB) on the south and west sides and private property on the north and east sides. The location is approximately 3-5 miles south and slightly west of the City of Lompoc and 2-3 miles north of the coast (Map 1). It is accessed via San Miguelito Road, a public road that winds through the project area and dead-ends at the VAFB property line at the northwest edge of the project (Map 2).

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The project area comprises 10 privately owned parcels covering approximately 2,950 acres (4.6 square miles). The properties are zoned for agriculture (AG-II-100) and all are under Williamson Act agricultural preserve contracts. The principal use of the land is cattle grazing. Single family residences or mobile homes and agricultural accessory structures are located on seven of the 10 parcels. Historically, rock quarrying occurred in the area. The adjacent private properties are also agriculturally zoned. Table 1 – Project Landowners Property Owner(s) Signorelli Family Trust/Joe & Sylvia Signorelli Trustees

Assessor Parcel Number(s) 083-100-008; 083-250-011 & 083-250-019 Gerald & Sandra Scolari Revocable Trust; Rosabel Scolari 083-090-001 & 083-090-002 Cameron; LeRoy Scolari Adam Signorelli Trust/Adam Signorelli Trustee 083-090-003 Alphonso Scolari Revocable Trust/LeRoy & Gerald 083-080-004 Scolari Trustees Peter & Etelvina Signorelli Family Trust/Joanna & Larry 083-090-004 & 083-100-007 Signorelli Trustees Larsen Family Trust/John & Marlene Larsen Trustees 083-100-004 The nearest private residences on non-project properties are located more than 1,000 feet outside the project area perimeter. Other structures and uses in the project vicinity include the VAFB’s Sudden Peak Tracking Station near the southern perimeter and Frick Springs, a City of Lompoc water facility on San Miguelito Road adjacent to the west side of the Larsen Property (Map 2). The terrain includes rolling hills and rugged, steeper slopes. The southern boundary with VAFB follows the ridgeline for much of its length. Prevailing winds from the northwest regularly flow over the ridges. Some of the prime wind sites in the southern project area are near the VAFB property line. The area is semi-arid, with annual rainfall of 20 inches at the higher elevations. The project area drains into Hondo and Miguelito Creeks. Minor drainage channels feeding into those creeks are found throughout the area. Groundwater resources are limited. Some seeps and springs are present. Lowproducing wells provide ranchers with a minimal water supply for domestic use and cattle grazing operations.

Site photo showing project area terrain

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Grasslands are the most extensive broad vegetation type on the site, maintained by grazing. Several types of grassland are present, including annual and native perennial grasses. Coastal scrub is most common on the steeper slopes, with high coverages in some areas. Evergreen forest species (coast live oak, tanoak) are found on north-facing slopes, ravines and drainages, and eucalyptus groves are present in some areas. No turbines are proposed to be located in forested areas. Seeps and springs support willows and riparian vegetation in some areas. Gaviota tarplant, a federally listed, endangered species, is found in the project area. The southeastern corner of the project area is within the designated critical habitat of the California red-legged frog, a federally listed, threatened species. Extensive biological and archeological surveys of the project area, as well as an environmental setting and analysis discussion, containing applicant proposed mitigation measures have been prepared by the applicant and are included in the project application as part of the project description. The proposed PG&E 115kV overhead power line route is approximately 9 miles long from the proposed onsite substation to the PG&E point of interconnection to the electric grid in Lompoc (Map 3). The route traverses several agricultural properties to reach San Miguelito Road, follows the road north for approximately 2 miles, and heads east and north to the interconnect location just inside the Lompoc city limit. Most of the land area along the proposed route is agricultural. However, there are also many residences near the route along San Miguelito Road and in the City of Lompoc. An existing 115kV line from the Celite mine (near where the proposed new route reaches San Miguelito Road) to Lompoc takes a more direct route to Lompoc across mining and agricultural property. Much of the Celite line is in the direct view shed of the City of Lompoc. There may be opportunities to consolidate the existing line with the new line, potentially reducing visual impacts. 3.0

Project Components

3.1

Wind Turbines

The proposed project includes 60-80 wind turbine generators (WTGs), each with a capacity to generate 1.5 to 3.0 MW of electricity. The WTGs would be 315-490 feet in total height, from foundation to blade tip. They would be located in designated construction corridors (Map 2). The number of turbines proposed for each corridor is as follows: Table 2 – Estimated Number of WTGs to be Installed in Each Construction Envelope

Construction Envelope

Range of WTGs

West Ridge Scolari Ridge Signorelli Ridge South Ridge Middle Ridge North Ridge Sudden Ridge Larsen Ridge

7 - 13 3-6 4-8 9 - 21 9 - 21 12 - 26 12 - 25 3-8

The applicant has provided a preliminary layout showing tentative locations of 76 WTGs within the 8 corridors. The final locations will be subject to adjustment within the corridor up until the

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time of construction. This flexibility in WTG layout is needed in case information acquired in the environmental review, geotechnical surveys, or further wind studies indicates a modified layout is preferable. The WTGs would generally be arranged in strings. The WTGs would be spaced apart a minimum of one and one-half rotor diameters (350 to 495 feet) within a string, and the strings would be separated by a minimum of 1,400 feet. The WTGs would be set back from private property lines at the project area perimeter by a distance equal to the total system height, as required by ordinance (Sec. 35-300.4.7). The project application includes an application for a variance from the setback requirement to allow the turbines to be located as close as 150 feet from the VAFB property lines along the south and west project boundaries and from internal property lines within the project. The intent is to position the WTGs close to the ridge lines to best capture the wind, avoid placement on steeper slopes, and optimize WTG layout. In some locations this would mean placing the WTGs within the setback area. 1.5 MW WTG (similar to proposed) The WTGs would be of the three-bladed, horizontal axis design, the type installed in most modern, commercial wind farms. The blades would be approximately 155-165 feet long. Major components of such turbines include laminated fiberglass blades, a rotor hub to which the blades are bolted, and a compartment or “nacelle” that houses the mechanical workings of the WTGs, including drive train, gearbox, generator, and electrical and hydraulic components. The WTGs would be equipped with sensors and yaw and pitch controls to adapt to different wind speeds and directions so as to maximize power output. The WTGs would be microprocessor-controlled and operating data would be transmitted to the O&M facility for system monitoring and control. Each WTG would also be equipped with fire detection systems in the nacelle and tower. The WTGs would include redundant braking systems to shut down in high winds if operating parameters deviated from the normal range, or if a fire were detected in the turbine. In addition, a fail-safe system would cause a shut-down in the event of power failure and as a precaution during maintenance. A pad-mounted transformer, if it is used, would be located at the base of each tower to step the voltage up from the 600 volts generated by the WTGs to 34.5kV. Some turbine models have the transformer located inside the tower or nacelle. The applicant’s project description provides information about WTG design standards, certification, safety, and related topics. The WTG towers would be 200-330 feet in height. They would be a heavy-duty welded steel, epoxy-coated tubular construction, mounted on a concrete foundation. They would taper from

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approximately 18 feet in diameter at the base to 7 feet at the nacelle. They would weigh 80-285 tons and be transported to the site via trucks in 2-5 sections. The Federal Aviation Administration would require lights on the turbines. However, as the project is within restricted air space of VAFB, the lighting requirements may be minimal. The applicant anticipates that approximately 10-20 WTGs would need to be equipped with FAA lights. The WTG foundations would be one of three designs, depending on geotechnical constraints and other factors. The design types described in the applicant’s project description are: a) Patrick & Henderson Inc. (“P&H”) patented post tensioned foundation; b) rock anchor type; or c) a modified spread type footing method of construction. Depending on the design, the foundation would be up to 33 x 33 feet and 33 feet deep. Total combined cut and fill volumes for the WTG foundations are estimated at 68,000 cubic yards. For all designs, the exposed concrete pad would be approximately 18 feet in diameter and extend 0.8 feet above the surface. The construction area at each site would be approximately 49 x 49 feet. An adjacent area of a minimum of 36 x 66 feet would need to be cleared and graded to accommodate a crane during WTG erection. The total disturbed area for all WTG sites would be 7 to 9 acres and permanently disturbed area would be between 4 and 6 acres, depending on how many turbines are ultimately installed. 3.2

