PITTSBURGH, Jan. 26, 2012 /Coal Geology-PRNewswire/ — CONSOL Energy Inc. (NYSE: CNX), the leading diversified fuel producer in the Eastern United States, reported net income for the quarter ended December 31, 2011 of $196 million, or $0.85 per diluted share, compared to $104 million, or $0.46 per diluted share from the year-earlier quarter. Record net income for 2011 was $632 million, or $2.76 per diluted share, compared to $347 million, or$1.60 per diluted share for 2010.

The company set other annual records in 2011, including:

• Record gas production of 153.5 Bcf (net to CONSOL), an increase of 20% from the 127.9 Bcf produced in 2010. Gas production in 2011 would have been approximately 160 Bcf, or a 25% increase, had the company not sold assets to Noble Energy and Antero Resources during the year.
• Record overseas coal sales of 11.4 million tons, an increase of 68% from the 6.8 million tons sold overseas in 2010.
• Record sales revenue of $5.7 billion, an increase of 14% from the $5.0 billion in 2010.
• Record cash flow from operations of $1.5 billion, an increase of 36% from the $1.1 billion in 2010.
• Baltimore Terminal shipped a record 12.6 million tons in 2011, besting the 1995 shipments of 12.4 million tons.

“CONSOL Energy has a world class set of assets,” commented J. Brett Harvey, chairman and CEO. “In our Coal Division for 2011, we were able to combine reliable operations with astute marketing to generate record net income. Our record results were even more impressive when one realizes that, on the gas side, weakening gas prices throughout 2011 largely offset our record gas production. For CONSOL, 2011 was a year characterized by our ability to seize opportunities and, in some cases, to create opportunities.”

Strategically, CONSOL Energy was successful in participating in the growth of world coal markets and in selling more of its crossover coal into lucrative met coal markets. CONSOL’s coal is currently being sold on four continents.

In gas, the company formed one strategic partnership with Noble Energy, Inc. to jointly develop 628,000 acres in the Marcellus Shale, and a second partnership with Hess Corporation to explore for and develop oil, liquids, and gas on 200,000 acres of Utica Shale in Ohio. The two partnerships, along with the sale of an overriding royalty interest to Antero generated gross proceeds to CONSOL Energy of $841 million in 2011, and are expected to generate proceeds and carry of nearly $3.3 billion in the coming years.

The influx of cash from the gas transactions, along with the record cash flow from operations in 2011 of $1.5 billion, considerably strengthened the company’s financial position during a time of economic uncertainty. During 2011, the company extended and expanded its revolvers, paid off all of its short term debt, and ended the year with a cash balance of $376 million. With 2011 capital expenditures of $1.4 billion and dividends paid of $96 million, the company was slightly cash flow positive, even before considering the proceeds received from the gas transactions. In response to the improved financial condition, CONSOL Energy’s Board of Directors increased the regular quarterly dividend by 25%, with the annual dividend now set at $0.50 per share.

In safety, CONSOL Energy logged its best year, when measured by incident rates. The one fatality, however, indicates that we have work to do to get to Absolute Zero.

2012 Capital Spending Revision

CONSOL Energy has trimmed its 2012 spending outlook to $1.5 billion, down from an earlier projected $1.7 billion. The revisions from the January 10, 2012 announcement are occurring mostly because a combination of mild weather and high production, which has caused natural gas prices to drop to a 10-year low. Gas investment in the Marcellus Shale has been reduced by approximately $130 million, as 23 (gross) wells have been deferred. CONSOL Energy and its joint development partner, Noble Energy, now expect to drill 99 Marcellus Shale wells. The reduction is not expected to impact 2012 estimated production of approximately 160 Bcf. Less drilling in 2012, however, coupled with the postponement of some pad development spending for the 2013 drilling program is causing the company to reduce its 2013 production guidance to 190 – 210 Bcfe, which would be 10 Bcfe lower than the earlier projection. CONSOL’s 2015 goal of 350 Bcfe, however, remains unchanged because the drilling schedule in the out years has enough flexibility in it to accommodate a slightly reduced production goal in 2013.

In coal, CONSOL Energy has determined that some efficiency projects will be postponed, resulting in a reduction in coal capital spending of approximately $44 million.

The company will continue to monitor its level of investment with macro and industry-specific events during 2012.

2011 Fourth Quarter Discussion

Reported net income for the quarter was $196 million, or $0.85 per diluted share. This included (after-tax) net income of $33 million, or $0.15 per diluted share from the closing of the Hess transaction on October 21.

