Notice of Intent To Prepare an Environmental Impact Statement for the Lake Charles Carbon Capture and Sequestration Project, Lake Charles, LA
The U.S. Department of Energy (DOE) announces its intent to prepare an Environmental Impact Statement (EIS) pursuant to the National Environmental Policy Act of 1969 (NEPA) (42 U.S.C. 4321 et seq.), the Council on Environmental Quality's (CEQ) NEPA regulations (40 CFR parts 1500-1508), and DOE's NEPA implementing procedures (10 CFR Part 1021), to assess the potential environmental impacts of providing financial assistance for the construction and operation of a project proposed by Leucadia Energy, LLC (Leucadia). DOE selected this project for an award of financial assistance through a competitive process under the Industrial Carbon Capture and Sequestration (ICCS) Program. The Lake Charles Carbon Capture and Sequestration Project (Lake Charles CCS Project) would demonstrate: (1) advanced technologies that capture carbon dioxide (CO2) emissions at the Lake Charles Cogeneration Gasification Project (the LCC Gasification Project) to be located on the west bank of the Calcasieu River in southern Calcasieu Parish, Louisiana; and (2) permanent storage of a portion of the CO2 injected as part of existing enhanced oil recovery (EOR) operations in the Hastings oil field south of Houston, Texas. During the DOE demonstration phase of the project, approximately 4 million tons per year of CO2 from two Acid Gas Removal (AGR) units would be captured, compressed and transported through a new pipeline connecting to Denbury Onshore, LLC's (Denbury's) existing Green Pipeline. The Green Pipeline is designed to transport approximately 800 million standard cubic feet of CO2 per day (about 17 million tons per year) and currently transports CO2 from natural sources to existing EOR operations along the Gulf Coast. A comprehensive research monitoring, verification, and accounting (MVA) program would be implemented on a portion of the existing CO2 EOR operations at the Hastings field to confirm permanent storage of about one million tons per year during the demonstration period. The EIS will inform DOE's decision on whether to provide financial assistance to Leucadia for the Lake Charles CCS Project. DOE proposes to provide Leucadia with up to $261.4 million of cost-shared financial assistance. The financial assistance would apply to the planning, designing, permitting, equipment procurement, construction, startup, and demonstration of the CCS technology and MVA program. DOE's contribution of $261.4 million would constitute about 60 percent of the estimated total development and capital cost of the CCS project, which is estimated to be $435.6 million (2010 dollars). The project will further the objective of the ICCS Program by demonstrating advanced technologies that integrate CO2 capture at industrial sources and monitor the sequestration of CO2 in underground formations. DOE is issuing this Notice of Intent (NOI) to: (1) Inform the public about DOE's proposed action and Leucadia's proposed project; (2) announce the public scoping meeting; (3) solicit comments for DOE's consideration regarding the scope and content of the EIS; (4) provide notice that the proposed project may involve impacts to floodplains and wetlands; and (5) invite those agencies with jurisdiction by law or special expertise to participate as cooperating agencies in the preparation of this EIS. DOE does not have regulatory jurisdiction over the Lake Charles CCS Project or its connected action, the LCC Gasification Project. DOE's decisions are limited to whether and under what circumstances it would provide financial assistance to the project. As part of the EIS process, DOE will consult with interested Native American Tribes and Federal, state, regional and local agencies.
