Summary of the Proposed Project. As certificated, the Ocean Express Pipeline Project would consist of a new 24-inch-diameter interstate natural gas pipeline, and certain ancillary facilities, that would extend approximately 54.5 miles from a receipt point on the Exclusive Economic Zone (EEZ) boundary between the United States and the Bahamas to two delivery points in Broward County, Florida, one at an interconnection with the existing Florida Gas Transmission System (FGT) pipeline at the Florida Power and Light (FPL) Fort Lauderdale Power Plant, and the other at an interconnection with the FPL gas line that serves the FPL Fort Lauderdale plant. Ocean Express’s proposed modifications reflect the incorporation of tunnel construction schedule. Ocean Express explains that the use of the tunnel construction methodology would allow it to construct the nearshore portion the pipeline using an approximately 14,000-foot-long tunnel, with certain minor route changes to accommodate the methodology, as opposed to the horizontal directional drills (HDDs) that the Commission has already approved. Ocean Express also proposes to increase the pipeline diameter from 24 inches to 26 inches and internally coat the pipeline, to allow for increased hourly flow rates, but does not propose to increase the certificated capacity (842,000 dekatherms/day) of its pipeline. Additionally, Ocean Express proposes to install a pressure reducing station inside the tunnel to reduce the onshore Maximum Allowable Operating Pressure (MAOP) to 1,480 pounds per square inch gauge (psig) or less, from the certificated MAOP of 2,200 psig. An aboveground tunnel shaft/access building and gas vent would also be installed at the Dania Beach Boulevard Traffic Circle.
Summary of the Proposed Project. Copiah wants to provide a storage facility that would act as a reservoir for a supply of natural gas to the Mississippi regional area. The proposed project would meet load swings brought about by gas-fired electric generation and the peak winter heating load and growth of local distribution companies for rapid fuel delivery services to nearby pipeline systems. The storage facility would have an initial natural gas storage working capacity of approximately 3.3 billion cubic feet (Bcf) with 300,000 dekatherms per day (Dth/d) of deliverability capability and 150,000 Dth/d of injection capability. Specifically, Copiah seeks authority to construct and operate: • A single 3.3 Bcf capacity gas storage cavern extending approximately 5,500 feet below the ground surface within an underground salt dome; • 13,350 horsepower (hp) of gas engine-driven compression at the new Copiah Storage Project compressor station to provide compression for injection and withdrawal of natural gas from the gas storage cavern; • Approximately 635 feet of 20-inch- diameter pipeline from the compressor station to the storage cavern wellhead; and • Up to five well sites consisting of a Land Requirements for Construction Approximately 730 acres have been identified by Copiah as the project area. However, only 59 acres would be disturbed by construction and 53 acres would be necessary for the operation of the proposed project. The EA Process The National Environmental Policy Act (NEPA) requires the Commission to take into account the environmental impacts that could result from an action whenever it considers the issuance of a Certificate of Public Convenience and Necessity. NEPA also requires us3 to discover and address concerns the public may have about proposals. We call this ‘‘scoping’’. The main goal of the scoping process is to focus the analysis in the EA on the important environmental issues. By this Notice of Intent, the Commission requests public comments on the scope of the issues it will address in the EA. All comments received are considered during the preparation of the EA. State and local government representatives are encouraged to notify their constituents of this proposed action and encourage them to comment on their areas of concern. The EA will discuss impacts that could occur as a result of the construction and operation of the proposed project under these general headings: • Geology and soils • Land use • Water resources, fisheries, and wetlands • Endangered and threaten...
Summary of the Proposed Project. CIG proposes to construct, operate, and abandon facilities in Colorado and Kansas to increase the maximum daily storage withdrawal quantity and increase capacity on its transmission system. CIG seeks authority to: • Drill one injection well/withdrawal well and convert one observation well to a salt water disposal well at the Fort Xxxxxx Storage Field and upgrade two segments of the Fort Xxxxxx Storage Field gathering system from an MAOP of 1,800 and 2,000 to an MAOP of 2,160 psig; • Increase Fort Xxxxxx Storage Field allowed maximum storage gas in place from 14,322 MMcf to 14,858 MMcf, and increase the average shut-in reservoir bottom hole pressure to a maximum of 2,390 psia; • Add 4 injection/withdrawal xxxxx and convert 8 injection/withdrawal xxxxx to observation xxxxx at the Xxxxx Storage Field; • Install a 600 horsepower compressor along with hydrogen sulfide treatment and appurtenant facilities at the Xxxxx Storage Field to remove Xxxxx Xxxxx Reservoir base gas. The compressor would be used until the pressure in the Xxxxx Sand Reservoir is too low to be effectively utilized. CIG would then abandon the compressor and the Xxxxx Xxxxx Reservoir; • Construct 26.2 miles of 24-inch- diameter pipeline loop adjacent to CIG’s existing pipeline which would run between CIG’s existing Cheyenne Compressor Station and Ault Meter Station in Weld County, Colorado; • Construct new Fort Xxxxxx Compressor Station consisting of three natural gas-fired reciprocating engines each rated at 2,225 horsepower and appurtenant facilities in Weld County, Colorado; • Construct 27 miles of 24-inch- diameter pipeline loop and appurtenant facilities from CIG’s proposed Fort Federal Register / Vol. 65, No. 228 / Monday, November 27, 2000 / Notices 70709 Xxxxxx Compressor Station in Weld County, Colorado to CIG’s existing Xxxxxxx Compressor Station in Xxxxx County, Colorado; and • Install miscellaneous facilities within the Xxxxxxx Compressor Station that include yard piping, pipe valves, fittings, controls and regulation and measurement equipment. CIG states that these facilities would increase its storage pool deliverability from 775 MMcf to 877 MMcf per day and increase capacity from the Cheyenne Compressor Station. The general location of the project facilities is shown in appendix 1.