Total company sales revenue was nearly $1.4 billion. This was the highest ever achieved for CONSOL in a fourth quarter. As has been the case throughout 2011, most of the increase came from higher average realized prices across all three coal segments. The company’s low-vol, high-vol and thermal coal categories had realized prices of $191, $78, and $59 per short ton, FOB mine, respectively. Coal margins, across all of the company’s sales, were $17.95 per ton, an increase of $1.18 per ton from the year-earlier quarter.  Expanding coal margins drove an increase in EBITDA(1) and cash flow from operations. EBITDA in the quarter ended December 31, 2011 was $440 million. Cash flow from operations was $275 million while capital expenditures were $385 million for the December 2011 quarter.

For the third consecutive quarter, CONSOL’s coal division has generated more cash from its met business than from its thermal business. This demonstrates the company’s significant presence in the growing metallurgical markets.

While the gas division reported net income of $43.0 million for the fourth quarter, this includes a $33 million (after-tax) gain from the Hess transaction. Excluding the transaction, net income was higher than the year-earlier quarter because lower prices were more than offset by higher volumes. The company is encouraged that within the overall cost structure, the (fully-loaded) costs associated with its Marcellus Shale operations were $2.74 per Mcf, an improvement of $0.51 versus the $3.25 per Mcf reported in the 2011 third quarter.

(1) The term “EBITDA” is a non-GAAP financial measure, which is defined and reconciled to the GAAP net income below, under the caption “Non-GAAP Financial Measures.”

Sales and production include CONSOL Energy’s portion from equity affiliates. Operating costs include items such as labor, supplies, power, preparation costs, project expenses, subsidence costs, gas well plugging costs, charges for employee benefits (including Combined Fund premiums), royalties, and production and property taxes.  Non-operating charges include items such as charges for long-term liabilities, direct administration, selling and general administration. Sales times Average Margin Per Ton, before DD&A is meant to approximate the amount of cash generated for the low-vol, high-vol, and thermal coal categories. This cash generation will be offset by maintenance of production (MOP) capital expenditures. N/A means not applicable; there is no inventory in the High-Vol segment.

During 2011, the operating costs per ton were up less than 5% after adjusting for the effects of higher realizations, the placing in service of a new water treatment plant, and a production shift towards higher cost mines. The DD&A rate was up 20%, reflecting continued investment in safe and efficient mines, as well as a full year of depreciation from the water treatment plant. Provisions and G&A increased by 22%, reflecting the effect of a lower discount rate, various long-term liabilities assumption changes, and increased support staffing. The company added more staff to prepare for growth, which we will be scaling back in this weaker environment. Overall costs per ton in 2011 were $52.22, versus $46.55 in 2010, for an increase of $5.67, or 12%.

Coal production in the quarter consisted of 1.4 million tons of low-vol, 1.2 million tons of high-vol, and 12.7 million tons of thermal, for a total of 15.3 million tons.

During the fourth quarter, total coal inventory increased by 0.1 million tons to 1.8 million tons as of December 31, 2011.  Thermal coal inventory was unchanged at 1.6 million tons and Low-vol Buchanan inventory increased by 0.1 million tons, to 0.2 million tons.

Coal Marketing Update:

Low-Vol: CONSOL achieved a record revenue year at Buchanan in 2011.  During the fourth quarter, two cargoes of a new high ash product were sold to China, opening up potentially new markets.  Additionally, 302,000 tons were booked for 2012 and 654,000 tons were re-priced.  Pricing averaged over $180 per ton, FOB mine.  Buchanan is 70% sold for 2012.

High-Vol: Development continues on the Bailey high-vol product as it is now being used in coking blends on four continents.  The coal is being tested for additional use at locations around the world.  CONSOL expects 2012 high-vol sales volumes to grow beyond the 4.8 million tons shipped in 2011.

Thermal:

U.S. Thermal: CONSOL’s thermal coals are nearly sold out for 2012.  During the fourth quarter, 7.5 million tons of thermal for 2012 were re-priced at $64.22 per ton.  This represented an overall price improvement for these coals versus 2011.

European Thermal: 2.15 million tons of additional export thermal were committed in the fourth quarter including two multi-year deals, 352,000 tons of which will be delivered in 2012.  The balance will ship in future periods.  Pricing (FOB mine) was favorable compared to the domestic market.

For 2012, CONSOL Energy expects to export 9 – 11 million tons, across all sales categories.

Gas Division Results:

CONSOL Energy released detailed information on its gas operations in a release dated January 17, 2012.

