/PRNewswire/ -- With gasoline and diesel pump prices in Georgia hovering in the $4.00 range, Atlanta Gas Light (AGL) today (May 12) filed a plan with the Georgia Public Service Commission (PSC) to build a network of Compressed Natural Gas (CNG) fueling stations over the next five years in the metropolitan Atlanta region and along major transportation corridors in the state. The plan also includes low-cost equipment leasing options for home fueling stations. CNG retail prices are over a third less than that of petroleum - $2.19 per gallon of gas equivalent – as currently posted at Georgia retailers.
"Demand for CNG is growing in the United States, and Atlanta Gas Light is committed to attracting interest in this important new investment opportunity to Georgia," said Ian Skelton, director of Atlanta Gas Light's natural gas vehicle program. "Natural gas is abundant and clean, and the U.S. is estimated to have a one hundred year supply that is readily deliverable to Georgia. Fleet owners and vehicle manufacturers are beginning to recognize the significant price advantage CNG holds over petroleum at the pump and, as a result, demand for CNG should increase. Making CNG stations more prevalent and accessible makes sense for Georgia, for businesses and for consumers."
Under the plan to be considered by the PSC later this summer, AGL proposes to invest nearly $12 million dollars to stimulate private investment in the construction of approximately 10 to 15 fueling stations, depending on the size of the station and the level of private investment. The stations would be owned and operated by private retailers who must invest approximately 50 percent of the cost of the CNG station. Retailers would purchase natural gas from certificated marketers and resell it as CNG to the public. The initial station locations will be largely determined based on proximity to commercial fleet customers who contract for service.
The capital used to seed the market would be expended from the Universal Service Fund, which is funded from rates paid by industrial customers and proceeds shared by energy asset management firms. AGL annually requests funds from the USF for line extensions to serve new customers and new regions of the state. The recessed economy has stalled line extensions that normally would come with growth, leaving a temporary surplus in the fund that can be used to foster CNG growth.
Atlanta Gas Light will not sell CNG to the public nor participate in the commercial operation of the stations as part of this program. AGL will own and maintain the CNG equipment connected to its traditional natural gas distribution system, enabling USF dollars to be used to construct the CNG facilities. Atlanta Gas Light will collect transportation delivery charges and actual costs associated with operations and maintenance from retailers. Revenue collected from a separate equipment utilization fee will be placed in a reserve account to fund a portion of the cost of leasing home refueling stations, erecting additional CNG facilities, and making repairs and replacing the CNG equipment.
In order to qualify for funding, applicants must demonstrate financial resources sufficient to secure the real estate for the station, develop the site consistent with local zoning, fund at least 50 percent of the total CNG station costs, and produce contracts with fleet or end use customers that utilize no less than 15,000 gas equivalent gallons per year for five years. The 50 percent match requirement is reduced to 20 percent after the first year if there are sufficient funds remaining.
The plan is the product of months of market studies and public hearings followed by legislative action. After filing a conceptual plan last September at the urging of PSC Commissioner Doug Everett, two public hearings were held in November 2010 and January 2011 to refine the plan. In March, the Georgia General Assembly gave express authorization for USF funds to be utilized for natural gas fueling infrastructure for motor vehicles.
Construction and maintenance of CNG facilities is not new to Atlanta Gas Light. The company installed its first CNG pumps at a public station in downtown Atlanta in the early 1990's. In 1996, AGL began its service to MARTA (Metropolitan Atlanta Rapid Transit Authority) when the transportation agency converted its bus fleet to CNG in advance of Atlanta hosting the Summer Olympics. Currently, the company owns equipment located at 10 CNG stations operated by private fleets and located on customer-owned premises, including municipal transit agencies, and has installed numerous others. The company also provides maintenance services to about 40 additional fleet customers who own their own CNG stations.
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Showing posts with label gas. Show all posts
Showing posts with label gas. Show all posts
Monday, May 16, 2011
Friday, April 8, 2011
Oglethorpe Power Completes Purchase of Combined Cycle Units
/PRNewswire/ -- Oglethorpe Power Corporation today completed the purchase of two natural gas-fired, combined cycle generating units in Murray County, Ga. with the acquisition of KGen Murray I and II, LLC, a wholly owned subsidiary of KGen Power Corporation. The purchase price was approximately $529 million, including working capital and other closing adjustments.
The two Murray units represent an aggregate summer planning reserve generating capacity of about 1,220 megawatts (MW). This brings Oglethorpe Power's total owned generating capacity to approximately 7,048 MW.
The Murray acquisition also includes an existing power purchase and sale agreement with Georgia Power Company for the entire output of Murray I through May 31, 2012. Initially, both units are planned to be operated independently of the other generating facilities owned and operated by Oglethorpe Power but will be integrated into the system as needed.
Oglethorpe Power first disclosed that it was negotiating to purchase some then-unnamed natural gas facilities in October 2010 and followed in January 2011 with an announcement that it had signed a purchase and sale agreement for the Murray units, subject to applicable regulatory approvals and approval by KGen stockholders.
"We couldn't be more pleased with today's acquisition," said Elizabeth B. Higgins, executive vice president and chief financial officer. "This purchase gives Oglethorpe Power and our Member Systems a significant block of generating capacity at a very reasonable cost without the added time and additional expense of constructing a new facility."
In purchasing the Murray units, Oglethorpe Power has now officially canceled construction of a planned 605-megawatt, combined cycle generating plant that was in the siting stage.
Ms. Higgins said Oglethorpe Power expects long-term financing for the Murray units to come primarily from loans guaranteed by the Rural Utilities Service (RUS). Taxable bonds would make up the difference for any amount not funded through the RUS loan program.
Oglethorpe Power Corporation (OPC) is the nation's largest power supply cooperative with more than $7 billion in assets serving 39 Electric Membership Corporations which, collectively, provide electricity to 4.1 million Georgians.
A proponent of conscientious energy development and use, OPC balances reliable and affordable energy with environmental responsibility and has an outstanding record of regulatory compliance. Its diverse energy portfolio includes natural gas, hydroelectric, coal and nuclear generating plants with a combined capacity of approximately 7,048 MW, as well as purchased power.
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The two Murray units represent an aggregate summer planning reserve generating capacity of about 1,220 megawatts (MW). This brings Oglethorpe Power's total owned generating capacity to approximately 7,048 MW.
The Murray acquisition also includes an existing power purchase and sale agreement with Georgia Power Company for the entire output of Murray I through May 31, 2012. Initially, both units are planned to be operated independently of the other generating facilities owned and operated by Oglethorpe Power but will be integrated into the system as needed.
Oglethorpe Power first disclosed that it was negotiating to purchase some then-unnamed natural gas facilities in October 2010 and followed in January 2011 with an announcement that it had signed a purchase and sale agreement for the Murray units, subject to applicable regulatory approvals and approval by KGen stockholders.
"We couldn't be more pleased with today's acquisition," said Elizabeth B. Higgins, executive vice president and chief financial officer. "This purchase gives Oglethorpe Power and our Member Systems a significant block of generating capacity at a very reasonable cost without the added time and additional expense of constructing a new facility."
In purchasing the Murray units, Oglethorpe Power has now officially canceled construction of a planned 605-megawatt, combined cycle generating plant that was in the siting stage.
Ms. Higgins said Oglethorpe Power expects long-term financing for the Murray units to come primarily from loans guaranteed by the Rural Utilities Service (RUS). Taxable bonds would make up the difference for any amount not funded through the RUS loan program.
Oglethorpe Power Corporation (OPC) is the nation's largest power supply cooperative with more than $7 billion in assets serving 39 Electric Membership Corporations which, collectively, provide electricity to 4.1 million Georgians.
A proponent of conscientious energy development and use, OPC balances reliable and affordable energy with environmental responsibility and has an outstanding record of regulatory compliance. Its diverse energy portfolio includes natural gas, hydroelectric, coal and nuclear generating plants with a combined capacity of approximately 7,048 MW, as well as purchased power.
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Tuesday, January 25, 2011
ArcLight Teams With GE and Singapore's GIC to Form Largest Fully Independent Power Producer in US Southeast
/PRNewswire/ -- ArcLight Capital Partners, LLC ("ArcLight"), GE Energy Financial Services, a unit of GE (NYSE: GE), and the Government of Singapore Investment Corporation Pte Ltd ("GIC") announced today they have agreed to become partners in five Georgia natural gas-fired power plants that together make up the largest fully independent power producer in the southeastern United States. The GE unit and GIC will each acquire 24.95 percent of the portfolio from an affiliate of ArcLight, now its sole owner. An affiliate of ArcLight will retain 50.10 percent.
Financial details of the transaction were not disclosed. The closing of the transaction remains subject to approval by the Federal Energy Regulatory Commission and Committee on Foreign Investment in the United States and is expected to occur toward the end of the first quarter of 2011.
The plants, located throughout Georgia, comprise a combined cycle facility and four single-cycle peaking facilities, each of which is less than 10 years old. Together, they are capable of generating more than 2,500 megawatts of power, in several cases using GE gas-fired turbines. All five facilities, critical to the regional power supply and grid stability, are contracted under long-term agreements to investment-grade counterparties and are managed by Consolidated Asset Management Services, an ArcLight affiliate.
The portfolio comprises:
* Monroe – a 320-megawatt plant in Monroe, 50 miles east of Atlanta
* Walton – a 450-megawatt plant in Monroe, adjacent to the Monroe plant
* Washington – a 602-megawatt plant in Linton, 50 miles east of Macon
* Sandersville – a 640-megawatt plant in Sandersville, seven miles from the Washington plant
* Effingham – a 515-megawatt plant in Rincon, 20 miles north of Savannah
The portfolio is well positioned to benefit from the macroeconomic recovery and more stringent energy and carbon legislation as well as the boom in production of unconventional natural gas in the United States. In addition, the portfolio will support additional infrastructure investment in the region to meet the demand for power and accommodate the power supply reconfiguration expected to unfold over the next decade.
"Since the initial investment in this portfolio in 2007, ArcLight and CAMS have developed a strong track record of operational success and commercial reliability in a promising regional market," said Dan Revers, Managing Partner of ArcLight. "We are excited about the opportunity to partner with these two highly respected and valued-added investors, and we look forward to working closely with GE and GIC to maximize value across the portfolio and platform."
ArcLight has completed several transactions with GE Energy Financial Services, including the GE unit's lead lending of $98 million in senior secured credit facilities for the Sandersville power plant.
"This transaction enables us to deepen our relationship with ArcLight, establish ties with an important new partner, GIC, and work together on an attractive set of assets in a core focus area, thermal power generation," said Kevin Walsh, managing director and leader of Power and Renewables at GE Energy Financial Services.
"This is an attractive portfolio of contracted power generation facilities in a region experiencing an increasing demand for low carbon, efficient power. The completion of this transaction complements our growing portfolio of infrastructure investments in the US. We are delighted to have ArcLight and GE, who have extensive experience in owning and operating similar assets, as our partners in this deal," said Mr. Ang Eng Seng, Global Head of GIC's Infrastructure Group.
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Financial details of the transaction were not disclosed. The closing of the transaction remains subject to approval by the Federal Energy Regulatory Commission and Committee on Foreign Investment in the United States and is expected to occur toward the end of the first quarter of 2011.