Access Roads

Numerous dirt roads are present throughout the project area and are maintained by the property owners for agricultural operations. To provide access during construction and operations, 8.3 miles of the existing roads would be improved and widened from their existing widths of 12-14 feet to 1624 feet. Some sections would need to be widened to 40 feet to provide access for the large cranes required for WTG installation. In addition, 5.23 miles of new roads would be constructed. Most of the new roads would be built to access the “North” corridor (see Map 2). Short sections of roadway would also be built in other parts of the project area. The wider stretches of road would be restored to a 24-foot width upon completion of WTG installation. The road work would include trenching and installation of underground electrical distribution lines and communication cables. The road would cross San Miguelito Creek at one point, requiring construction of a bridge. Crossings of 7 minor drainage channels would be accomplished with culverts. Portions of the proposed access roads are on relatively steep slopes (30%+). Based on the preliminary grading plan provided, total combined cut and fill volumes for the road work is estimated at 401,000 cubic yards. The total area disturbed by roads is estimated to be 27 acres, of which 23 acres would be permanently disturbed. All grading would be subject to a final, approved grading and erosion control plan to minimize erosion and ensure adequate slope stabilization. Disturbed areas would be revegetated following the roadwork. 3.3

Onsite Electrical Lines and Communication System

Each array of WTGs would be interconnected via cables. The cables would run underground from the transformer at the base of each WTG and connect to a riser linking the underground system to overhead 34.5kV distribution lines within the project area. The overhead lines would transmit the power from each array of WTGs to the proposed onsite collector substation. The voltage would be stepped up at the substation to 115kV to enter the proposed PG&E power line. The underground collector cables would follow the roads where feasible. Approximately 4 miles

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of aboveground, 34.5kV distribution lines would be required for the project. The aboveground lines would be supported by wooden single-poles or H-frame structures. Operation of the project would be controlled by an integrated, automatic control system, called Supervisory Control and Data Acquisition (SCADA), capable of monitoring all operational parameters and starting and stopping each wind turbine generator (WTG). The system is also interfaced with the fire detection system. The SCADA system transmits operating parameters and other data from each WTG to the central computer. The system allows remote control and monitoring of individual WTGs and the wind energy facility as a whole from the central host computer or a remote PC. The SCADA system can also send signals to a fax, pager or cell phone to alert operations staff to an operational problem. SCADA cables would be buried in the same trenches used for the electrical collector lines. 3.4

Meteorological Towers

Approximately six permanent meteorological towers would be installed in the project area to record weather data necessary to determine the most efficient operational strategy for the WTGs. The data collected includes wind speed and direction, temperature, humidity, barometric pressure, and rainfall. 3.5

Operations and Maintenance Facility

An operations and maintenance facility (O&M) is proposed to be located near the corner of Miguelito Canyon Road and Sudden Road (Map 2). The facility would occupy approximately 2 acres, and would include a main building with offices, spare parts storage, restroom, a shop area, outdoor parking facilities, a turn around area for larger vehicles, outdoor lighting and a gated access with partial or full perimeter fencing. The O&M building itself would be a pre-engineered metal building with a foundation footprint of approximately 50 x 100 feet. During construction, the O&M facility area will be leveled and graded and would serve as a central base of construction operations with up to 8 temporary office trailers. Water for the O&M facility operations would either be obtained from an unused well on the property or trucked in from Lompoc. Less than 500 gallons per day would be needed. The proposed water system includes a 5,000 gallon storage tank on the O&M facility grounds, a fire hydrant, and a sprinkler system in the O&M building. Effluent from the office drains would be disposed of through a proposed leach line system to be installed on the west side of the O&M facility. 3.6

Onsite Electrical Substation

Power from the overhead and underground distribution system would be delivered to the proposed substation located adjacent to the O&M facility (Substation Alternative #2). Two other alternative substation locations are shown on the project plan, in case routing of the 115kV power line or other factors make the applicant’s preferred Alternative #2 infeasible. The substation would consist of a main step-up transformer and other facilities to step up the 34.5kV power from the underground and overhead distribution lines to high voltage for delivery to PG&E’s 115kV grid. The substation would be approximately two acres in size, within a fenced enclosure and would consist of four components: a low voltage switchgear rack, step-up transformer, 115kV switchrack, and control building. The main step-up transformers would have

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a base rating of 85 megavolt amperes (MVA). The unit would be fan-cooled with two stages of fans, which increase the rating to 90-95-MVA. Fans are thermostatically controlled and would only run during periods of continuous high generator output. The 115kV switchrack would consist of a single line termination, disconnect switches, power circuit breaker, and a 115kV takeoff structure (the point at which PG&E would connect the new 115kV power line). The control building would house protective relaying and control equipment for the substation. 3.7

115kV Power Line

The 115kV power line would run approximately 7-9 miles to connect to the utility grid in Lompoc, the exact length depending on the final route selected (Map 3). The power line would run aboveground on wood or tubular steel poles. The proposed route runs approximately 2 miles northward through the project area, turns toward the southeast and then northeast over agricultural properties to San Miguelito Road at a point approximately ½ mile northeast of Miguelito County Park. From there, the proposed line follows San Miguelito Road northward for approximately 1½ miles and turns eastward across property owned by Celite Corporation. It crosses the existing 115kV Manville Tap power line and heads northward into the southeast corner of the City of Lompoc. It enters the City along Highway 1 and travels 2 blocks to Industrial Way. There it connects to PG&E’s existing Divide–Cabrillo #2 115kV power line outside the Cabrillo Substation. Although most of the proposed route is located on rural/agricultural property, the power line would come near a number of residences across San Miguelito Road and at the southeast corner of Lompoc. Alternative power line routes are discussed in PG&E’s Facilities Study. 3.8

PG&E System Upgrades

In order to connect the power generated by the project to PG&E’s existing power grid, upgrades to PG&E’s electrical system would need to be made, including: 1. Reconductoring (replacement of existing wires) on a portion of the Divide-Cabrillo #2 115kV line between Manville Junction and Switch 115, about ½-mile south of the Cabrillo Substation in the City of Lompoc. 2. Replacement of line relays and other equipment at the Divide Substation located on the east side of Highway 1 approximately 8.7 miles south of downtown Santa Maria. 3. Installation of protection equipment at the Morro Bay Substation at Duke Energy Power Plant (now LS Power) located in the City of Morro Bay and Atascadero Substation in Atascadero. Additional reconductoring may be required on the Midway-Temblor 115kV line and modifications may be needed at the Morro Bay Substation and Templeton Substation. The system upgrades are discussed in detail in PG&E’s Facilities Study. 3.9

Ordinance Amendments

The permit application includes an application for an amendment to the General Regulations of the County’s Inland Zoning Ordinance (Article III, Sec. 35-276) which limit the height of structures to 50 feet. The proposed amendment would allow the Planning Commission to grant exemptions to the height limit, on a project-by-project basis, to allow installation of wind

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turbines in agriculturally-zoned areas of the inland part of the County, taking into account visual impacts of the project. The ordinance amendment application also includes a request to amend the Ridgeline and Hillside Development Guidelines of the Inland Zoning Ordinance (Sec. Sec. 35-292b.3) to exempt wind turbines if the County determines that they are not already covered under the existing exemptions. 4.0

