Title 18—Conservation of Power and Water Resources--Volume 1
PART 380—REGULATIONS IMPLEMENTING THE NATIONAL ENVIRONMENTAL POLICY ACT
§ 380.1   Purpose.
The regulations in this part implement the Federal Energy Regulatory Commission's procedures under the National Environmental Policy Act of 1969 (NEPA). These regulations supplement the regulations of the Council on Environmental Quality, 40 CFR parts 1500 through 1508. The Commission will comply with the regulations of the Council on Environmental Quality except where those regulations are inconsistent with the statutory requirements of the Commission.
§ 380.2   Definitions and terminology.
For purposes of this part—
(a) Categorical exclusion means a category of actions described in § 380.4, which do not individually or cumulatively have a significant effect on the human environment and which the Commission has found to have no such effect and for which, therefore, neither an environmental assessment nor an environmental impact statement is required. The Commission may decide to prepare environmental assessments for the reasons stated in § 380.4(b).
(b) Commission means the Federal Energy Regulatory Commission.
(c) Council means the Council on Environmental Quality.
(d) Environmental assessment means a concise public document for which the Commission is responsible that serves to:
(1) Briefly provide sufficient evidence and analysis for determining whether to prepare an environmental impact statement or a finding of no significant impact.
(2) Aid the Commission's compliance with NEPA when no environmental impact statement is necessary.
(3) Facilitate preparation of a statement when one is necessary. Environmental assessments must include brief discussions of the need for the proposal, of alternatives as required by section 102(2)(E) of NEPA, of the environmental impacts of the proposed action and alternatives, and a listing of agencies and persons consulted.
(e) Environmental impact statement (EIS) means a detailed written statement as required by section 102(2)(C) of NEPA. DEIS means a draft EIS and FEIS means a final EIS.
(f) Environmental justice community means any community that has been historically marginalized and overburdened by pollution. Environmental justice communities include, but may not be limited to, minority populations, low-income populations, or indigenous peoples.
(g) Environmental report or ER means that part of an application submitted to the Commission by an applicant for authorization of a proposed action which includes information concerning the environment, the applicant's analysis of the environmental impact of the action, or alternatives to the action required by this or other applicable statutes or regulations.
(h) Finding of no significant impact (FONSI) means a document by the Commission briefly presenting the reason why an action, not otherwise excluded by § 380.4, will not have a significant effect on the human environment and for which an environmental impact statement therefore will not be prepared. It must include the environmental assessment or a summary of it and must note other environmental documents related to it. If the assessment is included, the FONSI need not repeat any of the discussion in the assessment but may incorporate it by reference.
§ 380.3   Environmental information to be supplied by an applicant.
(a) An applicant must submit information as follows:
(1) For any proposed action identified in §§ 380.5 and 380.6, an environmental report with the proposal as prescribed in paragraph (c) of this section.
(2) For any proposal not identified in paragraph (a)(1) of this section, any environmental information that the Commission may determine is necessary for compliance with these regulations, the regulations of the Council, NEPA and other Federal laws such as the Endangered Species Act, the National Historic Preservation Act or the Coastal Zone Management Act.
(b) An applicant must also:
(1) Provide all necessary or relevant information to the Commission;
(2) Conduct any studies that the Commission staff considers necessary or relevant to determine the impact of the proposal on the human environment and natural resources;
(3) Consult with appropriate Federal, regional, State, and local agencies during the planning stages of the proposed action to ensure that all potential environmental impacts are identified. (The specific requirements for consultation on hydropower projects are contained in § 4.38 and § 16.8 of this chapter and in section 4(a) of the Electric Consumers Protection Act, Pub. L. No. 99-495, 100 Stat. 1243, 1246 (1986));
(4) Submit applications for all Federal and State approvals as early as possible in the planning process; and
(5) Notify the Commission staff of all other Federal actions required for completion of the proposed action so that the staff may coordinate with other interested Federal agencies.
(c) Content of an applicant's environmental report for specific proposals —(1) Hydropower projects. The information required for specific project applications under part 4 or 16 of this chapter.
(2) Natural gas projects. (i) For any application filed under the Natural Gas Act for any proposed action identified in §§ 380.5 or 380.6, except for prior notice filings under § 157.208, as described in § 380.5(b), the information identified in § 380.12 and Appendix A of this part.
(ii) For prior notice filings under § 157.208, the report described by § 157.208(c)(11) of this chapter.
(3) Electric transmission project. For pre-filing requests and applications filed under section 216 of the Federal Power Act identified in §§ 380.5(b)(14) and 380.6(a)(5).
§ 380.4   Projects or actions categorically excluded.
(a) General rule. Except as stated in paragraph (b) of this section, neither an environmental assessment nor an environmental impact statement will be prepared for the following projects or actions:
(1) Procedural, ministerial, or internal administrative and management actions, programs, or decisions, including procurement, contracting, personnel actions, correction or clarification of filings or orders, and acceptance, rejection and dismissal of filings;
(2)(i) Reports or recommendations on legislation not initiated by the Commission, and
(ii) Proposals for legislation and promulgation of rules that are clarifying, corrective, or procedural, or that do not substantially change the effect of legislation or regulations being amended;
(3) Compliance and review actions, including investigations (jurisdictional or otherwise), conferences, hearings, notices of probable violation, show cause orders, and adjustments under section 502(c) of the Natural Gas Policy Act of 1978 (NGPA);
(4) Review of grants or denials by the Department of Energy (DOE) of any adjustment request, and review of contested remedial orders issued by DOE;
(5) Information gathering, analysis, and dissemination;
(6) Conceptual or feasibility studies;
(7) Actions concerning the reservation and classification of United States lands as water power sites and other actions under section 24 of the Federal Power Act;
(8) Transfers of water power project licenses and transfers of exemptions under Part I of the Federal Power Act and Part 9 of this chapter;
(9) Issuance of preliminary permits for water power projects under Part I of the Federal Power Act and Part 4 of this chapter;
(10) Withdrawals of applications for certificates under the Natural Gas Act, or for water power project preliminary permits, exemptions, or licenses under Part I of the Federal Power Act and Part 4 of this chapter;
(11) Actions concerning annual charges or headwater benefits, charges for water power projects under Parts 11 and 13 of this chapter and establishment of fees to be paid by an applicant for a license or exemption required to meet the terms and conditions of section 30(c) of the Federal Power Act;
(12) Approval for water power projects under Part I of the Federal Power Act, of “as built” or revised drawings or exhibits that propose no changes to project works or operations or that reflect changes that have previously been approved or required by the Commission;
(13) Surrender and amendment of preliminary permits, and surrender of water power licenses and exemptions where no project works exist or ground disturbing activity has occurred and amendments to water power licenses and exemptions that do not require ground disturbing activity or changes to project works or operation;
(14) Exemptions for small conduit hydroelectric facilities as defined in § 4.30(b)(30) of this chapter under Part I of the Federal Power Act and Part 4 of this chapter;
(15) Electric rate filings submitted by public utilities under sections 205 and 206 of the Federal Power Act, the establishment of just and reasonable rates, and confirmation, approval, and disapproval of rate filings submitted by Federal power marketing agencies under the Pacific Northwest Electric Power Planning and Conservation Act, the Department of Energy Organization Act, and DOE Delegation Order No. 0204-108.
(16) Approval of actions under sections 4(b), 203, 204, 301, 304, and 305 of the Federal Power Act relating to issuance and purchase of securities, acquisition or disposition of property, merger, interlocking directorates, jurisdictional determinations and accounting orders;
(17) Approval of electrical interconnections and wheeling under sections 202(b), 210, 211, and 212 of the Federal Power Act, that would not entail:
(i) Construction of a new substation or expansion of the boundaries of an existing substation;
(ii) Construction of any transmission line that operates at more than 115 kilovolts (KV) and occupies more than ten miles of an existing right-of-way; or
(iii) Construction of any transmission line more than one mile long if located on a new right-of-way;
(18) Approval of changes in land rights for water power projects under Part I of the Federal Power Act and Part 4 of this chapter, if no construction or change in land use is either proposed or known by the Commission to be contemplated for the land affected;
(19) Approval of proposals under Part I of the Federal Power Act and Part 4 of this chapter to authorize use of water power project lands or waters for gas or electric utility distribution lines, radial (sub-transmission) lines, communications lines and cables, storm drains, sewer lines not discharging into project waters, water mains, piers, landings, boat docks, or similar structures and facilities, landscaping or embankments, bulkheads, retaining walls, or similar shoreline erosion control structures;
(20) Action on applications for exemption under section 1(c) of the Natural Gas Act;
(21) Approvals of blanket certificate applications and prior notice filings under § 157.204 and §§ 157.209 through 157.218 of this chapter;
(22) Approvals of blanket certificate applications under §§ 284.221 through 284.224 of this chapter;
(23) Producers' applications for the sale of gas filed under §§ 157.23 through 157.29 of this chapter;
(24) Approval under section 7 of the Natural Gas Act of taps, meters, and regulating facilities located completely within an existing natural gas pipeline right-of-way or compressor station if company records show the land use of the vicinity has not changed since the original facilities were installed, and no significant nonjurisdictional facilities would be constructed in association with construction of the interconnection facilities;
(25) Review of natural gas rate filings, including any curtailment plans other than those specified in § 380.5(b)(5), and establishment of rates for transportation and sale of natural gas under sections 4 and 5 of the Natural Gas Act and sections 311 and 401 through 404 of the Natural Gas Policy Act of 1978;
(26) Review of approval of oil pipeline rate filings under Parts 340 and 341 of this chapter;
(27) Sale, exchange, and transportation of natural gas under sections 4, 5 and 7 of the Natural Gas Act that require no construction of facilities;
(28) Abandonment in place of a minor natural gas pipeline (short segments of buried pipe of 6-inch inside diameter or less), or abandonment by removal of minor surface facilities such as metering stations, valves, and taps under section 7 of the Natural Gas Act so long as appropriate erosion control and site restoration takes place;
(29) Abandonment of service under any gas supply contract pursuant to section 7 of the Natural Gas Act;
(30) Approval of filing made in compliance with the requirements of a certificate for a natural gas project under section 7 of the Natural Gas Act or a preliminary permit, exemption, license, or license amendment order for a water power project under Part I of the Federal Power Act;
(31) Abandonment of facilities by sale that involves only minor or no ground disturbance to disconnect the facilities from the system;
(32) Conversion of facilities from use under the NGPA to use under the NGA;
(33) Construction or abandonment of facilities constructed entirely in Federal offshore waters that has been approved by the Minerals Management Service and the Corps of Engineers, as necessary;
(34) Abandonment or construction of facilities on an existing offshore platform;
(35) Abandonment, construction or replacement of a facility (other than compression) solely within an existing building within a natural gas facility (other than LNG facilities), if it does not increase the noise or air emissions from the facility, as a whole; and
(36) Conversion of compression to standby use if the compressor is not moved, or abandonment of compression if the compressor station remains in operation.
(b) Exceptions to categorical exclusions. (1) In accordance with 40 CFR 1508.4, the Commission and its staff will independently evaluate environmental information supplied in an application and in comments by the public. Where circumstances indicate that an action may be a major Federal action significantly affecting the quality of the human environment, the Commission:
(i) May require an environmental report or other additional environmental information, and
(ii) Will prepare an environmental assessment or an environmental impact statement.
(2) Such circumstances may exist when the action may have an effect on one of the following:
(i) Indian lands;
(ii) Wilderness areas;
(iii) Wild and scenic rivers;
(iv) Wetlands;
(v) Units of the National Park System, National Refuges, or National Fish Hatcheries;
(vi) Anadromous fish or endangered species; or
(vii) Where the environmental effects are uncertain.
§ 380.5   Actions that require an environmental assessment.
(a) An environmental assessment will normally be prepared first for the actions identified in this section. Depending on the outcome of the environmental assessment, the Commission may or may not prepare an environmental impact statement. However, depending on the location or scope of the proposed action, or the resources affected, the Commission may in specific circumstances proceed directly to prepare an environmental impact statement.
(b) The projects subject to an environmental assessment are as follows:
(1) Except as identified in §§ 380.4, 380.6 and 2.55 of this chapter, authorization for the site of new gas import/export facilities under DOE Delegation No. 0204-112 and authorization under section 7 of the Natural Gas Act for the construction, replacement, or abandonment of compression, processing, or interconnecting facilities, onshore and offshore pipelines, metering facilities, LNG peak-shaving facilities, or other facilities necessary for the sale, exchange, storage, or transportation of natural gas;
(2) Prior notice filings under § 157.208 of this chapter for the rearrangement of any facility specified in §§ 157.202 (b)(3) and (6) of this chapter or the acquisition, construction, or operation of any eligible facility as specified in §§ 157.202 (b)(2) and (3) of this chapter;
(3) Abandonment or reduction of natural gas service under section 7 of the Natural Gas Act unless excluded under § 380.4 (a)(21), (28) or (29);
(4) Except as identified in § 380.6, conversion of existing depleted oil or natural gas fields to underground storage fields under section 7 of the Natural Gas Act.
(5) New natural gas curtailment plans, or any amendment to an existing curtailment plan under section 4 of the Natural Gas Act and sections 401 through 404 of the Natural Gas Policy Act of 1978 that has a major effect on an entire pipeline system;
(6) Licenses under Part I of the Federal Power Act and part 4 of this chapter for construction of any water power project—existing dam;
(7) Exemptions under section 405 of the Public Utility Regulatory Policies Act of 1978, as amended, and §§ 4.30(b)(31) and 4.101-4.108 of this chapter for small hydroelectric power projects of 10 MW or less;
(8) Licenses for additional project works at licensed projects under Part I of the Federal Power Act whether or not these are styled license amendments or original licenses;
(9) Licenses under Part I of the Federal Power Act and part 4 of this chapter for transmission lines only;
(10) Applications for new licenses under section 15 of the Federal Power Act;
(11) Approval of electric interconnections and wheeling under section 202(b), 210, 211, and 212 of the Federal Power Act, unless excluded under § 380.4(a)(17);
(12) Regulations or proposals for legislation not included under § 380.4(a)(2);
(13) Surrender of water power licenses and exemptions where project works exist or ground disturbing activity has occurred and amendments to water power licenses and exemptions that require ground disturbing activity or changes to project works or operations; and
(14) Except as identified in § 380.6, authorization to site new electric transmission facilities under section 216 of the Federal Power Act and DOE Delegation Order No. 00-004.00A.