The table below is a quarterly comparison of key metrics for the Gas Division:

Coalbed Methane (CBM): Total production was 23.8 Bcf, an increase of 1% from the 23.6 Bcf produced in the year-earlier quarter.

Marcellus Shale: Total production was 7.2 Bcf (net to CONSOL), an increase of 118% from the 3.3 Bcf produced in the year-earlier quarter. The increase is attributable to increased drilling and longer laterals. Production would have been 13.8 Bcf in the quarter, had the Noble Energy JV not been consummated.

Conventional: Total production was 8.2 Bcf, a decrease of 6% from the 8.7 Bcf produced in the year-earlier quarter.   The company has been shifting rigs and capital toward higher potential return Marcellus and Uticadrilling prospects.

CONSOL Energy 2012 Guidance

CONSOL Energy expects its net gas production to be approximately 160 Bcf (net to CONSOL) for 2012. First quarter gas production, net to CONSOL, is expected to be approximately 36 – 38 Bcf, as frac schedules and other seasonal factors are expected to limit wells turned online.

Total hedged gas production in the 2012 first quarter is 19.1 Bcf, at an average price of $5.25 per Mcf. The annual gas hedge position for three years is shown in the table below:

Liquidity

Total company liquidity as of December 31, 2011 was $2.7 billion, including cash of $375.6 million.

As of December 31, 2011, CONSOL Energy had $1,473.3 million in total liquidity, which is comprised of $39.0 million of cash, $200 million available under the accounts receivable securitization facility, and $1,234.3 million available to be borrowed under its $1.5 billion bank facility. CONSOL Energy also has outstanding letters of credit of $265.7 million.

As of December 31, 2011, CNX Gas Corporation had $1,266.5 million in total liquidity, which is comprised of$336.7 million of cash and $929.8 million available to be borrowed under its $1.0 billion bank facility.  CNX Gas’ credit facility has no borrowings thereunder, and outstanding letters of credit of $70.2 million.

CONSOL Energy Inc., the leading diversified fuel producer in the Eastern U.S., is a member of the Standard & Poor’s 500 Equity Index and the Fortune 500. It has 12 bituminous coal mining complexes in four states and reports proven and probable coal reserves of 4.4 billion tons. It is also a leading Eastern U.S. gas producer, with proved reserves of 3.7 trillion cubic feet, as of December 31, 2010.  Additional information about CONSOL Energy can be found at its web site: www.consolenergy.com . The company will host a conference call at 10:00 a.m. ET. The call can be accessed at the investor relations section of the company’s web site, at www.consolenergy.com . A set of slides accompanying the call will be posted to the web site approximately 30 minutes before the start of the call.

Non-GAAP Financial Measure

Definition: EBIT is defined as Earnings (including cumulative effect of adjustments to net income) before deducting net interest expense (interest expense less interest income) and income taxes.  EBITDA is defined as earnings before deducting net interest expense (interest expense less interest income), income taxes and depreciation, depletion and amortization.  Although EBIT and EBITDA are not measures of performance calculated in accordance with generally accepted accounting principles, management believes that it is useful to an investor in evaluating CONSOL Energy because it is widely used to evaluate a company’s operating performance before debt expense and its cash or as a substitute for measures of performance in accordance with generally accepted accounting principles.  In addition, because all companies do not calculate EBIT or EBITDA identically, the presentation here may not be comparable to similarly titled measures of other companies.

Reconciliation of  EBITDA to financial net income attributable to CONSOL Energy Shareholders is as follows:

Forward-Looking Statements

Various statements in this release, including those that express a belief, expectation or intention, may be considered forward-looking statements (as defined in Section 21E of the Exchange Act) that involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. The forward-looking statements may include projections and estimates concerning the timing and success of specific projects and our future production, revenues, income and capital spending. When we use the words “believe,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,” “estimate,” “plan,” “predict,” “project,” or their negatives, or other similar expressions, the statements which include those words are usually forward-looking statements. When we describe strategy that involves risks or uncertainties, we are making forward-looking statements. The forward-looking statements in this press release, if any, speak only as of the date of this press release; we disclaim any obligation to update these statements. We have based these forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks, contingencies and uncertainties relate to, among other matters, the following: deterioration in economic conditions in any of the industries in which our customers operate, or sustained uncertainty in financial markets cause conditions we cannot predict; an extended decline in prices we receive for our coal and gas affecting our operating results and cash flows; our customers extending existing contracts or entering into new long-term contracts for coal; our reliance on major customers; our inability to collect payments from customers if their creditworthiness declines; the disruption of rail, barge, gathering, processing and transportation facilities and other systems that deliver our coal and gas to market; a loss of our competitive position because of the competitive nature of the coal and gas industries, or a loss of our competitive position because of overcapacity in these industries impairing our profitability; coal users switching to other fuels in order to comply with various environmental standards related to coal combustion emissions; the impact of potential, as well as any adopted regulations relating to greenhouse gas emissions on the demand for coal and natural gas, as well as the impact of any adopted regulations on our coal mining operations due to the venting of coalbed methane which occurs during mining; foreign currency fluctuations could adversely affect the competitiveness of our coal abroad; the risks inherent in coal and gas operations being subject to unexpected disruptions, including geological conditions, equipment failure, timing of completion of significant construction or repair of equipment, fires, explosions, accidents and weather conditions which could impact financial results; our focus on new gas development projects and exploration for gas in areas where we have little or no proven gas reserves; decreases in the availability of, or increases in, the price of commodities and services used in our mining and gas operations, as well as our exposure under “take or pay” contracts we entered into with well service providers to obtain services of which if not used could impact our cost of production; obtaining and renewing governmental permits and approvals for our coal and gas operations; the effects of government regulation on the discharge into the water or air, and the disposal and clean-up of, hazardous substances and wastes generated during our coal and gas operations; the effects of stringent federal and state employee health and safety regulations, including the ability of regulators to shut down a mine or well; the potential for liabilities arising from environmental contamination or alleged environmental contamination in connection with our past or current coal and gas operations; the effects of mine closing, reclamation, gas well closing and certain other liabilities; uncertainties in estimating our economically recoverable coal and gas reserves; costs associated with perfecting title for coal or gas rights on some of our properties; the outcomes of various legal proceedings, which are more fully described in our reports filed under the Securities Exchange Act of 1934; the impacts of various asbestos litigation claims; increased exposure to employee related long-term liabilities; increased exposure to multi-employer pension plan liabilities; minimum funding requirements by the Pension Protection Act of 2006 (the Pension Act) coupled with the significant investment and plan asset losses suffered during the recent economic decline has exposed us to making additional required cash contributions to fund the pension benefit plans which we sponsor and the multi-employer pension benefit plans in which we participate; lump sum payments made to retiring salaried employees pursuant to our defined benefit pension plan exceeding total service and interest cost in a plan year; acquisitions and joint ventures that we recently have completed or entered into or may make in the future including the accuracy of our assessment of the acquired businesses and their risks, achieving any anticipated synergies, integrating the acquisitions and unanticipated changes that could affect assumptions we may have made and divestitures we anticipate may not occur or produce anticipated proceeds including joint venture partners paying anticipated carry obligations; the anti-takeover effects of our rights plan could prevent a change of control; increased exposure on our financial performance due to the degree we are leveraged; replacing our natural gas reserves, which if not replaced, will cause our gas reserves and gas production to decline; our ability to acquire water supplies needed for gas drilling, or our ability to dispose of water used or removed from strata in connection with our gas operations at a reasonable cost and within applicable environmental rules; our hedging activities may prevent us from benefiting from price increases and may expose us to other risks; and other factors discussed in the 2010 Form 10-K under “Risk Factors,” as updated by any subsequent Form 10-Qs, which are on file at the Securities and Exchange Commission.

SOURCE CONSOL Energy Inc.

CONTACT: Investor: Brandon Elliott, +1-724-485-4526; Dan Zajdel, +1-724-485-4169, Media: Lynn Seay, +1-724-485-4065

Web Site: http://www.consolenergy.com

WORCESTER, Mass., Jan. 26, 2012 /PRNewswire/ — ThermoEnergy Corp. (OTCBB: TMEN) expects that tough new rules on coal-fired power plant emissions which were finalized recently by the U.S. Environmental Protection Agency will spur demand for effective, efficient, clean combustion technology.
ThermoEnergy’s www.thermoenergy.com clean combustion technology, once commercialized, would allow power plants to burn coal with near-zero air emissions. The process efficiently captures carbon dioxide in clean form for sequestration or beneficial re-use. In addition, ThermoEnergy’s process simultaneously captures SOx, NOx, mercury, and particulates.

Cary Bullock, ThermoEnergy’s President and CEO, noted that the company’s patented technology for the electric utility industry holds the promise of eliminating harmful air emissions, while capturing nearly 100% of carbon dioxide.

The electric utility industry is expected to invest more than $10 billion by 2016 to install scrubber systems to reduce emissions of NOx, SOx, mercury, and particulates, in addition to carbon dioxide, Bullock noted.