Notice of Availability of the Draft Supplemental Environmental Impact Statement for the Nuclear Facility Portion of the Chemistry and Metallurgy Research Building Replacement Project at Los Alamos National Laboratory, Los Alamos, NM
The National Nuclear Security Administration (NNSA) announces the availability of the Draft Supplemental Environmental Impact Statement for the Nuclear Facility Portion of the Chemistry and Metallurgy Research Building Replacement Project at Los Alamos National Laboratory, Los Alamos, New Mexico (Draft CMRR-NF SEIS) (DOE/EIS-0350- S1), and the dates and locations for public hearings to receive comments on the Draft CMRR-NF SEIS. The Draft CMRR-NF SEIS analyzes the potential environmental impacts of alternatives for constructing and operating the nuclear facility (NF) portion of the Chemistry and Metallurgy Research Building Replacement (CMRR) Project. The CMRR Project was first analyzed in the 2003 Final Environmental Impact Statement for the Proposed Chemistry and Metallurgy Research Building Replacement Project at Los Alamos National Laboratory, Los Alamos, NM (the CMRR EIS) (DOE/EIS-0350), and NNSA issued a Record of Decision for the CMRR Project in February 2004 (68 FR 6420) announcing its decision to construct and operate a two building CMRR facility within Technical Area-55 (TA-55) at Los Alamos National Laboratory (LANL) in order to meet its need to sustain mission-critical specialized nuclear chemistry and metallurgy capabilities at LANL in a safe, secure and environmentally sound manner. Since that time, NNSA has constructed one of the two buildings for the CMRR Project (the Radiological Laboratory/ Utility/Office Building, also called the RLUOB), and has engaged in project planning and design processes for the second building, the CMRR-NF. The planning and design processes for the CMRR-NF have identified the need for various changes to the original design for the structure and additional project elements not envisioned in the 2003 NEPA analyses. These proposed changes, identified subsequent to the ROD, are the subject of the CMRR-NF SEIS analyses. The Draft CMRR-NF SEIS considers a No Action Alternative (the 2004 CMRR-NF), and two action alternatives (the Modified CMRR-NF Alternative, and the Continued Use of CMR Building Alternative). Under the No Action Alternative, NNSA analyzes construction and operation of the CMRR-NF as it was originally envisioned in 2004, although it has been determined that the structural design in this alternative would not meet current nuclear facility design safety requirements. Thus, this alternative no longer meets NNSA's purpose and need. The Modified CMRR-NF Alternative incorporates currently identified construction and operational requirements for the CMRR-NF, and meets NNSA's purpose and need. The Continued Use of CMR Building Alternative analyzes continued use of the CMR Building for as long as it may be safe to do so, together with the RLUOB, although this alternative would not fully meet NNSA's purpose and need. The Modified CMRR Alternative is NNSA's preferred alternative.
Electricity Market Transparency Provisions of Section 220 of the Federal Power Act
The Commission proposes to amend its regulations pursuant to section 220 of the Federal Power Act (FPA), as enacted by section 1281 of the Energy Policy Act of 2005 (EPAct 2005), to facilitate price transparency in markets for the sale and transmission of electric energy in interstate commerce. In doing so, the Commission proposes to require market participants that are excluded from the Commission's jurisdiction under FPA section 205 and have more than a de minimis market presence to file Electric Quarterly Reports (EQR) with the Commission. In addition, the Commission proposes to refine the existing EQR filing requirements by directing all filers to: report the transaction date and time, as well as the type of rate by which the price in the transaction or contract was set (i.e., fixed price, formula, index, regional transmission organization/independent system operator (RTO/ ISO) price, or index); indicate whether the transaction was reported to an index publisher; identify the broker or exchange used for a transaction, if applicable; and report electronic tag (e-Tag) ID data in EQRs. The Commission also proposes to: Standardize the unit for reporting energy and capacity transactions; omit the time zone from the contract section; and eliminate the Data Universal Numbering System (DUNS) data requirement. These refinements to the existing EQR filing requirements reflect the evolving nature of electricity markets and promote greater price transparency and confidence in electricity markets.
Blue Ribbon Commission on America's Nuclear Future
This notice announces an open meeting of the Blue Ribbon Commission on America's Nuclear Future (the Commission). The Commission was organized pursuant to the Federal Advisory Committee Act (Pub. L. 92-463, 86 Stat. 770) (the Act). This notice is provided in accordance with the Act.
Nuclear Energy Advisory Committee; Meeting
This notice announces a meeting of the Nuclear Energy Advisory Committee (NEAC). The Federal Advisory Committee Act (Pub. L. 92-463, 86 Stat. 770) requires that public notice of these meetings be announced in the Federal Register.
