CONSOL Energy Reports Second Quarter Results

PITTSBURGH, July 29, 2014 /PRNewswire/ -- Consol Energy Inc. (NYSE: CNX) reported a net loss of $25 million for the quarter ended June 30, 2014, or ($0.11) per diluted share. This is compared to a net loss of $13 million, or ($0.05) per diluted share from the year-earlier quarter. Adjusted EBITDA¹ was $246 million for the 2014 second quarter, compared to $181 million in the year-earlier quarter. Cash flow from operations in the just-ended quarter was $221 million, as compared to $125 million in the year-earlier quarter.

The second quarter earnings results included the following pre-tax items related to recent transactions completed by the company:

• The company incurred $74.3 million in expense related to the early extinguishment of debt due to the purchase of all the 8.00% senior notes that were due 2017.
• The company incurred a $3.0 million non-cash charge associated with entering into a new senior secured credit facility. The charge was related to the acceleration of previously deferred financing fees.
• The company incurred a non-cash charge of $20.7 million in association with a pension settlement.
• The company recognized a gain of $30.0 million related to a coal contract customer buyout. CONSOL received a cash payment of $30 million for Bailey tons that were dedicated to a non-core market. Now, CONSOL will be able to re-market these tons into core markets.

After adjusting for these items not found in security analysts' models and which are listed in the EBITDA reconciliation table, adjusted net income¹ in the 2014 second quarter, a non-GAAP financial measure, was $16 million.

CONSOL's E&P Division had an outstanding quarter. Production was a record 51.9 Bcfe, or an increase of 34% from the 38.6 Bcfe produced in the year-earlier quarter. Average realized prices of $4.44 per Mcfe, when combined with declining unit costs of $3.44 per Mcfe, resulted in a margin of $1.00 per Mcfe. This was 45% higher than the $0.69 per Mcfe margin achieved in the year-earlier quarter. Net Income attributable to CONSOL shareholders from the E&P Division was $15.5 million in the 2014 second quarter, compared to a loss of $2.7 million in the year-earlier quarter.

CONSOL Energy recently raised its 2014 E&P production guidance range to 225 - 235 Bcfe from earlier guidance of  215 - 235 Bcfe. To achieve the mid-point of the new range, the company will need to produce approximately 60 Bcfe in the third quarter and 70 Bcfe in the fourth quarter. The company has a record number of Marcellus Shale wells due to be tied into line in the third quarter.

CONSOL's Coal Division produced 8.3 million tons, achieving the mid-point of the guidance range of 8.1 - 8.5 million tons. Weaker markets for metallurgical coal, though, decreased pricing for the company's low-vol and high-vol coals. Thermal coal pricing was also lower in the quarter, when compared to the year-earlier quarter. Higher thermal coal sales volumes, however, enabled the thermal coal business to generate more cash before capital expenditures and depreciation, depletion, and amortization (DD&A) than in the year-earlier quarter.

The thermal coal segment achieved cash production costs of $40.47 per ton in the 2014 second quarter, as detailed in a table later in the release. This cost was lower than the $43.11 per ton cash production cost in the year-earlier quarter despite geologic issues at the Enlow Fork Mine and the change-out of a shearer at the new Harvey (formerly BMX) Mine.

In total, CONSOL's active coal operations generated $179 million of cash before capital expenditures and DD&A, as detailed later in the release. This was an increase of $4 million from the year-earlier quarter.

"CONSOL Energy did what we said we'd do," commented Nicholas J. DeIuliis, president and CEO. "Our quarterly gas production came in toward the upper end of our guidance range, our gas pricing held steady with last year's quarter while our unit costs dropped meaningfully, especially in the Marcellus Shale, where cash costs below $2 per Mcfe were achieved. In coal, we managed through some typical operating issues to again achieve our production target. In the first half of 2014, the Coal Division generated nearly $400 million in cash (before capital expenditures and DD&A). For the second half of 2014, our tactical focus remains on safety, compliance, and operational execution."