“ThermoEnergy sees a tremendous opportunity ahead, thanks to our proprietary technology and the timing of the stringent new EPA rules,” Bullock said.

Bullock said that early targets for ThermoEnergy’s technology would be existing power plants where a boiler replacement could be done at a fraction of the cost of building a new plant using conventional technology.

Dr. Ahmed F. Ghoniem, Professor of Mechanical Engineering at the Massachusetts Institute of Technology and a member of ThermoEnergy’s scientific advisory board, noted that the type of technology used by ThermoEnergy is expected to provide an increase in thermal efficiency for power plants versus certain other technologies that are attempting to reach commercialization.

About ThermoEnergy

Founded in 1988, ThermoEnergy Corporation is a diversified technologies company engaged in the development and sales of wastewater recovery and power generation technologies in global markets. Additional information on the Company and its technologies can be found on its website at www.thermoenergy.com.

THIS PRESS RELEASE INCLUDES STATEMENTS THAT MAY CONSTITUTE “FORWARD LOOKING” STATEMENTS, USUALLY CONTAINING THE WORDS “ESTIMATE”, “PROJECT”, “EXPECT” OR SIMILAR EXPRESSIONS. FORWARD LOOKING STATEMENTS INHERENTLY INVOLVE RISKS AND UNCERTAINTIES THAT COULD CAUSE ACTUAL RESULTS TO DIFFER MATERIALLY FROM CURRENT EXPECTATIONS. BY MAKING THESE FORWARD LOOKING STATEMENTS, THE COMPANY UNDERTAKES NO OBLIGATION TO UPDATE THESE STATEMENTS FOR REVISIONS OR CHANGES.

SOURCE ThermoEnergy Corp.
CONTACT: CONTACT: ThermoEnergy Contact, Ted Klowan, +1-508-854-1628, tklowan@thermoenergy.com, or Investor Relations Contact, Chris Camarra, +1-212-398-3487, ccamarra@allianceadvisors.net

Web Site: http://www.thermoenergy.com

For more detailed descriptions of each endangered area, SELC’s protection efforts, photographs and video, visit www.southernenvironment.org/topten . Interviews available upon request.

Many of the areas on SELC’s Top 10 list are endangered by pressure to undercut environmental protections and to lower the hurdles for potentially destructive projects, whether it’s fracking in the North Carolina Piedmont, uranium mining in Virginia, or deepwater drilling in the Gulf.

“The South’s special places and natural riches are threatened by a wave of calculated attacks on the bedrock laws that protect our environment and health,” said Marie Hawthorne, SELC’s Director of Development. “Under the guise of promoting economic growth, anti-environmental forces are working in Congress, in state legislatures, and in government agencies to gut our most essential safeguards.

“The truth is, environmental protection had nothing to do with the financial crisis or today’s weak economy,” Hawthorne added. “Doing away with effective laws and enforcement will accomplish nothing except sacrifice the natural treasures like those on our Top 10 list and other resources that make the South such a great place live, work, and raise our families. We owe it to ourselves — and to future generations — to make sure this doesn’t happen.”

Top 10 Endangered Places in the Southeast for 2012
The following endangered areas were chosen from among hundreds of special places that the SELC is defending through its law and policy work in the six states of Virginia, Tennessee, North Carolina, South Carolina, Georgia and Alabama.

Alabama’s coast: Following the tragic BP spill, the government has returned to business as usual and is authorizing risky deepwater drilling projects under the same assumptions that failed in the Deepwater Horizon disaster. This approach is irresponsible, illegal, and poses an ongoing threat to Alabama’s beaches, marshes, wildlife, and coastal communities.

Dawson Forest, Georgia : A costly, unnecessary proposed reservoir would siphon 100 million gallons per day from the Etowah River to fuel metro Atlanta’s unchecked sprawl, threatening prime habitat for endangered aquatic life, water supplies of downstream communities, and a popular recreation area.

Catawba-Wateree Basin, North Carolina & South Carolina: The health of the Catawba-Wateree River, which provides drinking water for hundreds of thousands of residents of central North Carolina and South Carolina, faces an array of threats, including pollution from toxin-laden coal ash ponds, hydroelectric dams that will continue to disrupt stream flows and fish migration, water withdrawals that rob water from downstream farms and communities, and unnecessary reservoir projects that promote inefficient development and water use.