Summary of the Proposed Project. CNG Transmission Corporation (CNG) wants to facilitate the recovery of injected storage gas that migrated to an undeveloped portion of its North Summit Storage Complex in Fayette County, Pennsylvania. CNG seeks authority to: • Convert two observation xxxxx (UW–204 and UW–207) to storage xxxxx; • Replace 0.4 mile of 6-inch-diameter pipeline with an equal length of 8-inch- diameter pipeline (Line No. UP–1); • Install 2.4 miles of 8-inch-diameter pipeline (Line No. UP–24); • Install 0.7 mile of 8-inch-diameter pipeline (Line No. UP–25); and • Install tie-in facilities to Well Nos. UW–204 and UW–207 including a meter, step-ladder drip, separator, fiberglass holding tank, alcohol dropper, valves, a pig launcher and receiver, and other appurtenances. The location of the project facilities is shown in appendix 2. Land Requirements for Construction Construction of the proposed facilities would require about 29.8 acres of land. Following construction, about 20.8 acres would be maintained as new permanent right-of-way and about 0.7 acre as new aboveground facility sites. The remaining 8.3 acres of land would be allowed to revert to its former use. The EA Process The National Environmental Policy Act (NEPA) requires the Commission to take into account the environmental impacts that could result from an action whenever it considers the issuance of a Certificate of Public Convenience and Necessity. NEPA also requires us to discover and address concerns the public may have about proposals. We call this ‘‘scoping’’. The main goal of the scoping process is to focus the analysis in the EA on the important environmental issues. By this Notice of Intent, the Commission requests public comments on the scope of the issues it will address in the EA. All comments received are considered during the preparation of the EA. State and local government representatives are encouraged to notify their constituents of this proposed action and encourage 2 The appendices referenced in this notice are not being printed in the Federal Register . Copies are available from the Commission’s Public Reference and Files Maintenance Branch, 000 Xxxxx Xxxxxx, X.X., Xxxxxxxxxx, X.X. 00000, or call (202) 208– 1371. Copies of the appendices were sent to all those receiving this notice in the mail. them to comment on their areas of concern. The EA will discuss impacts that could occur as a result of the construction and operation of the proposed project under these general headings: • Geology and soils. ...
Summary of the Proposed Project. Columbia Gas Transmission Corporation (Columbia) proposes to amend its Market Expansion Project authorized in a Commission Order dated May 14, 1997 (Order). Columbia states that due to a more detailed facility design analysis, it has determined that certain compression facilities approved in the Order are no longer required and certain other facilities not approved in the Order will be needed. The effect of the proposed facility revisions would be to decrease the overall cost of the Market Expansion Project facilities by about $3,280,700. The new facilities that Columbia proposes to construct and the facilities its proposes to delete from the Market Expansion Project (facilities approved but not yet constructed) are listed below: New Proposed Facilities (Louisa County, Virginia) • Line VM–105 Loop—construct 0.3 mile of 20-inch-diameter loop on the suction side of the Boswells Tavern compressor Station; • Line VM–106 Replacement— replace 0.6 mile of 12-inch-diameter pipeline with 24-inch-diameter pipeline on the discharge side of the Boswells Tavern Compressor Station; • Upgrade a meter station within the Boswells Tavern Compressor Station; and • Line VM–109—construct 6.0 miles of 24-inch-diameter pipeline loop from its mainline valve 3 to its Louisa Compressor Station.