"Our strategic focus, however, remains on NAV per share accretion. The latest example of that focus is our recently-announced gas midstream MLP that we intend to have up and running in the next few months. Also at our recent analyst day, we discussed potential non-core asset sales of $1 billion over the next five years. All in all," continued Mr. DeIuliis, "the pace of change at CONSOL Energy is accelerating the point in time when we become net free cash flow positive, which creates additional opportunities for NAV per share accretion."

E&P Division:

E&P Mid-Year PV-10 Sensitivity Analysis:

CONSOL Energy updated the PV-10² calculation of its 5.731 Tcfe of proved reserves as of December 31, 2013 using latest twelve month pricing as of June 30, 2014. The PV-10 valuation at year-end 2013 was $2.78 billion (without the assumption of drilling carry), with pricing of $3.67 per MMBtu.  The 2014 mid-year PV-10 increased to $4.5 billion using latest twelve month SEC pricing as of June 30 of $4.10 per MMBtu, which resulted in realizing the carried interest of our JV partner.

E&P Second Quarter Results:

The table below summarizes the quarterly comparison of key metrics for the E&P Division. Revenue and production both increased by 34% in the just-ended quarter, when compared to the year-earlier quarter. These metrics, when combined with much lower unit costs, enabled the E&P Division to post net income of $15.5 million in the quarter, compared to a net loss of $2.7 million in the year-earlier quarter.

E&P Division capital expenditures in the quarter set a record at $304.5 million, as the company increased drilling and completion investments to achieve its production growth targets. CONSOL's quarterly capital expenditures were net of $25.6 million of drilling carry from its joint venture partner in the Marcellus Shale and $14.1 million of carry from its joint venture partner in the Utica Shale.

¹ The terms "Adjusted EBITDA" and "Adjusted Net Income" are non-GAAP financial measures, which are defined and reconciled to GAAP net income below, under the caption "Non-GAAP Financial Measure."

² Pre-tax discounted present value, or "PV-10," is a non-GAAP financial measure as defined by the SEC. CONSOL believes that the presentation of pre-tax discounted present value is relevant and useful to investors because it presents the discounted future net cash flows attributable to the company's proved reserves prior to taking into account corporate future income taxes and the current tax structure. CONSOL believe investors and creditors use pre-tax discounted present value as a basis for comparison of the relative size and value of our reserves as compared with other companies. The pre-tax discounted present value may be reconciled to the standardized measure of discounted future net cash flows by reducing the pre-tax discounted present value by the discounted future income taxes associated with such reserves. This reconciliation is included in the slides posted today to the company's web site, at www.consolenergy.com.

CONSOL's E&P division production in the quarter came from the following categories:

Liquids production of 2.6 Bcfe, as a percentage of the total of 51.9 Bcfe, was 5% in the just-ended quarter.

The average sales price per Mcfe within the E&P Division was nearly flat in the just-ended quarter, when compared to the year-earlier quarter. A greater proportion of liquids production — which receives higher unit pricing — offset the negative impact of gas hedges in the just-ended quarter.

Unit costs were improved in the just-ended quarter, as higher production volumes spread fixed costs, such as direct administration, over more units. Unit costs were also improved, as low-cost Marcellus Shale production represented a much higher proportion of total production.

All-in unit costs in the Marcellus Shale category were $2.94 per Mcfe in the just-ended quarter, or a decrease of $0.42 from the $3.36 per Mcfe in the year-earlier quarter. The decrease in unit costs was primarily related to the 120% increase in Marcellus gas sales volumes during the just-ended quarter.

E&P Marketing and Transportation Update:

Second quarter 2014 average dry gas prices, including the impact of our hedging program and net of basis, averaged $4.10 per Mcf. CONSOL's expansion into wet gas production areas provided a liquids value uplift of $0.34 per Mcfe, bringing the overall average sales price to $4.44 per Mcfe. Second quarter 2014 liquids volumes of 2.6 Bcfe were nearly five times greater than in the 2013 second quarter. CONSOL will continue to experience liquids uplift on future average sales prices as additional wells are brought online in the liquid-rich areas of the Marcellus and Utica.