North Carolina Piedmont: The gas drilling industry and its allies in the North Carolina General Assembly are pushing hard to pass legislation that would expedite hydraulic fracturing (a.k.a. ‘fracking’) to extract natural gas, despite mounting evidence that the drilling technique, in the absence of appropriate regulatory controls, can lead to the contamination of groundwater and surface water. Potential fracking sites in North Carolina’s Piedmont are underneath or upstream from water supplies for 2.4 million people.

Savannah River, South Carolina & Georgia : The U.S. Army Corps of Engineers’ plan to deepen 38 miles of the Savannah River shipping channel would increase saltwater intrusion in the river and jeopardize freshwater marshlands in the Savannah National Wildlife Refuge, drinking water supplies for Savannah and other communities, and habitat for endangered aquatic species.

Chilhowee Mountain, Tennessee: The outdated plan for completing Corridor K between Chattanoogaand Asheville includes a proposal to cut a new four-lane highway through the Cherokee National Forest near the Ocoee Gorge, even though improvements to the existing two-lane highway on its current footprint would be less damaging, less costly, and no less effective.

Chesapeake Bay, Virginia: For decades the Bay has suffered from pollution from all sides — air, land, and water. Unfortunately, industry interests and their political allies are doing all they can to impede a comprehensive rescue plan.

Mountains of Tennessee & Virginia: Mountaintop removal and other destructive coal mining practices have already destroyed at least 500 mountains and damaged 1,700 miles of streams in Virginia,Tennessee and other central Southern Appalachian states, and pressure continues to mount.
Charlottesville, Virginia & Surrounding Countryside: Local and state decision-makers are attempting to revive a wasteful, destructive, and ineffective proposed bypass that would leave a permanent scar on one of the South’s most special communities.

Southside Virginia: An intense push to mine uranium in southern Virginia risks polluting drinking water supplies with radioactive and toxin-laden wastewater. Lifting the state’s ban on uranium mining could open up Virginia’s Piedmont countryside to more large-scale mining projects.

About the Southern Environmental Law Center (SELC)
SELC is the largest environmental organization focused exclusively on the South. For 25 years, the Southern Environmental Law Center has worked successfully in all three branches of government to create, implement, and enforce environmental law and policy. Their major programs cover clean energy, transportation and land use, southern forests, the coast and wetlands, and preservation of rural countryside and community character. SELC has 46 attorneys (out of a total staff of 90) and offices inCharlottesville (SELC’s headquarters) and Richmond, Virginia; Chapel Hill and Asheville, North Carolina;Charleston, South Carolina; Atlanta, Georgia; Birmingham, Alabama; and Washington, D.C.www.SouthernEnvironment.org.

ARLINGTON, Va. — The U.S. Department of Labor’s Mine Safety and Health Administration today launched the third phase of an outreach and enforcement program designed to strengthen efforts to prevent mining fatalities. “Rules to Live By III: Preventing Common Mining Deaths” will focus on 14 safety standards that were chosen because violations related to each have been cited as contributing to at least five mining accidents and at least five deaths during the 10-year period of Jan. 1, 2001, to Dec. 31, 2010.

“The goal of this phase of ‘Rules to Live By’ is to reduce numbers of deaths and injuries from the targeted standards by having mine operators identify and correct all hazardous conditions, direct MSHA enforcement toward confirming that violations related to these conditions are not present at mines, and ensure miners are better trained to recognize and avoid these particular hazards,” said Joseph A. Main, assistant secretary of labor for mine safety and health.

From 2001 through 2010, 609 miners lost their lives in workplace accidents. Violations associated with eight coal standards contributed to 75 deaths during this period, while violations associated with six metal and nonmetal standards contributed to 50 deaths.

The coal standards are as follows:

75.362(a)(1) on-shift examination
77.404(a) machinery and equipment; operation and maintenance
77.405(b) performing work from a raised position; safeguards
77.1000 highwalls, pits and spoil banks; plans
77.1605(b) loading and haulage equipment; installations
77.1606(a) loading and haulage equipment; inspection and maintenance
77.1607(b) loading and haulage equipment; operation
77.1713(a) daily inspection of surface coal mine; certified person; reports of inspection

The metal and nonmetal standards are as follows:

46.7(a) new task training
56.3130 wall, bank and slope stability
56.3200 correction of hazardous conditions
56.15020 life jackets and belts
56.14100(b) safety defects; examination, correction and records
57.14100(b) safety defects; examination, correction and records

Beginning April 1, MSHA will focus more attention on these 14 standards with enhanced enforcement efforts, increased scrutiny for related violations, and instructions to inspectors to more carefully evaluate gravity and negligence – consistent with the seriousness of the violation – when citing violations that cause or contribute to mining fatalities. MSHA inspectors will receive online training to promote consistency in enforcement activity across the agency.