Project Construction

The construction phase would commence as soon as the requisite project approvals, including land use, grading, building, and other permits were obtained from the County. Construction is currently scheduled to occur in 2007-2008 and would last approximately 6-10 months. PG&E would proceed with power line construction after a public notice period lasting approximately 90 days following certification of the EIR, provided there were no significant environmental issues. However, if the EIR concluded that PG&E’s part of the project (i.e., 115kV power line and grid system upgrades) would cause significant unavoidable environmental impacts, or if protests were filed with the California Public Utilities Commission (CPUC) concerning potential environmental impacts of the power line, then PG&E may be required to apply to the CPUC for a Permit to Construct. The project would employ 50-100 workers at the site during the peak of construction. Grading would occur in the dry season to the extent practicable. Normally, construction would occur during daylight hours; however, some activities would require extended hours due to scheduling constraints, to maintain structural integrity of concrete pours, or due to other time-sensitive matters. The applicant-prepared project description includes details on project management, contracting, quality assurance, environmental protection program, safety program, etc. The following focuses mainly on the physical construction process. 4.1

General Procedures

The application states that construction “will be performed in a manner that will incorporate the impact mitigation methods outlined in other sections of this application, including, but not limited to erosion control measures, emission controls, surface water control measures, spillage prevention and control measures, environmental health mitigation measures, traffic control measures, and other construction practice measures that will minimize the project’s impact on the environment and the surrounding area.” Construction would be performed in stages, including: • Grading of field construction office and substation areas (also used for O&M building); • Construction of site roads, turn-around areas and crane pads at each wind turbine location; • Construction of the turbine tower foundations and transformer pads; • Installation of the electrical collection system – underground and overhead lines; • Assembly and erection of the WTGs;

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• Construction and installation of the substation; • Plant commissioning and energization. 4.2

Field survey and Construction Specifications

A site survey will be performed to stake out the exact location of the WTGs, site roads, and electrical lines. This will be followed by detailed geotechnical studies at each WTG location and the O&M building site. The studies would involve bore holes (e.g., 30-40 foot depth) and shallow trenching to identify soil and rock types and evaluate their properties. Using the acquired data, including geotechnical information, environmental and climatic conditions, site topography, etc., applicant’s engineering group will establish a set of site-specific construction specifications for each WTG and other components of the project. 4.3

Site Preparation and Road Construction

Construction activities would begin with construction of site access entry ways from San Miguelito Road, rough grading of access roads, leveling of the construction site office parking area and installation of 6 to 8 temporary site office trailers with temporary power at the intersection of San Miguelito Road and Sudden Road. Access roads would be gravel surfaced unless extremely steep slopes necessitate paving. Road construction would be performed in multiple passes starting with the rough grading and leveling of the roadway areas. Once rough grade is achieved, base rock would be trucked in, spread and compacted to create a road base. A capping rock would then be spread over the road base and roll-compacted to finished grade. Once heavy construction was complete, a final pass would be made with the grading equipment to level-out road surfaces and more capping rock would be spread and compacted in areas where needed. Water bars, similar to speed bumps, would be cut in to the roads in areas where needed to allow for natural drainage of water over the road surface and to prevent road washout. All road work would be performed under final approved grading, erosion control, and storm water quality management plans. Excess excavated soil and rock would be disposed of on site at approved disposal areas such as eroded gullies and ravines. Larger excavated rocks also would be disposed of at approved sites or crushed and re-used on-site as backfill or roadway material. Project road construction would involve the use of several pieces of heavy machinery including bulldozers, track-hoe excavators, front-end loaders, dump trucks, motor graders, water trucks and rollers for compaction. Storm water controls, such as hay bales and diversion ditches in some areas would control storm water runoff during construction. Access from public roads would have locked gates as agreed upon with the landowners. 4.4

Equipment and Water Requirements

Heavy equipment would be needed to clear the sites, build roads and WTG foundations, haul and lift materials, and pull power line. Once roads were opened and foundations built, cranes and trucks would move in to haul and lift the WTG parts into position for assembly. Approximately 420 to 600 trucks hauling WTG parts, each with a gross weight ranging between 30,000 and 150,000 pounds, would travel to the project site. The trucks would enter the area from Lompoc

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using truck routes and proceed to designated areas for unloading. Road material, concrete and water would be hauled from local sources. Table 3 – Equipment Requirements Equipment

Fuel Type

No. Units

Diesel Diesel Diesel Diesel Diesel Diesel Diesel Diesel Diesel Diesel Diesel

2 1 2 1 1 1 1 2 1 2-3 2

Excavator D-9 bulldozer D-8 bulldozer D-6 bulldozer 980 front-end loader 300-ton crane 120-ton crane 90-ton crane 14-H load grader Water truck Compactor

Equipment

Fuel Type

No. Units

Diesel Diesel Diesel Diesel Diesel Gasoline Electric Diesel Diesel Diesel

4-6 2 1 1 1 8 - 14 4 2 2 1

Concrete truck Dump truck Forklift Concrete pump truck Generator Pick-up truck Welder Line truck Scraper Trencher

It may be necessary to set up a concrete batch plant on the project site to meet construction needs. Foundations for each WTG require up to several hundred yards of concrete, which must generally be poured within 45 minutes of being made or “batched.” Because of the distances concrete trucks would have to travel to each WTG foundation and the quantities of concrete required, an onsite batch plant would reduce the travel time for the mixer trucks and might also reduce the number of trips over public or non-site roads. Reclaimed water from the Lompoc Waste Water Plant would be trucked in as needed for dust control during construction. An average of up to 9,000 gallons of water (5-6 truck trips) could be needed on days when dust control is needed. Total water usage for dust control and foundation construction would be approximately 38 acre-feet of water. Additional water would be trucked in for the concrete batch plant. 4.5

Disturbed Areas

Based on the project application, the areas of disturbance for the proposed project would be as follows: Table 4 – Estimated Temporary and Permanent Land Disturbance Project Component WTGs Met. Towers Access Roads O & M Building Substation

Area Disturbed per Project Component 0.114 acres / .069 acres permanent 0.02 acres 13.53 miles 2.0 acres 2.0 acres

Number of Components

Total Disturbance (acres)

Permanent Disturbance (acres)

60 - 80

6.8 - 9.1

4.1 - 5.5

6 n/a n/a n/a

0.12 27 2.0 2.0

0.12 23 2.0 2.0

Totals

38.0 - 40.2

31.3 - 32.6

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Foundation Construction

Foundations will be required for each WTG and pad transformer, the substation equipment and the O&M facility. Once the roads were completed for a particular row of WTGs, construction of the foundations for WTGs in that row would commence. Depending on foundation type used, each WTG foundation could require approximately 90 cubic yards of 4,000-6,000 psi test concrete and 80 cubic yards of 1,000 psi slurry mix, totaling approximately 18 to 20 truckloads of concrete per WTG. Anchor bolts would be embedded in the concrete, and the foundation would be allowed to cure prior to tower erection. Foundation pads and crane pads would be left in their graded condition and revegetated after WTG installation. Foundation construction would include the following stages: drilling, blasting (if required) and hole excavation, outer form setting, rebar and bolt cage assembly, casting and finishing of the concrete, removal of the forms, backfilling and compacting, construction of the pad transformer foundation, and foundation site area restoration. Excavation and foundation construction would be conducted in a manner that would minimize the size and duration of excavated areas required to install foundations. Portions of the work may require over excavation and/or shoring. Backfilling would be done immediately after approval by the engineer’s field inspectors. On-site excavated materials would be used for backfill where possible. An estimated 125 cubic yards of excavated soil would remain from each WTG. The excess soil not used as backfill for the foundations would be used to level out low spots on the crane pads and roads consistent with the surrounding grade and reseeded with a designated mix of grasses and/or seeds around the edges of the disturbed areas. Larger rocks would be disposed of off-site, or crushed into smaller rock for use as backfill or road material. Excess soil not used immediately around the turbine sites would be disposed of in eroded areas on site. 4.7

Electrical Collection System

After the roads and WTG foundations and transformer pads were completed for a particular row of turbines, underground cables would be installed along that road section. Trenches would be cut to the required depth. Cables would laid in the trenches, surrounded with a cushion of clean fill, inspected, and backfilled. Shallower trenches might be required where solid rock is encountered, and the cables would be protected with concrete. The 34.5kV cables would be connected to the WTG pad mounted transformers, and low-voltage wiring between the transformers and the bus cabinet inside the WTG towers would be completed, inspected, and tested. A field survey would be conducted to determine the exact power pole locations for overhead collector lines. Holes would be drilled and the poles erected with a small crane or boom truck. The poles would be set in place using concrete or compacted clean fill, according to the engineer’s specifications. The overhead lines would be connected to the underground cables at each end through a fused disconnect. 4.8