The plants, located throughout Georgia, comprise a combined cycle facility and four single-cycle peaking facilities, each of which is less than 10 years old. Together, they are capable of generating more than 2,500 megawatts of power, in several cases using GE gas-fired turbines. All five facilities, critical to the regional power supply and grid stability, are contracted under long-term agreements to investment-grade counterparties and are managed by Consolidated Asset Management Services, an ArcLight affiliate.
The portfolio comprises:
* Monroe – a 320-megawatt plant in Monroe, 50 miles east of Atlanta
* Walton – a 450-megawatt plant in Monroe, adjacent to the Monroe plant
* Washington – a 602-megawatt plant in Linton, 50 miles east of Macon
* Sandersville – a 640-megawatt plant in Sandersville, seven miles from the Washington plant
* Effingham – a 515-megawatt plant in Rincon, 20 miles north of Savannah
The portfolio is well positioned to benefit from the macroeconomic recovery and more stringent energy and carbon legislation as well as the boom in production of unconventional natural gas in the United States. In addition, the portfolio will support additional infrastructure investment in the region to meet the demand for power and accommodate the power supply reconfiguration expected to unfold over the next decade.
"Since the initial investment in this portfolio in 2007, ArcLight and CAMS have developed a strong track record of operational success and commercial reliability in a promising regional market," said Dan Revers, Managing Partner of ArcLight. "We are excited about the opportunity to partner with these two highly respected and valued-added investors, and we look forward to working closely with GE and GIC to maximize value across the portfolio and platform."
ArcLight has completed several transactions with GE Energy Financial Services, including the GE unit's lead lending of $98 million in senior secured credit facilities for the Sandersville power plant.
"This transaction enables us to deepen our relationship with ArcLight, establish ties with an important new partner, GIC, and work together on an attractive set of assets in a core focus area, thermal power generation," said Kevin Walsh, managing director and leader of Power and Renewables at GE Energy Financial Services.
"This is an attractive portfolio of contracted power generation facilities in a region experiencing an increasing demand for low carbon, efficient power. The completion of this transaction complements our growing portfolio of infrastructure investments in the US. We are delighted to have ArcLight and GE, who have extensive experience in owning and operating similar assets, as our partners in this deal," said Mr. Ang Eng Seng, Global Head of GIC's Infrastructure Group.
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Thursday, October 28, 2010
Atlanta Gas Light's Residential Rates to Increase 90 Cents per Month
/PRNewswire/-- Following a 4-1 vote October 27 by the Georgia Public Service Commission (PSC), residential customers of Atlanta Gas Light will receive a 90-cent monthly net increase in service rates effective November 1. The adjustment, the first base rate increase for the company since 1993, equates to an overall increase of one percent for the typical residential customer's annual natural gas bill. The adjustment will be reflected in the monthly Atlanta Gas Light charges as billed by certificated gas marketers to customers.
After weighing evidence and hearing testimony during the last six months, the PSC concluded that a $26.7 million increase in the company's revenue requirement was warranted to provide the company with sufficient revenue to meet reasonable expenses, pay interest on debt, continue to attract capital at favorable rates and provide a reasonable return to shareholders in order to continue to attract investment. The company originally sought $54.2 million in additional revenues in its case filed May 3, 2010, before adjusting the amount in October to $48.2 million to reflect more current economic conditions.
The company expects a final written order to be issued within the next 30 days, at which time parties to the case have 10 days to file for reconsideration of the decision with the PSC.
"Although we made a strong case for a larger revenue requirement to fund our service obligations, we recognize the economic climate weighed heavily on the commission as it worked to find the right balance for the company, our customers and shareholders," said Suzanne Sitherwood, president, Atlanta Gas Light.
"It is never an easy decision to increase rates, particularly in a difficult economy," Sitherwood said. "However, the action by the PSC provides necessary revenues to sustain our operations and meet the growing demands for compliance and safety work, while improving our customer service levels."
The PSC also approved a rate-design change that closes the cost-of-service gap between residential and commercial customers. Small commercial customers with a Designated Design Day Capacity (DDDC) factor of less than 7.0, which includes approximately 82% of all commercial customers, will see no rate increase or a small decrease. Large commercial customers will receive a monthly increase in their total bill similar in percentage to that of residential customers. In addition, monthly rates charged to agricultural customers will be reduced by $73 on average, particularly to bring poultry growers' rates more in line with general commercial accounts and help them better manage peak costs during winter.
The company also was ordered to investigate whether additional senior citizens might be eligible to participate in Atlanta Gas Light's senior discount program. Individuals age 65 or older with annual income of $14,355 or less are eligible to receive a monthly discount of up to $14.00.
Other details and provisions of the decision include:
* Acceptance of a revenue requirement of approximately $450 million, which equates to an unadjusted increase of approximately $1.46 per residential customer.
* Two changes in the company's surcharges totaling approximately $12.1 million annually, which will offset the impact of the rate increase by approximately 56 cents per month on the customer's monthly bill. This includes a temporary shift of $6.5 million from the Universal Service Fund to fund the Senior Citizen Discount Program, and acceptance of an October filing by Atlanta Gas Light to reduce the environmental cost recovery surcharge rate for an annual reduction of $5.6 million.
* Established an authorized return on equity of 10.75 percent, which is within the estimated range of 10.5 percent to 11.25 percent recommended by the company.
* Approval of a capital structure for the company of 51 percent common equity, 44.63 percent long-term debt and 4.37 percent short-term debt.
* A return to a traditional method of calculating depreciation expense using net value methodology with a salvage rate of negative 30 percent.
* Approval of an in-home appliance repair program that permits Atlanta Gas Light service technicians to perform minor repairs of low cost and short duration when responding to the home for other purposes, while providing referrals to Natural Gas Advantage Dealer companies for more substantial repairs or appliance replacements.
* Funding of the new Customer Care Center in Riverdale, Georgia, to better handle customer issues and support 74 new jobs in Georgia.
* Increase the number of service technicians on staff to make them available to reduce the average time to establish service and fulfill other customer orders from five business days to three.
* Adoption of a new acquisition synergy sharing policy that is expected to hold down future operating expenses by incentivizing the company to make prudent utility acquisitions that capture savings for customers while insulating them from risk of increased costs from such transactions. Customers will share equally in any savings from future transactions after the company demonstrates savings through a future proceeding.
* Allocation of $4.4 million in annual revenue to the company to recognize equitable treatment of current and ongoing savings produced from the acquisition by AGL Resources of NUI Corporation. Evidence in the case demonstrated that since 2005 approximately $150 million in savings were generated from previous acquisitions which were applied to reduce Atlanta Gas Light's operating expenses.
* Improvements to technology systems intended to provide quicker response times and greater capacity to perform additional marketer and customer services.
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After weighing evidence and hearing testimony during the last six months, the PSC concluded that a $26.7 million increase in the company's revenue requirement was warranted to provide the company with sufficient revenue to meet reasonable expenses, pay interest on debt, continue to attract capital at favorable rates and provide a reasonable return to shareholders in order to continue to attract investment. The company originally sought $54.2 million in additional revenues in its case filed May 3, 2010, before adjusting the amount in October to $48.2 million to reflect more current economic conditions.
The company expects a final written order to be issued within the next 30 days, at which time parties to the case have 10 days to file for reconsideration of the decision with the PSC.
"Although we made a strong case for a larger revenue requirement to fund our service obligations, we recognize the economic climate weighed heavily on the commission as it worked to find the right balance for the company, our customers and shareholders," said Suzanne Sitherwood, president, Atlanta Gas Light.
"It is never an easy decision to increase rates, particularly in a difficult economy," Sitherwood said. "However, the action by the PSC provides necessary revenues to sustain our operations and meet the growing demands for compliance and safety work, while improving our customer service levels."
The PSC also approved a rate-design change that closes the cost-of-service gap between residential and commercial customers. Small commercial customers with a Designated Design Day Capacity (DDDC) factor of less than 7.0, which includes approximately 82% of all commercial customers, will see no rate increase or a small decrease. Large commercial customers will receive a monthly increase in their total bill similar in percentage to that of residential customers. In addition, monthly rates charged to agricultural customers will be reduced by $73 on average, particularly to bring poultry growers' rates more in line with general commercial accounts and help them better manage peak costs during winter.
The company also was ordered to investigate whether additional senior citizens might be eligible to participate in Atlanta Gas Light's senior discount program. Individuals age 65 or older with annual income of $14,355 or less are eligible to receive a monthly discount of up to $14.00.
Other details and provisions of the decision include:
* Acceptance of a revenue requirement of approximately $450 million, which equates to an unadjusted increase of approximately $1.46 per residential customer.
* Two changes in the company's surcharges totaling approximately $12.1 million annually, which will offset the impact of the rate increase by approximately 56 cents per month on the customer's monthly bill. This includes a temporary shift of $6.5 million from the Universal Service Fund to fund the Senior Citizen Discount Program, and acceptance of an October filing by Atlanta Gas Light to reduce the environmental cost recovery surcharge rate for an annual reduction of $5.6 million.
* Established an authorized return on equity of 10.75 percent, which is within the estimated range of 10.5 percent to 11.25 percent recommended by the company.
* Approval of a capital structure for the company of 51 percent common equity, 44.63 percent long-term debt and 4.37 percent short-term debt.
* A return to a traditional method of calculating depreciation expense using net value methodology with a salvage rate of negative 30 percent.
* Approval of an in-home appliance repair program that permits Atlanta Gas Light service technicians to perform minor repairs of low cost and short duration when responding to the home for other purposes, while providing referrals to Natural Gas Advantage Dealer companies for more substantial repairs or appliance replacements.
* Funding of the new Customer Care Center in Riverdale, Georgia, to better handle customer issues and support 74 new jobs in Georgia.
* Increase the number of service technicians on staff to make them available to reduce the average time to establish service and fulfill other customer orders from five business days to three.
* Adoption of a new acquisition synergy sharing policy that is expected to hold down future operating expenses by incentivizing the company to make prudent utility acquisitions that capture savings for customers while insulating them from risk of increased costs from such transactions. Customers will share equally in any savings from future transactions after the company demonstrates savings through a future proceeding.
* Allocation of $4.4 million in annual revenue to the company to recognize equitable treatment of current and ongoing savings produced from the acquisition by AGL Resources of NUI Corporation. Evidence in the case demonstrated that since 2005 approximately $150 million in savings were generated from previous acquisitions which were applied to reduce Atlanta Gas Light's operating expenses.
* Improvements to technology systems intended to provide quicker response times and greater capacity to perform additional marketer and customer services.
-----
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Friday, September 24, 2010
Southern Company Captures CO2 at Georgia Power Plant; Research Milestone is a First for Company
/PRNewswire/ -- Southern Company has captured carbon dioxide from one of its power plants for the first time, a milestone that significantly advances the development of technology considered crucial to reducing greenhouse gas emissions from power generation.
The research accomplishment was achieved this month at subsidiary Georgia Power's Plant Yates near Newnan, Ga.
The pilot-scale project at Plant Yates, which uses a capture system developed by Mitsubishi Heavy Industries (MHI), will provide additional process improvements before the technology is demonstrated next year at a much larger 25-megawatt scale at Plant Barry, which is owned and operated by Southern Company subsidiary Alabama Power near Mobile, Ala.
During the pilot at Plant Yates, a small amount of carbon dioxide (CO2) was captured, using a solvent that absorbs CO2, and then returned to the plant's flue gas. At Plant Barry, the carbon dioxide will be compressed and transported via pipeline to deep underground storage formations.