Version One Regional Reliability Standards for Facilities Design, Connections, and Maintenance; Protection and Control; and Voltage and Reactive
Under section 215 of the Federal Power Act, the Commission hereby approves four revised regional Reliability Standards developed by the Western Electricity Coordinating Council and approved by the North American Electric Reliability Corporation, which the Commission has certified as the Electric Reliability Organization responsible for developing and enforcing mandatory Reliability Standards. These regional Reliability Standards have been designated by the Western Electricity Coordinating Council as FAC-501-WECC-1Transmission Maintenance, PRC-004-WECC-1Protection System and Remedial Action Scheme Misoperation, VAR-002-WECC-1Automatic Voltage Regulators, and VAR-501-WECC-1Power System Stabilizer. Reliability Standard FAC-501- WECC-1 addresses transmission maintenance for specified transmission paths in the Western Interconnection. Reliability Standard PRC-004- WECC-1 addresses the analysis of misoperations that occur on transmission and generation protection systems and remedial action schemes in the Western Interconnection. Reliability Standard VAR-002- WECC-1 is meant to ensure that automatic voltage regulators remain in service on synchronous generators and condensers in the Western Interconnection. Reliability Standard VAR-501-WECC-1 is meant to ensure that power system stabilizers remain in service on synchronous generators in the Western Interconnection. In addition, the Commission approves five new regional definitions applicable within the Western Interconnection.
Availability of E-Tag Information to Commission Staff
The Federal Energy Regulatory Commission (Commission) proposes to revise its regulations to require the Commission-certified Electric Reliability Organization to make available to Commission staff, on an ongoing basis, access to complete electronic tagging data used to schedule the transmission of electric power in wholesale markets. This information will aid the Commission in market monitoring and preventing market manipulation, help assure just and reasonable rates, and aid in monitoring compliance with certain business practice standards adopted by the North American Energy Standards Board and incorporated by reference into its regulations and public utility tariffs by the Commission. The Commission is also considering making this information available to entities involved in market monitoring functions and invites comments on this option.
Application of the Energy Planning and Management Program Power Marketing Initiative to the Boulder Canyon Project
The Western Area Power Administration (Western), a Federal power marketing agency of the Department of Energy (DOE), will apply the Energy Planning and Management Program (Program) Power Marketing Initiative (PMI), as modified in this notice, to the Boulder Canyon Project (BCP), as proposed in a Federal Register notice (FRN) published on November 20, 2009. As a result, Western will extend a major percentage of the marketable capacity and energy to existing BCP customers. The remaining marketable resource shall form a resource pool that shall be marketed by Western to eligible customers by means of a public process. Western has determined that all BCP electric service contracts resulting from this effort shall have a term of thirty (30) years commencing October 1, 2017. Western is also making new proposals relative to the BCP remarketing effort including marketable capacity and energy, a resource pool percentage, and excess energy provisions, as described in this notice. Western is accepting public comments on these proposals. All comments previously submitted in response to Western's November 20, 2009, notice will be considered in this process and are not required to be resubmitted.
Version One Regional Reliability Standard for Transmission Operations
Under section 215(d)(2) of the Federal Power Act, the Federal Energy Regulatory Commission approves regional Reliability Standard TOP-007-WECC-1 (System Operating Limits) developed by the Western Electric Coordinating Council (WECC) and submitted to the Commission for approval by the North American Electric Reliability Corporation. The primary purpose of this regional Reliability Standard is to ensure that actual flows and associated scheduled flows on major WECC transfer paths do not exceed system operating limits for more than 30 minutes. The Commission also approves the retirement of WECC regional Reliability Standard TOP-STD-007-0, which is replaced by the regional Reliability Standard approved in this Final Rule. The Commission also directs WECC to modify the associated violation risk factors and violation severity levels.
Electric Reliability Organization Interpretations of Interconnection Reliability Operations and Coordination and Transmission Operations Reliability Standards
Pursuant to section 215 of the Federal Power Act, the Federal Energy Regulatory Commission hereby approves the North American Electric Reliability Corporation's (NERC) interpretation of the Commission-approved Reliability Standards, IRO-005-1, Reliability CoordinationCurrent-Day Operations, Requirement R12, and TOP-005-1, Operational Reliability Information, Requirement R3. Specifically, the interpretation finds that a transmission owner must report a Special Protection System that is operating with only one communication channel in service to the reliability coordinator and neighboring systems upon request, or when the loss of the communication channel will result in the failure of the Special Protection System to operate as designed.