Substation and 115kV Power Line

As discussed previously, Substation Alternative #2 adjacent to the O&M building is the substation location preferred by the applicant. Alternate substation locations are shown on the

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site plan in case an alternative route is selected for the 115kV power line or Alternative #2 proves unsuitable for other reasons. A discussion of alternate power line routes is contained in the PG&E Facilities Study provided with the project application. The substation and interconnection facilities construction involves several stages of work including possible construction of access roads to pole locations, grading of the substation area, installation of a grounding mat, the construction of several foundations for the transformers, erection and placement of the steel work and all outdoor equipment, and electrical work for all of the required terminations. The high- and low-voltage sides of the substation may be separated by a fence and provided with separate control houses, as the high and low sides would be under separate control by PG&E and the project operator, respectively. Following construction of the substation, an inspection and commissioning test plan would be executed prior to substation energization. The proposed PG&E 115kV overhead power line would be constructed utilizing standard utility practices. The poles would be primarily single wood poles or light-duty steel poles up to approximately 75 feet tall. In some locations engineered structures with concrete foundations might be used to support the conductors. PG&E would be responsible for engineering, design and construction of the 115kV line and connections to the new substation. PG&E would also be responsible for making transmission system upgrades to accommodate the power generated by the project, as described in the PG&E Facilities Study. 4.9

WTG Erection

The WTG components would be delivered to the project site on flatbed transport trucks and the main components off-loaded at the individual turbine sites or possibly staged on the site before transport to the final location. After setting the WTG buss cabinet and ground control panels on the foundation, the tower would be erected by crane in sections. Tower construction would be followed by hoisting and installation of the nacelle; assembly, hoisting and installation of the rotor; connection and termination of internal cables; and inspection and testing of the electrical system. 4.10 Hazardous Materials Hazardous materials anticipated to be used or produced during the implementation of the project include fuels (gasoline and diesel), lubricants and motor oil, combustion emissions (e.g., NOx, carbon monoxide, hydrocarbons), and power line emissions (NOx and ozone). Accidental spills or leakage could occur. Construction equipment and O&M trucks would be properly maintained to minimize leaks of motor oils, hydraulic fluids, and fuels. Major vehicle maintenance would be performed off site at an appropriate facility. Gasoline- and diesel-powered vehicles and equipment would be re-fueled onsite at designated locations by a mobile fuel service truck. Handling of hazardous liquids would be subject to a Hazardous Materials Management Plan and Fire Protection Plan approved by the County Fire Department. 4.11 Start-Up When the installation of each WTG was complete, it would be inspected and checked for mechanical, electrical and control functions in accordance with the manufacturer’s specifications before being released for start-up testing. A series of start up procedures would then be

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performed by the manufacturer’s technicians, a process that requires 4 to 6 hours per turbine, or approximately 1½ to 3 months to commission 60-80 WTGs. Final testing involves mechanical, electrical, control and communications inspections and tests to ensure that all systems are working properly. After the WTGs have been commissioned and are producing power, a period of acceptance testing begins to ensure that the WTGs are performing according to the agreed-upon parameters, including the manufacturer’s warranted power curve. During this time, the power produced would be fed into the utility grid. Electrical tests on the transformers, power lines and substation would be performed by qualified engineers, electricians and test personnel to ensure that all electrical equipment is operating within tolerances and that all such equipment been installed in accordance with design specifications. PG&E would perform inspections and tests on the power lines and interconnection facilities. 4.12 Site Restoration Site restoration and clean up would include reseeding of disturbed areas, which would be done during the first suitable weather conditions after all of the heavy construction activities have been completed. Other activities following the main construction phase would include interior finishing of the O&M building, landscaping around the O&M area, washing of WTGs, painting of scratches on WTGs and exposed bolts, normal construction clean-up, etc. 5.0

Wind Farm Operation

During the operational phase of the wind project, a staff of approximately 10 staff would be employed onsite. Staff would monitor WTG and system operation, perform routine maintenance, troubleshoot malfunctions, and shut down and restart turbines when necessary. They would be headquartered at the O&M facility and travel around the site as needed. Normal operations could involve deployment of up to 3 crews of two technicians around the site and 2-3 personnel in the office. Staff might not be present at the site 24 hours per day. However, operations would be continuously monitored through the Supervisory Control and Data Acquisition (SCADA) system, which could be accessed from remote locations. Equipment, supplies, and spare parts would be stored inside the O&M facility. Spare parts might include large components such as a spare blade set or gearbox. The O&M facility would have equipment needed for routine operations and maintenance (e.g., forklift for unloading parts). Specialized equipment not needed routinely (e.g., cranes) would be brought onsite as needed. Service vehicles would be maintained at the facility. Maintenance of some components of onsite infrastructure (e.g., roads and electrical lines) may be sub-contracted out to qualified local firms. After the initial break-in period, the WTGs would be serviced at 6-month intervals, taking them offline for one day, one at a time. An annual overhaul maintenance service would also be performed. The service program is expected to maintain the WTGs operationally available 98% of the time. Most servicing would be performed on site and without using a crane to remove the nacelle or rotor from the tower. Service access is from inside the tower, via a door in the base. The 6-month routine would consist of inspections and testing of all safety systems, inspection of wear-and-tear components such as seals, bearings, bushings, etc., lubrication of the mechanical systems, electronic diagnostics on the control systems, pre-tension verification of mechanical

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fasteners and overall inspection of the structural components of the WTGs. Electrical equipment such as breakers, relays, and transformers generally require weekly visual inspections, which does not affect overall availability, and testing or calibrations every 1-3 years which may force outages. Blade cleaning is required when the accumulation of debris on the lead edge reduces aerodynamic performance. The blades would be spray-washed with water using a high pressure sprayer with extension nozzles from a standard boom manlift. Planned maintenance would be coordinated with PG&E and include a detailed schedule of planned outages. The outage schedule would be prepared annually and submitted to PG&E for approval. Periodic grading and compacting will be done on project access roads to maintain the design, safety and environmental requirements during the life of the project. Maintenance on cut and fill slopes, culverts, grade separations and drainage areas will be performed as necessary to minimize erosion problems and maintain functional drainage structures. The applicant would be responsible for cleaning up all construction debris and maintaining the appearance of all project roads and rights-of-way in cooperation with the project landowners. In the event that severe storms result in a downed collector line or power line, procedures outlined in the emergency response plan would be applied. Tensioning sites will be located within the overhead distribution line rights-of-way to facilitate line replacements. In the event of a high voltage grid outage, the WTGs have internal protective control mechanisms to safely shut the wind turbines down. The WTGs require the grid to be energized in order to generate power when the wind is blowing. A separate low voltage distribution service feed may be connected to the low voltage side of the collector substation as a back-up system to provide auxiliary power to project facilities in case of outages. Public access to public areas would not be impeded by the project, as the proposed facilities are located on private property (except for the section of the 115 kV transmission line that follows Miguelito Canyon Road). For safety, the proposed substation would be fenced, locked, and provided with proper signage to prevent access to high voltage equipment. Safety signing would be posted around all WTGs, transformers, and other high voltage facilities, and along roads, as required. The project site is within the County's High Fire Hazard Area. Vegetation would cleared and clearance maintained around the substation, transformers, riser poles, and O&M building. During the operational phase of the project, the applicant and landowners utilizing Miguelito Canyon Road and Sudden Road beyond their intersection may request the County to close this road to public travel. Only the landowners involved in the project and VAFB would utilize the road. A turn-around area would be provided at the end of the public road next to the O&M building. This option could benefit project safety and security. Hazardous and potentially hazardous chemicals (e.g., oil, grease, ethylene glycol) would be used to lubricate and cool the WTGs and ancillary facilities. The WTGs would be equipped with leakproof gaskets. Possible leakage or spillage during WTG operation and maintenance would be confined within the towers. A supply of chemicals would be stored onsite at the maintenance yard. To minimize the potential for harmful releases through spills or contaminated runoff, they would be stored in tanks or drums located within secondary containment areas. Use of extremely