Faster-than-expected replenishment of gas inventories and increasing Marcellus production have put downward pressure on gas prices. These factors have contributed to a decline in the NYMEX index price for natural gas along with the basis differentials for most Appalachian market sales points. CONSOL continues to mitigate the effect of the current downward basis pressure by finding opportunities to optimize and diversify sales opportunities among our 80+ customers located in five index markets. In addition, CONSOL Energy continues to manage the impact of price volatility through an active hedge program.

CONSOL Energy continues to develop a diversified portfolio of firm transportation capacity options to support the three-year production growth plan. Primary production areas in Southwestern Pennsylvania, Northern West Virginia, and Eastern Ohio are served by a large concentration of existing pipeline infrastructure that provides capacity to move production to major gas markets. The company is negotiating with pipeline and utility companies to expand our market reach into the premium markets of the upper-Midwest/Canada and the Southeast.

The company currently has a total of 1.3 Bcf per day of effective firm transportation capacity. This capacity is adequate for the remainder of 2014 and supports the majority of projected volumes for the three-year growth plan. This is comprised of 0.7 Bcf per day of firm capacity on existing pipelines, contracted volumes of 0.3 Bcf per day on several pipeline projects that will be completed over the next several years, and an additional 0.3 Bcf per day of long-term firm sales with major customers that have their own firm capacity. The average demand cost for the existing and committed firm capacity is approximately $0.24 per MMBtu.

In addition to firm transportation capacity, CONSOL has developed a processing portfolio that supports the increasing volumes from our wet production areas. The company has agreements to support the processing of 129 MMcf per day of gross gas volumes growing to more than 380 MMcf per day in the next twelve months. These commitments are sufficient to cover projected processing requirements for the next two years. CONSOL will continue to layer in processing capacity as needed to support the liquids development plan.

In addition to establishing a solid processing portfolio, CONSOL is developing a diversified approach to managing ethane. The company has entered into supply agreements with INEOS Europe and are also contracted to supply volumes to Shell's cracker plant in Monaca, PA.  CONSOL is actively negotiating to supply ethane to other proposed regional cracker facilities. In addition to term sales, the company executed several spot deals to move ethane to Mt. Belvieu via the ATEX pipeline. CONSOL will also realize ethane value through blending capabilities. The company recently constructed an ethane pipeline to bring ethane supplies to the McQuay station where it will be blended with significant volumes of dry gas blend stock. Employing this multi-faceted approach enables us to diversify the ethane portfolio and capitalizes on changes in ethane pricing.

Coal Division:

Coal Reserve Mid-Year Update:

In June 2014, CONSOL completed a multi-year re-evaluation of its remaining Pittsburgh seam longwall mineable reserves utilizing mine plans and mining horizon assumptions specific to each mine/reserve.  In prior years, reserves estimates were based on a fixed 70% mining recovery of the Pittsburgh seam main bench only.  This reevaluation is primarily predicated on advances in mining technology which have increased both mine recovery and the recovery of additional coal above the Pittsburgh main seam and advances in mine planning and modeling technology allowing CONSOL to estimate and capture these changes.  As a direct result of this reevaluation, which was audited by a reputable third party, the company's Pittsburgh Seam reserve tonnage increased by 442 million tons to 1.805 billion tons.

CONSOL is also updating its estimate of its Illinois Basin coal reserves. This study should be complete in the next few months.

Coal Second Quarter Summary:

For the second quarter, CONSOL's Coal Division achieved the mid-point of its guidance range by producing 8.3 million tons. Realized prices per ton were lower for each category of coal than in the year-earlier quarter. Low-vol and high-vol coking coal prices reflected the oversupply of coal used in steelmaking, while thermal coal pricing was lower because of the roll-off of some higher-priced legacy contracts.

Coal costs in the low-vol coal category in the 2014 second quarter were much improved over the year-earlier quarter on a per ton basis despite lower volumes, as the mine was optimized to reflect lower production. Coal costs in the thermal coal category were improved when compared to the year-earlier quarter, but not as good as what was achieved in the 2014 first quarter. Geologic issues at the Enlow Fork Mine and an equipment change-out at the Harvey Mine led to higher-than expected thermal costs per ton. The challenging geology at Enlow Fork Mine is expected to continue until approximately mid-August.