§ 380.6   Actions that require an environmental impact statement.
(a) Except as provided in paragraph (b) of this section, an environmental impact statement will normally be prepared first for the following projects:
(1) Authorization under sections 3 or 7 of the Natural Gas Act and DOE Delegation Order No. 0204-112 for the siting, construction, and operation of jurisdictional liquefied natural gas import/export facilities used wholly or in part to liquefy, store, or regasify liquefied natural gas transported by water;
(2) Certificate applications under section 7 of the Natural Gas Act to develop an underground natural gas storage facility except where depleted oil or natural gas producing fields are used;
(3) Major pipeline construction projects under section 7 of the Natural Gas Act using rights-of-way in which there is no existing natural gas pipeline;
(4) Licenses under Part I of the Federal Power Act and part 4 of this chapter for construction of any unconstructed water power projects; and
(5) Major electric transmission facilities under section 216 of the Federal Power Act and DOE Delegation Order No. 00-004.00A using right-of-way in which there is no existing facility.
(b) If the Commission believes that a proposed action identified in paragraph (a) of this section may not be a major Federal action significantly affecting the quality of the human environment, an environmental assessment, rather than an environmental impact statement, will be prepared first. Depending on the outcome of the environmental assessment, an environmental impact statement may or may not be prepared.
(c) An environmental impact statement will not be required if an environmental assessment indicates that a proposal has adverse environmental affects and the proposal is not approved.
§ 380.7   Format of an environmental impact statement.
In addition to the requirements for an environmental impact statement prescribed in 40 CFR 1502.10 of the regulations of the Council, an environmental impact statement prepared by the Commission will include a section on the literature cited in the environmental impact statement and a staff conclusion section. The staff conclusion section will include summaries of:
(a) The significant environmental impacts of the proposed action;
(b) Any alternative to the proposed action that would have a less severe environmental impact or impacts and the action preferred by the staff;
(c) Any mitigation measures proposed by the applicant, as well as additional mitigation measures that might be more effective;
(d) Any significant environmental impacts of the proposed action that cannot be mitigated; and
(e) References to any pending, completed, or recommended studies that might provide baseline data or additional data on the proposed action.
§ 380.8   Preparation of environmental documents.
The preparation of environmental documents, as defined in § 1508.10 of the regulations of the Council (40 CFR 1508.10), on hydroelectric projects, natural gas facilities, and electric transmission facilities in national interest electric transmission corridors is the responsibility of the Commission's Office of Energy Projects, 888 First Street NE., Washington, DC 20426, (202) 502-8700. Persons interested in status reports or information on environmental impact statements or other elements of the NEPA process, including the studies or other information the Commission may require on these projects, can contact this office.
§ 380.9   Public availability of NEPA documents and public notice of NEPA related hearings and public meetings.
(a)(1) The Commission will comply with the requirements of 40 CFR 1506.6 of the regulations of the Council for public involvement in NEPA.
(2) If an action has effects of primarily local concern, the Commission may give additional notice in a Commission order.
(b) The Commission will make environmental impact statements, environmental assessments, the comments received, and any underlaying documents available to the public pursuant to the provisions of the Freedom of Information Act (5 U.S.C. 552 (1982)). The exclusion in the Freedom of Information Act for interagency memoranda is not applicable where such memoranda transmit comments of Federal agencies on the environmental impact of the proposed action. Such materials will be made available to the public through the Commission's website, https://www.ferc.gov, at a fee and in the manner described in part 388 of this chapter. A copy of an environmental impact statement or environmental assessment for hydroelectric projects may also be made available for inspection at the Commission's regional office for the region where the proposed action is located.
§ 380.10   Participation in Commission proceedings.
(a) Intervention proceedings involving a party or parties —(1) Motion to intervene. (i) In addition to submitting comments on the NEPA process and NEPA related documents, any person may file a motion to intervene in a Commission proceeding dealing with environmental issues under the terms of § 385.214 of this chapter. Any person who files a motion to intervene on the basis of a draft environmental impact statement will be deemed to have filed a timely motion, in accordance with § 385.214, as long as the motion is filed within the comment period for the draft environmental impact statement.
(ii) Any person that is granted intervention after petitioning becomes a party to the proceeding and accepts the record as developed by the parties as of the time that intervention is granted.
(2)(i) Issues not set for trial-type hearing. An intervenor who takes a position on any environmental issue that has not yet been set for hearing must file a timely motion with the Secretary containing an analysis of its position on such issue and specifying any differences with the position of Commission staff or an applicant upon which the intervenor wishes to be heard at a hearing.
(ii) Issues set for trial-type hearing. (A) Any intervenor that takes a position on an environmental issue set for hearing may offer evidence for the record in support of such position and otherwise participate in accordance with the Commission's Rules of Practice and Procedure. Any intervenor must specify any differences from the staff's and the applicant's positions.
(B) To be considered, any facts or opinions on an environmental issue set for hearing must be admitted into evidence and made part of the record of the proceeding.
(iii) Commission pre-filing activities commenced under §§ 157.21 and 50.5 of this chapter, respectively, are not considered proceedings under part 385 of this chapter and are not open to motions to intervene. Once an application is filed under part 157 subpart A or part 50 of this chapter, any person may file a motion to intervene in accordance with §§ 157.10 or 50.10 of this chapter or in accordance with this section.
(b) Rulemaking proceedings. Any person may file comments on any environmental issue in a rulemaking proceeding.
§ 380.11   Environmental decisionmaking.
(a) Decision points. For the actions which require an environmental assessment or environmental impact statement, environmental considerations will be addressed at appropriate major decision points.
(1) In proceedings involving a party or parties and not set for trial-type hearing, major decision points are the approval or denial of proposals by the Commission or its designees.
(2) In matters set for trial-type hearing, the major decision points are the initial decision of an administrative law judge or the decision of the Commission.
(3) In a rulemaking proceeding, the major decision points are the Notice of Proposed Rulemaking and the Final Rule.
(b) Environmental documents as part of the record. The Commission will include environmental assessments, findings of no significant impact, or environmental impact statements, and any supplements in the record of the proceeding.
(c) Application denials. Notwithstanding any provision in this part, the Commission may dismiss or deny an application without performing an environmental impact statement or without undertaking environmental analysis.
§ 380.12   Environmental reports for Natural Gas Act applications.
(a) Introduction. (1) The applicant must submit an environmental report with any application that proposes the construction, operation, or abandonment of any facility identified in § 380.3(c)(2)(i). The environmental report shall consist of the thirteen resource reports and related material described in this section.
(2) The detail of each resource report must be commensurate with the complexity of the proposal and its potential for environmental impact. Each topic in each resource report shall be addressed or its omission justified, unless the resource report description indicates that the data is not required for that type of proposal. If material required for one resource report is provided in another resource report or in another exhibit, it may be incorporated by reference. If any resource report topic is required for a particular project but is not provided at the time the application is filed, the environmental report shall explain why it is missing and when the applicant anticipates it will be filed.
(3) The appendix to this part contains a checklist of the minimum filing requirements for an environmental report. Failure to provide at least the applicable checklist items will result in rejection of the application unless the Director of the Office of Energy Projects determines that the applicant has provided an acceptable reason for the item's absence and an acceptable schedule for filing it. Failure to file within the accepted schedule will result in rejection of the application.
(b) General requirements. As appropriate, each resource report shall:
(1) Address conditions or resources that might be directly or indirectly affected by the project;
(2) Identify significant environmental effects expected to occur as a result of the project;
(3) Identify the effects of construction, operation (including maintenance and malfunctions), and termination of the project, as well as cumulative effects resulting from existing or reasonably foreseeable projects;
(4) Identify measures proposed to enhance the environment or to avoid, mitigate, or compensate for adverse effects of the project;
(5) Provide a list of publications, reports, and other literature or communications, including agency contacts, that were cited or relied upon to prepare each report. This list should include the name and title of the person contacted, their affiliations, and telephone number;
(6) Whenever this section refers to “mileposts” the applicant may substitute “survey centerline stationing” if so desired. However, whatever method is chosen should be used consistently throughout the resource reports.
(c) Resource Report 1—General project description. This report is required for all applications. It will describe facilities associated with the project, special construction and operation procedures, construction timetables, future plans for related construction, compliance with regulations and codes, and permits that must be obtained. Resource Report 1 must:
(1) Describe and provide location maps of all jurisdictional facilities, including all aboveground facilities associated with the project (such as: meter stations, pig launchers/receivers, valves), to be constructed, modified, abandoned, replaced, or removed, including related construction and operational support activities and areas such as maintenance bases, staging areas, communications towers, power lines, and new access roads (roads to be built or modified). As relevant, the report must describe the length and diameter of the pipeline, the types of aboveground facilities that would be installed, and associated land requirements. It must also identify other companies that must construct jurisdictional facilities related to the project, where the facilities would be located, and where they are in the Commission's approval process.
(2) Identify and describe all nonjurisdictional facilities, including auxiliary facilities, that will be built in association with the project, including facilities to be built by other companies.
(i) Provide the following information:
(A) A brief description of each facility, including as appropriate: Ownership, land requirements, gas consumption, megawatt size, construction status, and an update of the latest status of Federal, state, and local permits/approvals;
(B) The length and diameter of any interconnecting pipeline;
(C) Current 1:24,000/1:25,000 scale topographic maps showing the location of the facilities;
(D) Correspondence with the appropriate State Historic Preservation Officer (SHPO) or duly authorized Tribal Historic Preservation Officer (THPO) for tribal lands regarding whether properties eligible for listing on the National Register of Historic Places (NRHP) would be affected;
(E) Correspondence with the U.S. Fish and Wildlife Service (and National Marine Fisheries Service, if appropriate) regarding potential impacts of the proposed facility on federally listed threatened and endangered species; and
(F) For facilities within a designated coastal zone management area, a consistency determination or evidence that the owner has requested a consistency determination from the state's coastal zone management program.
(ii) Address each of the following factors and indicate which ones, if any, appear to indicate the need for the Commission to do an environmental review of project-related nonjurisdictional facilities.
(A) Whether or not the regulated activity comprises “merely a link” in a corridor type project (e.g., a transportation or utility transmission project).
(B) Whether there are aspects of the nonjurisdictional facility in the immediate vicinity of the regulated activity which uniquely determine the location and configuration of the regulated activity.
(C) The extent to which the entire project will be within the Commission's jurisdiction.
(D) The extent of cumulative Federal control and responsibility.
(3) Provide the following maps and photos:
(i) Current, original United States Geological Survey (USGS) 7.5-minute series topographic maps or maps of equivalent detail, covering at least a 0.5-mile-wide corridor centered on the pipeline, with integer mileposts identified, showing the location of rights-of-way, new access roads, other linear construction areas, compressor stations, and pipe storage areas. Show nonlinear construction areas on maps at a scale of 1:3,600 or larger keyed graphically and by milepost to the right-of-way maps.
(ii) Original aerial images or photographs or photo-based alignment sheets based on these sources, not more than 1 year old (unless older ones accurately depict current land use and development) and with a scale of 1:6,000 or larger, showing the proposed pipeline route and location of major aboveground facilities, covering at least a 0.5 mile-wide corridor, and including mileposts. Older images/photographs/alignment sheets should be modified to show any residences not depicted in the original. Alternative formats (e.g., blue-line prints of acceptable resolution) need prior approval by the environmental staff of the Office of Energy Projects.
(iii) In addition to the copy required under § 157.6(a)(2) of this chapter, applicant should send two additional copies of topographic maps and aerial images/photographs directly to the environmental staff of the Office of Energy Projects.
(4) When new or additional compression is proposed, include large scale (1:3,600 or greater) plot plans of each compressor station. The plot plan should reference a readily identifiable point(s) on the USGS maps required in paragraph (c)(3) of this section. The maps and plot plans must identify the location of the nearest noise-sensitive areas (schools, hospitals, or residences) within 1 mile of the compressor station, existing and proposed compressor and auxiliary buildings, access roads, and the limits of areas that would be permanently disturbed.
(5)(i) Identify facilities to be abandoned, and state how they would be abandoned, how the site would be restored, who would own the site or right-of-way after abandonment, and who would be responsible for any facilities abandoned in place.
(ii) When the right-of-way or the easement would be abandoned, identify whether landowners were given the opportunity to request that the facilities on their property, including foundations and below ground components, be removed. Identify any landowners whose preferences the company does not intend to honor, and the reasons therefore.
(6) Describe and identify by milepost, proposed construction and restoration methods to be used in areas of rugged topography, residential areas, active croplands, sites where the pipeline would be located parallel to and under roads, and sites where explosives are likely to be used.
(7) Unless provided in response to Resource Report 5, describe estimated workforce requirements, including the number of pipeline construction spreads, average workforce requirements for each construction spread and meter or compressor station, estimated duration of construction from initial clearing to final restoration, and number of personnel to be hired to operate the proposed project.
(8) Describe reasonably foreseeable plans for future expansion of facilities, including additional land requirements and the compatibility of those plans with the current proposal.
(9) Describe all authorizations required to complete the proposed action and the status of applications for such authorizations. Identify environmental mitigation requirements specified in any permit or proposed in any permit application to the extent not specified elsewhere in this section.
(10) Provide the names and mailing addresses of all affected landowners specified in § 157.6(d) and certify that all affected landowners will be notified as required in § 157.6(d).