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hazardous materials is not anticipated. Storage and use of hazardous materials would be subject to a Hazardous Materials Management Plan approved by the County Fire Department. Standard operating procedures and employee training relating to safety, potential emergency situations and potential malfunctions would cover emergency evacuation, emergency response, safety, electrical equipment failures, fire prevention and control, mechanical malfunctions, notification procedures, maintenance activities and schedules. 6.0

Decommissioning

The anticipated life of the project is greater than 30 years. At the end of its useful life, the project could be “repowered” (i.e., replace WTGs), renovated or upgraded, or decommissioned. The decision to decommission versus repower would depend on energy economics at the time, technological options, the landowners’ willingness to renew the leases with the project owner, and other considerations. If the project were repowered, full decommissioning would most likely be required before repowering. Depending on the new WTGs selected, none of the project components other than roads could normally be reused other than roads. At the end of the projected life of the project and expiration of leases, any leases that were not renewed would require full decommissioning of that portion of the project. If a portion of the project were to remain in operation and some new leases negotiated, some units would have to be decommissioned and collection lines rerouted if new rights-of-way could not be negotiated. If and when the project is decommissioned, all structures and equipment at the site would be dismantled and removed, and the land surface would be restored as close to the original condition as practical. Reclamation would be conducted on all disturbed areas to comply with County policy on reclamation. The short-term goal would be to stabilize disturbed areas as rapidly as possible, thereby protecting sites and adjacent undisturbed areas from degradation. The long-term goal would be to return the land to approximate pre-disturbance conditions. The leases with local landowners require Pacific Renewable Energy Generation to prepare a reclamation plan for the project. The County may also require a reclamation plan. The applicant proposes that the decommissioning plan would, at a minimum, a) identify and discuss the proposed decommissioning activities and how they would comply with the applicable regulatory requirements, and b) describe alternative decommissioning activities. Components proposed to be removed include: ● ● ● ● ●

WTGs including foundations, to a level 4 feet below the existing grade; Overhead poles and electric lines within the Project area; Underground collection lines to 4 feet below grade. The buried cables would remain. Substation, if project-owned. If it is utility owned, it could remain to be used as part of the utility service to supply other applications. Project roads would be reclaimed and reseeded to their original use, unless the project landowners wished to retain the improved roads for access throughout their property.

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If towers were sold for reuse, they would be dismantled at their bolted joints and removed by crane and trucked off the site the same way they were delivered. This might require the roads to be widened to the original construction width for crane access. Units sold as scrap would most likely not require widening of the roads for removal.

G:\GROUP\ENERGY\AltEnergy\Wind-EHN\CEQA\NOP-NOC\Attachment A - Proj Description.doc

Map 1: Project Vicinity

Map 2: Turbine Construction Corridors

Map 3: Proposed 115kV PG&E Powerline Route

ATTACHMENT B EIR Scope of Work I.

OBJECTIVES

The objective of this process is to develop an Environmental Impact Report (EIR) for the Lompoc Wind Energy Project under the California Environmental Quality Act (CEQA) to meet the legal requirements of a complete, adequate, and objective report of the proposed project's potential environmental consequences. The EIR will be a Project EIR pursuant to CEQA Guidelines §15161. It will serve as an informational document for the public as well as County of Santa Barbara and State of California agencies. The County will have the responsibility of considering certification of the final environmental document. The process will culminate with hearings in front of the Santa Barbara County Planning Commission and possibly the Board of Supervisors to make permitting decisions on the proposed project. II.

NECESSARY ENVIRONMENTAL ANALYSIS

The EIR must document the current baseline setting of the project area and proposed PG&E power line. The analysis must consider impacts to the environment resulting from all project components, including the wind turbines, new roads and changes to existing roads, stream crossings, permanent meteorological towers, maintenance building, water well or other source of water, sewage effluent disposal system, underground and aboveground 35kV onsite electrical lines, onsite electrical substation, PG&E 115 kV electrical power line to Lompoc, and upgrades to PG&E’s electrical system network. The analysis will need to encompass the construction and operational phases of the project, which may continue in operation for 20 to 30 years or more, and any reasonably foreseeable environmental effects of future decommissioning of the wind farm. The project application delineates construction corridors, within which the wind turbines will be located. Although a tentative turbine layout has been provided, the numbers and point locations of the turbines in each corridor are subject to change up until time of construction. The layout may change as a result of information acquired in geotechnical studies, environmental review, further meteorological studies, or other factors. Similarly, the tower heights, turbine rotor diameters, overall heights, and turbine electrical generation capacities are given as ranges, rather than firm numbers (e.g., overall height of 315-490 feet, to the top of the rotor), as the precise design will be specific to each turbine location. The applicant has committed to a total turbine height of 400 feet or less on the ridges immediately adjacent to Vandenberg Air Force Base (VAFB). Therefore, for purposes of analyzing potential adverse effects of the project on each resource, a worst-case configuration should be evaluated (i.e., the configuration with the greatest adverse effects to the resource being evaluated). The worst-case configuration may vary depending on which resource is being evaluated. For instance, locating turbines further down on steep slopes may reduce visual/aesthetic impacts while increasing grading-related impacts.

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All discussions of impacts should compare potential impacts to County thresholds of significance. In addition to the County thresholds, air quality issues should be analyzed pursuant to Air Pollution Control District (APCD) thresholds of significance. For all issue areas and potential impacts, discuss potential cumulative impacts as well as mitigation measures that could be used to minimize impacts to the environment. Mitigation measures conceived during the evaluation of the project must be refined in the EIR to ensure their feasibility, specificity and enforceability. Mitigations shall be explicitly written in language which can be directly applied to conditions of approval by the decision makers.1 Mitigation measures should be drafted in the County’s standard format. Each mitigation measure shall have a corresponding monitoring component which will describe, at a minimum, the party responsible for monitoring and when the monitoring shall occur. The monitoring component will also describe specific monitoring actions if they are not evident from reading the mitigation measure. 2 The analysis must include thorough discussions of project alternatives, short-term versus longterm impacts, the project’s consistency with relevant local and state policies, and any other required CEQA sections. III.

ENVIRONMENTAL ANALYSES AND APPLICANT-PROPOSED MITIGATION MEASURES PROVIDED IN THE PROJECT APPLICATION

The project application contains an extensive Biological Resources section (Appendix 2) prepared by Thomas Olson, Wildlife Biologist, and Katherine Rindlaub, Botanist, under contract with the applicant. This report contains substantial information on project setting, impact analysis, and proposed mitigation measures and should be reviewed carefully and incorporated in the EIR, according to the professional judgment of the EIR consultant. It should be noted that the extent of the areas examined in the biological studies may not exactly correspond to the turbine corridors and roads proposed in the final application, due to changes made during the initial application review process. The application also contains a Phase I Archeological Study (Appendix 3) prepared by Laurence Spanne under contract with the applicant. This study should be reviewed and incorporated in the EIR, according to the professional judgment of the EIR consultant. The application also contains an applicant-prepared Environmental Setting and Analysis section (Tab H), which includes proposed mitigation measures. This information should be used in preparation of the EIR, as appropriate in the professional judgment of the EIR consultant. In determining levels of environmental impact, the EIR analysis must take into account all the mitigation measures proposed by the applicant in its Project Description, Environmental Setting 1

Refer to Section VII.D of Santa Barbara County Guidelines for the Implementation of the California Environmental Quality Act of 1970, as Amended (Revised 11/22/05). 2 Ibid., Section VII.E

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and Analysis, Biological Resources Report and Phase I Archaeological Survey Report. These applicant-proposed mitigation measures are an integral part of the project description and are intended by the applicant to be implemented as enforceable permit conditions. The discussion of mitigation measures must distinguish between the measures which are proposed by project proponents to be included in the project and other measures proposed by the lead agency or that the lead agency determines could reasonably be expected to reduce adverse impacts if required as conditions of approval for the project. IV.