Coal Marketing Update:

Low Vol:

Production cuts continue to take place, both in the U.S. and elsewhere, and a better supply/demand balance will eventually occur in the market. CONSOL currently expects to ship approximately 5 million tons of met (both low vol and high vol in 2014). This is 1 million tons lower than the projection the company made three months ago. Buchanan shipped 0.95 million tons in the second quarter of 2014. CONSOL has been very active in the domestic met market for 2015, and expects to increase its 2015 domestic sales of low vol by at least 50%. CONSOL's sales efforts are aided by having the lowest cost low vol mine in the U.S. and by having a strong balance sheet.

High Vol:

Bailey coal continues to have a place in the high vol market, even though the overall met market remains weak.  CONSOL will continue to send tons where they create the most shareholder value. In the second quarter, 330,000 tons of Bailey production was sold into the high vol markets.

Thermal:

For 2014, CONSOL has been able to consistently transport all Bailey coal produced, even though there have been challenges with capacity in the US rail system. CONSOL has been able to move these tons to market due to having dual rail access facilities that can load 130 car trains in less than 2 hours, and also because of efficient logistics coordination with both the Norfolk Southern and CSX railroads and our customers.

For 2015 and 2016, CONSOL continues to successfully market Bailey tons into target core markets. During the second quarter, nearly 5.0 million annual tons were committed for 2015, and 4.0 million tons were committed for 2016. An additional 9.0 million tons are currently under negotiation for 2015 and 2016.

E&P Division Guidance:

Third quarter gas production, net to CONSOL, is expected to be 59 – 61 Bcfe, while annual 2014 production guidance was recently raised to 225 – 235 Bcfe, from 215 – 235 Bcfe. CONSOL Energy expects its 2015 and 2016 annual gas production to grow by 30%.

Total hedged natural gas production in the 2014 third quarter is 41.7 Bcf, at an average price of $4.58 per Mcf. CONSOL uses a dual-track approach to its gas hedging. The company uses a formulaic approach to a base of hedges, but can decide to layer-in additional opportunistic hedges to capture value from price spikes. CONSOL does not expect to hedge more than 80% of its estimated natural gas production for any given year. The annual gas hedge position for three years is shown in the table below:

The hedged gas volumes shown in the previous table include the following NYMEX hedges that have basis hedged as well.

Coal Division Guidance:

In coal, the low vol guidance range for 2014 has again been lowered from that shown three months ago to reflect a deterioration in pricing. For 2015, the low vol guidance was left unchanged from the previous guidance on the assumption that pricing will improve from current levels.

The thermal guidance for 2014 has increased from the previous guidance due to the strong start in both sales and production. The company believes that generators will be busy replenishing inventories that were drawn down due to the cold winter, which should translate into additional thermal sales opportunities. For 2015, thermal guidance was left unchanged.

Liquidity:

Consol Energy Inc. entered into a new Amended and Restated Credit Agreement dated as of June 18, 2014 for a $2.0 billion senior secured revolving credit facility. The new senior secured revolving credit facility replaced the existing $1.0 billion senior secured revolving credit facility which had been entered into as of April 12, 2011 and was amended and restated on December 5, 2013. The new senior secured revolving credit facility also replaced the existing $1.0 billion senior secured revolving credit facility of CNX Gas Corporation and its subsidiaries that had been entered into as of April 12, 2011.

As of June 30, 2014, CONSOL Energy had $1.9 billion in total liquidity, which is comprised of $147.4 million of cash, $24.0 million available to be borrowed under the accounts receivable securitization facility, and $1.7 billion available to be borrowed under its $2.0 billion bank facility. CONSOL Energy's credit facility has no borrowings. Outstanding letters of credit under the bank facility are $260.4 million.

CONSOL's liquidity in the second quarter was improved by $112 million from the receipt of a federal cash tax refund in association with last year's sale of five mines. The cash from the $30 million coal contract buyout occurred in July,  so it will be reflected in the third quarter financial statements.