(d) Resource Report 2—Water use and quality. This report is required for all applications, except those which involve only facilities within the areas of an existing compressor, meter, or regulator station that were disturbed by construction of the existing facilities, no wetlands or waterbodies are on the site and there would not be a significant increase in water use. The report must describe water quality and provide data sufficient to determine the expected impact of the project and the effectiveness of mitigative, enhancement, or protective measures. Resource Report 2 must:
(1) Identify and describe by milepost perennial waterbodies and municipal water supply or watershed areas, specially designated surface water protection areas and sensitive waterbodies, and wetlands that would be crossed. For each waterbody crossing, identify the approximate width, state water quality classifications, any known potential pollutants present in the water or sediments, and any potable water intake sources within 3 miles downstream.
(2) Compare proposed mitigation measures with the staff's current “ Wetland and Waterbody Construction and Mitigation Procedures ,” which are available from the Commission Internet home page or the Commission staff, describe what proposed alternative mitigation would provide equivalent or greater protection to the environment, and provide a description of site- specific construction techniques that would be used at each major waterbody crossing.
(3) Describe typical staging area requirements at waterbody and wetland crossings. Also, identify and describe waterbodies and wetlands where staging areas are likely to be more extensive.
(4) Include National Wetland Inventory (NWI) maps. If NWI maps are not available, provide the appropriate state wetland maps. Identify for each crossing, the milepost, the wetland classification specified by the U.S. Fish and Wildlife Service, and the length of the crossing. Include two copies of the NWI maps (or the substitutes, if NWI maps are not available) clearly showing the proposed route and mileposts directed to the environmental staff. Describe by milepost, wetland crossings as determined by field delineations using the current Federal methodology.
(5) Identify aquifers within excavation depth in the project area, including the depth of the aquifer, current and projected use, water quality and average yield, and known or suspected contamination problems.
(6) Describe specific locations, the quantity required, and the method and rate of withdrawal and discharge of hydrostatic test water. Describe suspended or dissolved material likely to be present in the water as a result of contact with the pipeline, particularly if an existing pipeline is being retested. Describe chemical or physical treatment of the pipeline or hydrostatic test water. Discuss waste products generated and disposal methods.
(7) If underground storage of natural gas is proposed:
(i) Identify how water produced from the storage field will be disposed of, and
(ii) For salt caverns, identify the source locations, the quantity required, and the method and rate of withdrawal of water for creating salt cavern(s), as well as the means of disposal of brine resulting from cavern leaching.
(8) Discuss proposed mitigation measures to reduce the potential for adverse impacts to surface water, wetlands, or groundwater quality to the extent they are not described in response to paragraph (d)(2) of this section. Discuss the potential for blasting to affect water wells, springs, and wetlands, and measures to be taken to detect and remedy such effects.
(9) Identify the location of known public and private groundwater supply wells or springs within 150 feet of proposed construction areas. Identify locations of EPA or state-designated sole-source aquifers and wellhead protection areas crossed by the proposed pipeline facilities.
(e) Resource Report 3—Fish, wildlife, and vegetation. This report is required for all applications, except those involving only facilities within the improved area of an existing compressor, meter, or regulator station. It must describe aquatic life, wildlife, and vegetation in the vicinity of the proposed project; expected impacts on these resources including potential effects on biodiversity; and proposed mitigation, enhancement or protection measures. Resource Report 3 must:
(1) Describe commercial and recreational warmwater, coldwater, and saltwater fisheries in the affected area and associated significant habitats such as spawning or rearing areas and estuaries.
(2) Describe terrestrial habitats, including wetlands, typical wildlife habitats, and rare, unique, or otherwise significant habitats that might be affected by the proposed action. Describe typical species that have commercial, recreational, or aesthetic value.
(3) Describe and provide the acreage of vegetation cover types that would be affected, including unique ecosystems or communities such as remnant prairie or old-growth forest, or significant individual plants, such as old-growth specimen trees.
(4) Describe the impact of construction and operation on aquatic and terrestrial species and their habitats, including the possibility of a major alteration to ecosystems or biodiversity, and any potential impact on state-listed endangered or threatened species. Describe the impact of maintenance, clearing and treatment of the project area on fish, wildlife, and vegetation. Surveys may be required to determine specific areas of significant habitats or communities of species of special concern to state or local agencies.
(5) Identify all federally listed or proposed endangered or threatened species and critical habitat that potentially occur in the vicinity of the project. Discuss the results of the consultation requirements listed in § 380.13(b) at least through § 380.13(b)(5)(i) and include any written correspondence that resulted from the consultation. The initial application must include the results of any required surveys unless seasonal considerations make this impractical. If species surveys are impractical, there must be field surveys to determine the presence of suitable habitat unless the entire project area is suitable habitat.
(6) Identify all federally listed essential fish habitat (EFH) that potentially occurs in the vicinity of the project. Provide information on all EFH, as identified by the pertinent Federal fishery management plans, that may be adversely affected by the project and the results of abbreviated consultations with NMFS, and any resulting EFH assessments.
(7) Describe site-specific mitigation measures to minimize impacts on fisheries, wildlife, and vegetation.
(8) Include copies of correspondence not provided pursuant to paragraph (e)(5) of this section, containing recommendations from appropriate Federal and state fish and wildlife agencies to avoid or limit impact on wildlife, fisheries, and vegetation, and the applicant's response to the recommendations.
(f) Resource Report 4—Cultural resources. This report is required for all applications. In preparing this report, the applicant must follow the principles in § 380.14 of this part. Guidance on the content and the format for the documentation listed below, as well as professional qualifications of preparers, is detailed in “ Office of Energy Projects' (OEP) Guidelines for Reporting on Cultural Resources Investigations ,” which is available from the Commission Internet home page or from the Commission staff.
(1) Resource Report 4 must contain:
(i) Documentation of the applicant's initial cultural resources consultation, including consultations with Native Americans and other interested persons (if appropriate);
(ii) Overview and Survey Reports, as appropriate;
(iii) Evaluation Report, as appropriate;
(iv) Treatment Plan, as appropriate; and
(v) Written comments from State Historic Preservation Officer(s) (SHPO), Tribal Historic Preservation Officers (THPO), as appropriate, and applicable land-managing agencies on the reports in paragraphs (f)(1)(i)-(iv) of this section.
(2) Initial filing requirements. The initial application must include the documentation of initial cultural resource consultation, the Overview and Survey Reports, if required, and written comments from SHPOs, THPOs and land-managing agencies, if available. The initial cultural resources consultations should establish the need for surveys. If surveys are deemed necessary by the consultation with the SHPO/THPO, the survey report must be filed with the application.
(i) If the comments of the SHPOs, THPOs, or land-management agencies are not available at the time the application is filed, they may be filed separately, but they must be filed before a final certificate is issued.
(ii) If landowners deny access to private property and certain areas are not surveyed, the unsurveyed area must be identified by mileposts, and supplemental surveys or evaluations shall be conducted after access is granted. In such circumstances, reports, and treatment plans, if necessary, for those inaccessible lands may be filed after a certificate is issued.
(3) The Evaluation Report and Treatment Plan, if required, for the entire project must be filed before a final certificate is issued.
(i) The Evaluation Report may be combined in a single synthetic report with the Overview and Survey Reports if the SHPOs, THPOs, and land-management agencies allow and if it is available at the time the application is filed.
(ii) In preparing the Treatment Plan, the applicant must consult with the Commission staff, the SHPO, and any applicable THPO and land-management agencies.
(iii) Authorization to implement the Treatment Plan will occur only after the final certificate is issued.
(4) Applicant must request privileged treatment for all material filed with the Commission containing location, character, and ownership information about cultural resources in accordance with § 388.112 of this chapter. The cover and relevant pages or portions of the report should be clearly labeled in bold lettering: “CONTAINS PRIVILEGED INFORMATION—DO NOT RELEASE.”
(5) Except as specified in a final Commission order, or by the Director of the Office of Energy Projects, construction may not begin until all cultural resource reports and plans have been approved.
(g) Resource Report 5—Socioeconomics. This report is required only for applications involving significant aboveground facilities, including, among others, conditioning or liquefied natural gas (LNG) plants. It must identify and quantify the impacts of constructing and operating the proposed project on factors affecting towns and counties in the vicinity of the project. Resource Report 5 must:
(1) Describe the socioeconomic impact area.
(2) Evaluate the impact of any substantial immigration of people on governmental facilities and services and plans to reduce the impact on the local infrastructure.
(3) Describe on-site manpower requirements and payroll during construction and operation, including the number of construction personnel who currently reside within the impact area, would commute daily to the site from outside the impact area, or would relocate temporarily within the impact area.
(4) Determine whether existing housing within the impact area is sufficient to meet the needs of the additional population.
(5) Describe the number and types of residences and businesses that would be displaced by the project, procedures to be used to acquire these properties, and types and amounts of relocation assistance payments.
(6) Conduct a fiscal impact analysis evaluating incremental local government expenditures in relation to incremental local government revenues that would result from construction of the project. Incremental expenditures include, but are not limited to, school operating costs, road maintenance and repair, public safety, and public utility costs.
(h) Resource Report 6—Geological resources. This report is required for applications involving LNG facilities and all other applications, except those involving only facilities within the boundaries of existing aboveground facilities, such as a compressor, meter, or regulator station. It must describe geological resources and hazards in the project area that might be directly or indirectly affected by the proposed action or that could place the proposed facilities at risk, the potential effects of those hazards on the facility, and methods proposed to reduce the effects or risks. Resource Report 6 must:
(1) Describe, by milepost, mineral resources that are currently or potentially exploitable;
(2) Describe, by milepost, existing and potential geological hazards and areas of nonroutine geotechnical concern, such as high seismicity areas, active faults, and areas susceptible to soil liquefaction; planned, active, and abandoned mines; karst terrain; and areas of potential ground failure, such as subsidence, slumping, and landsliding. Discuss the hazards posed to the facility from each one.
(3) Describe how the project would be located or designed to avoid or minimize adverse effects to the resources or risk to itself, including geotechnical investigations and monitoring that would be conducted before, during, and after construction. Discuss also the potential for blasting to affect structures, and the measures to be taken to remedy such effects.
(4) Specify methods to be used to prevent project-induced contamination from surface mines or from mine tailings along the right-of-way and whether the project would hinder mine reclamation or expansion efforts.
(5) If the application is for underground storage facilities:
(i) Describe how the applicant would control and monitor the drilling activity of others within the field and buffer zone;
(ii) Describe how the applicant would monitor potential effects of the operation of adjacent storage or production facilities on the proposed facility, and vice versa;
(iii) Describe measures taken to locate and determine the condition of old wells within the field and buffer zone and how the applicant would reduce risk from failure of known and undiscovered wells; and
(iv) Identify and discuss safety and environmental safeguards required by state and Federal drilling regulations.
(i) Resource Report 7—Soils. This report is required for all applications except those not involving soil disturbance. It must describe the soils that would be affected by the proposed project, the effect on those soils, and measures proposed to minimize or avoid impact. Resource Report 7 must:
(1) List, by milepost, the soil associations that would be crossed and describe the erosion potential, fertility, and drainage characteristics of each association.
(2) If an aboveground facility site is greater than 5 acres:
(i) List the soil series within the property and the percentage of the property comprised of each series;
(ii) List the percentage of each series which would be permanently disturbed;
(iii) Describe the characteristics of each soil series; and
(iv) Indicate which are classified as prime or unique farmland by the U.S. Department of Agriculture, Natural Resources Conservation Service.
(3) Identify, by milepost, potential impact from: Soil erosion due to water, wind, or loss of vegetation; soil compaction and damage to soil structure resulting from movement of construction vehicles; wet soils and soils with poor drainage that are especially prone to structural damage; damage to drainage tile systems due to movement of construction vehicles and trenching activities; and interference with the operation of agricultural equipment due to the probability of large stones or blasted rock occurring on or near the surface as a result of construction.
(4) Identify, by milepost, cropland and residential areas where loss of soil fertility due to trenching and backfilling could occur.
(5) Describe proposed mitigation measures to reduce the potential for adverse impact to soils or agricultural productivity. Compare proposed mitigation measures with the staff's current “ Upland Erosion Control, Revegetation and Maintenance Plan, ” which is available from the Commission Internet home page or from the Commission staff, and explain how proposed mitigation measures provide equivalent or greater protections to the environment.
(j) Resource Report 8—Land use, recreation and aesthetics. This report is required for all applications except those involving only facilities which are of comparable use at existing compressor, meter, and regulator stations. It must describe the existing uses of land on, and (where specified) within 0.25 mile of, the proposed project and changes to those land uses that would occur if the project is approved. The report shall discuss proposed mitigation measures, including protection and enhancement of existing land use. Resource Report 8 must:
(1) Describe the width and acreage requirements of all construction and permanent rights-of-way and the acreage required for each proposed plant and operational site, including injection or withdrawal wells.
(i) List, by milepost, locations where the proposed right-of-way would be adjacent to existing rights-of-way of any kind.
(ii) Identify, preferably by diagrams, existing rights-of-way that would be used for a portion of the construction or operational right-of-way, the overlap and how much additional width would be required.
(iii) Identify the total amount of land to be purchased or leased for each aboveground facility, the amount of land that would be disturbed for construction and operation of the facility, and the use of the remaining land not required for project operation.
(iv) Identify the size of typical staging areas and expanded work areas, such as those at railroad, road, and waterbody crossings, and the size and location of all pipe storage yards and access roads.
(2) Identify, by milepost, the existing use of lands crossed by the proposed pipeline, or on or adjacent to each proposed plant and operational site.
(3) Describe planned development on land crossed or within 0.25 mile of proposed facilities, the time frame (if available) for such development, and proposed coordination to minimize impacts on land use. Planned development means development which is included in a master plan or is on file with the local planning board or the county.
(4) Identify, by milepost and length of crossing, the area of direct effect of each proposed facility and operational site on sugar maple stands, orchards and nurseries, landfills, operating mines, hazardous waste sites, state wild and scenic rivers, state or local designated trails, nature preserves, game management areas, remnant prairie, old-growth forest, national or state forests, parks, golf courses, designated natural, recreational or scenic areas, or registered natural landmarks, Native American religious sites and traditional cultural properties to the extent they are known to the public at large, and reservations, lands identified under the Special Area Management Plan of the Office of Coastal Zone Management, National Oceanic and Atmospheric Administration, and lands owned or controlled by Federal or state agencies or private preservation groups. Also identify if any of those areas are located within 0.25 mile of any proposed facility.