"Capturing CO2 from an operating power plant is an important step forward in our efforts to develop effective and cost-efficient technologies to reduce carbon dioxide emissions while ensuring a continued reliable and affordable supply of electricity for our customers," said Chris Hobson, Southern Company chief environmental officer. "Along with our other carbon capture and storage research initiatives, our success here will help us move closer to the ultimate goal of commercial deployment."
Southern Company is a participant in several major research initiatives to advance the development of carbon capture and storage technology, a key component in the nation's effort to reduce greenhouse gas emissions.
In addition to the projects at Yates and Barry, Southern Company operates the National Carbon Capture Center for the U.S. Department of Energy near Birmingham, Ala., and its subsidiary Mississippi Power is building an advanced commercial-scale coal gasification power plant in Kemper County, Miss., that will include carbon capture and re-use for enhanced oil recovery. Other carbon capture and storage projects are under way or completed at other Southern Company facilities.
The test at Plant Yates will help confirm MHI's emission-control design and provide other findings important to the much larger-scale work next year at the Plant Barry test, which represents one of the industry's largest demonstrations of a start-to-finish power plant carbon capture and storage system.
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The research accomplishment was achieved this month at subsidiary Georgia Power's Plant Yates near Newnan, Ga.
The pilot-scale project at Plant Yates, which uses a capture system developed by Mitsubishi Heavy Industries (MHI), will provide additional process improvements before the technology is demonstrated next year at a much larger 25-megawatt scale at Plant Barry, which is owned and operated by Southern Company subsidiary Alabama Power near Mobile, Ala.
During the pilot at Plant Yates, a small amount of carbon dioxide (CO2) was captured, using a solvent that absorbs CO2, and then returned to the plant's flue gas. At Plant Barry, the carbon dioxide will be compressed and transported via pipeline to deep underground storage formations.
"Capturing CO2 from an operating power plant is an important step forward in our efforts to develop effective and cost-efficient technologies to reduce carbon dioxide emissions while ensuring a continued reliable and affordable supply of electricity for our customers," said Chris Hobson, Southern Company chief environmental officer. "Along with our other carbon capture and storage research initiatives, our success here will help us move closer to the ultimate goal of commercial deployment."
Southern Company is a participant in several major research initiatives to advance the development of carbon capture and storage technology, a key component in the nation's effort to reduce greenhouse gas emissions.
In addition to the projects at Yates and Barry, Southern Company operates the National Carbon Capture Center for the U.S. Department of Energy near Birmingham, Ala., and its subsidiary Mississippi Power is building an advanced commercial-scale coal gasification power plant in Kemper County, Miss., that will include carbon capture and re-use for enhanced oil recovery. Other carbon capture and storage projects are under way or completed at other Southern Company facilities.
The test at Plant Yates will help confirm MHI's emission-control design and provide other findings important to the much larger-scale work next year at the Plant Barry test, which represents one of the industry's largest demonstrations of a start-to-finish power plant carbon capture and storage system.
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Tuesday, August 3, 2010
Nationwide Low-Carbon Fuel Standard Would Increase Global Greenhouse Gas Emissions, Study Finds
/PRNewswire/ -- The implementation of a nationwide low-carbon fuel standard (LCFS) in the United States would increase global greenhouse gas emissions by up to 19 million metric tons each year - contradicting the claim of LCFS advocates that the standard would reduce such emissions - according to a study issued today.
The study assumes that because an LCFS would prevent American refineries from importing petroleum obtained from oil sands in neighboring Western Canada, the United States would instead have to import more oil in tankers from the Middle East and elsewhere. At the same time, the Canadian oil would be shipped in tankers across the Pacific to China and other Asian locations.
The study calls this long-distance movement of oil thousands of miles around the world in tankers a "shuffle" that would result in higher carbon dioxide emissions than simply extracting the Canadian petroleum from the oil sands for U.S. consumption, due to emissions created by shipping the oil such great distances.
Barr Engineering Company of Minneapolis conducted the study for members of NPRA, the National Petrochemical & Refiners Association.
"In conducting this technical study, we looked at the most accurate data publicly available, and the conclusion was clear," said Joel Trinkle, senior air quality consultant at Barr and one of the authors of the study. "Crude shuffling under a nationwide LCFS would substantially raise overall greenhouse gas emissions."
The study found that:
-- "A LCFS implemented in the U.S. results in a notable increase in
greenhouse gas emissions due to the displacement of Canadian crude
imports to the U.S. and re-routing of crude imports and exports to
accommodate this displacement. ... Nearby Canadian crude sources
would be diverted to regions not affected by LCFS and replaced with
supplies from distant parts of the world." (Page 2)
-- "While it is likely that LCFS would change the mix of crude imports to
the United States, LCFS implemented in the United States is not
expected to change overall trends in energy use and demand for crude
resources throughout the rest of the world. A shift in U.S.
crude-supply preferences will simply cause redirection of crude
supplies elsewhere." (Page 4-5)
-- "This analysis of the change in crude-transport-related emissions
accompanying implementation of a LCFS indicates that the net effect
will be a doubling of GHG [greenhouse gas] emissions associated with
changes in crude-transport patterns. It indicates an increase in
global GHG emissions by 7.1 to 19.0 million metric tons per year,
depending on the extent of resulting Canadian crude displacement."
(Page 3)
Canada is currently the largest supplier of petroleum imported into the United States, but other nations are looking to the Canadian oil sands as a potential energy source. China alone has already invested more than $6 billion in Canadian oil sands projects as it continues to rapidly increase its presence in overseas energy production.
"By denying the American people access to oil from our friendly neighbor Canada, a low-carbon fuel standard would raise fuel costs and wipe out millions of American jobs," said NPRA President Charles T. Drevna. "Now this latest study shows that a nationwide LCFS won't reduce overall global greenhouse gas emissions - it will actually raise them. These findings simply reinforce NPRA's long-held belief that a federal low-carbon fuel standard is a policy of all pain and no gain."
Additional concerns regarding American access to Canadian oil sands resources have surfaced following a recent U.S. State Department decision regarding a proposed pipeline to transport Canadian crude to refineries in the Gulf Coast region. The decision will allow federal agencies an additional 90 days to comment on TransCanada's proposed Keystone XL project, pending the State Department's release of a final environmental impact statement. The proposed pipeline expansion would more than double the amount of Canadian crude imported to the United States.
Several regional and state LCFS initiatives are currently underway, including a statewide LCFS program in California established as part of the state's AB 32 climate law, and proponents of a federal LCFS continue to seek its enactment.
A federal LCFS provision was included in the 2008 Lieberman-Warner climate change bill that was defeated in the Senate. The 2009 Waxman-Markey climate change bill also contained an LCFS provision, although it was removed before the bill was passed by the House.
Two other recent studies cast additional doubt on the efficacy of low-carbon fuel standards:
-- A June 2010 report by Charles River Associates found that a nationwide
LCFS implemented in 2015 would result by 2025 in: the loss of between
2.3 million and 4.5 million American jobs; an increase of up to 170
percent in the price of gasoline and diesel fuel; and a 2 to 3 percent
decrease in the U.S. Gross Domestic Product (totaling between $410
billion and $750 billion).
-- A report by the Canadian Energy Research Institute issued in October
2009 examined the impacts of developing Canadian oil sands on the U.S.
economy. It found that such development - which would be threatened by
the implementation of a nationwide LCFS in the United States - would
result in an estimated 343,000 new U.S. jobs between 2011 and 2015,
and that U.S. output of goods and services would increase by an
average of $62 billion per year from 2009 through 2025.
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The study assumes that because an LCFS would prevent American refineries from importing petroleum obtained from oil sands in neighboring Western Canada, the United States would instead have to import more oil in tankers from the Middle East and elsewhere. At the same time, the Canadian oil would be shipped in tankers across the Pacific to China and other Asian locations.
The study calls this long-distance movement of oil thousands of miles around the world in tankers a "shuffle" that would result in higher carbon dioxide emissions than simply extracting the Canadian petroleum from the oil sands for U.S. consumption, due to emissions created by shipping the oil such great distances.
Barr Engineering Company of Minneapolis conducted the study for members of NPRA, the National Petrochemical & Refiners Association.
"In conducting this technical study, we looked at the most accurate data publicly available, and the conclusion was clear," said Joel Trinkle, senior air quality consultant at Barr and one of the authors of the study. "Crude shuffling under a nationwide LCFS would substantially raise overall greenhouse gas emissions."
The study found that:
-- "A LCFS implemented in the U.S. results in a notable increase in
greenhouse gas emissions due to the displacement of Canadian crude
imports to the U.S. and re-routing of crude imports and exports to
accommodate this displacement. ... Nearby Canadian crude sources
would be diverted to regions not affected by LCFS and replaced with
supplies from distant parts of the world." (Page 2)
-- "While it is likely that LCFS would change the mix of crude imports to
the United States, LCFS implemented in the United States is not
expected to change overall trends in energy use and demand for crude
resources throughout the rest of the world. A shift in U.S.
crude-supply preferences will simply cause redirection of crude
supplies elsewhere." (Page 4-5)
-- "This analysis of the change in crude-transport-related emissions
accompanying implementation of a LCFS indicates that the net effect
will be a doubling of GHG [greenhouse gas] emissions associated with
changes in crude-transport patterns. It indicates an increase in
global GHG emissions by 7.1 to 19.0 million metric tons per year,
depending on the extent of resulting Canadian crude displacement."
(Page 3)
Canada is currently the largest supplier of petroleum imported into the United States, but other nations are looking to the Canadian oil sands as a potential energy source. China alone has already invested more than $6 billion in Canadian oil sands projects as it continues to rapidly increase its presence in overseas energy production.
"By denying the American people access to oil from our friendly neighbor Canada, a low-carbon fuel standard would raise fuel costs and wipe out millions of American jobs," said NPRA President Charles T. Drevna. "Now this latest study shows that a nationwide LCFS won't reduce overall global greenhouse gas emissions - it will actually raise them. These findings simply reinforce NPRA's long-held belief that a federal low-carbon fuel standard is a policy of all pain and no gain."
Additional concerns regarding American access to Canadian oil sands resources have surfaced following a recent U.S. State Department decision regarding a proposed pipeline to transport Canadian crude to refineries in the Gulf Coast region. The decision will allow federal agencies an additional 90 days to comment on TransCanada's proposed Keystone XL project, pending the State Department's release of a final environmental impact statement. The proposed pipeline expansion would more than double the amount of Canadian crude imported to the United States.
Several regional and state LCFS initiatives are currently underway, including a statewide LCFS program in California established as part of the state's AB 32 climate law, and proponents of a federal LCFS continue to seek its enactment.
A federal LCFS provision was included in the 2008 Lieberman-Warner climate change bill that was defeated in the Senate. The 2009 Waxman-Markey climate change bill also contained an LCFS provision, although it was removed before the bill was passed by the House.
Two other recent studies cast additional doubt on the efficacy of low-carbon fuel standards:
-- A June 2010 report by Charles River Associates found that a nationwide
LCFS implemented in 2015 would result by 2025 in: the loss of between
2.3 million and 4.5 million American jobs; an increase of up to 170
percent in the price of gasoline and diesel fuel; and a 2 to 3 percent
decrease in the U.S. Gross Domestic Product (totaling between $410
billion and $750 billion).