ENVIRONMENTAL FACTORS POTENTIALLY AFFECTED

The environmental impacts discussed below reflect a preliminary assessment of potential impacts, based on the project application and information on wind energy projects elsewhere. The following discussion is not intended to be comprehensive. The EIR should address potential environmental impacts and appropriate mitigation measures thoroughly. A.

Aesthetics / Visual Impacts

Impact Discussion The proposed project, which comprises 60 to 80 wind turbines standing 315 to 490 feet high, except for those ridges immediately adjacent to VAFB where total turbine height will be 400 feet or less, has potential for significant visual impacts. Analysis will require photo-simulations from multiple vantage points. The proposed wind farm could alter the visual character of the area and could potentially be considered aesthetically offensive or incompatible with the landscape. For aviation safety, some of the towers would need to be equipped with night lighting as determined by the Federal Aviation Administration (FAA), which could impact nighttime views of the southern skyline from across the Lompoc Valley. Both close-range and distant views could be affected and should be evaluated. The project area is not within a County-designated scenic highway corridor. Relatively few people would see the turbines at close range, due to the somewhat remote location, hilly terrain, and lack of any public destination in the last few miles of San Miguelito Road. However, the turbines would dominate the landscape for those who did see them close-up. Affected public would include sight-seers, naturalists, cyclists and others who venture out to the end of San Miguelito Road. Some turbines might be visible from parts of Lompoc, although many views would be blocked by the intervening hills. At distances of five to ten miles, turbines could be visible from the Lompoc Valley, Vandenberg Village, and possibly Jalama beach or other sites. At these distances, the turbines might be visually subordinate to the landscape, or might stand out enough to be considered visually significant or intrusive. The City of Lompoc has expressed concern about visual impacts, as the project area is situated within a view corridor on the City of Lompoc’s Scenic Roads and Ridgelines Map. Visual impacts of the proposed new PG&E 115 kV power line should also be considered. As proposed, the power line would be visible along Highway 1 (a designated Scenic Highway) approaching the Lompoc City limit. It would also run along San Miguelito Road for approximately 1½ miles. The proposed operations and maintenance facility (O&M facility),

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substation, and other onsite facilities would create some visual impacts as seen from San Miguelito Road. Visual impacts during the construction-phase would be limited mainly to the immediate project site, but should be evaluated to an appropriate level of detail. Mitigation Measures Alternative routes for the 115 kV power line may help minimize visual impacts of the power line. B.

Biological Resources

Impact Discussion Potential adverse impacts from construction and operation of the project are described extensively in the biological resources study accompanying the project application. Construction and widening of dirt/gravel roads, turbines, power lines, and other facilities could result in temporary direct impacts (e.g., loss of wildlife and plant individuals, loss or alteration of habitat) and indirect impacts (e.g., noise, human activity resulting in habitat avoidance by wildlife, night lighting, introduction and spread of weeds). Of special note are anticipated impacts to Gaviota tarplant, a federal and state listed, endangered species. Tarplant is found in the project area, and several acres of tarplant habitat would be permanently lost due to construction of the O&M building, substation, and turbines. 3 Also, the southeastern-most proposed turbine corridor is partially within the designated critical habitat of the California red-legged frog, a federally listed, threatened species. Road widening and turbine construction in that area could adversely affect red-legged frog habitat. Direct adverse impacts during wind farm operation would include collisions of birds and bats with turbines, power poles and power lines. Indirect effects on habitat would include increased human activity, noise, night lighting, dust, vehicle emissions, spread of weeds, etc. These effects could result in habitat avoidance by some wildlife species. The biological resources study suggests that impacts to birds may be less than significant with recommended mitigations, based on the numbers and species of birds observed in the area, the low-speed turbine design, and other factors. The potential for impacts to bats is uncertain. Mitigation Measures The environmental analysis and biological resources study provided in the project application lists a wide range of design features, construction techniques, operational measures, restoration approaches, and specific mitigations proposed to minimize identified impacts. For example, some of the measures suggested for Gaviota tarplant are: minimizing the extent of habitat disruption, tarplant seed collection prior to excavation, conservation of the soil seed bank, on-site restoration, and ecological research. Measures suggested for raptors and bats include design features to minimize avian collisions with turbines and wires, wildlife studies, timing of construction to avoid impacts to nesting raptors, avian mortality studies during wind farm operational phase, measures to reduce ground squirrel density to reduce attraction of raptors to 3

Please refer to the discussion of Gaviota tarplant in the Biological Resources Study contained in the project application (p. 52), which suggests that the species may be widely distributed between Point Sal and Gaviota.

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the area. As discussed in Section III above, all applicant proposed mitigation measures must be included in the analysis when determining levels of environmental impact from the project. C.

Archeological / Ethnic Resources

Impact Discussion The project location includes at least 15 archeological sites, some of which have potentially high significance. The sites are associated with prehistoric quarrying of Monterey Chert outcrops, plant processing, and other uses, as documented in a Phase I Archeological Survey conducted for the applicant. The study concludes that “…the project area must be considered highly sensitive in terms of archeological resources. The presence of numerous sites leads to the conclusion that this project has, without implementation of appropriate mitigation measures, a high potential to adversely impact significant archeological resources.” The survey indicates that extended Phase I and Phase II studies are needed to assess the resources and develop options to avoid disturbance of archeological sites and mitigate potential impacts. Mitigation Measures Mitigation measures that could minimize archeological impacts and potentially reduce them to a level of insignificance include: avoidance of known sites, capping roads with soil or gravel to isolate cultural deposits, Phase II archeological studies where site avoidance is infeasible, monitoring of excavation by a County-approved archeologist and a Native American Monitor, and suspension of work if potentially important cultural materials or human remains are discovered. D.

Geology / Soils

Impact Discussion The project involves substantial grading for roads and turbine foundations, which in some cases would be on steep slopes (20% to over 30% gradient). Roads and road widening would also require creek crossings: a bridge at Hondo Creek and culverts at seven minor drainage channels. Some existing roads would need to be temporarily widened to a width of 40 feet during construction, to accommodate large cranes. Following construction, roads would be restored to widths of 16-24 feet. Grading volumes are estimated at 245,000 cubic yards cut and 245,000 cubic yards fill. The volumes could be more or less, depending on final siting of the turbines. Potentially significant impacts include erosion, slope failure, and topsoil loss. Minor seismic faults are present in the project vicinity, raising the possibility of turbine structural failure during earthquakes. Mitigation Measures Proper engineering design and mitigation measures can significantly reduce geologic/soils impacts, potentially reducing them to a less-than-significant level. County-approved final grading and drainage and erosion control plans would be required prior to issuance of construction permits. Geotechnical testing would be conducted at all turbine sites to ensure stability and adequacy of the foundations, and all earthwork would be monitored and tested by a geotechnical engineer. The application states that the turbines will be constructed to Seismic Zone 4 standards, reducing possible risk from earthquakes. Soils would be analyzed for

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expansion potential. Specific measures may be implemented in the grading and erosion control plans to minimize surface runoff and siltation, stabilize slopes, ensure rapid revegetation, and preserve topsoil. Grading could be limited to the dry season. The applicant proposes to use excess excavated soil to fill eroded gullies and ravines on the project parcels, thereby reclaiming currently unusable land for grazing use, a potentially beneficial impact. A significant reduction of impacts to geology/soils might be achieved by restricting the turbines to the less steep slopes. However, this approach might come at the expense of other adverse impacts (e.g., visual), could place turbines unacceptably close to property lines, and might eliminate many turbines, possibly making the project financially infeasible. This approach should be discussed in the EIR. E.