(5) Identify, by milepost, all residences and buildings within 50 feet of the proposed pipeline construction right-of-way and the distance of the residence or building from the right-of-way. Provide survey drawings or alignment sheets to illustrate the location of the facilities in relation to the buildings.
(6) Describe any areas crossed by or within 0.25 mile of the proposed pipeline or plant and operational sites which are included in, or are designated for study for inclusion in: The National Wild and Scenic Rivers System (16 U.S.C. 1271); The National Trails System (16 U.S.C. 1241); or a wilderness area designated under the Wilderness Act (16 U.S.C. 1132).
(7) For facilities within a designated coastal zone management area, provide a consistency determination or evidence that the applicant has requested a consistency determination from the state's coastal zone management program.
(8) Describe the impact the project will have on present uses of the affected area as identified above, including commercial uses, mineral resources, recreational areas, public health and safety, and the aesthetic value of the land and its features. Describe any temporary or permanent restrictions on land use resulting from the project.
(9) Describe mitigation measures intended for all special use areas identified under paragraphs (j)(2) through (6) of this section.
(10) Describe proposed typical mitigation measures for each residence that is within 50 feet of the edge of the pipeline construction right-of-way, as well as any proposed residence-specific mitigation. Describe how residential property, including for example, fences, driveways, stone walls, sidewalks, water supply, and septic systems, would be restored. Describe compensation plans for temporary and permanent rights-of-way and the eminent domain process for the affected areas.
(11) Describe measures proposed to mitigate the aesthetic impact of the facilities especially for aboveground facilities such as compressor or meter stations.
(12) Demonstrate that applications for rights-of-way or other proposed land use have been or soon will be filed with Federal land-management agencies with jurisdiction over land that would be affected by the project.
(k) Resource Report 9—Air and noise quality. This report is required for applications involving compressor facilities at new or existing stations, and for all new LNG facilities. It must identify the effects of the project on the existing air quality and noise environment and describe proposed measures to mitigate the effects. Resource Report 9 must:
(1) Describe the existing air quality, including background levels of nitrogen dioxide and other criteria pollutants which may be emitted above EPA-identified significance levels.
(2) Quantitatively describe existing noise levels at noise-sensitive areas, such as schools, hospitals, or residences and include any areas covered by relevant state or local noise ordinances.
(i) Report existing noise levels as the L eq (day), L eq (night), and L dn and include the basis for the data or estimates.
(ii) For existing compressor stations, include the results of a sound level survey at the site property line and nearby noise-sensitive areas while the compressors are operated at full load.
(iii) For proposed new compressor station sites, measure or estimate the existing ambient sound environment based on current land uses and activities.
(iv) Include a plot plan that identifies the locations and duration of noise measurements, the time of day, weather conditions, wind speed and direction, engine load, and other noise sources present during each measurement.
(3) Estimate the impact of the project on air quality, including how existing regulatory standards would be met.
(i) Provide the emission rate of nitrogen oxides from existing and proposed facilities, expressed in pounds per hour and tons per year for maximum operating conditions, include supporting calculations, emission factors, fuel consumption rates, and annual hours of operation.
(ii) For major sources of air emissions (as defined by the Environmental Protection Agency), provide copies of applications for permits to construct (and operate, if applicable) or for applicability determinations under regulations for the prevention of significant air quality deterioration and subsequent determinations.
(4) Provide a quantitative estimate of the impact of the project on noise levels at noise-sensitive areas, such as schools, hospitals, or residences.
(i) Include step-by-step supporting calculations or identify the computer program used to model the noise levels, the input and raw output data and all assumptions made when running the model, far-field sound level data for maximum facility operation, and the source of the data.
(ii) Include sound pressure levels for unmuffled engine inlets and exhausts, engine casings, and cooling equipment; dynamic insertion loss for all mufflers; sound transmission loss for all compressor building components, including walls, roof, doors, windows and ventilation openings; sound attenuation from the station to nearby noise-sensitive areas; the manufacturer's name, the model number, the performance rating; and a description of each noise source and noise control component to be employed at the proposed compressor station. For proposed compressors the initial filing must include at least the proposed horsepower, type of compression, and energy source for the compressor.
(iii) Far-field sound level data measured from similar units in service elsewhere, when available, may be substituted for manufacturer's far-field sound level data.
(iv) If specific noise control equipment has not been chosen, include a schedule for submitting the data prior to certification.
(v) The estimate must demonstrate that the project will comply with applicable noise regulations and show how the facility will meet the following requirements:
(A) The noise attributable to any new compressor station, compression added to an existing station, or any modification, upgrade or update of an existing station, must not exceed a day- night sound level (L dn ) of 55 dBA at any pre-existing noise-sensitive area (such as schools, hospitals, or residences).
(B) New compressor stations or modifications of existing stations shall not result in a perceptible increase in vibration at any noise-sensitive area.
(5) Describe measures and manufacturer's specifications for equipment proposed to mitigate impact to air and noise quality, including emission control systems, installation of filters, mufflers, or insulation of piping and buildings, and orientation of equipment away from noise-sensitive areas.
(l) Resource Report 10—Alternatives. This report is required for all applications. It must describe alternatives to the project and compare the environmental impacts of such alternatives to those of the proposal. The discussion must demonstrate how environmental benefits and costs were weighed against economic benefits and costs, and technological and procedural constraints. The potential for each alternative to meet project deadlines and the environmental consequences of each alternative shall be discussed. Resource Report 10 must:
(1) Discuss the “no action” alternative and the potential for accomplishing the proposed objectives through the use of other systems and/or energy conservation. Provide an analysis of the relative environmental benefits and costs for each alternative.
(2) Describe alternative routes or locations considered for each facility during the initial screening for the project.
(i) For alternative routes considered in the initial screening for the project but eliminated, describe the environmental characteristics of each route or site, and the reasons for rejecting it. Identify the location of such alternatives on maps of sufficient scale to depict their location and relationship to the proposed action, and the relationship of the pipeline to existing rights-of-way.
(ii) For alternative routes or locations considered for more in-depth consideration, describe the environmental characteristics of each route or site and the reasons for rejecting it. Provide comparative tables showing the differences in environmental characteristics for the alternative and proposed action. The location of any alternatives in this paragraph shall be provided on maps equivalent to those required in paragraph (c)(2) of this section.
(m) Resource Report 11—Reliability and safety. This report is required for applications involving new or recommissioned LNG facilities. Information previously filed with the Commission need not be refiled if the applicant verifies its continued validity. This report shall address the potential hazard to the public from failure of facility components resulting from accidents or natural catastrophes, how these events would affect reliability, and what procedures and design features have been used to reduce potential hazards. Resource Report 11 must:
(1) Describe measures proposed to protect the public from failure of the proposed facilities (including coordination with local agencies).
(2) Discuss hazards, the environmental impact, and service interruptions which could reasonably ensue from failure of the proposed facilities.
(3) Discuss design and operational measures to avoid or reduce risk.
(4) Discuss contingency plans for maintaining service or reducing downtime.
(5) Describe measures used to exclude the public from hazardous areas. Discuss measures used to minimize problems arising from malfunctions and accidents (with estimates of probability of occurrence) and identify standard procedures for protecting services and public safety during maintenance and breakdowns.
(n) Resource Report 12—PCB contamination. This report is required for applications involving the replacement, abandonment by removal, or abandonment in place of pipeline facilities determined to have polychlorinated biphenyls (PCBs) in excess of 50 ppm in pipeline liquids. Resource Report 12 must:
(1) Provide a statement that activities would comply with an approved EPA disposal permit, with the dates of issuance and expiration specified, or with the requirements of the Toxic Substances Control Act.
(2) For compressor station modifications on sites that have been determined to have soils contaminated with PCBs, describe the status of remediation efforts completed to date.
(o) Resource Report 13—Engineering and design material. This report is required for construction of new liquefied natural gas (LNG) facilities, or the recommissioning of existing LNG facilities. If the recommissioned facility is existing and is not being replaced, relocated, or significantly altered, resubmittal of information already on file with the Commission is unnecessary. Resource Report 13 must:
(1) Provide a detailed plot plan showing the location of all major components to be installed, including compression, pretreatment, liquefaction, storage, transfer piping, vaporization, truck loading/unloading, vent stacks, pumps, and auxiliary or appurtenant service facilities.
(2) Provide a detailed layout of the fire protection system showing the location of fire water pumps, piping, hydrants, hose reels, dry chemical systems, high expansion foam systems, and auxiliary or appurtenant service facilities.
(3) Provide a layout of the hazard detection system showing the location of combustible-gas detectors, fire detectors, heat detectors, smoke or combustion product detectors, and low temperature detectors. Identify those detectors that activate automatic shutdowns and the equipment that would shut down. Include all safety provisions incorporated in the plant design, including automatic and manually activated emergency shutdown systems.
(4) Provide a detailed layout of the spill containment system showing the location of impoundments, sumps, subdikes, channels, and water removal systems.
(5) Provide manufacturer's specifications, drawings, and literature on the fail-safe shut-off valve for each loading area at a marine terminal (if applicable).
(6) Provide a detailed layout of the fuel gas system showing all taps with process components.
(7) Provide copies of company, engineering firm, or consultant studies of a conceptual nature that show the engineering planning or design approach to the construction of new facilities or plants.
(8) Provide engineering information on major process components related to the first six items above, which include (as applicable) function, capacity, type, manufacturer, drive system (horsepower, voltage), operating pressure, and temperature.
(9) Provide manuals and construction drawings for LNG storage tank(s).
(10) Provide up-to-date piping and instrumentation diagrams. Include a description of the instrumentation and control philosophy, type of instrumentation (pneumatic, electronic), use of computer technology, and control room display and operation. Also, provide an overall schematic diagram of the entire process flow system, including maps, materials, and energy balances.
(11) Provide engineering information on the plant's electrical power generation system, distribution system, emergency power system, uninterruptible power system, and battery backup system.
(12) Identify all codes and standards under which the plant (and marine terminal, if applicable) will be sited, designed, constructed, tested, monitored, operated, and maintained, and any special considerations or safety provisions that were applied to the design of plant components.
(13) Provide a list of all permits or approvals from local, state, Federal, or Native American groups or Indian agencies required prior to and during construction of the plant, and the status of each, including the date filed, the date issued, and any known obstacles to approval. Include a description of data records required for submission to such agencies and transcripts of any public hearings by such agencies. Also provide copies of any correspondence relating to the actions by all, or any, of these agencies regarding all required approvals.
(14) Identify all Federal, state, and local regulations and requirements that apply to the siting, design, construction, testing, monitoring, operation, and maintenance of the proposed project and explain how the proposed project will comply with the applicable Federal regulations, including codes and standards incorporated by reference into Federal regulations.
(15) Provide information to demonstrate that the proposed facilities will be sited, designed, constructed, and operated to maintain reliability and will not significantly impact public safety given geotechnical conditions and the occurrence of a natural hazard identified in paragraphs (o)(15)(i) through (iii) of this section. Site information must provide geotechnical studies and natural hazard studies based on the site location, which must provide impacts and magnitude of historical events and projected impacts and magnitude of events based on projected prescriptive/deterministic events and projected probabilistic events corresponding to mean recurrence intervals. Design information must provide the basis of design supported by site information, including design parameters and criteria and preliminary resultant design loads used in the geotechnical and structural design of LNG facilities. Construction and operation information must also include discussion of quality assurance and quality control plans, monitoring programs, and action programs developed in preparation of and response to geotechnical and natural hazards. All information provided must, at a minimum, demonstrate compliance with all applicable Federal requirements and applicable codes and standards, and identify any applicable state and local requirements for the siting, design, construction, testing, monitoring, operation, and maintenance used to safeguard against significant impacts caused by geotechnical conditions and natural hazards.
(i) General information. Provide site information that includes:
(A) A description of all structures, systems, and components, including, at a minimum, the layout of all proposed above ground and below ground structures, systems, and components including temporary access roads used during construction and permanent roads used during operation.
(B) The design classification for each structure, system, and component in accordance with, at a minimum, all applicable Federal requirements and applicable codes and standards.
(C) The derivation and values for risk category and mean recurrence intervals that are, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards.
(D) A description of all load combinations for each design classification for all structures, systems, and components that are, at a minimum, in accordance with design methods and all applicable Federal requirements and applicable codes and standards.
(E) A description of all preliminary dead loads that are, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards, and include, at a minimum, weight of materials of construction of structures, systems, and components; weight of any hydrostatic test fluid service within structures, systems, and components during commissioning; weight of fluid services within structures, systems, and components during startup, normal operation, abnormal operation, and shutdown; and soil and hydrostatic pressure loads and potential uplift of below ground structures, systems, and components.
(F) A description of all preliminary live loads that are, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards, and include, at a minimum, dynamic loads from movement during transportation of structures, systems, and components; induced loads from construction equipment atop of below ground structures, systems, and components; uniform and concentrated loads from construction and operation personnel and equipment on structures, systems, and components; and crane loads for structures, systems, and components.
(G) A description of all preliminary loads induced from natural hazards for all structures, systems, and components that are, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards as described in paragraph (o)(15)(iii) of this section.
(H) A description of all mitigation measures to protect against natural hazards (like earthquakes) including, at a minimum, a discussion of the proposed site elevation and design of any storm walls or barriers relative to information described in paragraphs (o)(15)(ii) and (iii) of this section.
(I) A description of a natural hazard preparedness and action program, which includes facilitating timely decisions concerning the present or future state of the LNG facility that address, at a minimum, the natural hazards described in paragraph (o)(15)(iii) of this section.
(ii) Geotechnical information. Provide a geotechnical investigation that includes:
(A) A summary of the site investigation that lists the applicant's exploratory program for the site and the types of subsurface investigations performed and planned to be performed for the site.
(B) A list and description of all in situ tests performed, standards used for tests, and their results including all standard penetration tests, cone penetration tests (static and dynamic), test pits, trenches, borings, rock coring, soil sampling, plate load tests, and in situ shear strength tests.