About CONSOL

Consol Energy Inc. (NYSE: CNX) is a Pittsburgh-based producer of natural gas and coal. The company is one of the largest independent natural gas exploration, development and production companies, with operations centered in the major shale formations of the Appalachian basin. CONSOL Energy deploys an organic growth strategy focused on rapidly developing its resource base. As of December  31, 2013, CONSOL Energy had 5.7 trillion cubic feet equivalent of proved natural gas reserves. The company's premium coals are sold to electricity generators and steel makers, both domestically and internationally.  CONSOL Energy is a member of the Standard & Poor's 500 Equity Index and the Fortune 500. Additional information can be found at www.consolenergy.com.

Non-GAAP Financial Measures

Definition: EBIT is defined as earnings 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.  Adjusted EBITDA is defined as EBITDA after adjusting for the discrete items listed below. Although EBIT, EBITDA, and Adjusted EBITDA are not measures of performance calculated in accordance with generally accepted accounting principles, management believes that they are useful to an investor in evaluating CONSOL Energy because they are widely used to evaluate a company's operating performance. Investors should not view these metrics as a substitute for measures of performance in that are calculated in accordance with generally accepted accounting principles.  In addition, because all companies do not calculate EBIT, EBITDA, or Adjusted EBITDA identically, the presentation here may not be comparable to similarly titled measures of other companies.

Reconciliation of EBIT, EBITDA and Adjusted EBITDA to financial net income attributable to CONSOL Energy Shareholders is as follows (dollars in 000):

Cautionary 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 a worldwide financial downturn; an extended decline in prices we receive for our gas, natural gas liquids and coal including the impact on gas prices of our gas operations being concentrated in Appalachia which has experienced a dramatic increase in gas production and decline in gas pricing relative to the benchmark Henry Hub prices; our customers extending existing contracts or entering into new long-term contracts for coal; the expiration or failure to extend existing long-term contracts; 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 gas and coal to market; a loss of our competitive position because of the competitive nature of the gas and coal 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 natural gas and coal, 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; the risks inherent in gas and coal 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; 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 gas and coal 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 well or mine; the potential for liabilities arising from environmental contamination or alleged environmental contamination in connection with our past or current gas and coal operations; the effects of mine closing, reclamation, gas well closing and certain other liabilities; uncertainties in estimating our economically recoverable gas and coal reserves; defects may exist in our chain of title and we may incur additional costs associated with perfecting title for gas or coal rights on some of our properties or failing to acquire these additional rights we may have to reduce our estimated reserves;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; 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; replacing our natural gas reserves, which if not replaced, will cause our gas reserves and gas production to decline; acquisitions that we may make in the future involve risks including the accuracy of our assessment of the acquired businesses and their risks, achieving any anticipated synergies, integrating the acquisitions and divestitures we may make may not occur or produce anticipated proceeds; existing and future gas joint ventures may restrict our operational and corporate flexibility, we may be materially impacted by actions taken by our joint venture partners and we may not realize anticipated benefits such as carried costs; 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; provisions of our debt agreements may restrict our flexibility and the risks associated with the degree to which we are leveraged; our hedging activities may prevent us from benefiting from price increases and may expose us to other risks; changes in federal or state income tax laws, particularly in the area of percentage depletion and intangible drilling costs, could cause our financial position and profitability to deteriorate; the risks in making strategic determinations, including the allocation of capital and other resources among our strategic opportunities may adversely affect our financial condition; failure by Murray Energy Corporation to satisfy the liabilities it assumed from us as well as to perform its obligations under various agreements; we may not be able to consummate a sale or MLP transaction of our gas midstream assets; and other factors discussed in the 2013 Form 10-K under "Risk Factors," as updated by any subsequent Form 10-Qs, which are on file at the Securities and Exchange Commission.

A registration statement relating to the securities of the MLP that would be sold in the offering has not been filed with the Securities and Exchange Commission or become effective. This announcement does not constitute an offer to sell, or the solicitation of an offer to buy, any securities. This announcement is being issued pursuant to, and in accordance with, Rule 135 under the Securities Act of 1933.