Water Resources

Impact Discussion The proposed project is situated on the hills and ridges that drain into Hondo and Miguelito Creeks. Project roads will cross the upper reaches of Hondo Creek and seven minor drainage channels. Construction of roads and turbine foundations may increase surface runoff and siltation. Due to limited on-site water resources, the water required during construction would be obtained from City of Lompoc supplies and the Lompoc Waste Water Plant. During the project operational phase, an existing, unused water well at the site would provide the small amount of water needed at the O&M facility, estimated to be less than 500 gallons per day. An alternative of trucking in potable water to the O&M facility should be analyzed in the EIR. Approximately one truck load of water would be needed every 10 days. A sewage effluent system would be built near the O&M facility. Neither construction-phase nor operational-phase water use or disposal is expected to have significant impacts to groundwater resources. However, potential impacts on area groundwater should be examined thoroughly in the EIR. Mitigation Measures The County and the State Regional Water Quality Control Board will require a storm water quality management plan that incorporates appropriate best management practices. Implementation of the approved grading and erosion control plans, together with the storm water quality management plan, is expected to minimize increases in surface water runoff and reduce potential water quality impacts. F.

Transportation / Circulation

Impact Discussion During the project construction phase, there would be numerous truck trips to the project site via San Miguelito Road. The application anticipates 5-6 round trips per day of a 1,500 gallon water truck to the Lompoc Waste Water Plant. During the projected 6-month construction phase, up to 600 trucks carrying 30,000 to 150,000 pounds of turbine parts would arrive on site, as well as large construction vehicles and cranes. The heavy trucks may cause damage to the road surface. It is estimated that 30 trucks would enter and leave the area daily. Approximately 50-100

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construction workers would be employed at the site; assuming 70 workers, they would add another 140 trips per day. The construction traffic, primarily the large trucks, may be expected to impede travel on San Miguelito Road. During the project’s operational phase, a normal staffing of 10 full-time workers will be employed at the facility, up to a potential maximum of 30 workers. Currently there is no turn-around area at the end of San Miguelito Road where it deadends at Vandenberg AFB. On occasion, motorists get stuck in the ditch trying to turn around. The presence of a the wind farm could induce additional traffic on San Miguelito Road during the operational phase from individuals wishing to see the turbines, which could result in increased motorist strandings. Mitigation Measures Mitigation measures to reduce the construction-phase impacts on traffic and road conditions include the following: preparation of a detailed traffic control plan, photo documentation of preand post-construction condition of San Miguelito Road beyond the Celite mine, and payment for or repair of road damage. Construction of a turn-around area at the end of the road could eliminate the stranded motorist problem. G.

Noise

Impact Discussion Noise in the project area during construction could be substantial. In addition to traffic and construction noise, blasting may be required. Construction noise is a temporary impact; construction is expected to last approximately 6 months. There are few noise-sensitive receptors in the area, but all should be identified in the EIR. During wind farm operation, noise is not expected to be a significant impact. The modern wind turbines proposed operate at low speeds, nominally 10-23 RPM. A representative noise curve for a turbine of the general type proposed shows the sound level to exceed 50 dB(A) near the turbine, falling off to 35-40 dB(A) at 500 meters, the approximate distance to the nearest residence neighboring the project site. This noise level is comparable to the noise level within an average residence or the hum of a refrigerator. Further analysis will be required to estimate the overall noise impact of 80 turbines operating simultaneously at the site. Mitigation Measures Since the project is located in a very rural area of the County, the EIR should evaluate the need for restricted work hours versus the requirement that the applicant finish the project during the dry season. Additional mitigation measures should be recommended if blasting is required. Measures needed to mitigate significant operational noise impacts should be determined in the EIR, as appropriate. H.

Air Quality

Impact Discussion Grading, excavation, trenching, drilling, concrete mixing, and other construction activities using heavy equipment during the construction phase could result in adverse, short-term impacts from emissions and dust, and should be discussed in the EIR. Preliminary comments from the Santa

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Barbara County APCD indicate that “construction emissions are close to being significant (generally approx. 25 tpy of NOx is considered significant).” Operation of the wind farm should result in no emissions, apart from minor quantities of lubricants, solvents, and cooling fluids handled during maintenance and emissions from maintenance vehicles. Future project repowering or decommissioning could result in air quality impacts. Mitigation Measures To mitigate potentially significant emissions, APCD would require use of Ultra Low Sulfur Diesel, which will be available by this fall. The applicant also proposes to use high pressure injectors on certain Caterpillar engines to reduce NOx emissions and to ensure engines and emission systems are properly maintained. A dust control plan should be prepared, stipulating standard mitigation measures, such as water sprays of construction areas, 15 mph onsite speed limit, mulching and reseeding, etc., of disturbed areas, covering piles of topsoil, and covering trucks transporting soil. I.

Land Use

Impact Discussion The proposed project is located on agriculturally zoned property (Ag-II-100) in the inland area of the County. The Inland Zoning Ordinance (Chapter 35, Article III, Sec. 35-300) specifically allows for large wind energy projects on agricultural land, subject to a major conditional use permit. The EIR should include a preliminary analysis of the project’s potential consistency with a number of Comprehensive Plan policies and Zoning Ordinance requirements. In general, the project is likely to be consistent with the County’s Hillside and Watershed Protection, Streams and Creeks, and Historical and Archeological Site Protection policies. Additional policies and goals that should be reviewed include the following: Land Use Element – Visual Resource Policy #2: “In areas designated as rural on the land use plan maps, the height, scale, and design of structures shall be compatible with the character of the surrounding natural environment, except where technical requirements dictate otherwise. Structures shall be subordinate in appearance to natural landforms; shall be designed to follow the natural contours of the landscape; and shall be sited so as not to intrude into the skyline as seen from public viewing places.” Land Use Element Area/Community Goals applicable to the Lompoc Area, including: “The unique character of the area should be protected and enhanced with particular emphasis on protection of agricultural lands, grazing lands, and natural amenities.” “Commercial and industrial development that complements and expands the existing agricultural industry of the area should be encouraged.”

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The Inland Zoning Ordinance (Sec. 35-276) places a 50-foot limit on the height of structures, effectively precluding wind turbines. (Wind turbines are currently not included among the exceptions to the 50-foot limit.) The project application includes an application to amend the ordinance to provide a limited exception for wind farm projects. The Ridgeline and Hillside Development Guidelines (Sec. 35-292b) are intended to “provide visual protection of the County’s ridgelines and hillsides” and “encourage architectural designs and landscaping which conform to the natural topography on hillsides and ridgelines.” Conformance with the guidelines would limit turbine height to 16 feet, precluding the project. The project application includes a proposal to amend the ordinance to allow for wind energy projects if it is determined that none of the existing exemptions to the guidelines would apply. The Wind Energy Systems ordinance (Sec. 35-300.4.7) requires that the base of turbine towers be set back from property lines a minimum distance equal to the height of the system, including turbine blades. A major reason for the setback is to provide a buffer between turbines and adjacent properties, in case of a tower collapse or blade throw. The project application requests variances to reduce these setbacks to 150 feet along the Vandenberg AFB property line and between project-participant properties. Without a setback variance, the turbines would have to be sited up to 490 feet away from the property lines, in less advantageous wind locations or on steeper slopes. The project abuts VAFB property for much of the project’s southern boundary. The applicant has been in communication with Base officials to ensure the project does not conflict with Base operations, including flight paths, microwave paths, and telemetry tracks. Preliminary studies are included in the project application. Base personnel are currently reviewing the project application. Any issues raised by the Base concerning height, location of turbines, or other factors could constrain turbine configuration and affect potential impacts. The applicant has agreed to restrict total turbine height to 400 feet or less on the ridge lines immediately adjacent to the VAFB property lines. The applicant has submitted a draft turbine and construction corridor layout to VAFB for review. Discussions with VAFB on issues affecting the Base will be coordinated through the County and applicant. J.