(C) A plot plan that identifies the number, location, spacing, cross-sections, and depths of each in situ test.
(D) A description of completed surveys, standards used for surveys, and the results of surveys that were conducted to obtain continuous lateral and depth information for the evaluation of subsurface conditions including all seismic refraction and reflection surveys.
(E) A description of the applicant's laboratory testing program that includes the treatment of samples, the preparation of the soil specimen for testing, the techniques to detect sample disturbance, and the laboratory testing specifications.
(F) A list and description of all laboratory tests performed, standards used for tests, and their results, including results from all soil classification tests, index tests, strength and compressibility tests, permeability tests, and soil corrosivity tests.
(G) A description of proposed mitigation measures for soil improvement or other mitigation that would remediate low bearing strength, poor consolidation, poor permeability, high corrosivity, or other geotechnical issues discovered during in situ or laboratory tests.
(H) A discussion of subsurface conditions and profiles based on the results of the subsurface exploration and field test conducted at the site. Subsurface profiles must identify groundwater conditions and the physicochemical properties of the groundwater, soil/rock layers and parameters, and various soil strata in various cross-section drawings spanning across the site including the LNG storage tank areas.
(I) A description of soil conditions that indicate compressible or expansive soils, corrosive soils, collapsible soils, erodible soils, liquefaction-susceptible soils, frost-heave susceptible soils, frozen soils, sanitary landfill, or contaminated soils.
(J) An analysis of actual or potential hazards ( e.g., landslides, subsidence, uplift, capable faults, or collapse resulting from natural features such as tectonic depressions and cavernous or karst terrains) to the site.
(K) A discussion of the relationship between the regional and local geology and the site location.
(L) An evaluation and discussion of surface displacement caused by faulting or seismically induced lateral spreading or lateral flow, regional subsidence, local subsidence, and heave.
(M) Drawings of existing and proposed site elevation contours.
(N) A slope-stability analysis, including slope stabilization methods, sloping topography for the site, recommendations for slope stability, static and seismic stability, and factor of safety.
(O) Recommendations for site improvement to increase bearing capacity, reduce the potential of liquefaction and lateral spreading, and mitigate poor or unusual soil conditions.
(P) Recommendations for site improvement to mitigate soil contaminants and shoreline erosion control.
(Q) An evaluation and discussion of the expected total settlement over the design life of the facilities that considers soil conditions, regional subsidence, and local subsidence.
(R) Recommendations for shallow foundations, including, at a minimum, ultimate bearing capacity, factor of safety, allowable bearing capacity, total and differential settlement criteria, liquefaction settlements, settlement monitoring, and lateral resistance.
(S) Recommendations for deep foundations, including, at a minimum, acceptable foundation type, bearing capacity, total pile capacities, axial capacity, lateral capacity, group effects, down-drag, factor of safety, settlement of single pile and pile groups, lateral movement of pile groups, pile installation, pile cap, indicator piles and pile load test programs, static axial pile load test, lateral load test, and dynamic pile load test.
(T) A summary of information needed to establish broad design parameters and conclusions used to determine the proposed layout and design of buildings, structures, and support facilities.
(U) A description of the implementation of the geotechnical monitoring system for the site and structures, including inclinometer, extensometers, piezometer, tiltmeter, settlement monuments or cells, pressure and load cells, and crack monitoring devices.
(iii) Natural hazard information. Provide studies, basis of design, and plans for all natural hazards, including, at a minimum, each natural hazard in paragraphs (o)(15)(iii)(A) through (G) of this section:
(A) Seismic information. Provide a discussion of seismic design and hazards analysis that includes:
( 1 ) The seismic design basis and criteria that are, at a minimum, in accordance with all applicable Federal requirements, and applicable codes, standards, and specifications used as basis of design.
( 2 ) A description of seismic setting and seismic hazard investigation.
( 3 ) A description of seismological characteristics of the geographical region within 100 miles of the site.
( 4 ) A description of capable faults, including any part of a fault within five miles of the site, the fault characteristics in the site vicinity, the methods and techniques used for fault analysis and investigations, and the potential effect of fault displacement on structures, systems, and components.
( 5 ) Derivation of the site class describing the soil conditions and supportive geotechnical studies that are, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards.
( 6 ) Criteria used to determine potential soil liquefaction, subsidence, fault rupture, seismic slope stability, and lateral spreading.
( 7 ) A historical ground motion analysis, including a description of past seismic events of Modified Mercalli Intensity greater than IV or magnitude greater than 3.0 within 100 miles of the site, including date of seismic events, magnitude of seismic events, distance from site to epicenter of seismic events, depth of seismic events, and resultant ground motions recorded or estimated at site location.
( 8 ) A site-specific ground motion analysis based on ground motions projected from the U.S. Geological Survey national seismic maps and any deterministic seismic hazard analyses (DSHA) and probabilistic seismic hazard analyses (PSHA).
( 9 ) Derivation of all ground motions used for the Operating Basis Earthquake (OBE), Safe Shutdown Earthquake (SSE), site-specific design earthquake (DE), site-specific peak ground motion (PGA), and aftershock level earthquake (ALE) that are, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards.
( 10 ) A list of OBE, SSE, and ALE site-specific ground motion spectral values for 0.5%, 1%, 2%, 5%, 7%, 10%, 15%, and 20% damping during all periods range.
( 11 ) The DE seismic coefficients and seismic design parameters, including the spectral response acceleration and five percent damped design spectral response acceleration parameters at a short-period, at a period of one second, and at other periods; short-period site coefficient and long-period site coefficient; importance factor; component importance factor; fundamental period of the structure; long-period transition period; and response modification coefficient that are, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards.
( 12 ) A description of site-specific response spectrum analysis method, time history analysis method, or equivalent static load analysis.
( 13 ) A seismic analysis for soil-structure interaction that is, at a minimum, in accordance with all applicable Federal requirements and applicable codes and standards, and includes, at a minimum, a discussion of the modeling methods and the factors considered in the modeling methods, including the extent of embedment, the layering of the soil/rock strata, and the boundary of soil-structure model.
( 14 ) A comparison of seismic responses used for each design classification for all structures, systems, and components.
( 15 ) A list of seismic hazard curves of spectral accelerations for all periods for the site.
( 16 ) Vertical response spectra for seismic design and ratio to horizontal response spectra.
( 17 ) Natural frequencies and responses for each LNG tank system and associated safety systems and associated structures, systems, and components.
( 18 ) A description of procedures used for structural analyses, including consideration of incorporating the stiffness, mass, and damping characteristics of the structural systems into the analytical models.
( 19 ) A description of determination of seismic overturning moments and sliding forces for each LNG tank system and associated safety related structures, systems, and components, including consideration of the three components of input motion and the simultaneous action of vertical and horizontal seismic forces.
( 20 ) A description of design procedure for seismically isolated structures, systems, and components.
( 21 ) A description of seismic design basis and criteria for the LNG storage tank(s) and foundation(s). The seismic design basis and criteria must include the flexibility of the tank shell(s) and its influence on the natural frequencies of the tank(s), liquid level, effects of liquid motion or pressure changes; minimum design freeboard; sloshing and impulsive loads; seismic coefficients; importance factor(s); reduction factor(s); slosh height(s); sloshing periods of LNG storage tank(s); global stability of the tank(s) in terms of the potential for overturning and sliding; differential displacement between the tank(s) and the first support; and a total settlement monitoring program for the tank foundation(s).
( 22 ) A description of seismic monitoring system in accordance with, at a minimum, all applicable Federal requirements and applicable codes and standards, including any triaxial ground motion recorder installed to register the free-field ground motion and additional triaxial ground motion recorders on each LNG tank system foundation, LNG tank roof, and associated safety related structures, systems, and components. The proposed seismic monitoring must include the installation locations on a plot plan; description of the triaxial strong motion recorders or other seismic instrumentation; the proposed alarm set points, and operating procedures (including emergency operating procedures) for control room operators in response to such alarms/data obtained from seismic instrumentation; and maintenance procedures.
( 23 ) A cross reference to potential for earthquake generated tsunamis and seiches provided in paragraph (o)(15)(iii)(B) of this section, earthquake generated floods in paragraph (o)(15)(iii)(C) of this section, earthquake generated landslides in paragraph (o)(15)(iii)(G) of this section, and earthquake generated releases and fires in paragraph (m) of this section.
(B) Tsunami and seiche information. Provide a discussion of tsunami and seiche design and hazards that includes:
( 1 ) The tsunami and seismic design basis and criteria with a description of the applicable requirements and guidelines, and generally accepted codes, standards, and specifications used as basis of design.
( 2 ) The seiche design inundation and run-up elevations and corresponding return periods for all structures, systems, and components.
( 3 ) The maximum considered tsunami (MCT) inundation and run-up elevation for the site, including the maximum considered earthquake (MCE) level ground motions at the site if the MCE is the triggering source of the MCT.
( 4 ) A comparison of design loads of seiche water inundation elevations with inundation elevation corresponding to return periods of MCE and MCT for all structures, systems, and components.
( 5 ) The Tsunami Risk Category for the site and a description of potential tsunami generation by seismic sources, and the prevention and mitigation plan for potential tsunami and seiche hazards.
( 6 ) A cross reference to potential tsunami and seiche generated floods in paragraph (o)(15)(iii)(C) of this section, tsunami and seiche generated landslides in paragraph (o)(15)(iii)(G) of this section, and tsunami and seiche generated releases and fires in paragraph (m) of this section.
(C) Flood information. Provide a discussion of flood design criteria and hazards that includes:
( 1 ) The floods design basis and criteria with references to applicable requirements and guidelines, and generally accepted codes, standards, and specifications used as basis of design.
( 2 ) A description of flooding potential in the region surrounding the site due to one or more natural causes such as storm surge, tides, wind generated waves, meteorological tsunamis or seiches, extreme precipitation, or other natural hazard events that have a common cause.
( 3 ) A comparison of flood design loads corresponding to return periods of 10,000-year, 5,000-year, 1,000-year, 500-year, and 100-year for all structures, systems, and components.
( 4 ) A discussion of final designed site elevations and storm surge walls or floodwalls for the site that includes tsunami considerations, flood design considerations, site total settlements, sea level rise, subsidence.
(D) Hurricane information. Provide a discussion of hurricanes and other meteorological events design criteria and hazards that includes:
( 1 ) The wind and storm surge design basis and criteria that are, at a minimum, in accordance with all applicable Federal requirements, and applicable codes, standards, and specifications used as basis of design.
( 2 ) A comparison of design wind loads for both sustained and three-second gusts and storm surge elevations, including consideration for still water, wind/wave run-up effects, and crest elevations, with hurricanes and other meteorological events at the site location corresponding to return periods of 10,000-year, 5,000-year, 1,000-year, 500-year, and 100-year for all structures, systems, and components.
( 3 ) A discussion of historic hurricane frequencies and hurricane categories equivalent on the Saffir-Simpson Hurricane Wind Scale at the site and associated wind speeds and storm surge.
( 4 ) The design regional subsidence that includes a discussion of the elevation change used to account for regional subsidence for the design life of the facilities at the site.
(E) Tornado information. Provide a discussion of tornado design criteria and hazards that includes:
( 1 ) The tornadoes design basis and criteria that are, at a minimum, in accordance with all applicable Federal requirements, and applicable codes, standards, and specifications used as basis of design.
( 2 ) A comparison of tornado design loads corresponding to return periods of 10,000-year, 5,000-year, 1,000-year, 500-year, and 100-year for all structures, systems, and components.
( 3 ) A discussion of historic tornado frequencies and tornado categories as classified on the Enhanced Fujita (EF) Scale at the site and associated wind speeds.
( 4 ) A discussion of tornado loads determination and design procedure.
( 5 ) A comparison of impact between wind loads and tornado loads for the site.
(F) Rain, ice, snow, and related precipitation information. Provide a discussion of rain, ice, snow, and related precipitation design criteria and hazards that includes:
( 1 ) The rain, ice, and snow design basis and criteria that are, at a minimum, in accordance with all applicable Federal requirements, and applicable codes, standards, and specifications used as basis of design.
( 2 ) The identification of stormwater flows, outfalls, and stormwater management systems for all surfaces, including spill containment system with sump pumps or other water removal systems.
( 3 ) The comparison of rain, ice, and snow design loads with rainfall rates, snow loads, and ice loads corresponding to return periods of 10,000-year, 5,000-year, 1,000-year, 500-year, and 100-year for all structures, systems, and components.
( 4 ) A discussion of historic ice and blizzard events and frequencies and other ice and snow events at the site and associated loads.
(G) Landslides, wildfires, volcanic activity, and geomagnetism information. Provide a discussion of landslides, wildfires, volcanic activity, and geomagnetism design criteria and hazards that includes:
( 1 ) The landslides, wildfires, volcanic activity, and geomagnetism design basis and criteria that are, at a minimum, in accordance with all applicable Federal requirements, and applicable codes, standards, and specifications used as basis of design.
( 2 ) A discussion of historic landslide, wildfire, volcano activity, and geomagnetic disturbance risks and intensities at the site.
( 3 ) A description of capable volcanoes, volcanic characteristics of the region, and a discussion of potentially hazardous volcanic phenomena considerations.
§ 380.13   Compliance with the Endangered Species Act.
(a) Definitions. For purposes of this section:
(1) Listed species and critical habitat have the same meaning as provided in 50 CFR 402.02.
(2) Project area means any area subject to construction activities (for example, material storage sites, temporary work areas, and new access roads) necessary to install or abandon the facilities.
(b) Procedures for informal consultation —(1) Designation of non-Federal representative. The project sponsor is designated as the Commission's non-Federal representative for purposes of informal consultations with the U.S. Fish and Wildlife Service (FWS) and the National Marine Fisheries Service (NMFS) under the Endangered Species Act of 1973, as amended (ESA).