-- A report by the Canadian Energy Research Institute issued in October
2009 examined the impacts of developing Canadian oil sands on the U.S.
economy. It found that such development - which would be threatened by
the implementation of a nationwide LCFS in the United States - would
result in an estimated 343,000 new U.S. jobs between 2011 and 2015,
and that U.S. output of goods and services would increase by an
average of $62 billion per year from 2009 through 2025.
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Tuesday, May 25, 2010
Waste Management Debuts New Landfill-Gas-to-Energy Facility at Superior Landfill in Savannah, Ga.
PRNewswire -- Waste Management today debuted a landfill-gas-to-energy facility at its Superior Landfill and Recycling Center, which uses methane gas to power up to 3,400 homes in the surrounding area. More than 100 state and local officials, business and community leaders gathered for an opening event and tours showcasing the new facility.
The facility is among the largest of its kind in Georgia and the Southeast, according to U.S. Environmental Protection Agency (EPA) data. It represents a new source of green energy entering the power grid, lessening our dependence on fossil fuels. Methane gas -- created from the natural decomposition of waste -- is taken from the landfill through a series of wells placed around the site. From there, gas is used to power eight large engines to generate electricity, creating approximately 6.4 megawatts of power.
"The opening of this facility represents a new source of clean, renewable energy for our community," said Robby White, district manager for Waste Management in Savannah. "It is an environmentally responsible way to harness the energy from the waste we all generate."
Georgia Power and Waste Management Renewable Energy LLC entered into a 10-year deal for electricity, which was approved by the Georgia Public Service Commission in April. Georgia Power selected Waste Management from a number of independent renewable generators that submitted bids through the company's green request for proposals issued in April 2009. The energy from Superior is helping grow Georgia Power's Green Energy program.
"Landfill gas is a clean energy resource that has been endorsed by the U.S. EPA as an environmentally wise alternative that reduces our reliance on fossil fuels," said Paul Pabor, vice president of Renewable Energy for Waste Management. "Over the years, Waste Management has worked closely with businesses, industries and public utilities to develop many beneficial-use projects. We currently have more than 115 projects across North America, including three other sites in Georgia."
Waste Management tailors its services to meet the needs of each customer group and to ensure consistent, superior service at the local level. Waste Management, based in Houston, Texas, is the leading provider of comprehensive waste management services in North America. Its subsidiaries provide collection, transfer, recycling and resource recovery, and disposal services. It is also a leading developer, operator and owner of landfill gas-to-energy and waste-to-energy facilities in the United States. With nearly 800 employees in Georgia, the company serves residential, commercial, industrial and municipal customers throughout North America.
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The facility is among the largest of its kind in Georgia and the Southeast, according to U.S. Environmental Protection Agency (EPA) data. It represents a new source of green energy entering the power grid, lessening our dependence on fossil fuels. Methane gas -- created from the natural decomposition of waste -- is taken from the landfill through a series of wells placed around the site. From there, gas is used to power eight large engines to generate electricity, creating approximately 6.4 megawatts of power.
"The opening of this facility represents a new source of clean, renewable energy for our community," said Robby White, district manager for Waste Management in Savannah. "It is an environmentally responsible way to harness the energy from the waste we all generate."
Georgia Power and Waste Management Renewable Energy LLC entered into a 10-year deal for electricity, which was approved by the Georgia Public Service Commission in April. Georgia Power selected Waste Management from a number of independent renewable generators that submitted bids through the company's green request for proposals issued in April 2009. The energy from Superior is helping grow Georgia Power's Green Energy program.
"Landfill gas is a clean energy resource that has been endorsed by the U.S. EPA as an environmentally wise alternative that reduces our reliance on fossil fuels," said Paul Pabor, vice president of Renewable Energy for Waste Management. "Over the years, Waste Management has worked closely with businesses, industries and public utilities to develop many beneficial-use projects. We currently have more than 115 projects across North America, including three other sites in Georgia."
Waste Management tailors its services to meet the needs of each customer group and to ensure consistent, superior service at the local level. Waste Management, based in Houston, Texas, is the leading provider of comprehensive waste management services in North America. Its subsidiaries provide collection, transfer, recycling and resource recovery, and disposal services. It is also a leading developer, operator and owner of landfill gas-to-energy and waste-to-energy facilities in the United States. With nearly 800 employees in Georgia, the company serves residential, commercial, industrial and municipal customers throughout North America.
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Friday, May 21, 2010
Chevron Energy Solutions and Marine Corps Logistics Base Albany Announce First Navy Landfill Gas Project
/PRNewswire/ -- Chevron Energy Solutions, a unit of Chevron Corporation (NYSE:CVX) , and the Marine Corps Logistics Base (MCLB) Albany today announced the start of construction for the Department of Navy's first landfill gas cogeneration project.
The project will produce 1.9 megawatts of renewable electric power and steam by burning landfill gas collected from a nearby landfill. Chevron Energy Solutions will also complete industrial lighting retrofits in 82 buildings and expand the existing energy management control system. When combined with the cogeneration project, these measures will reduce the base's purchase of utility power and reduce MCLB's carbon emissions by 19,300 tons annually, equivalent to removing 16,000 cars from the road.
"This project is important to the Department of the Navy, the Marine Corps and Dougherty County. And with the help of Chevron Energy Solutions we will surpass our federal renewal energy goals, and fulfill our aspiration of becoming the 'greenest' Marine Corps installation in the nation," said Col. Terry V. Williams, commanding officer, MCLB Albany. "In addition to providing renewable power and energy security and reliability to MCLB, the project provides a valuable long-term source of revenue for Dougherty County. It took the hard work of many different partners to make this project a reality."
Chevron Energy Solutions developed and designed the project and will maintain the landfill gas-to-energy facility, pipeline and landfill gas processing equipment. The new facility will house a dual-fuel engine generator, a stack heat recovery steam generator and two dual-fuel boilers. The primary equipment can operate on landfill gas or natural gas, which provides energy security benefits. MCLB's use of renewable power will increase to 19 percent, which exceeds the EPAct of 2005 and Energy Independence and Security Act of 2007 mandate of 7.5 percent renewable power use by 2013.
Chevron Energy Solutions and MCLB will share in the operation of the generator and steam-producing equipment. Through an Energy Savings Performance Contract (ESPC), Chevron Energy Solutions arranged the financing for the project, which is repaid through the energy costs avoided. The company also guarantees system performance for 22 years.
"MCLB Albany is harnessing the power of an important renewable energy source through a partnership with the local community and we are proud of this effort," said Jim Davis, president of Chevron Energy Solutions. "The project is funded entirely by energy savings and demonstrates how military bases and local governments can work together with private industry to meet federal mandates without increasing taxpayer costs."
Dougherty County will extract and sell the landfill gas to MCLB from the Fleming/Gaissert Road Landfill, which receives approximately 100,000 tons of municipal solid waste each year. The biological decomposition of the waste generates landfill gas that is approximately 50 percent methane gas by volume.
A groundbreaking ceremony was held today and military, government and business officials attended. The project is expected to be completed by April 2011.
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The project will produce 1.9 megawatts of renewable electric power and steam by burning landfill gas collected from a nearby landfill. Chevron Energy Solutions will also complete industrial lighting retrofits in 82 buildings and expand the existing energy management control system. When combined with the cogeneration project, these measures will reduce the base's purchase of utility power and reduce MCLB's carbon emissions by 19,300 tons annually, equivalent to removing 16,000 cars from the road.
"This project is important to the Department of the Navy, the Marine Corps and Dougherty County. And with the help of Chevron Energy Solutions we will surpass our federal renewal energy goals, and fulfill our aspiration of becoming the 'greenest' Marine Corps installation in the nation," said Col. Terry V. Williams, commanding officer, MCLB Albany. "In addition to providing renewable power and energy security and reliability to MCLB, the project provides a valuable long-term source of revenue for Dougherty County. It took the hard work of many different partners to make this project a reality."
Chevron Energy Solutions developed and designed the project and will maintain the landfill gas-to-energy facility, pipeline and landfill gas processing equipment. The new facility will house a dual-fuel engine generator, a stack heat recovery steam generator and two dual-fuel boilers. The primary equipment can operate on landfill gas or natural gas, which provides energy security benefits. MCLB's use of renewable power will increase to 19 percent, which exceeds the EPAct of 2005 and Energy Independence and Security Act of 2007 mandate of 7.5 percent renewable power use by 2013.
Chevron Energy Solutions and MCLB will share in the operation of the generator and steam-producing equipment. Through an Energy Savings Performance Contract (ESPC), Chevron Energy Solutions arranged the financing for the project, which is repaid through the energy costs avoided. The company also guarantees system performance for 22 years.
"MCLB Albany is harnessing the power of an important renewable energy source through a partnership with the local community and we are proud of this effort," said Jim Davis, president of Chevron Energy Solutions. "The project is funded entirely by energy savings and demonstrates how military bases and local governments can work together with private industry to meet federal mandates without increasing taxpayer costs."
Dougherty County will extract and sell the landfill gas to MCLB from the Fleming/Gaissert Road Landfill, which receives approximately 100,000 tons of municipal solid waste each year. The biological decomposition of the waste generates landfill gas that is approximately 50 percent methane gas by volume.
A groundbreaking ceremony was held today and military, government and business officials attended. The project is expected to be completed by April 2011.
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Wednesday, March 10, 2010
Oglethorpe Power To Build Gas-Fired Generating Plant
/PRNewswire/ -- Oglethorpe Power Corporation will construct a new 605-megawatt, natural-gas-powered "combined-cycle" generating facility in Georgia to help meet the growing energy needs of its members, the company announced today. The corporation recently received final approval from its member EMCs to proceed with the project.
The facility, which represents a capital investment of about $750 million (including interest during construction), will use natural gas to produce electricity and will gain additional efficiency by capturing waste heat from the combustion process and using it to generate more power. The final location for the project has not yet been determined. However, land already owned by Oglethorpe in Monroe County, as well as several other unspecified sites, will be considered.
Oglethorpe Power Chief Operating Officer Mike Price said combined cycle facilities offer many benefits, including very high efficiency, low emissions and good track records for reliability. "We expect this facility to be an outstanding addition to our power generating portfolio, providing clean, reliable electricity for our member owners throughout the state," Price said.
Over the coming months, Oglethorpe Power will be evaluating several potential sites for the plant, then will make a decision on a preferred location. Construction on the facility would begin in 2013, and the plant would become operational in 2015. About 22 full-time employees would operate the facility. In addition, up to 250 workers would be needed during the approximately 30-month construction period.
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The facility, which represents a capital investment of about $750 million (including interest during construction), will use natural gas to produce electricity and will gain additional efficiency by capturing waste heat from the combustion process and using it to generate more power. The final location for the project has not yet been determined. However, land already owned by Oglethorpe in Monroe County, as well as several other unspecified sites, will be considered.
Oglethorpe Power Chief Operating Officer Mike Price said combined cycle facilities offer many benefits, including very high efficiency, low emissions and good track records for reliability. "We expect this facility to be an outstanding addition to our power generating portfolio, providing clean, reliable electricity for our member owners throughout the state," Price said.
Over the coming months, Oglethorpe Power will be evaluating several potential sites for the plant, then will make a decision on a preferred location. Construction on the facility would begin in 2013, and the plant would become operational in 2015. About 22 full-time employees would operate the facility. In addition, up to 250 workers would be needed during the approximately 30-month construction period.
