PostRock Reports 2013 Results

OKLAHOMA CITY, March 26, 2014 (GLOBE NEWSWIRE) -- PostRock Energy Corporation (Nasdaq:PSTR) today announced its results for the year ended December 31, 2013.

Key Operating Results

• Based on a 27:1 oil-to-gas conversion (the Company's 2013 realized price differential), production increased 4% from the prior year.

• Oil sales doubled to an average of 527 net barrels a day.
• Gas sales averaged 39.8 net MMcf a day, an 11% decline.

• Based on a 6:1 oil-to-gas conversion, production declined 8%.
• Oil reserves increased 63% to 4.4 million barrels. Based on the 27:1 conversion noted above, oil now represents 58% of proved reserves.
• Gas reserves increased 24% to 86.6 Bcf. Based on the 27:1 conversion, gas now represents 42% of proved reserves.

Key Financial Results

• Revenue totaled $72.3 million, up 32% from the prior year.
• Oil contributed 25+% of revenues, versus 16% in 2012.
• Production costs, excluding one-time items discussed below, decreased 4%.
• General and administrative expenses, excluding one-time items and non-cash compensation discussed below, decreased 20%.

Development and Leasing Activities

Central Oklahoma. In May 2013, the Company acquired approximately 4,300 net acres located in Lincoln and Payne Counties of Oklahoma. In November, slightly over 22,000 net acres of leasehold in Seminole, Pottawatomie, Cleveland and McClain Counties were purchased along with associated production. Subsequent to these acquisitions, total leasehold in Central Oklahoma currently approximates 35,000 net acres, of which 11,000 net acres are held by production.

During the year, nine wells were recompleted and two vertical wells were drilled in Oklahoma targeting multiple oil pays, including the Hunton and Woodford formations. In addition, an initial, horizontal Hunton well was drilled and put on production. These 12 projects had a total cost of $7.7 million. Two water disposal wells were drilled and four tank batteries were built at a total cost of $1.9 million.

Cherokee Basin. During 2013, 62 wells were recompleted, 143 wells were drilled and brought on line and nine wells previously drilled were brought on line at a total cost of $18.9 million. Nine water disposal wells were drilled and 22 tank batteries were built at a total cost of $2.4 million. Since August, development work in the Cherokee Basin has been deferred as the Company has shifted its focus to Central Oklahoma to realize higher returns.

One of the Company's most significant projects has been to reconfigure its Cherokee Basin compression system. This project improves energy efficiency and reduces gathering and operating costs. The program was piloted in 2012 and began to be implemented in 2013. At present, only the Company's largest compressor station remains to be converted. The Company expects the project to be complete in May at a total cost of $8.2 million. Roughly $5.5 million of the project cost will fall in 2014. In aggregate, the project is expected to reduce costs by approximately $3.2 million a year while reducing fuel usage by 2.5 MMcf per day.

2013 Results

Revenue increased 32% from the prior year to $72.3 million. Despite lower sales volumes, gas revenue increased 17% to $51.5 million. The increase was driven by a 32% increase in realized prices to $3.55 per Mcf. Oil revenue increased 111% to $18.2 million as production doubled and the realized price of $94.56 per barrel was slightly above the prior year. Gas gathering revenue increased 7% to $2.6 million as higher gas pricing offset lower volumes.

Production costs, including lease operating expenses, gathering costs and production taxes, decreased 5% to $40.1 million. Production costs in 2012 had included $368,000 related to a field reorganization. Excluding this cost, production costs fell $1.8 million, or 4%. The largest contributors to the cost reduction were a $1.1 million reduction in compressor rentals, lower repair and maintenance costs of $635,000, lower workover costs of $486,000, and lower ad valorem taxes of $271,000. These reductions were partially offset by a $614,000 increase in production taxes and increased electricity costs of $263,000. Production costs were $2.56 per Mcfe, up from an adjusted $2.47 per Mcfe in the prior year, primarily due to lower production volumes.

General and administrative expenses increased 8% from the prior year to $16.0 million. Excluding non-cash compensation of $1.3 million and $4.3 million from 2012 and 2013, respectively, a $503,000 charge related to a headquarters reorganization in 2012, $1.6 million of legal fees related to the Constellation Energy Partners ("CEP") and Sanchez Energy Partners I ("Sanchez") litigation in 2013, and a $454,000 workman's compensation charge related to a 2010-2011 audit settlement, general and administrative expenses totaled $9.7 million, a 20% decrease from the prior year adjusted total. The decrease was due primarily to reduced wages, benefits and bonuses of $601,000, higher capitalized general and administrative expenses of $434,000, and lower contract labor and other services of $299,000.

The Company had a realized hedging loss of $2.3 million in 2013. This compared to a gain of $73.2 million in 2012 when the Company exited above-market natural gas swap contracts.