(2) Consultation requirement. (i) Prior to the filing of the environmental report specified in § 380.12 or § 380.16, as applicable, the project sponsor must contact the appropriate regional or field office of the FWS or the NMFS, or both if appropriate, to initiate informal consultations, unless it is proceeding pursuant to a blanket clearance issued by the FWS and/or NMFS which is less than 1 year old and the clearance does not specify more frequent consultation.
(ii) If a blanket clearance is more than 1 year old or less than 1 year old and specifies more frequent consultations, or if the project sponsor is not proceeding pursuant to a blanket clearance, the project sponsor must request a list of federally listed or proposed species and designated or proposed critical habitat that may be present in the project area, or provide the consulted agency with such a list for its concurrence.
(iii) The consulted agency will provide a species and critical habitat list or concur with the species list provided within 30 days of its receipt of the initial request. In the event that the consulted agency does not provide this information within this time period, the project sponsor may notify the Director of the Office of Energy Projects and continue with the remaining procedures of this section.
(3) End of informal consultation. (i) At any time during the informal consultations, the consulted agency may determine or confirm:
(A) That no listed or proposed species, or designated or proposed critical habitat, occurs in the project area; or
(B) That the project is not likely to adversely affect a listed species or critical habitat;
(ii) If the consulted agency provides the determination or confirmation described in paragraph (b)(3)(i) of this section, no further consultation is required.
(4) Potential impact to proposed species. (i) If the consulted agency, pursuant to informal consultations, initially determines that any species proposed to be listed, or proposed critical habitat, occurs in the project area, the project sponsor must confer with the consulted agency on methods to avoid or reduce the potential impact.
(ii) The project sponsor shall include in its proposal, a discussion of any mitigating measures recommended through the consultation process.
(5) Continued informal consultations for listed species. (i) If the consulted agency initially determines, pursuant to the informal consultations, that a listed species or designated critical habitat may occur in the project area, the project sponsor must continue informal consultations with the consulted agency to determine if the proposed project may affect the species or designated critical habitat. These consultations may include discussions with experts (including experts provided by the consulted agency), habitat identification, field surveys, biological analyses, and the formulation of mitigation measures. If the provided information indicates that the project is not likely to adversely affect a listed species or critical habitat, the consulting agency will provide a letter of concurrence which completes informal consultation.
(ii) The project sponsor must prepare a Biological Assessment unless the consulted agency indicates that the proposed project is not likely to adversely affect a specific listed species or its designated critical habitat. The Biological Assessment must contain the following information for each species contained in the consulted agency's species list:
(A) Life history and habitat requirements;
(B) Results of detailed surveys to determine if individuals, populations, or suitable, unoccupied habitat exists in the proposed project's area of effect;
(C) Potential impacts, both beneficial and negative, that could result from the construction and operation of the proposed project, or disturbance associated with the abandonment, if applicable; and
(D) Proposed mitigation that would eliminate or minimize these potential impacts.
(iii) All surveys must be conducted by qualified biologists and must use FWS and/or NMFS approved survey methodology. In addition, the Biological Assessment must include the following information:
(A) Name(s) and qualifications of person(s) conducting the survey;
(B) Survey methodology;
(C) Date of survey(s); and
(D) Detailed and site-specific identification of size and location of all areas surveyed.
(iv) The project sponsor must provide a draft Biological Assessment directly to the environmental staff of the Office of Energy Projects for review and comment and/or submission to the consulted agency. If the consulted agency fails to provide formal comments on the Biological Assessment to the project sponsor within 30 days of its receipt, as specified in 50 CFR 402.120, the project sponsor may notify the Director, OEP, and follow the procedures in paragraph (c) of this section.
(v) The consulted agency's comments on the Biological Assessment's determination must be filed with the Commission.
(c) Notification to Director. In the event that the consulted agency fails to respond to requests by the project sponsor under paragraph (b) of this section, the project sponsor must notify the Director of the Office of Energy Projects. The notification must include all information, reports, letters, and other correspondence prepared pursuant to this section. The Director will determine whether:
(1) Additional informal consultation is required;
(2) Formal consultation must be initiated under paragraph (d) of this section; or
(3) Construction may proceed.
(d) Procedures for formal consultation. (1) In the event that formal consultation is required pursuant to paragraphs (b)(5)(v) or (c)(2) of this section, the Commission staff will initiate formal consultation with the FWS and/or NMFS, as appropriate, and will request that the consulted agency designate a lead Regional Office, lead Field/District Office, and Project Manager, as necessary, to facilitate the formal consultation process. In addition, the Commission will designate a contact for formal consultation purposes.
(2) During formal consultation, the consulted agency, the Commission, and the project sponsor will coordinate and consult to determine potential impacts and mitigation which can be implemented to minimize impacts. The Commission and the consulted agency will schedule coordination meetings and/or field visits as necessary.
(3) The formal consultation period will last no longer than 90 days, unless the consulted agency, the Commission, and project sponsor mutually agree to an extension of this time period.
(4) The consulted agency will provide the Commission with a Biological Opinion on the proposed project, as specified in 50 CFR 402.14(e), within 45 days of the completion of formal consultation.
§ 380.14   Compliance with the National Historic Preservation Act.
(a) Section 106 of the National Historic Preservation Act, as amended (54 U.S.C. 306108) (NHPA), requires the Commission to take into account the effect of a proposed project on any historic property and to afford the Advisory Council on Historic Preservation (Council) an opportunity to comment on projects if required under 36 CFR 800. The project sponsor, as a non-Federal party, assists the Commission in meeting its obligations under NHPA section 106 and the implementing regulations at 36 CFR part 800 by following the procedures at § 380.12(f) or § 380.16(f), as applicable. The project sponsor may contact the Commission at any time for assistance. The Commission will review the resultant filings.
(1) The Commission's NHPA section 106 responsibilities apply to public and private lands, unless subject to the provisions of paragraph (a)(2) of this section. The project sponsor will assist the Commission in taking into account the views of interested parties, Native Americans, and tribal leaders.
(2) If Federal or Tribal land is affected by a proposed project, the project sponsor shall adhere to any requirements for cultural resources studies of the applicable Federal land- managing agencies on Federal lands and any tribal requirements on Tribal lands. The project sponsor must identify, in Resource Report 4 filed with the application, the status of cultural resources studies on Federal or Tribal lands, as applicable.
(3) The project sponsor must consult with the SHPO(s) and THPOs, if appropriate. If the SHPO or THPO declines to consult with the project sponsor, the project sponsor shall not continue with consultations, except as instructed by the Director of the Office of Energy Projects.
(4) If the project is covered by an agreement document among the Commission, Council, SHPO(s), THPO(s), land-managing agencies, project sponsors, and interested persons, as appropriate, then that agreement will provide for compliance with NHPA section 106, as applicable.
(b) [Reserved]
§ 380.15   Siting and maintenance requirements.
(a) Avoidance or minimization of effects. The siting, construction, and maintenance of facilities shall be undertaken in a way that avoids or minimizes effects on scenic, historic, wildlife, and recreational values.
(b) Landowner consideration. The desires of landowners should be taken into account in the planning, locating, clearing, and maintenance of rights-of-way and the construction of facilities on their property, so long as the result is consistent with applicable requirements of law, including laws relating to land-use and any requirements imposed by the Commission.
(c) Landowner notification. (1) (i) No activity described in paragraphs (a) and (b) of this section that involves ground disturbance is authorized unless a company makes a good faith effort to notify in writing each affected landowner, as noted in the most recent county/city tax records as receiving the tax notice, whose property will be used and subject to ground disturbance as a result of the proposed activity, at least five days prior to commencing any activity under this section. A landowner may waive the five-day prior notice requirement in writing, so long as the notice has been provided. No landowner notice under this section is required:
(A) If all ground disturbance will be confined entirely to areas within the fence line of an existing above-ground site of facilities operated by the company; or
(B) For activities done for safety, DOT compliance, or environmental or unplanned maintenance reasons that are not foreseen and that require immediate attention by the company.
(ii) The notification shall include at least:
(A) A brief description of the facilities to be constructed or replaced and the effect the activity may have on the landowner's property;
(B) The name and phone number of a company representative who is knowledgeable about the project; and
(C) A description of the Commission's Landowner Helpline, which an affected person may contact to seek an informal resolution of a dispute as explained in § 1b.22(a) of this chapter and the Landowner Helpline number.
(2) “Affected landowners” include owners of interests, as noted in the most recent county/city tax records as receiving tax notice, in properties (including properties subject to rights-of-way and easements for facility sites, compressor stations, well sites, and all above-ground facilities, and access roads, pipe and contractor yards, and temporary work space) that will be directly affected by ( i.e., used) and subject to ground disturbance as a result of activity under this section.
(d) Safety regulations. The requirements of this paragraph do not affect a project sponsor's obligations to comply with safety regulations of the U.S. Department of Transportation and recognized safe engineering practices for Natural Gas Act projects and the National Electric Safety Code for section 216 Federal Power Act projects.
(e) Pipeline and electric transmission facilities construction. (1) The use, widening, or extension of existing rights-of-way must be considered in locating proposed facilities.
(2) In locating proposed facilities, the project sponsor shall, to the extent practicable, avoid places listed on, or eligible for listing on, the National Register of Historic Places; natural landmarks listed on the National Register of Natural Landmarks; officially designated parks; wetlands; and scenic, recreational, and wildlife lands. If rights-of-way must be routed near or through such places, attempts should be made to minimize visibility from areas of public view and to preserve the character and existing environment of the area.
(3) Rights-of-way should avoid forested areas and steep slopes where practical.
(4) Rights-of-way clearing should be kept to the minimum width necessary.
(5) In selecting a method to clear rights-of-way, soil stability and protection of natural vegetation and adjacent resources should be taken into account.
(6) Trees and vegetation cleared from rights-of-way in areas of public view should be disposed of without undue delay.
(7) Remaining trees and shrubs should not be unnecessarily damaged.
(8) Long foreground views of cleared rights-of-way through wooded areas that are visible from areas of public view should be avoided.
(9) Where practical, rights-of-way should avoid crossing hills and other high points at their crests where the crossing is in a forested area and the resulting notch is clearly visible in the foreground from areas of public view.
(10) Screen plantings should be employed where rights-of-way enter forested areas from a clearing and where the clearing is plainly visible in the foreground from areas of public view.
(11) Temporary roads should be designed for proper drainage and built to minimize soil erosion. Upon abandonment, the road area should be restored and stabilized without undue delay.
(f) Right-of-way maintenance. (1) Vegetation covers established on a right-of-way should be properly maintained.
(2) Access and service roads should be maintained with proper cover, water bars, and the proper slope to minimize soil erosion. They should be jointly used with other utilities and land-management agencies where practical.
(3) Chemical control of vegetation should not be used unless authorized by the landowner or land-managing agency. When chemicals are used for control of vegetation, they should be approved by EPA for such use and used in conformance with all applicable regulations.
(g) Construction of aboveground facilities. (1) Unobtrusive sites should be selected for the location of aboveground facilities.
(2) Aboveground facilities should cover the minimum area practicable.
(3) Noise potential should be considered in locating compressor stations, or other aboveground facilities.
(4) The exterior of aboveground facilities should be harmonious with the surroundings and other buildings in the area.
(5) For Natural Gas Act projects, the site of aboveground facilities which are visible from nearby residences or public areas, should be planted in trees and shrubs, or other appropriate landscaping and should be installed to enhance the appearance of the facilities, consistent with operating needs.
§ 380.16   Environmental reports for section 216 Federal Power Act Permits.
(a) Introduction. (1) The applicant must submit an environmental report with any application that proposes the construction or modification of any facility identified in § 380.3(c)(3). The environmental report must include the 14 resource reports and related material described in this section.
(2) The detail of each resource report must be commensurate with the complexity of the proposal and its potential for environmental impact. Each topic in each resource report must be addressed or its omission justified, unless the data is not required for that type of proposal. If material required for one resource report is provided in another resource report or in another exhibit, it may be cross referenced. If any resource report topic is required for a particular project but is not provided at the time the application is filed, the environmental report must explain why it is missing and when the applicant anticipates it will be filed.
(b) General requirements. As appropriate, each resource report must:
(1) Address conditions or resources that are likely to be directly or indirectly affected by the project;
(2) Identify significant environmental effects expected to occur as a result of the project;
(3) Identify the effects of construction, operation (including malfunctions), and maintenance, as well as cumulative effects resulting from the incremental effects of the project when added to the effects of other past, present, and reasonably foreseeable actions;
(4) Identify measures proposed to enhance the environment or to avoid, mitigate, or compensate for adverse effects of the project; and
(5) Provide a list of publications, reports, and other literature or communications, including agency contacts, that were cited or relied upon to prepare each report. This list must include the names and titles of the persons contacted, their affiliations, and telephone numbers.
(6) Whenever this section refers to “mileposts” the applicant may substitute “survey centerline stationing” if so preferred. However, whatever method is chosen must be used consistently throughout the resource reports.
(c) Resource Report 1—General project description. This report must describe facilities associated with the project; special construction, operation, and maintenance procedures; construction timetables; future plans for related construction; compliance with regulations and codes; and permits that must be obtained. Resource Report 1 must:
(1) Describe and provide location maps of all project facilities (such as transmission line towers, substations, and any appurtenant facilities) to be constructed, modified, replaced, or removed, and related construction and operational support activities and areas, such as maintenance bases, staging areas, communications towers, power lines, and new access roads (roads to be built or modified). As relevant, the report must describe the length and size of the proposed transmission line conductor cables, the types of appurtenant facilities that would be constructed, and associated land requirements.
(2) Provide the following maps and photos:
(i) Current, original United States Geological Survey (USGS) 7.5-minute series topographic maps, or maps of equivalent detail, covering at least a 0.5-mile-wide corridor centered on the electric transmission facility centerline, with integer mileposts identified, showing the location of rights-of-way, new access roads, other linear construction areas, substations, and construction materials storage areas. Nonlinear construction areas must be shown on maps at a scale of 1:3,600, or larger, keyed graphically and by milepost to the right-of-way maps. The topographic maps must depict the facilities identified under paragraph (l)(5) of this section, including any facilities located outside of the 0.5-mile-wide corridor.