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Friday, January 29, 2010
Pelosi Statement on President's Announcement of Greenhouse Gas Emissions Reduction Target
/PRNewswire/ -- Speaker Nancy Pelosi issued the following statement today on President Obama's announcement of a greenhouse gas emissions reduction target for the federal government:
"The effort to build a future founded on sustainability, clean energy, and conservation begins in homes and offices nationwide. The federal government is no exception.
"Our 'Green the Capitol' initiative is a symbol of Congress' commitment to the future. We've reduced our reliance on fossil fuels with wind power and conservation, started printing the Congressional Record on 100 percent recycled paper, replaced traditional light bulbs with energy-efficient alternatives, and increased recycling across all Members' offices. So far, we have already reduced our carbon footprint by 74 percent. These steps save money for our nation's taxpayers, create good-paying jobs, and cut pollution caused by global warming.
"President Obama's announcement marks a critical step forward in our effort to reduce the carbon footprint of the federal government -- the largest consumer of energy in the U.S. economy. This measure will spur investment in clean energy jobs, place innovation at the center of our economic agenda, and decrease the emissions that harm our environment.
"With the President's renewed call to complete work on a clean energy bill this year, we look forward to putting people to work building up the industries of tomorrow, reducing our dangerous dependence on foreign oil, and preserving our natural resources for generations to come."
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"The effort to build a future founded on sustainability, clean energy, and conservation begins in homes and offices nationwide. The federal government is no exception.
"Our 'Green the Capitol' initiative is a symbol of Congress' commitment to the future. We've reduced our reliance on fossil fuels with wind power and conservation, started printing the Congressional Record on 100 percent recycled paper, replaced traditional light bulbs with energy-efficient alternatives, and increased recycling across all Members' offices. So far, we have already reduced our carbon footprint by 74 percent. These steps save money for our nation's taxpayers, create good-paying jobs, and cut pollution caused by global warming.
"President Obama's announcement marks a critical step forward in our effort to reduce the carbon footprint of the federal government -- the largest consumer of energy in the U.S. economy. This measure will spur investment in clean energy jobs, place innovation at the center of our economic agenda, and decrease the emissions that harm our environment.
"With the President's renewed call to complete work on a clean energy bill this year, we look forward to putting people to work building up the industries of tomorrow, reducing our dangerous dependence on foreign oil, and preserving our natural resources for generations to come."
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Saturday, December 12, 2009
NGO Says Natural Gas Provides New Option for Immediate U.S. Carbon Cuts
/PRNewswire/ -- The American Clean Skies Foundation (ACSF), together with the UN Foundation and the Worldwatch Institute, today hosted a major side event in Copenhagen focusing on the ways natural gas -- and, in particular, the discovery of vast reserves of unconventional, or shale gas -- can accelerate the transition to a global low-carbon economy. Natural gas can generate electricity with 50-70 percent less CO(2) than coal per BTU. As is the case in the U.S., many other countries have also recently discovered very large new unconventional reserves of natural gas, primarily in deeply buried shale rock formations.
At the side event, ACSF released a comprehensive new working paper entitled "North America's New Natural Gas Resources and their Potential Impact on Energy and Climate Security." The paper shows why natural gas offers an immediate opportunity for climate action and describes the necessary U.S. legislative policies for pursuing this option. It is authored jointly by ACSF's CEO, Gregory C. Staple, a respected climate policy expert, and Dr. Joel L. Swerdlow, author of the noted National Geographic Society Book titled Nature's Medicine. Copies can be obtained from the Foundation at http://www.cleanskies.org/new-energy/. Event details can be found at www.cleanskies.org/pdf/acsf-agenda-121209.pdf
The Chairman and CEO of Chesapeake Energy Corp., Aubrey K. McClendon, who also serves as Chairman of ACSF, and Mr. Staple offered the following statements:
"We are in the midst of a natural gas renaissance in the United States -- a renaissance that gives the U.S. an unprecedented means to demonstrate global economic and environmental leadership because gas is a much lower carbon fuel than coal or oil. The U.S. boom in shale gas production also provides a historic opportunity to unite the business and environmental communities, since it may create hundreds of thousands of new jobs while producing large environmental benefits.
There is no longer any debate about natural gas supply in America: we have an abundance of natural gas. Big shale plays have become a key part of America's effort to gain a much greater degree of energy security, and we hope that in the next decade shale gas will also help Europe and Asia do likewise. What we need now is the political will to make sure that natural gas-based fuel switching is a leading part of our country's CO(2) reduction strategy. The more successful we are at producing shale gas in North America, the more likely it is that the U.S. and the world will have a new roadmap for energy and climate security."
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At the side event, ACSF released a comprehensive new working paper entitled "North America's New Natural Gas Resources and their Potential Impact on Energy and Climate Security." The paper shows why natural gas offers an immediate opportunity for climate action and describes the necessary U.S. legislative policies for pursuing this option. It is authored jointly by ACSF's CEO, Gregory C. Staple, a respected climate policy expert, and Dr. Joel L. Swerdlow, author of the noted National Geographic Society Book titled Nature's Medicine. Copies can be obtained from the Foundation at http://www.cleanskies.org/new-energy/. Event details can be found at www.cleanskies.org/pdf/acsf-agenda-121209.pdf
The Chairman and CEO of Chesapeake Energy Corp., Aubrey K. McClendon, who also serves as Chairman of ACSF, and Mr. Staple offered the following statements:
"We are in the midst of a natural gas renaissance in the United States -- a renaissance that gives the U.S. an unprecedented means to demonstrate global economic and environmental leadership because gas is a much lower carbon fuel than coal or oil. The U.S. boom in shale gas production also provides a historic opportunity to unite the business and environmental communities, since it may create hundreds of thousands of new jobs while producing large environmental benefits.
There is no longer any debate about natural gas supply in America: we have an abundance of natural gas. Big shale plays have become a key part of America's effort to gain a much greater degree of energy security, and we hope that in the next decade shale gas will also help Europe and Asia do likewise. What we need now is the political will to make sure that natural gas-based fuel switching is a leading part of our country's CO(2) reduction strategy. The more successful we are at producing shale gas in North America, the more likely it is that the U.S. and the world will have a new roadmap for energy and climate security."
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Wednesday, December 9, 2009
EPA Reports Exhaust Harms the Planet. HH2 Hydrogen Water Cell Reduces Greenhouse Gases, Exhaust Emissions Helps Reduce Global Warming.
/PRNewswire/ -- HH2 Hydrogen is the company ready to help the Planet. Patent Pending system creates Hydrogen and Oxygen gas vapors extracted separately from water & input both of the gases directly into Air Cleaner intake. HH2 fits all existing fossil fuel vehicles.
The HH2 system works with gasoline, Diesel and CNG. No on board storage required, no stopping to fill up Hydrogen from a station. Unit licensing will be available to Auto Makers, OEM's and manufacturers' world wide.
The unique HH2(TM) system extracts separated Hydrogen and Oxygen gas vapors from distilled water into small sized devices installed in a vehicle. The unit uses a little of the vehicles excess energy to produce just the right amount of Hydrogen and Oxygen gases required to blend with existing fuel to cause complete combustion of fuel inside the engine combustion chambers.
HH2 HYDROGEN incinerates most fuel toxins, poisons and particulate matter due to catalytic action (Octane 130), resulting in a clean warm moist air exhaust discharge. HH2 is not HHO/Browns gas.
Vehicles that require premium fuels now can use regular fuel when using HH2 Hydrogen systems.
CARB Executive Order D-643 for vehicles using Gasoline and Diesel fuels. CARB is accepted world wide as it is the toughest emissions agency in the world. Big Diesel testing is underway.
The system uses 12 Volt battery power and is very efficient, total burning of fuel results in increased fuel economy, cleaner exhaust and smoother running due to complete burning inside the engine. Please visit the company website at: www.HH2.US for more detailed information. HH2 Hydrogen Fuel Cell Devices have no moving parts and last for years. IRS tax credits of $1000 & $2000 may be available to USA taxpayers, using forms 8911; 3500 and 3800 of section 535 of the IRS code.
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The HH2 system works with gasoline, Diesel and CNG. No on board storage required, no stopping to fill up Hydrogen from a station. Unit licensing will be available to Auto Makers, OEM's and manufacturers' world wide.
The unique HH2(TM) system extracts separated Hydrogen and Oxygen gas vapors from distilled water into small sized devices installed in a vehicle. The unit uses a little of the vehicles excess energy to produce just the right amount of Hydrogen and Oxygen gases required to blend with existing fuel to cause complete combustion of fuel inside the engine combustion chambers.
HH2 HYDROGEN incinerates most fuel toxins, poisons and particulate matter due to catalytic action (Octane 130), resulting in a clean warm moist air exhaust discharge. HH2 is not HHO/Browns gas.
Vehicles that require premium fuels now can use regular fuel when using HH2 Hydrogen systems.
CARB Executive Order D-643 for vehicles using Gasoline and Diesel fuels. CARB is accepted world wide as it is the toughest emissions agency in the world. Big Diesel testing is underway.
The system uses 12 Volt battery power and is very efficient, total burning of fuel results in increased fuel economy, cleaner exhaust and smoother running due to complete burning inside the engine. Please visit the company website at: www.HH2.US for more detailed information. HH2 Hydrogen Fuel Cell Devices have no moving parts and last for years. IRS tax credits of $1000 & $2000 may be available to USA taxpayers, using forms 8911; 3500 and 3800 of section 535 of the IRS code.
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Monday, November 30, 2009
Georgia Consumers Compare Costs and Choices to Cut Heating Bills via Allconnect.com
(BUSINESS WIRE)--With temperatures falling and gas bills rising, Georgia consumers are ensuring they’re staying warm at the lowest price possible by comparing options at Allconnect.com.
Deregulation of the gas industry has expanded choices and introduced competition, both of which benefit consumers. The challenge is to keep up with the options and the offers. Allconnect.com is a free online resource to review and compare the costs and choices for natural gas, as well as other essential home services including high speed Internet, phone, cable TV, satellite TV, home security systems, and electricity.
By going to Allconnect.com and entering a home address, Georgia consumers instantly see the options, prices, and promotions for all the home service providers in their area, including natural gas. Promotions and pricing options, such as fixed rates versus variable rates, are presented; and plans can be evaluated easily by using a side-by-side comparison tool. Allconnect’s service is free and comes with a lowest-available price guarantee. Consumers can also call 1-800-ALLCONNECT to reach a Home Service Consultant who can explain specific options.
“With the deregulation of natural gas in Georgia, consumers realize they have a choice when it comes to providers. Now they also have a convenient resource for evaluating the choices,” said Mark Miller, Allconnect CEO. “Allconnect.com makes it simple and less time-consuming with a free, one-stop resource for comparing options, as well as the different rate plans and special offers.”
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Deregulation of the gas industry has expanded choices and introduced competition, both of which benefit consumers. The challenge is to keep up with the options and the offers. Allconnect.com is a free online resource to review and compare the costs and choices for natural gas, as well as other essential home services including high speed Internet, phone, cable TV, satellite TV, home security systems, and electricity.
By going to Allconnect.com and entering a home address, Georgia consumers instantly see the options, prices, and promotions for all the home service providers in their area, including natural gas. Promotions and pricing options, such as fixed rates versus variable rates, are presented; and plans can be evaluated easily by using a side-by-side comparison tool. Allconnect’s service is free and comes with a lowest-available price guarantee. Consumers can also call 1-800-ALLCONNECT to reach a Home Service Consultant who can explain specific options.