Each quarter, PostRock is required to assess the recoverability of the carrying value of its oil and gas properties against their present value utilizing a first-of-the-month twelve-month average price for oil and natural gas. An impairment of $5.9 million was recognized in 2012 due to depressed gas prices. With the recovery in gas prices during the year, no impairment was recognized in 2013.

Due to appreciation of the market price of CEP units in 2013, a mark-to-market gain of $6.8 million was recorded.

Fourth Quarter Results

Revenue increased 14% from the prior-year period to $18.0 million. Despite a 6% increase in realized pricing to $3.46 per Mcf, natural gas revenue decreased 5% from the prior-year period to $12.2 million due to a 10% decrease in average daily sales volumes to 38.3 MMcf per day. Oil revenue increased 120% from the prior-year period to $5.2 million as production nearly doubled to an average of 607 barrels per day and the $93.90 a barrel realized price was 11% higher. Gas gathering revenue decreased 3% to $605,000 as lower volume offset higher gas prices.

Production costs decreased 5% from the prior-year period to $9.6 million. Compressor rental costs decreased $637,000 and vehicle and equipment costs decreased $163,000. These reductions were partly offset by a decrease in capitalized lease operating expenses of $357,000 and an increase in electricity costs of $199,000. In total, production costs were $2.49 an Mcfe, compared to $2.46 an Mcfe from the prior-year period, primarily due to lower production volumes.

General and administrative expenses increased 36% from the prior-year period to $4.7 million. Excluding non-cash compensation of $622,000 and $2.2 million from 2012 and 2013, respectively, and $1.5 million of legal fees related to the litigation with CEP and Sanchez in 2013, ongoing general and administrative expenses totaled $2.0 million, a 32% decrease from the prior-year period's adjusted total. The decrease was due primarily to reduced wages, benefits and bonuses of $458,000 and lower franchise taxes of $164,000.

The Company had a $77,000 realized hedging gain in the quarter compared to a gain of $39.8 million in the prior-year period.

Due to appreciation of the market price of CEP units in the fourth quarter, a mark-to-market gain of $1.6 million was recorded.

Hedges

The Company's natural gas and crude oil swaps for 2014 cover an average of 28.3 MMcf and 318 Bbls per day at a weighted average price of $4.01 and $95.19, respectively. This represents roughly 79% and 50%, respectively, of the Company's 2014 production forecast in its December 31, 2013 reserve report. The following table summarizes the Company's derivative positions at December 31, 2013. The Company has no Southern Star basis swaps outstanding.

Debt

At December 31, 2013, $92.0 million was drawn under the Company's revolving credit facility, an increase of $34.5 million from the prior year and a $5.5 million increase from September 30, 2013. At March 25, 2014, $94.5 million was drawn under the revolving credit facility, an increase of $2.5 million from year end. The increase was driven by an acquisition of additional well interests in Central Oklahoma and legal costs related to the litigation with CEP and Sanchez, both of which are discussed in more detail below. The facility requires that a leverage ratio (ratio of consolidated funded debt to consolidated EBITDAX for the four fiscal quarters ending on the applicable fiscal quarter-end) be maintained at less than 3.5 to 1.0 as of each quarter-end. The leverage ratio at December 31, 2013 was very slightly above this limit. However, the banks granted a waiver. PostRock expects to be in full compliance with its covenants at March 31, 2014. The Company was in compliance with all other financial covenant ratios as of December 31, 2013.

On December 13, 2013, 1,123,981 shares of common stock were issued to White Deer in exchange for 22,241,333 warrants with the associated voting preferred. As a result, the Company removed the carrying value of the affected Series A Preferred Stock out of temporary and permanent equity and added $64.5 million, the fair value of the affected Series A Preferred Stock, to long-term liabilities, pursuant to applicable accounting guidance.

At December 31, 2013, PostRock elected to again pay in-kind its quarterly dividend on the preferred, increasing the liquidation value of the preferred by $3.0 million to $102.8 million. White Deer also received 2.5 million additional warrants with a weighted average strike price of $1.22 a share. At year end, White Deer held a total of 20.2 million warrants exercisable at an average price of $1.54 a share and 11.0 million common shares.

CEP Litigation

On August 30, 2013, a wholly owned subsidiary of the Company filed suit against CEP and Sanchez, et al. The lawsuit arose from a transaction that was closed between CEP and Sanchez on August 9^th that diluted PostRock's ownership interest in CEP and removed certain rights of PostRock.

The trial has been postponed pending an anticipated settlement. While nothing has been finalized, the proposed settlement contemplates PostRock recovering a target of $21.6 million via the sale of its A Units to CEP and Sanchez, followed by the orderly disposition of its B Units in various market and block transactions in the course of 2014. The settlement, as currently proposed, would eliminate all disputes between the parties.