(ii) Original aerial images or photographs or photo-based alignment sheets based on these sources, not more than one year old (unless older ones accurately depict current land use and development) and with a scale of 1:6,000, or larger, showing the proposed transmission line route and location of transmission line towers, substations and appurtenant facilities, covering at least a 0.5-mile-wide corridor, and including mileposts. The aerial images or photographs or photo-based alignment sheets must show all existing transmission facilities located in the area of the proposed facilities and the facilities identified under paragraph (l)(5) of this section, including any facilities located outside of the 0.5-mile-wide corridor. Older images/photographs/alignment sheets must be modified to show any facilities not depicted in the original. Alternative formats ( e.g., blue-line prints of acceptable resolution) need prior approval by the environmental staff of the Commission's Office of Energy Projects.
(iii) In addition to the requirements under § 50.3(b) of this chapter, the applicant must contact the environmental staff of the Office of Energy Projects regarding the need for any additional copies of topographic maps and aerial images/photographs.
(3) Describe and identify, by milepost, proposed general construction and restoration methods, and any special methods to be used in areas of rugged topography, residential areas, active croplands, and sites where explosives are likely to be used. Describe any proposed horizontal directional drilling and pile driving that may be necessary.
(4) Identify the number of construction spreads, average workforce requirements for each construction spread and estimated duration of construction from initial clearing to final restoration. Indicate the days of the week and times of the day that proposed construction activities would occur and describe any proposed nighttime construction activities.
(5) Describe reasonably foreseeable plans for future expansion of facilities, including additional land requirements and the compatibility of those plans with the current proposal.
(6) Describe all authorizations required to complete the proposed action and the status of applications for such authorizations. Identify environmental mitigation requirements specified in any permit or proposed in any permit application to the extent not specified elsewhere in this section.
(7) Provide the names and mailing addresses of all affected landowners identified in § 50.5(c)(4) of this chapter and certify that all affected landowners will be notified as required in § 50.4(c) of this chapter.
(d) Resource Report 2—Water use and quality. This report must describe water quality and provide data sufficient to determine the expected impact of the project and the effectiveness of mitigative, enhancement, or protective measures. Resource Report 2 must:
(1) Identify and describe by milepost waterbodies and municipal water supply or watershed areas, specially designated surface water protection areas and sensitive waterbodies, and wetlands that would be crossed. For each waterbody crossing, identify the approximate width, State water quality classifications, any known potential pollutants present in the water or sediments, and any potable water intake sources within three miles downstream.
(2) Provide a description of site-specific construction techniques that will be used at each major waterbody crossing.
(3) Describe typical staging area requirements at waterbody and wetland crossings. Also, identify and describe waterbodies and wetlands where staging areas are likely to be more extensive.
(4) Include National Wetland Inventory (NWI) maps. If NWI maps are not available, provide the appropriate State wetland maps. Identify for each crossing, the milepost, the wetland classification specified by the U.S. Fish and Wildlife Service, and the length of the crossing. Include two copies of the NWI maps (or the substitutes, if NWI maps are not available) clearly showing the proposed route and mileposts. Describe by milepost, wetland crossings as determined by field delineations using the current Federal methodology.
(5) Identify aquifers within excavation depth in the project area, including the depth of the aquifer, current and projected use, water quality, and known or suspected contamination problems.
(6) Discuss proposed mitigation measures to reduce the potential for adverse impacts to surface water, wetlands, or groundwater quality. Discuss the potential for blasting or contamination/spills to affect water wells, springs, and wetlands, and measures to be taken to detect and remedy such effects. Describe the impact of proposed land clearing and vegetation management practices, including herbicide treatment, in the project area on water resources.
(7) Identify the location of known public and private groundwater supply wells or springs within 150 feet of proposed construction areas. Identify locations of Environmental Protection Agency or State-designated, sole-source aquifers and wellhead protection areas crossed by the proposed transmission line facilities.
(e) Resource Report 3—Fish, wildlife, and vegetation. This report must describe aquatic life, wildlife, and vegetation in the vicinity of the proposed project; expected impacts on these resources including potential effects on biodiversity; and proposed mitigation, enhancement, or protection measures. Resource Report 3 must:
(1) Describe commercial and recreational warmwater, coldwater, and saltwater fisheries in the affected area and associated significant habitats such as spawning or rearing areas and estuaries.
(2) Describe terrestrial habitats, including wetlands, typical wildlife habitats and corridors, and rare, unique, or otherwise significant habitats that might be affected by the proposed action. Describe typical species that have commercial, recreational, or aesthetic value.
(3) Describe and provide the acreage of vegetation cover types that would be affected, including unique ecosystems or communities, such as remnant prairie, interior forest, or old-growth forest, or significant individual plants, such as old-growth specimen trees. Describe any areas of noxious weeds and non-native species in the project area.
(4) Describe the impact of construction, operation, and maintenance on aquatic and terrestrial species and their habitats, including the possibility of a major alteration to ecosystems or biodiversity, and any potential impact on State-listed endangered or threatened species. Describe the impact of proposed land clearing and vegetation management practices, including herbicide treatment, in the project area on fish; wildlife, including migratory birds and bald and golden eagles; and vegetation. Surveys may be required to determine specific areas of significant habitats or communities of species of special concern to State, Tribal, or local agencies.
(5) Identify all federally listed or proposed threatened or endangered species and critical habitat that potentially occur in the vicinity of the project. Discuss the results of the consultation requirements listed in § 380.13(b) through § 380.13(b)(5)(i) and include any written correspondence that resulted from the consultation. The application must include the results of any required surveys unless seasonal considerations make this impractical. If species surveys are impractical, there must be field surveys to determine the presence of suitable habitat unless the entire project area is suitable habitat.
(6) Identify all federally listed essential fish habitat (EFH) that potentially occurs in the vicinity of the project. Provide information on all EFH, as identified by the pertinent Federal fishery management plans, that may be adversely affected by the project and the results of abbreviated consultations with the National Marine Fisheries Service, and any resulting EFH assessments.
(7) Identify migratory bird species and bald and golden eagles that potentially occur in the vicinity of the project, including bald and golden eagle nesting and roosting sites, migratory bird flyways, and any habitat/sites important to migratory bird breeding, feeding, and sheltering.
(8) Describe proposed, site-specific mitigation measures to minimize impacts on fisheries; wildlife, including migratory birds and bald and golden eagles; and vegetation.
(9) Include copies of correspondence not provided under paragraph (e)(5) of this section, containing recommendations from appropriate Federal and State fish and wildlife agencies to avoid or limit impacts on wildlife, including migratory birds and bald and golden eagles; fisheries; and vegetation, and the applicant's response to the recommendations.
(f) Resource Report 4—Cultural resources. In order to prepare this report, the applicant must follow the principles in § 380.14.
(1) Resource Report 4 must contain:
(i) Documentation of the applicant's initial cultural resource consultations, including engagement with Indian Tribes and other interested persons (if appropriate);
(ii) Overview and Survey Reports, as appropriate;
(iii) An Evaluation Report, as appropriate;
(iv) A Treatment Plan, as appropriate; and
(v) Written comments from State Historic Preservation Officer(s) (SHPO), Tribal Historic Preservation Officers (THPO), as appropriate, and applicable land-management agencies on the reports in paragraphs (f)(1)(i) through (iv) of this section.
(2) The application or pre-filing documents, as applicable, must include the documentation of initial cultural resource consultation(s), the Overview and Survey Reports, if required, and written comments from SHPOs, THPOs, and land-management agencies, if available. The initial cultural resource consultations should establish the need for surveys. If surveys are deemed necessary by the consultation with the SHPO/THPO, the survey reports must be filed with the application or pre-filing documents.
(i) If the comments of the SHPOs, THPOs, or land-management agencies are not available at the time the application is filed, they may be filed separately, but they must be filed before a permit is issued.
(ii) If landowners deny access to private property and certain areas are not surveyed, the unsurveyed area must be identified by mileposts, and supplemental surveys or evaluations must be conducted after access is granted. In those circumstances, reports, and treatment plans, if necessary, for those inaccessible lands may be filed after a permit is issued.
(3) The Evaluation Report and Treatment Plan, if required, for the entire project must be filed before a permit is issued.
(i) In preparing the Treatment Plan, the applicant must consult with the Commission staff, the SHPO, and any applicable THPO and land-management agencies.
(ii) Authorization to implement the Treatment Plan will occur only after the permit is issued.
(4)The applicant must request privileged treatment for all material filed with the Commission containing location, character, and ownership information about cultural resources in accordance with § 388.112 of this chapter. The cover and relevant pages or portions of the report should be clearly labeled in bold lettering: “CONTAINS PRIVILEGED INFORMATION—DO NOT RELEASE.”
(5) Except as specified in a final Commission order, or by the Director of the Office of Energy Projects, construction may not begin until all cultural resource reports and plans have been approved.
(g) Resource Report 5—Socioeconomics. This report must identify and quantify the impacts of project construction, operation, and maintenance on factors affecting municipalities and counties in the vicinity of the project. Resource Report 5 must:
(1) Describe the socioeconomic impact area.
(2) Evaluate the impact of any substantial migration of people on governmental facilities and services and plans to reduce the impact on the local infrastructure.
(3) Describe on-site manpower requirements and payroll during construction, operation, and maintenance, including the number of construction personnel who currently reside within the impact area, will commute daily to the site from outside the impact area, or will relocate temporarily within the impact area.
(4) Determine whether existing housing within the impact area is sufficient to meet the needs of the additional population.
(5) Describe the number and types of residences and businesses that will be displaced by the project, procedures to be used to acquire these properties, and types and amounts of relocation assistance payments.
(6) Conduct a fiscal impact analysis evaluating incremental local government expenditures in relation to incremental local government revenues that will result from the project. Incremental expenditures include, but are not limited to, school operation, road maintenance and repair, public safety, and public utilities.
(h) Resource Report 6 — Tribal resources. This report must describe Indian Tribes, Tribal lands, and Tribal interests that may be affected by the proposed project. Resource Report 6 must:
(1) Identify Indian Tribes that may be affected by the construction, operation, and maintenance of the proposed transmission facilities.
(2) Describe the impacts of construction, operation, and maintenance of the project on Indian Tribes and Tribal interests, including those related to: water use and quality; wildlife and vegetation; cultural and historic resources; socioeconomics; geological resources; soils; land use, recreation, and aesthetics; air quality and environmental noise; traffic; and health.
(3) Identify project impacts that may affect Tribal interests not necessarily associated with resources specified in paragraph (h)(2) of this section, e.g., treaties, Tribal practices, or agreements between the Indian Tribe and entities other than the applicant.
(4) Identify Indian Tribes that may attach religious and cultural significance to historic properties within the proposed project right-of-way or in the project vicinity, as well as available information on Tribal traditional cultural and religious properties, whether on or off of any Indian reservation.
(5) Ensure that information made available under this section does not include specific site or property locations, the disclosure of which will create a risk of harm, theft, or destruction of archaeological or Tribal cultural resources or to the site at which the resources are located, or which would violate any Federal law, including the Archaeological Resources Protection Act of 1979, 16 U.S.C. 470hh, and the National Historic Preservation Act of 1966, 54 U.S.C. 307103.
(6) Describe any proposed mitigation measures to avoid or minimize impacts on Tribal resources, including any input received from Indian Tribes on the proposed measures and how the input informed the proposed measures.
(i) Resource Report 7—Environmental justice. This report must address the effects of the proposed project on environmental justice communities, as defined in § 380.2 of this chapter. Resource Report 7 must:
(1) Identify environmental justice communities within the area of potential project impacts using current guidance and data, including localized data, from the Environmental Protection Agency, the Council, the Census Bureau, and other authoritative sources. Provide maps depicting identified environmental justice communities in relation to the proposed project facilities using localized data.
(2) Describe the impacts of construction, operation, and maintenance of the project on environmental justice communities, including those related to: water use and quality; wildlife and vegetation; cultural and historic resources; socioeconomics; geological resources; soils; land use, recreation, and aesthetics; air quality and environmental noise; traffic; and health. Identify any disproportionate and adverse impacts on environmental justice communities.
(3) Discuss any cumulative impacts on environmental justice communities, regarding resources affected by the project, including whether any cumulative impacts would be disproportionate and adverse. Describe the proposed project's impacts in relation to the aggregation of past, present, and reasonably foreseeable actions taken by Federal or non-Federal entities, and the environmental justice communities' capacity to tolerate additional impacts.
(4) Describe any proposed mitigation measures to avoid or minimize impacts on environmental justice communities, including any community input received on the proposed measures and how the input informed the proposed measures.
(j) Resource Report 8—Geological resources. This report must describe geological resources and hazards in the project area that might be directly or indirectly affected by the proposed action or that could place the proposed facilities at risk, the potential effects of those hazards on the facility, and methods proposed to reduce the effects or risks. Resource Report 8 must:
(1) Describe, by milepost, mineral resources that are currently or potentially exploitable.
(2) Describe, by milepost, existing and potential geological hazards and areas of nonroutine geotechnical concern, such as high seismicity areas, active faults, and areas susceptible to soil liquefaction; planned, active, and abandoned mines; karst terrain; and areas of potential ground failure, such as subsidence, slumping, and landsliding. Discuss the hazards posed to the facility from each one.
(3) Describe how the project will be located or designed to avoid or minimize adverse effects to geological resources or risk to itself. Describe any geotechnical investigations and monitoring that would be conducted before, during, and after construction. Discuss the potential for blasting to affect structures and the proposed measures to be taken to remedy such effects.
(4) Specify methods to be used to prevent project-induced contamination from surface mines or from mine tailings along the right-of-way and whether the project would hinder mine reclamation or expansion efforts.
(k) Resource Report 9—Soils. This report must describe the soils that will be affected by the proposed project, the effect on those soils, and measures proposed to minimize or avoid impacts. Resource Report 9 must:
(1) List, by milepost, the soil associations that would be crossed and describe the erosion potential, fertility, and drainage characteristics of each association.