“With the deregulation of natural gas in Georgia, consumers realize they have a choice when it comes to providers. Now they also have a convenient resource for evaluating the choices,” said Mark Miller, Allconnect CEO. “Allconnect.com makes it simple and less time-consuming with a free, one-stop resource for comparing options, as well as the different rate plans and special offers.”
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Monday, November 16, 2009
Reducing Greenhoue Gases May Not be Enough to Slow Climate Change
Georgia Tech City and Regional Planning Professor Brian Stone publishes a paper in the December edition of Environmental Science and Technology that suggests policymakers need to address the influence of global deforestation and urbanization on climate change, in addition to greenhouse gas emissions.
According to Stone’s paper, as the international community meets in Copenhagen in December to develop a new framework for responding to climate change, policymakers need to give serious consideration to broadening the range of management strategies beyond greenhouse gas reductions alone.
“Across the U.S. as a whole, approximately 50 percent of the warming that has occurred since 1950 is due to land use changes (usually in the form of clearing forest for crops or cities) rather than to the emission of greenhouse gases,” said Stone. “Most large U.S. cities, including Atlanta, are warming at more than twice the rate of the planet as a whole – a rate that is mostly attributable to land use change. As a result, emissions reduction programs – like the cap and trade program under consideration by the U.S. Congress – may not sufficiently slow climate change in large cities where most people live and where land use change is the dominant driver of warming.”
According to Stone’s research, slowing the rate of forest loss around the world, and regenerating forests where lost, could significantly slow the pace of global warming.
“Treaty negotiators should formally recognize land use change as a key driver of warming,” said Stone. “The role of land use in global warming is the most important climate-related story that has not been widely covered in the media.”
Stone recommends slowing what he terms the “green loss effect” through the planting of millions of trees in urbanized areas and through the protection and regeneration of global forests outside of urbanized regions. Forested areas provide the combined benefits of directly cooling the atmosphere and of absorbing greenhouse gases, leading to additional cooling. Green architecture in cities, including green roofs and more highly reflective construction materials, would further contribute to a slowing of warming rates. Stone envisions local and state governments taking the lead in addressing the land use drivers of climate change, while the federal government takes the lead in implementing carbon reduction initiatives, like cap and trade programs.
“As we look to address the climate change issue from a land use perspective, there is a huge opportunity for local and state governments,” said Stone. “Presently, local government capacity is largely unharnessed in climate management structures under consideration by the U.S. Congress. Yet local governments possess extensive powers to manage the land use activities in both the urban and rural areas.”
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According to Stone’s paper, as the international community meets in Copenhagen in December to develop a new framework for responding to climate change, policymakers need to give serious consideration to broadening the range of management strategies beyond greenhouse gas reductions alone.
“Across the U.S. as a whole, approximately 50 percent of the warming that has occurred since 1950 is due to land use changes (usually in the form of clearing forest for crops or cities) rather than to the emission of greenhouse gases,” said Stone. “Most large U.S. cities, including Atlanta, are warming at more than twice the rate of the planet as a whole – a rate that is mostly attributable to land use change. As a result, emissions reduction programs – like the cap and trade program under consideration by the U.S. Congress – may not sufficiently slow climate change in large cities where most people live and where land use change is the dominant driver of warming.”
According to Stone’s research, slowing the rate of forest loss around the world, and regenerating forests where lost, could significantly slow the pace of global warming.
“Treaty negotiators should formally recognize land use change as a key driver of warming,” said Stone. “The role of land use in global warming is the most important climate-related story that has not been widely covered in the media.”
Stone recommends slowing what he terms the “green loss effect” through the planting of millions of trees in urbanized areas and through the protection and regeneration of global forests outside of urbanized regions. Forested areas provide the combined benefits of directly cooling the atmosphere and of absorbing greenhouse gases, leading to additional cooling. Green architecture in cities, including green roofs and more highly reflective construction materials, would further contribute to a slowing of warming rates. Stone envisions local and state governments taking the lead in addressing the land use drivers of climate change, while the federal government takes the lead in implementing carbon reduction initiatives, like cap and trade programs.
“As we look to address the climate change issue from a land use perspective, there is a huge opportunity for local and state governments,” said Stone. “Presently, local government capacity is largely unharnessed in climate management structures under consideration by the U.S. Congress. Yet local governments possess extensive powers to manage the land use activities in both the urban and rural areas.”
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Thursday, October 29, 2009
Climate Change Legislation Will Increase Diesel Prices, Hurt Consumers
/PRNewswire/ -- The American Trucking Associations (ATA) First Vice Chair Barbara Windsor told the Senate Environment and Public Works Committee today that the current cap-and-trade proposal will increase the price and volatility of diesel fuel for the trucking industry without significantly reducing carbon emissions.
"ATA strongly supports efforts to reduce greenhouse gas emissions and make this country more energy independent," said Windsor, who is President and CEO of Hahn Transportation in New Market, Md. "However, an economy-wide cap and trade system is not the answer." Proponents of an economy-wide cap-and-trade system say increasing the price of fuel will reduce consumption, Windsor said, but that does not hold true in the trucking industry.
"In our industry, a higher fuel price does not translate into fewer miles traveled because the nation depends on trucks to deliver nearly 100 percent of the food, clothes, and medicines that we use in our daily lives," said Windsor. "Instead, this increase in diesel prices will raise logistics costs within the economy and hurt the American consumer."
Cap-and-trade requires oil refineries to purchase emission allowances that cover their direct refining operations and the amount of carbon produced by downstream combustion of the produced fuels. "The costs associated with obtaining these allowances will be passed on the fuel consumers in the form of higher prices," said Windsor. "A major petroleum supplier to the trucking industry has advised that diesel fuel costs could rise by up to 88 cents."
"Should Congress move forward with a cap-and-trade carbon control system, oil refinery carbon caps should apply only to the refinery's direct carbon emissions and not to the downstream combustion of the products they produce such as gasoline, diesel, and jet fuel," said Windsor.
Cap-and-trade also will increase price volatility as carbon prices will fluctuate. Volatile fuel prices make it very difficult for trucking companies to accurately predict expenses and pass them on to customers.
ATA is concerned with the support of various investment banks for cap-and-trade. These firms would profit from volatility in the energy futures markets and a carbon derivatives market. Congress must reform commodity trading before creating new derivative carbon markets.
Windsor's testimony suggested alternative methods of reducing carbon emissions from the trucking industry. These alternatives are set forth in ATA's environmental sustainability plan, which would reduce fuel consumption by 86 billion gallons and reduce the carbon footprint of all vehicles by nearly a billion tons over the next 10 years. The sustainability plan includes: a national 65 mph speed limit and governing new truck speeds to 65 mph or below; decreasing idling; reducing highway congestion through highway infrastructure improvements; increasing fuel efficiency through EPA's SmartWay Program; promoting the use of more productive truck combinations; and supporting national fuel economy standards for medium- and heavy-duty trucks.
"Our plan can achieve real results with far less cost and disruption to our industry sector than under a cap-and-trade scenario," said Windsor.
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"ATA strongly supports efforts to reduce greenhouse gas emissions and make this country more energy independent," said Windsor, who is President and CEO of Hahn Transportation in New Market, Md. "However, an economy-wide cap and trade system is not the answer." Proponents of an economy-wide cap-and-trade system say increasing the price of fuel will reduce consumption, Windsor said, but that does not hold true in the trucking industry.
"In our industry, a higher fuel price does not translate into fewer miles traveled because the nation depends on trucks to deliver nearly 100 percent of the food, clothes, and medicines that we use in our daily lives," said Windsor. "Instead, this increase in diesel prices will raise logistics costs within the economy and hurt the American consumer."
Cap-and-trade requires oil refineries to purchase emission allowances that cover their direct refining operations and the amount of carbon produced by downstream combustion of the produced fuels. "The costs associated with obtaining these allowances will be passed on the fuel consumers in the form of higher prices," said Windsor. "A major petroleum supplier to the trucking industry has advised that diesel fuel costs could rise by up to 88 cents."
"Should Congress move forward with a cap-and-trade carbon control system, oil refinery carbon caps should apply only to the refinery's direct carbon emissions and not to the downstream combustion of the products they produce such as gasoline, diesel, and jet fuel," said Windsor.
Cap-and-trade also will increase price volatility as carbon prices will fluctuate. Volatile fuel prices make it very difficult for trucking companies to accurately predict expenses and pass them on to customers.
ATA is concerned with the support of various investment banks for cap-and-trade. These firms would profit from volatility in the energy futures markets and a carbon derivatives market. Congress must reform commodity trading before creating new derivative carbon markets.
Windsor's testimony suggested alternative methods of reducing carbon emissions from the trucking industry. These alternatives are set forth in ATA's environmental sustainability plan, which would reduce fuel consumption by 86 billion gallons and reduce the carbon footprint of all vehicles by nearly a billion tons over the next 10 years. The sustainability plan includes: a national 65 mph speed limit and governing new truck speeds to 65 mph or below; decreasing idling; reducing highway congestion through highway infrastructure improvements; increasing fuel efficiency through EPA's SmartWay Program; promoting the use of more productive truck combinations; and supporting national fuel economy standards for medium- and heavy-duty trucks.
"Our plan can achieve real results with far less cost and disruption to our industry sector than under a cap-and-trade scenario," said Windsor.
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Wednesday, October 28, 2009
GE Announces Latest Advancements to Leading Gas Turbine
(BUSINESS WIRE)--Using next generation gas turbine technology to increase output and efficiency, GE Energy today introduced its upgraded Frame 7FA gas turbine to meet growing performance requirements for power plant operators. The upgraded turbine is designed to help power plant operators reduce their total cost of ownership and environmental impact by allowing them to use less fuel to generate power.
The continuing evolution of GE’s gas turbine technology supports a growing industry trend toward the use of natural gas. A recent report by the Colorado School of Mines indicated that following recent discoveries, the United States now has 1,800 trillion cubic feet of natural gas, the equivalent of 320 billion barrels of oil—more than Saudi Arabia’s 264 billion barrels. That available supply, coupled with the current low cost and the fact that natural gas emits less carbon than other fossil fuels, has spurred many power generators to consider switching from other fuels to gas.
A typical power plant operating two new 7FA gas turbines with a single steam turbine in combined cycle configuration would achieve a fuel cost savings of more than $2.1 million per year at a natural gas price of $6 per MMBtu when compared to a similar plant with an earlier version of the 7FA for equivalent net plant output. This updated plant would also avoid the emission of more than 19,000 metric tons of CO2 per year compared to the earlier version, an improvement equivalent to the CO2 emissions of approximately 3,800 cars on U.S. roads.
“Investing in the needs of tomorrow with R&D and technology is at the foundation of GE and helps us to maintain a competitive advantage in the power generation arena,” said Steve Bolze, president of GE Energy’s Power & Water business. “Today’s announcement demonstrates our ongoing commitment to GE’s leadership in advanced gas turbine technology that helps deliver power more efficiently and flexibly to our customers without compromising their high standards for operational excellence.”
“Since its introduction, our F technology has consistently set industry standards for reliability and efficiency,” said Rick Stanley, vice president of engineering for GE Energy. “The 7FA upgrade underscores our commitment to continue refining the technology to meet the evolving needs of today’s customers.”