Capital Expenditures

During the fourth quarter, capital expenditures totaled $16.7 million. This included $11.5 million spent on land, primarily the two November acquisitions. A total of $3.4 million was spent on oil directed drilling and recompletions and the remaining $1.8 million was spent on maintenance projects, largely on the ongoing Cherokee Basin compressor optimization project.

Capital expenditures totaled $60.7 million in 2013. This included $40.0 million spent on exploration and development. Land expenditures totaled $16.6 million including leasing and the three Central Oklahoma acquisitions completed in 2013. Maintenance expenditures, including the compressor optimization project, totaled $4.1 million.

Reserves

Based on a 6:1 oil-to-gas conversion, proved reserves increased 32% to 112.9 Bcfe at year end 2013. Gas reserves increased 16.9 Bcf, or 24%. Of this amount, 91.6 MMcf was gained from acquisitions, 23.5 Bcf was gained as the result of a 33% increase in pricing, 6.1 Bcf was gained due to decreasing operating costs, and 1.8 Bcf was gained as a result of additions to the reserve base and positive revisions to previous estimates. These increases were partially offset by production of 14.5 Bcf. Oil reserves increased 1.7 million barrels, or 63%. Of this amount, 449,500 barrels were gained from acquisitions, 23,700 barrels were gained as the result of a 2% increase in pricing, 108,000 barrels were gained due to lower operating costs, and 1.3 million barrels were gained as a result of additions to the reserve base and positive revisions to previous estimates. These increases were partially offset by production of 192,500 barrels. At year-end 2013, approximately 90% of the Company's reserves were classified as proved developed.

Subsequent Event

In January 2014, the Company acquired additional interests, associated with the larger acquisition made in November 2013, for $1.8 million. The interests were purchased with $900,000 of cash and 725,806 shares of common stock.

Management Comment

Terry W. Carter, PostRock's President and Chief Executive Officer, said, "In 2013 PostRock made meaningful progress on increasing oil production and oil reserves. In particular, I believe the development success, small acquisitions, and land additions in Central Oklahoma along with our continued focus on reducing operating costs will prove to be the foundation for future growth and at long last provide us the ability to create shareholder value."

Webcast and Conference Call

PostRock will host its quarterly webcast and conference call tomorrow, Thursday, March 27, 2013, at 10:00 a.m. Central Time. The live webcast will be accessible on the 'Investors' page at www.pstr.com, where it will also be available for replay. The conference call number for participation is (866) 516-1003.

PostRock Energy Corporation is engaged in the acquisition, exploration, development, production and gathering of crude oil and natural gas. Its primary production activity is focused in the Cherokee Basin, a 15-county region in southeastern Kansas and northeastern Oklahoma, and Central Oklahoma. The Company owns and operates over 3,000 wells and maintains nearly 2,200 miles of gas gathering lines in the Basin. It also owns and operates minor oil and gas producing properties in the Appalachian Basin.

Forward-Looking Statements

Opinions, forecasts, projections or statements, other than statements of historical fact, are forward-looking statements that involve risks and uncertainties. Forward-looking statements in this announcement are made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable, it can give no assurance such expectations will prove correct. Actual results may differ materially due to a variety of factors, some of which may not be foreseen. These risks and other risks are detailed in the Company's filings with the Securities and Exchange Commission, including risk factors listed in the Annual Report on Form 10-K and other filings. The Company's SEC filings may be found at www.pstr.com or www.sec.gov. By making these forward-looking statements, the Company undertakes no obligation to update these statements for revisions or changes.

Reconciliation of Non-GAAP Financial Measures

The following table represents a reconciliation of net income (loss) to EBITDA and adjusted EBITDA, as defined, for the periods presented.

Although adjusted EBITDA is not a measure of performance calculated in accordance with generally accepted accounting principles, or GAAP, management considers it an important measure of performance. Adjusted EBITDA is not a substitute for the GAAP measures of earnings or cash flow and is not necessarily a measure of the Company's ability to fund its cash needs. In addition, it should be noted that companies calculate adjusted EBITDA differently, and therefore adjusted EBITDA as presented herein may not be comparable to adjusted EBITDA reported by other companies. Adjusted EBITDA has material limitations as a performance measure because it excludes, among other things, (a) interest expense, which is a necessary element of business to the extent that an entity incurs debt, (b) depreciation, depletion and amortization, which are necessary elements of any business that uses capital assets, (c) impairments of oil and gas properties, which may at times be a material element of an independent oil company's business, and (d) income taxes, which may become a material element of the Company's operations in the future. Because of its limitations, adjusted EBITDA should not be considered a measure of discretionary cash available to invest in the growth of PostRock's business.