Agriculture

Impact Discussion The proposed project is located on agriculturally-zoned property currently used for cattle grazing. Based on estimates in the project application, construction of roads, turbines, and other facilities would result in loss of less than 1% of the approximately 2,950 acres in the project area. Wind farm operations would be compatible with the grazing use of the land. Additionally, the supplementary income to the land owners through the wind farm leases could help ensure continued viability of their grazing operations. The County’s Agricultural Preserve Advisory Committee reviewed the project on June 2, 2006, and determined that it is a compatible use under the existing Agricultural Preserve contracts.

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K.

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Energy / Electric Utilities

Impact Discussion The proposed wind farm would have a maximum generation capacity of 80-120 MW of electricity, which would be sold to PG&E and flow onto the power grid. The application states that the project could generate up to 350 million kilowatt hours of electricity annually. (This is the equivalent of 100 MW installed capacity, operating at 40% efficiency.) Even the minimum proposed turbine capacity of 80 MW operating at 30% efficiency would generate 210 MW of electricity, enough to power over 30,000 residences. The energy produced would displace (i.e., avert the future need for) the same amount of fossil fuel-generated electricity. The project would help meet regional energy needs with clean, alternative energy, a beneficial impact to the environment. The project is well-aligned with certain policies in the Energy Element of the County’s Comprehensive Plan. Goal #5 of the Energy Element is to “Encourage the use of alternative energy for environmental and economic benefits, and encourage opportunities for businesses that develop or market alternative energy technologies.” Policy 5.1 states that during environmental analysis “the County consider the full life-cycle environmental effects and embedded energy requirements to provide such alternative energy,” and encourage alternatives with sufficient environmental benefits. The “full life-cycle environmental effects and embedded energy requirements” should be thoroughly discussed in the EIR. Policy 5.2 states, “The County shall encourage the use of alternative energy technology in appropriate new and existing development.” Regulatory Incentive 5.2.1 states, “Where appropriate and feasible, the County shall remove impediments (e.g., prolonged review due to a proposal including a new and different technology) to the utilization of alternative energy technologies that are cost-effective and contribute to improved environmental conditions.” L.

Fire Protection and Emergency Services

Impact Discussion The proposed project is located in a high fire hazard area of the County. The construction phase of the project has some potential to cause a fire, due for example, to sparks from equipment, welding, hot vehicle mufflers, etc. A fire could also be started during the operational phase, as a result of the increased onsite vehicular traffic and human presence, substation and power lines, and anticipated increase in sight-seers on San Miguelito Road. However, wind-farm personnel would be on the site, at least during daylight hours, improving fire detection and reporting in the area.

Notice of Preparation Attachment B – EIR Scope of Work June 30, 2006

Lompoc Wind Energy Project Page 12

Mitigation Measures Some fire-fighting equipment would be located at the substation, O&M facility, and carried in the vehicles. Each turbine would be equipped with a fire-detection system. A 5,000 gallon water tank would be located at the O&M facility, which would supply a fire hydrant and a sprinkler system in the building. The improved access roads would serve as fire breaks and facilitate access to fire fighting equipment. Regular clearing of vegetation would be required around the turbines, substation, O&M facility, and power poles. The applicant would prepare a Fire Protection Plan for approval by the County Fire Department. Workers would receive training on safety procedures, including emergency evacuation, emergency response, safety, fire prevention and control, and notification. Fire prevention would be reviewed at regularly held safety meetings. Smoking would be prohibited. M.

Risk of Accidents / Hazardous Materials / Safety

Impact Discussion Wind turbine blades have been known to dislocate from the hub under conditions that create excessive speed or vibration. The potential hazard posed by thrown blades should be addressed in the EIR. Wind turbine towers have also been known to fail structurally. Collapse of a tower could be triggered by an earthquake. With modern turbine and tower designs, the probability of blade throw or structural failure are believed to be very low, but should be considered in the EIR. For the proposed project, the consequence of such an accident may be low for most potential turbine locations, due to the low human usage of the area and distance of turbine corridors from residences. Potential consequences of an accident are higher for turbines located near San Miguelito road, and the risks of an accident should be evaluated in the EIR using the County’s Public Safety Thresholds. As discussed in Section I, the County’s wind ordinance requires that the base of turbine towers be set back from property lines a minimum distance equal to the height of the system, including turbine blades. The application requests a variance to reduce the setbacks to 150 feet from property lines between properties that are part of the project. The reduced setback could result in turbines up to 490 feet in height being sited as near as 150 feet from the publicly traveled San Miguelito Road near the proposed O&M facility. As an alternative to repositioning or eliminating turbine locations adjacent to Miguelito Canyon Road, the EIR should evaluate the impacts of closing public access to Miguelito Canyon Road and Sudden Road beyond their intersection and providing a turn-around at that location. Potentially hazardous materials will be used during construction, including adhesives, oil, grease, solvents, paints, propane, coolants, and fuels. There will be no onsite fuel storage; fuel trucks will be used for onsite refueling. There is potential for onsite spills of these materials. Potential EMF exposure of residents from the proposed 115 kV power line that should be discussed in the EIR. Power line proximity to residences should be taken into account in alternate power line routes evaluated in the project alternatives section of the EIR.

Notice of Preparation Attachment B – EIR Scope of Work June 30, 2006

Lompoc Wind Energy Project Page 13

Mitigation Measures The wind turbines proposed for this project are equipped with mechanisms to feather the blades and shut down the rotor under high wind conditions. A fail-safe braking system is designed to shut down the rotor in case of power loss. The application states that the turbines will be constructed to meet or exceed Seismic Zone 4 standards, reducing possible risk from earthquakes. Refueling of vehicles would be done in designated areas to avoid potential impacts to sensitive resources, and refueling trucks would be posted with spill contact information. A Hazardous Materials Business Plan and Fire Protection Plan would be required by the County Fire Department. The plan would include: 1) procedures for storage, use and handling; 2) a Spill Prevention, Control and Countermeasures Plan; 3) emergency response procedures; 4) employee training; 5) spill reporting; and 6) recordkeeping. N.

Impacts to Other Resources

Our preliminary analysis has not identified any potentially significant adverse effects for the following resources: ● ● ● ● ● ●

Recreation Mineral Resources Public Services Utilities / Service Systems Population / Housing Historic Resources

The EIR should address these issue areas to an appropriate level of detail. V.

PROJECT ALTERNATIVES

In addition to the “No Project” alternative required by CEQA, the following project alternatives should be included among those analyzed in the EIR. All alternatives should be clearly and concisely compared to the proposed project and the Environmentally Preferred Alternative should be identified. A.

Restriction of Construction Corridors

One or more of the alternatives analyzed should include curtailment of construction corridors so as to exclude areas with greatest potential for adverse impacts, while retaining as much of the wind harnessing capability as possible. The reduced corridors should exclude the steeper slopes, most important archeological sites, and/or areas of greatest biological sensitivity. The reduced corridors could also exclude locations with greatest visual impacts, if such locations are identified. The analysis should include a discussion of the effect of corridor reduction on project economics.

Notice of Preparation Attachment B – EIR Scope of Work June 30, 2006

B.

Lompoc Wind Energy Project Page 14

Power Line Routing Options

One or more of the alternatives should identify routing options for the 115 kV power line to minimize the proximity of the line to residences and visual impacts. One option may be to supplant the existing 115 kV Manville tap that supplies the Celite facility. Replacing the existing line with a new, consolidated line serving both Celite and the proposed project, if feasible, might result in reduced impacts. Alternative power line routes might require alternative locations for the proposed substation. C.

Substation Alternatives

The EIR should analyze the impacts of feasible alternative locations for the project substation. D.

Alternative Project Sites

As required by CEQA, the EIR must evaluate feasible alternative sites for the wind energy project. This analysis should consider the following factors: site suitability, economic viability, availability of infrastructure, general plan consistency, other plans or regulatory limitations, and jurisdictional boundaries. E.

Additional Alternatives

The EIR should identify and analyze other feasible alternatives that would reduce significant impacts.

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