“GE is focused on delivering products and services that help our customers save significant operating costs while simultaneously slashing emissions and fuel consumption. We have amassed technological advances from across our expansive portfolio of power generating and aviation turbines and delivered them in this upgraded 7FA turbine,” said John Reinker, general manager of gas turbine and combined cycle products for GE Energy. “Of the 1,000 plus GE F-technology gas turbines shipped worldwide, more than 70% are 7FA units—and the advances now available for the 7FA will ensure that it continues to be the industry's workhorse advanced technology turbine.”
Many companies have already evaluated the new gas turbine technology. Some of the first new 7FA turbines are planned for the proposed Oakley Generating Station in Oakley, Calif. The plant, which is projected to generate 586 megawatts of power, is being developed by Radback Energy, Inc., and is expected to be transferred to Pacific Gas and Electric Company (PG&E) after it enters commercial operation.
The new turbine is a part of GE’s ecomagination portfolio, due to the increase in net plant efficiency and higher output delivered by this machine compared to all earlier 7FA models, which should result in less fuel consumption and lower emissions on a megawatt per hour basis than delivered by previous 7FA models.
Key regions for the upgraded, 60-hertz 7FA will include North America, Latin America, Saudi Arabia, Japan, Taiwan and South Korea. The upgraded 7FA will begin shipping in early 2012 and will be manufactured at GE Energy’s gas turbine facility in Greenville, S.C.
GE ecomagination certification
The ecomagination Product Review (EPR) process provides a third-party verification of claims, quantifying operating and environmental performance benefits that accrue to GE’s customers by using ecomagination products relative to baselines such as competitors' best products, the installed base of products and regulatory standards. These ecomagination claims can be found in GE's printed materials and advertisements and on the Web at www.ge.com/ecomagination. Ecomagination products are re-certified regularly to help ensure that claims remain accurate.
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The continuing evolution of GE’s gas turbine technology supports a growing industry trend toward the use of natural gas. A recent report by the Colorado School of Mines indicated that following recent discoveries, the United States now has 1,800 trillion cubic feet of natural gas, the equivalent of 320 billion barrels of oil—more than Saudi Arabia’s 264 billion barrels. That available supply, coupled with the current low cost and the fact that natural gas emits less carbon than other fossil fuels, has spurred many power generators to consider switching from other fuels to gas.
A typical power plant operating two new 7FA gas turbines with a single steam turbine in combined cycle configuration would achieve a fuel cost savings of more than $2.1 million per year at a natural gas price of $6 per MMBtu when compared to a similar plant with an earlier version of the 7FA for equivalent net plant output. This updated plant would also avoid the emission of more than 19,000 metric tons of CO2 per year compared to the earlier version, an improvement equivalent to the CO2 emissions of approximately 3,800 cars on U.S. roads.
“Investing in the needs of tomorrow with R&D and technology is at the foundation of GE and helps us to maintain a competitive advantage in the power generation arena,” said Steve Bolze, president of GE Energy’s Power & Water business. “Today’s announcement demonstrates our ongoing commitment to GE’s leadership in advanced gas turbine technology that helps deliver power more efficiently and flexibly to our customers without compromising their high standards for operational excellence.”
“Since its introduction, our F technology has consistently set industry standards for reliability and efficiency,” said Rick Stanley, vice president of engineering for GE Energy. “The 7FA upgrade underscores our commitment to continue refining the technology to meet the evolving needs of today’s customers.”
“GE is focused on delivering products and services that help our customers save significant operating costs while simultaneously slashing emissions and fuel consumption. We have amassed technological advances from across our expansive portfolio of power generating and aviation turbines and delivered them in this upgraded 7FA turbine,” said John Reinker, general manager of gas turbine and combined cycle products for GE Energy. “Of the 1,000 plus GE F-technology gas turbines shipped worldwide, more than 70% are 7FA units—and the advances now available for the 7FA will ensure that it continues to be the industry's workhorse advanced technology turbine.”
Many companies have already evaluated the new gas turbine technology. Some of the first new 7FA turbines are planned for the proposed Oakley Generating Station in Oakley, Calif. The plant, which is projected to generate 586 megawatts of power, is being developed by Radback Energy, Inc., and is expected to be transferred to Pacific Gas and Electric Company (PG&E) after it enters commercial operation.
The new turbine is a part of GE’s ecomagination portfolio, due to the increase in net plant efficiency and higher output delivered by this machine compared to all earlier 7FA models, which should result in less fuel consumption and lower emissions on a megawatt per hour basis than delivered by previous 7FA models.
Key regions for the upgraded, 60-hertz 7FA will include North America, Latin America, Saudi Arabia, Japan, Taiwan and South Korea. The upgraded 7FA will begin shipping in early 2012 and will be manufactured at GE Energy’s gas turbine facility in Greenville, S.C.
GE ecomagination certification
The ecomagination Product Review (EPR) process provides a third-party verification of claims, quantifying operating and environmental performance benefits that accrue to GE’s customers by using ecomagination products relative to baselines such as competitors' best products, the installed base of products and regulatory standards. These ecomagination claims can be found in GE's printed materials and advertisements and on the Web at www.ge.com/ecomagination. Ecomagination products are re-certified regularly to help ensure that claims remain accurate.
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Thursday, October 22, 2009
Landrieu, Chambliss Announce Creation of Senate Natural Gas Caucus
United States Senators Mary L. Landrieu, D-La., and Saxby Chambliss, R-Ga., today announced the creation of the bipartisan Senate Natural Gas Caucus.
“When we produce natural gas in America, we produce jobs in America,” said Sen. Landrieu, Co-Chair of the Senate Natural Gas caucus. “A reliable and affordable supply of U.S. energy has profound impacts on every sector of our economy and is the backbone of the U.S. employment base. Natural gas is a clean burning, low-carbon fuel that is predominantly produced here at home. This caucus will serve to investigate and debate the economic and national security implications of the newfound abundance of natural gas in the United States.”
“America has an abundant supply of clean, natural gas and has the means to access these resources in an environmentally friendly way,” said Chambliss. “Increasing domestic production is a critical component of a comprehensive energy policy that will reduce America’s dependence on foreign sources for our energy needs. I’m pleased to join Senator Landrieu in creating this caucus. It is my hope that we can start a serious conversation in the Senate about our nation’s energy policy.”
Natural gas is produced in 33 states and relied upon as an energy source in many others. Over 20 percent of the electricity in the United States is generated by natural gas. Natural gas is also an important feedstock in chemical and fertilizer production, and is used to eliminate soot in clean diesel fuel. Natural gas is used as a raw material that goes into lightweight cars, wind power blades, solar panels and energy-efficient materials.
In 2008, nearly 90 percent of the natural gas consumed in the United States came from domestic U.S. supplies. Thanks to technological advances, the U.S. now has triple the amount of natural gas than was estimated in 1966, and 40 percent more than previously believed just a couple of years ago.
Approximately 1.3 million people are employed directly by the companies that drill, ship and supply natural gas to American consumers, with another 2.7 million Americans employed in supporting positions indirectly created by the development of America's domestic energy supplies. The combined economic impact of natural gas development, exploration, production and usage to the U.S. economy in 2008 was $385.5 billion.
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“When we produce natural gas in America, we produce jobs in America,” said Sen. Landrieu, Co-Chair of the Senate Natural Gas caucus. “A reliable and affordable supply of U.S. energy has profound impacts on every sector of our economy and is the backbone of the U.S. employment base. Natural gas is a clean burning, low-carbon fuel that is predominantly produced here at home. This caucus will serve to investigate and debate the economic and national security implications of the newfound abundance of natural gas in the United States.”
“America has an abundant supply of clean, natural gas and has the means to access these resources in an environmentally friendly way,” said Chambliss. “Increasing domestic production is a critical component of a comprehensive energy policy that will reduce America’s dependence on foreign sources for our energy needs. I’m pleased to join Senator Landrieu in creating this caucus. It is my hope that we can start a serious conversation in the Senate about our nation’s energy policy.”
Natural gas is produced in 33 states and relied upon as an energy source in many others. Over 20 percent of the electricity in the United States is generated by natural gas. Natural gas is also an important feedstock in chemical and fertilizer production, and is used to eliminate soot in clean diesel fuel. Natural gas is used as a raw material that goes into lightweight cars, wind power blades, solar panels and energy-efficient materials.
In 2008, nearly 90 percent of the natural gas consumed in the United States came from domestic U.S. supplies. Thanks to technological advances, the U.S. now has triple the amount of natural gas than was estimated in 1966, and 40 percent more than previously believed just a couple of years ago.
Approximately 1.3 million people are employed directly by the companies that drill, ship and supply natural gas to American consumers, with another 2.7 million Americans employed in supporting positions indirectly created by the development of America's domestic energy supplies. The combined economic impact of natural gas development, exploration, production and usage to the U.S. economy in 2008 was $385.5 billion.
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Wednesday, October 7, 2009
Georgia Public Service Commission Allows Atlanta Gas Light to Make New STRIDES for Better Service
/PRNewswire/ -- Atlanta Gas Light received approval from the Georgia Public Service Commission (PSC) today to begin a multi-year system upgrade to improve the utility's ability to provide service on peak demand days.
This program, called the Georgia Strategic Infrastructure Development and Enhancement Program (STRIDE), will merge into the company's existing Pipeline Replacement Program (PRP) and incorporate a new Integrated System Reinforcement Program (i-SRP). STRIDE's initial three-year construction phase, which was approved today, is estimated at $175.7 million.
"STRIDE's approach to regulatory oversight and rate recovery began with the Public Service Commission's creation of the PRP mechanism in 1998," said Hank Linginfelter, executive vice president, Utility Operations, AGL Resources. "The Georgia Public Service commission continues to show leadership in the area of limiting rate impacts on our customers while encouraging necessary investment."
Atlanta's metropolitan area has experienced rapid growth in the past two decades, and much of that growth has shifted to regions farther removed from Atlanta Gas Light's existing interstate supply points and high-pressure transmission pipeline system. STRIDE system improvements will target the counties of Cherokee, Clayton, Cobb, Coweta, Gwinnett, Fulton, Forsyth, Henry, Paulding and Rockdale.
"Atlanta Gas Light has an obligation to maintain its system to provide adequate operating pressures to serve our customers on the coldest days of the year," said Suzanne Sitherwood, president, Atlanta Gas Light. "We proposed STRIDE as a new regulatory approach to perform the necessary improvements and keep our monthly customer charges as low as possible."
The PSC also authorized Atlanta Gas Light to implement recovery for the STRIDE program. The initial charge, expected to begin in late October, will increase rates for all firm customers by an additional $0.39 per month. Beginning October 2010, the rates will be $0.78 per month, and beginning in October 2011, the rates will be $1.18 per month.
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This program, called the Georgia Strategic Infrastructure Development and Enhancement Program (STRIDE), will merge into the company's existing Pipeline Replacement Program (PRP) and incorporate a new Integrated System Reinforcement Program (i-SRP). STRIDE's initial three-year construction phase, which was approved today, is estimated at $175.7 million.
"STRIDE's approach to regulatory oversight and rate recovery began with the Public Service Commission's creation of the PRP mechanism in 1998," said Hank Linginfelter, executive vice president, Utility Operations, AGL Resources. "The Georgia Public Service commission continues to show leadership in the area of limiting rate impacts on our customers while encouraging necessary investment."