Summary of the Proposed Project. Columbia Gulf wants to replace an aging compressor package at its existing Xxxxxxx Compressor Station. Columbia Gulf seeks authority for the following activities: • Abandon by removal one 12,050- horsepower (hp) gas-powered turbine compressor and driver, the related compressor and control buildings, and associated piping and valves; • Construct and operate a new 14,470-hp gas turbine compressor package within a new prefabricated building; • Construct a second prefabricated building to house compressor control and communication equipment; and
Summary of the Proposed Project. Maritimes wants to extend its mainline system from a point near Methuen, Massachusetts, to an interconnection with Algonquin’s proposed HubLine facilities in Beverly, Massachusetts. Maritimes’ proposed Phase III facilities would have an initial capacity to deliver approximately 360,000 million British thermal units per day of natural gas. Algonquin wants to interconnect with the proposed Maritimes system in Beverly, Massachusetts, by constructing the proposed HubLine facilities from Beverly to an interconnect with its existing I–9 pipeline system at the Sithe Fore River Power Plant in Weymouth, Massachusetts. Maritimes seeks authority to construct and operate: • Approximately 23.8 miles of 30- inch-daimeter pipeline and 1.0 mile of 24-inch-diameter pipeline; and • Appurtenant facilities to include three mainline valves, one tap valve, two cathodic protection ground beds, and two meter stations. Algonquin seeks authority to construct and operate: • Approximately 29.4 miles of 24- inch-diameter offshore mainline pipeline;
Summary of the Proposed Project. Paiute wants to abandon and replace a deteriorating segment of pipeline, install a new loop 3 at another segment along its existing Xxxxxx Lateral; and increase capacity at 4 existing regulation stations. The proposed facilities would allow Paiute to expand its existing natural gas transmission system capacity by 5,868 dekatherms per day to meet the future demands of existing shippers. Paiute seeks to: • Construct and operate about 6.4 miles of new 20-inch-diameter loop between mileposts (MP) 9.45 and 15.85 on Paiute’s existing Xxxxxx Lateral, parallel to U.S. Highway 95A north of Silver Springs, in Lyon County, Nevada (Highway 95A Loop); • Abandon in place about 8.0 miles of 10-inch-diameter pipeline between MP 37.34 and MP 45.34 on the Xxxxxx Lateral in Lyon County, Nevada; • Construct and operate about 8.1 miles of 20-inch-diameter pipeline, to replace the pipe abandoned in place, between MP 37.34 and MP 45.34 on the Xxxxxx Lateral, parallel to U.S. Highway 50 near Dayton, in Lyon County, Nevada (Highway 50 Replacement); and • Replace and/or install pressure regulation facilities at the White Sage Pressure Limiting Station in Lyon City Gate in Douglas County, Nevada; and the California Check Meter in Washoe County, Nevada. The general location of the proposed facilities is shown in appendix 1.4
Summary of the Proposed Project. Xxxxxxxx wants to expand the capacity of its facilities in Oklahoma, Kansas, and Missouri to transport an additional 55,000 decatherms per day of natural gas to Empire District Electric Company’s (Empire) State Line Plant. (This would result in a total of 83,800 decatherms per day of natural gas to the State Line Plant.) Xxxxxxxx seeks authority to: • Reclaim three mainline valves and two mainline drips, replace fine mainline valves and one mainline drip, replace 11 road crossings, and install a 16-inch-diameter pig launcher and appurtenant piping along the existing 16-inch-diameter, 85-mile-long Xxxxxxxxx-Xxxxxx Valley pipeline in Xxx, Osage, and Washington Counties, Oklahoma; • Upgrade 14 domestic meters, which would include upgrading/replacing regulators and valves as needed, along with Xxxxxxxxx-Xxxxxx Valley pipeline in Xxx, Osage, and Washington Counties, Oklahoma; • Increase the maximum allowable pressure along the Xxxxxxxxx-Xxxxxx Valley pipeline from 500 psig to 690 2 The appendices referenced in this notice are not being printed in the Federal Register . Copies are available from the Commission’s Public Reference and Files Maintenance Branch, 000 Xxxxx Xxxxxx, XX., Xxxxxxxxxx, XX 00000, or call (202) 208–1371. Copies of the appendices were sent to all those receiving this notice in the mail. psig in Xxx, Osage, and Washington Counties, Oklahoma; • Extend the existing 20-inch- diameter Southern Trunk Loop an additional 36.8 miles in Labette and Cherokee Counties, Kansas; • Relocate the existing 20-inch- diameter pig receiver to the end of the 36.8-mile Southern Trunk Loop and install two mainline valves in Cherokee County, Kansas; • Install a dual 6-inch regulator setting, a dual 8-inch turbine meter setting, an 8-inch flow control setting, and about 450 feet of 16-inch-diameter pipeline at a new location within the existing Empire property area in Jasper County, Missouri; and • Install a 4-inch flow control setting at Empire’s existing site in Jasper County, Missouri. The general location of the project facilities as well as a detailed version of the Southern Trunk Loop are shown in appendix 2.