As with the first two phases of “Rules to Live By,” online training will be available to the mining industry and the public on MSHA’s website, and MSHA will provide operators with program and resource information. The agency also will reach out to engage miners and their representatives during the course of MSHA inspections to disseminate appropriate compliance assistance materials – including engineering suggestions, safety target materials packages and other resources – so that they have the appropriate information to address and eliminate workplace hazards.

“In 2011, mining deaths fell to the second lowest annual total on record – a testament to the commitment of miners, mine operators, miners’ representatives, labor and industry organizations, state agencies and grantees, members of the mining community and MSHA,” said Main. “While the mining community achieved near-record low numbers of mining deaths in the United States and has seen a significant decline in fatal mining accidents during the past 10 years, too many miners still lose their lives in preventable accidents. The loss of even one miner causes devastation and pain to the victim’s family, friends and co-workers.

“Compliance with safety and health standards is the responsibility of mine operators, with the assistance of miners. Ultimately, all of us must focus on why these accidents happen and how to prevent them,” he added.

The first phase of “Rules to Live By” began in February 2010.

For additional information about “Rules to Live By,” visit http://www.msha.gov/focuson/rulestoliveby.asp.

Web Site: http://www.peabodyenergy.com

Company Poised to Produce an Anticipated $1.9 Billion in Cash Flow from Operations in 2012

CONTACT: Steve Baisden, Vice President, Investor Relations and Communications, +1-216-694-5280; Jessica Moran, Manager, Investor Relations, +1-216-694-6532; Patricia Persico, Sr. Manager, Global Communications, +1-216-694-5316

Web Site: http://www.cliffsnaturalresources.com

ST. LOUIS, Jan. 27, 2012 /Coal Geology-PRNewswire/ – On Thursday, February 2, 2012, Patriot Coal Corporation (NYSE: PCX) will announce results for the quarter and year ended December 31, 2011.  A conference call with management is scheduled for 10:00 a.m. Central Time on Thursday, February 2.

Participants may access the call using the following phone numbers:

U.S. & Canada (800) 398-9386

International (612) 332-0523

The call, replay and other investor data will also be available through the Company’s website atwww.patriotcoal.com.

About Patriot Coal

Patriot Coal Corporation is a leading producer and marketer of coal in the eastern United States, with 14 active mining complexes in Appalachia and the Illinois Basin.  The Company ships to domestic and international electricity generators, industrial users and metallurgical coal customers, and controls approximately 1.9 billion tons of proven and probable coal reserves.  The Company’s common stock trades on the New York Stock Exchange under the symbol PCX.

SOURCE Patriot Coal Corporation

CONTACT: Janine Orf, +1-314-275-3680, jorf@patriotcoal.com

Web Site: http://www.patriotcoal.com

At the same time Ukraine’s leader mentioned, that the country’s integration into the European energy space would strengthen energy security of the entire region. Remaining a reliable partner in transferring hydrocarbons, Ukraine was also interested in cooperation to create new energy pipeline corridors, said the President. At the forum Ukraine was mentioned to possess rich potential for developing alternative and unconventional energy sources.

It was essential to continue the technical revolutions in extracting shale gas as well as implementing clean coal technologies, for the old technologies had lost their economic and ecological sustainability, according to Ukraine’s Energy Minister Yuriy Boyko. Currently, Ukraine looks into implement the new environmentally conscious hydro-coal technology, which is claimed to enable utilities, refineries and industrial energy users to produce significantly cheaper and cleaner synthetic fuels from coal through enhance reactivity. Notably, in 2011 Ukraine produced 82 million tons of coal.

Speaking of energy sources diversification for Ukraine, the country is eyeing joint projects with Azerbaijan. After the recent round of negotiations, two protocols between the countries were ready to be signed, and the experts have already started their work on technical parameters of the documents. Moreover, Ukraine is currently negotiating a three-way partnership with Azerbaijan and Turkey. In his interview with journalists Ukrainian leader added that Ukraine would consider creating a gas transportation consortium and make such partnership profitable for all parties. The price of the project (reliable gas transportation to Europe and modernization of the pipelines) was estimated at USD 5-7 billions.

Ukraine is also dedicated to constructing of the LNG terminal with a general volume of 10 billion cubic meters on the Black Sea shore. The construction is planned to be completed by 2014. The project is supervised by the National Project LNG-terminal, a state owned company. On October 19-21, 2011, the Spanish company Socoin conducted a feasibility study of the marine LNG terminal in Ukraine.