Atlanta's metropolitan area has experienced rapid growth in the past two decades, and much of that growth has shifted to regions farther removed from Atlanta Gas Light's existing interstate supply points and high-pressure transmission pipeline system. STRIDE system improvements will target the counties of Cherokee, Clayton, Cobb, Coweta, Gwinnett, Fulton, Forsyth, Henry, Paulding and Rockdale.
"Atlanta Gas Light has an obligation to maintain its system to provide adequate operating pressures to serve our customers on the coldest days of the year," said Suzanne Sitherwood, president, Atlanta Gas Light. "We proposed STRIDE as a new regulatory approach to perform the necessary improvements and keep our monthly customer charges as low as possible."
The PSC also authorized Atlanta Gas Light to implement recovery for the STRIDE program. The initial charge, expected to begin in late October, will increase rates for all firm customers by an additional $0.39 per month. Beginning October 2010, the rates will be $0.78 per month, and beginning in October 2011, the rates will be $1.18 per month.
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Monday, September 21, 2009
Isakson, Chambliss Urge Administration to Open New Areas for Natural Gas, Oil Development
Expansion Would Create Jobs, Lessen Dependence on Foreign Oil
U.S. Senators Johnny Isakson, R-Ga., and Saxby Chambliss, R-Ga., today joined with 33 of their Senate colleagues in a bipartisan letter to the Administration expressing their strong support for a proposal by the Minerals Management Service to open up new offshore areas for natural gas and oil leasing and development.
“Environmentally responsible exploration of our offshore oil and natural gas resources is a critical part of a comprehensive policy that will enable the United States to become energy independent,” Isakson said. “I hope Secretary Salazar and President Obama will move quickly to utilize these resources, which are important to our national security and economic well-being.”
“It’s important that we utilize all of our domestic energy sources in an environmentally friendly way so that America can become energy independent,” said Chambliss. “Moving forward with the proposed program to lease areas in the Outer Continental Shelf for oil and gas exploration and development is a step in the right direction.”
The full text of the letter to Interior Secretary Ken Salazar is below:
Dear Mr. Secretary:
We are writing to convey our strong support for the Draft Proposed Outer Continental Shelf (OCS) Oil and Gas Leasing Program (DPP) proposed by the U.S. Minerals Management Service (MMS). By opening up new offshore areas for natural gas and oil leasing and development and also allowing for the development of renewable energy as proposed in the DPP, the Department of the Interior can provide the United States with an opportunity to responsibly produce our own energy. This development will bolster our nation’s economy, create new jobs and decrease our dependence on foreign sources of energy.
It is more important than ever that the federal government allow for development of domestic offshore energy supplies made available in the DPP. By offering new leasing opportunities, the DPP is appropriately expansive and provides the Department with maximum flexibility to properly utilize our nation’s domestic resources.
Now is the appropriate time to promote long-term policies that responsibly encourage job creation while growing the economy. Important offshore areas, like those in Alaska, offer tremendous natural gas and oil resources. By some estimates, the Chukchi Sea alone off Alaska’s coast contains as much natural gas and oil as the country has produced in the Gulf of Mexico since 1942.
Additionally, we urge MMS to move forward with the 2007-2012 Leasing Program while working to approve and finalize the new DPP. Implementing a sensible, forward-thinking energy policy will allow for responsible leasing and development of America’s energy resources and will help industries and businesses here at home that rely heavily on natural gas and crude oil. It will also further our national security and energy security interests and, of course, spur jobs and economic growth as we open new areas to leasing and development.
In conclusion, we are pleased to see that the MMS has included new leasing areas in the DPP and has acknowledged the need for the United States to begin responsibly developing the abundant energy resources located off our coasts. We believe that the DPP is an important step in creating a robust, diverse, national energy policy which will help secure our energy future.
We urge you to move forward on the DPP as you work to finalize a new five-year OCS plan. Thank you for your attention to this important matter. Please do not hesitate to contact us if we can be of assistance to you.
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U.S. Senators Johnny Isakson, R-Ga., and Saxby Chambliss, R-Ga., today joined with 33 of their Senate colleagues in a bipartisan letter to the Administration expressing their strong support for a proposal by the Minerals Management Service to open up new offshore areas for natural gas and oil leasing and development.
“Environmentally responsible exploration of our offshore oil and natural gas resources is a critical part of a comprehensive policy that will enable the United States to become energy independent,” Isakson said. “I hope Secretary Salazar and President Obama will move quickly to utilize these resources, which are important to our national security and economic well-being.”
“It’s important that we utilize all of our domestic energy sources in an environmentally friendly way so that America can become energy independent,” said Chambliss. “Moving forward with the proposed program to lease areas in the Outer Continental Shelf for oil and gas exploration and development is a step in the right direction.”
The full text of the letter to Interior Secretary Ken Salazar is below:
Dear Mr. Secretary:
We are writing to convey our strong support for the Draft Proposed Outer Continental Shelf (OCS) Oil and Gas Leasing Program (DPP) proposed by the U.S. Minerals Management Service (MMS). By opening up new offshore areas for natural gas and oil leasing and development and also allowing for the development of renewable energy as proposed in the DPP, the Department of the Interior can provide the United States with an opportunity to responsibly produce our own energy. This development will bolster our nation’s economy, create new jobs and decrease our dependence on foreign sources of energy.
It is more important than ever that the federal government allow for development of domestic offshore energy supplies made available in the DPP. By offering new leasing opportunities, the DPP is appropriately expansive and provides the Department with maximum flexibility to properly utilize our nation’s domestic resources.
Now is the appropriate time to promote long-term policies that responsibly encourage job creation while growing the economy. Important offshore areas, like those in Alaska, offer tremendous natural gas and oil resources. By some estimates, the Chukchi Sea alone off Alaska’s coast contains as much natural gas and oil as the country has produced in the Gulf of Mexico since 1942.
Additionally, we urge MMS to move forward with the 2007-2012 Leasing Program while working to approve and finalize the new DPP. Implementing a sensible, forward-thinking energy policy will allow for responsible leasing and development of America’s energy resources and will help industries and businesses here at home that rely heavily on natural gas and crude oil. It will also further our national security and energy security interests and, of course, spur jobs and economic growth as we open new areas to leasing and development.
In conclusion, we are pleased to see that the MMS has included new leasing areas in the DPP and has acknowledged the need for the United States to begin responsibly developing the abundant energy resources located off our coasts. We believe that the DPP is an important step in creating a robust, diverse, national energy policy which will help secure our energy future.
We urge you to move forward on the DPP as you work to finalize a new five-year OCS plan. Thank you for your attention to this important matter. Please do not hesitate to contact us if we can be of assistance to you.
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Thursday, July 23, 2009
Coweta-Fayette EMC Natural Gas Launches a New Website
Company takes its transparency and exceptional customer service online
Coweta-Fayette EMC (CFEMC) Natural Gas, known for its simple pricing structures and easy to understand bills, has launched a new website at www.cfemcnaturalgas.com that makes it easier for all Georgians on the Atlanta Gas Light distribution pipeline to get competitively priced natural gas service.
Customers can see how much they can save each year on the most commonly used natural gas powered appliances, which include the water heater, oven range, furnace, and gas grill compared to other natural gas marketers. Making this information readily available helps customers make informed decisions about their natural gas marketer selection.
“CFEMC Natural Gas has provided competitive, easy to understand pricing with exceptional customer service since natural gas was first deregulated in Georgia,” said Dan Hart, President and CEO of Coweta-Fayette EMC Natural Gas. “It was a natural decision to take that same approach to our new website, and the initial response has been fantastic. People really appreciate the opportunity to quickly and easily see the cost difference between natural gas marketers, regardless of where they live in Georgia.”
CFEMC Natural Gas consistently offers some of the most competitive prices among all natural gas marketers on the Atlanta Gas Light pipeline. Rates and sign-up information are prominently displayed on every page of the website in an intuitive, user-friendly design. Energy saving tips, safety information and the Kids Korner section for children also are easily found from anywhere on the site.
The company’s spirit of transparency and full disclosure is experienced through quick links to the Georgia Public Service Commission’s (PSC’s) list of current gas prices from certified natural gas marketers, the PSC’s Gas Marketers’ Scorecard, and the section of the Atlanta Gas Light website that details how monthly base charges are calculated.
Consumers statewide were given the ability to select the natural gas marketer of their choice when the State of Georgia deregulated natural gas service in 1998. As a result, any Georgia resident or business that receives natural gas from the Atlanta Gas Light (AGL) pipeline can select their natural gas marketer. CFEMC Natural Gas was founded to fill that need for Coweta-Fayette EMC customers as well as residents and businesses throughout the state that are not in the EMC’s service territory.
Coweta-Fayette EMC Natural Gas is a natural gas marketer registered with the Georgia Public Service Commission (PSC) that offers customers easy to understand bills, simple pricing structures, and local customer service. Coweta-Fayette EMC Natural Gas customers can choose monthly variable-rate pricing without a contract or fixed pricing that allows them to lock in their natural gas price for the winter heating season.
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Coweta-Fayette EMC (CFEMC) Natural Gas, known for its simple pricing structures and easy to understand bills, has launched a new website at www.cfemcnaturalgas.com that makes it easier for all Georgians on the Atlanta Gas Light distribution pipeline to get competitively priced natural gas service.
Customers can see how much they can save each year on the most commonly used natural gas powered appliances, which include the water heater, oven range, furnace, and gas grill compared to other natural gas marketers. Making this information readily available helps customers make informed decisions about their natural gas marketer selection.
“CFEMC Natural Gas has provided competitive, easy to understand pricing with exceptional customer service since natural gas was first deregulated in Georgia,” said Dan Hart, President and CEO of Coweta-Fayette EMC Natural Gas. “It was a natural decision to take that same approach to our new website, and the initial response has been fantastic. People really appreciate the opportunity to quickly and easily see the cost difference between natural gas marketers, regardless of where they live in Georgia.”
CFEMC Natural Gas consistently offers some of the most competitive prices among all natural gas marketers on the Atlanta Gas Light pipeline. Rates and sign-up information are prominently displayed on every page of the website in an intuitive, user-friendly design. Energy saving tips, safety information and the Kids Korner section for children also are easily found from anywhere on the site.
The company’s spirit of transparency and full disclosure is experienced through quick links to the Georgia Public Service Commission’s (PSC’s) list of current gas prices from certified natural gas marketers, the PSC’s Gas Marketers’ Scorecard, and the section of the Atlanta Gas Light website that details how monthly base charges are calculated.
Consumers statewide were given the ability to select the natural gas marketer of their choice when the State of Georgia deregulated natural gas service in 1998. As a result, any Georgia resident or business that receives natural gas from the Atlanta Gas Light (AGL) pipeline can select their natural gas marketer. CFEMC Natural Gas was founded to fill that need for Coweta-Fayette EMC customers as well as residents and businesses throughout the state that are not in the EMC’s service territory.
Coweta-Fayette EMC Natural Gas is a natural gas marketer registered with the Georgia Public Service Commission (PSC) that offers customers easy to understand bills, simple pricing structures, and local customer service. Coweta-Fayette EMC Natural Gas customers can choose monthly variable-rate pricing without a contract or fixed pricing that allows them to lock in their natural gas price for the winter heating season.
---
Community News You Can Use
Follow us on Twitter: @gafrontpage
www.FayetteFrontPage.com
www.GeorgiaFrontPage.com
www.PoliticalPotluck.com
www.ArtsAcrossGeorgia.com
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