(2) Identify, by milepost, potential impacts from: soil erosion due to water, wind, or loss of vegetation; soil compaction and damage to soil structure resulting from movement of construction vehicles; wet soils and soils with poor drainage that are especially prone to structural damage; damage to drainage tile systems due to movement of construction vehicles and excavating activities; and interference with the operation of agricultural equipment due to the possibility of large stones or blasted rock occurring on or near the surface as a result of construction.
(3) Identify, by milepost, cropland and residential areas where project construction may result in the loss of soil fertility, including any land classified as prime or unique farmland by the U.S. Department of Agriculture, Natural Resources Conservation Service.
(4) Describe any proposed mitigation measures to reduce the potential for adverse impacts to soils or agricultural productivity.
(l) Resource Report 10—Land use, recreation, and aesthetics. This report must describe the existing uses of land in the project vicinity and changes to those land uses that will occur if the project is approved. The report must discuss proposed mitigation measures, including the protection and enhancement of existing land use. Resource Report 10 must:
(1) Describe the width and acreage requirements of all construction and permanent rights-of-way for project construction, operation and maintenance.
(i) List, by milepost, locations where the proposed construction or permanent rights-of-way would be adjacent to existing rights-of-way of any kind.
(ii) Identify, preferably by diagrams, existing rights-of-way that will be used for a portion of the construction or permanent rights-of-way, the overlap and how much additional width will be required.
(iii) Identify the total amount of land to be purchased or leased for each project facility; the amount of land that would be disturbed for construction, operation, and maintenance of the facility; and the proposed use of the remaining land not required for project operation and maintenance, if any.
(iv) Identify the size of typical staging areas and expanded work areas, such as those at railroad, road, and waterbody crossings, and the size and location of all construction materials storage yards and access roads.
(2) Identify, by milepost, the existing use of lands crossed by, or adjacent to, the proposed project facilities or rights-of-way.
(3) Describe planned development on land crossed by, or within 0.25 mile of, the proposed facilities, the time frame (if available) for such development, and proposed coordination to minimize impacts on land use. Planned development means development that is included in a master plan or is on file with the local planning board or the county.
(4) Identify, by milepost and length of crossing, the area of direct effect of each proposed facility and operational site on sugar maple stands; orchards and nurseries; landfills; operating mines; hazardous waste sites; State wild and scenic rivers; State or local designated trails; nature preserves; game management areas; remnant prairie; old-growth forest; interior forest; national or State forests or parks; golf courses; designated natural, recreational or scenic areas; registered natural landmarks; Native American religious sites and traditional cultural properties (to the extent they are known to the public at large) and reservations; lands identified under the Special Area Management Plan of the Office of Coastal Zone Management, National Oceanic and Atmospheric Administration; and lands owned or controlled by Federal or State agencies or private preservation groups. Also identify if any of those areas are located within 0.25 mile of any proposed facility.
(5) Identify and describe buildings, electronic installations, airstrips, airports, and heliports in the project vicinity. The facilities identified under this paragraph must be depicted on the maps and photographs in Resource Report 1, as required by paragraph (c)(2) of this section.
(i) Buildings. List all single-family and multi-family dwellings and related structures, mobile homes, apartment buildings, commercial structures, industrial structures, business structures, churches, hospitals, nursing homes, schools, or other structures normally inhabited by humans or intended to be inhabited by humans on a daily or regular basis within a 0.5-mile-wide corridor centered on the proposed transmission line alignment. Provide a general description of each habitable structure and its distance from the centerline of the proposed project. In cities, towns, or rural subdivisions, houses can be identified in groups. Provide the number of habitable structures in each group and list the distance from the centerline to the closest habitable structure in the group. Provide a list of all habitable structures within 200 feet of a proposed construction work area for all proposed project facilities, including transmission line towers, substations, access roads, and appurtenant facilities; a general description of each habitable structure; and the distance of each habitable structure from the proposed construction work area.
(ii) Electronic installations. List all commercial AM radio transmitters located within 10,000 feet of the centerline of the proposed project and all FM radio transmitters, microwave relay stations, or other similar electronic installations located within 2,000 feet of the centerline of the proposed project. Provide a general description of each installation and its distance from the centerline of the proposed project.
(iii) Airstrips, airports, and heliports. List all known private airstrips within 10,000 feet of the centerline of the project. List all airports registered with the Federal Aviation Administration (FAA), with at least one runway more than 3,200 feet in length, that are located within 20,000 feet of the centerline of the proposed project. Indicate whether any transmission structures will exceed a 100:1 horizontal slope (one foot in height for each 100 feet in distance) from the closest point of the closest runway. List all airports registered with the FAA having no runway more than 3,200 feet in length that are located within 10,000 feet of the centerline of the proposed project. Indicate whether any transmission structures will exceed a 50:1 horizontal slope from the closest point of the closest runway. List all heliports located within 5,000 feet of the centerline of the proposed project. Indicate whether any transmission structures will exceed a 25:1 horizontal slope from the closest point of the closest landing and takeoff area of the heliport. Provide a general description of each private airstrip, registered airport, and registered heliport, and state the distance of each from the centerline of the proposed transmission line. Include copies of any consultation with the FAA.
(6) Describe any areas crossed by, or within 0.25 mile of, the proposed transmission project facilities that are included in, or are designated for study for inclusion in: the National Wild and Scenic Rivers System (16 U.S.C. 1271), the National Trails System (16 U.S.C. 1241), or a wilderness area designated under the Wilderness Act (16 U.S.C. 1132).
(7) For facilities within a designated coastal zone management area, provide a consistency determination or evidence that the applicant has requested a consistency determination from the State's coastal zone management program.
(8) Describe the impact the project will have on present uses of the affected areas as identified above, including commercial uses, mineral resources, recreational areas, public health and safety, and the aesthetic value of the land and its features. Describe any temporary or permanent restrictions on land use resulting from the project.
(9) Describe proposed mitigation measures intended for all special use areas identified under this section.
(10) Identify the area of potential visual effects from the proposed project. Describe the visual characteristics of the lands and waters affected by the project, including any visually sensitive areas, visual classifications, and key viewpoints in the project vicinity. Describe how the transmission line project facilities will impact the visual character and scenic quality of the landscape and proposed mitigation measures to lessen these impacts. Provide visual aids to support the textual descriptions required by this paragraph. Identify, and justify the selection of, the tools or methodologies used to develop the information required in this paragraph.
(11) Demonstrate that applications for rights-of-way authorizations or other proposed land uses have been, or soon will be, filed with Federal land-management agencies with jurisdiction over land that would be affected by the project.
(m) Resource Report 11—Air quality and environmental noise. This report must estimate emissions from the proposed project and the corresponding impacts on air quality and the environment, estimate the impact of the proposed project on the noise environment, and describe proposed measures to mitigate the impacts. Resource Report 11 must:
(1) Describe the existing air quality in the project area, indicate if any project facilities are located within a designated nonattainment or maintenance area under the Clean Air Act (42 U.S.C. 7401 et seq. ), and provide the distance from the project facilities to any Class I area in the project vicinity.
(2) For proposed substations and appurtenant facilities, quantitatively describe existing noise levels at nearby noise-sensitive areas, such as schools, hospitals, or residences.
(i) Report existing noise levels as the Leq (day), Leq (night), and Ldn (day-night) and include the basis for the data or estimates.
(ii) Include a plot plan that identifies the locations and duration of noise measurements, time of day, weather conditions, wind speed and direction, engine load, and other noise sources present during each measurement.
(iii) Identify any State or local noise regulations that may be applicable to the project facilities.
(3) Estimate emissions from the proposed project and the corresponding impacts on air quality and the environment.
(i) Estimate the reasonably foreseeable emissions from construction, operation, and maintenance of the project facilities (such as emissions from tailpipes, equipment, fugitive dust, open burning, and substations) expressed in tons per year. Include supporting calculations, emissions factors, fuel consumption rates, and annual hours of operation.
(ii) For each designated nonattainment or maintenance area, provide a comparison of the emissions from construction, operation, and maintenance of the project facilities with the applicable General Conformity thresholds (40 CFR part 93).
(iii) Identify the corresponding impacts on communities and the environment in the project area from the estimated emissions.
(iv) Describe any proposed mitigation measures to control emissions identified under this section.
(4) Estimate the impact of the proposed project on the noise environment.
(i) Provide a quantitative estimate of the impact of transmission line operation on noise levels at the edge of the proposed right-of-way, including corona, insulator, and Aeolian noise. For proposed substations and appurtenant facilities, provide a quantitative estimate of the impact of operations on noise levels at nearby noise-sensitive areas, including discrete tones.
(A) Include step-by-step supporting calculations or identify the computer program used to model the noise levels, input and raw output data and all assumptions made when running the model, far-field sound level data for maximum facility operation, and source of the data.
(B) Include sound pressure levels for project facilities, dynamic insertion loss for structures, and sound attenuation from the project facilities to the edge of the right-of-way or to nearby noise-sensitive areas (as applicable).
(C) Far-field sound level data measured from similar project facilities in service elsewhere, when available, may be substituted for manufacturer's far-field sound level data.
(D) The operational noise estimates must demonstrate that noise attributable to any proposed substation or appurtenant facility does not exceed a day-night sound level (Ldn) of 55 decibels on the A-weighted scale (dBA) at any pre-existing noise-sensitive area. Compare the proposed project's operational noise estimates with applicable State and local noise regulations.
(ii) Describe the impact of proposed construction activities, including any nighttime construction, on the noise environment. Estimate the impact of any horizontal directional drilling, pile driving, or blasting on noise levels at nearby noise-sensitive areas and include supporting assumptions and calculations.
(iii) Describe any proposed mitigation measures to reduce noise impacts identified under this section.
(n) Resource Report 12—Alternatives. This report must describe alternatives to the project and compare the environmental impacts (as identified in Resource Reports 1 through 11 of this section) of such alternatives to those of the proposal. The potential for each alternative to meet project purposes and the environmental consequences of each alternative must be discussed. Resource Report 12 must:
(1) Discuss the “no action” alternative and other alternatives given serious consideration to achieve the proposed objectives.
(2) Provide an analysis of the relative environmental benefits and impacts of each such alternative, including but not limited to:
(i) For alternatives considered in the initial screening for the project but eliminated, describe the environmental characteristics of each alternative, and the reasons for rejecting it. Where applicable, identify the location of such alternatives on maps of sufficient scale to depict their relationship to the proposed action and existing rights-of-way; and
(ii) For alternatives that were given more in-depth consideration, describe the environmental characteristics of each alternative and the reasons for rejecting it. Provide comparative tables showing the differences in environmental characteristics for the alternatives and proposed action. The location, where applicable, of any alternatives in this paragraph shall be provided on maps equivalent to those required in paragraph (c)(2) of this section.
(o) Resource Report 13—Reliability and safety. This report must address the potential hazards to the public from failure of facility components resulting from, among other things, accidents or natural catastrophes; how these events would affect reliability; and proposed procedures and design features to reduce potential hazards. Resource Report 13 must:
(1) Discuss hazards, environmental impacts, and service interruptions that could reasonably ensue from failure of the proposed facilities.
(2) Describe proposed measures to protect the public from failure of the proposed facilities (including coordination with local agencies).
(3) Discuss proposed design and operational measures to avoid or reduce risk, including any measures to ensure that the proposed project facilities would be resilient against future climate change impacts in the project area.
(4) Discuss proposed contingency plans for maintaining service or reducing downtime to ensure that the proposed facilities would not adversely affect the bulk electric system in accordance with applicable North American Electric Reliability Corporation reliability standards.
(5) Describe proposed measures to exclude the public from hazardous areas. Discuss measures used to minimize problems arising from malfunctions and accidents (with estimates of probability of occurrence) and identify standard procedures for protecting services and public safety during maintenance and breakdowns.
(6) Provide a description of the electromagnetic fields to be generated by the proposed transmission lines, including their strength and extent. Provide a depiction of the expected field compared to distance horizontally along the right-of-way under the conductors, and perpendicular to the centerline of the right-of-way laterally.
(7) Discuss the potential for electrical noise from electric and magnetic fields, including shadowing and reradiation, as they may affect health or communication systems along the transmission right-of-way.
(8) Discuss the potential for induced or conducted currents along the transmission right-of-way from electric and magnetic fields.
(p) Resource Report 14—Design and engineering. This report consists of general design and engineering drawings of the principal project facilities described under Resource Report 1—General project description. If the version of this report submitted with the application is preliminary in nature, the applicant must state that in the application. The drawings must conform to the specifications determined in the initial consultation meeting required by § 50.5(b) of this chapter.
(1) The drawings must show all major project structures in sufficient detail to provide a full understanding of the project including:
(i) Plans (overhead view);
(ii) Elevations (front view);
(iii) Profiles (side view); and
(iv) Sections.
(2) The applicant may submit preliminary design drawings with the pre-filing documents or application. The final design drawings may be submitted during the construction permit process or after the Commission issues a permit and must show the precise plans and specifications for proposed structures. If a permit is granted on the basis of preliminary designs, the applicant must submit final design drawings for written approval by the Director of the Office of Energy Projects prior to commencement of any construction of the project.
(3) Supporting design report. The applicant must submit, at a minimum, the following supporting information to demonstrate that existing and proposed structures are safe and adequate to fulfill their stated functions and must submit such information in a separate report at the time the application is filed:
(i) An assessment of the suitability of the locations of proposed transmission line towers, substations, and appurtenant structures based on geological and subsurface investigations, including investigations of soils and rock borings and tests evaluating all foundations and construction materials;
(ii) Copies of boring logs, geology reports, and laboratory test reports;
(iii) An identification of all borrow areas and quarry sites and an estimate of required quantities of suitable construction material; and
(iv) Stability and stress analyses for all major transmission structures and conductors under all probable loading conditions, including seismic, wind, and ice loading, as appropriate, in sufficient detail to permit independent staff evaluation.
(4) The applicant must submit the supporting design report described in paragraph (p)(3) of this section at the time preliminary and final design drawings are filed. If the report contains preliminary drawings, it must be designated as a “Preliminary Supporting Design Report.”