Source: Worldwide News Ukraine

For more information, please contact Maryna Khorunzha +380443324784 news@wnu-ukraine.com, Project Manager at Worldwide News Ukraine

In the past year, employees brought to a successful conclusion a multi-year, nearly $1 billion initiative to install state-of-the-art environmental controls at the plant – an effort that was honored as the Best Coal-Fired Project of 2011 by Power Engineering magazine. The project is featured in this month’s issue of the publication.

Plant Miller also was recently honored with the Best Performing Plant award by the Electric Utility Cost Group (EUCG), a national organization dedicated to improving the cost and performance of electric generating plants. EUCG recognized Plant Miller as one of the top electric generating plants in the nation, and for the best performance and cost management by a large electric generating facility over a five-year period.

Plant Miller was also recognized this month by Mitsubishi Heavy Industries, Ltd. (MHI) as part of its Best Innovation 2011 awards. Miller was cited as the successful test site for a new emissions-reduction system that garnered MHI’s Special Award for Best New Technology.

“Again and again, Plant Miller and our employees demonstrate that they are among the best in the business,” said Ted McCullough, senior vice president and senior production officer for Alabama Power.

Perry Boren, plant manager at Miller, said employees take pride in delivering exceptional service for the benefit of Alabama Power customers. “Providing outstanding reliability at the lowest cost is our goal, along with meeting our commitments for protecting the environment and the safety of employees,” Boren said.

Emission reductions are among Plant Miller’s many achievements. Since 1996, the plant has cut its emissions of nitrogen oxides by 76 percent and sulfur dioxide by 95 percent, thanks to the successful installation and operation of new scrubbers and selective catalytic reduction technology on all four of the plant’s generating units.

The scrubber project is a prime example of superior service. The $900 million project was completed in early 2011 – within budget and months faster than the original schedule. Scrubber performance has also exceeded expectations.

The largest electric generating plant in the state, Plant Miller is located in Jefferson County, northwest ofBirmingham, and provides enough power to serve the needs of about 800,000 homes. The plant employs about 330 people, many of whom are involved in community volunteerism through the Alabama Power Service Organization (APSO). In 2011 alone, APSO members at Plant Miller contributed more than 3,600 volunteer hours and donated more than $65,000 in cash and in-kind contributions to community projects.

Alabama Power, a subsidiary of Atlanta-based Southern Company (NYSE: SO), provides affordable, reliable power to more than 1.4 million customers across the state. To learn more, visitwww.alabamapower.com.

SOURCE Alabama Power

WASHINGTON – The U.S. Environmental Protection Agency (EPA) today announced that it will provide $9.8 million in grants to 38 states, territories and tribes to help protect the health of swimmers at America’s beaches. The agency also launched an improved website for beach advisories and closings, which will allow the public to more quickly and easily access the most current water quality and pollution testing information for more than 6,000 U.S. beaches.

The website, called BEACON, has the capability to update as frequently as every two hours based on new data provided by states, territories and tribes. Users will have access to mapped location data for beaches and water monitoring stations, monitoring results for various pollutants such as bacteria and algae, and data on public notification of beach water quality advisories and closures. For the first time, users can also access reports that combine notifications and water quality monitoring data. The enhanced system also uses enhanced map navigation and report display tools.

The majority of beach advisories and closures in the United States are due to water test results indicating bacterial contamination, which can make people sick. Bacterial contamination comes from a variety of sources. Some examples are sewer overflows, untreated stormwater runoff, boating wastes, wildlife and pet waste, and malfunctioning septic systems.

During each swimming season, state and local health and environmental protection agencies monitor the quality of water at the nation’s beaches. When bacteria levels in the water are too high, these agencies notify the public by posting beach warnings or closing the beach.

The grants will help local authorities monitor beach water quality and notify the public of conditions that may be unsafe for swimming.

This is the 12th year that EPA is providing beach grant funds, bringing the total amount EPA has made available to nearly $111 million. As a result, the number of monitored beaches has more than tripled to

more than 3,600 in 2010. Grant applications must be received within 60 days of publication of EPA’s notice in the Federal Register. EPA expects to award the grants later this year.

View EPA’s enhanced beach advisory and closing information: http://watersgeo.epa.gov/BEACON2/<http://watersgeo.epa.gov/BEACON2/>

More information on the grants: http://water.epa.gov/grants_funding/beachgrants/index.cfm<http://water.epa.gov/grants_funding/beachgrants/index.cfm>