PostRock Reports First Quarter Results OKLAHOMA CITY, May 13, 2014 (GLOBE NEWSWIRE) -- PostRock Energy Corporation (Nasdaq:PSTR) today announced its results for the quarter ended March 31, 2014. Highlights *Revenue totaled $21.8 million, up 36% from the prior-year period. *Production, using a 19:1 oil-to-gas economic equivalency, averaged 47.5 MMcfe per day, down 2% from the prior-year period due primarily to adverse weather in the quarter. *Oil production averaged 595 barrels a day, a 64% increase from the prior-year period. *Oil contributed 23% of revenues, compared to 18% in the prior-year period. *A settlement was reached with Constellation Energy Partners, LLC ("CEP") and Sanchez Energy Partners I, L.P. ("SEPI"). To date, the Company has received $9.1 million pursuant to the settlement and hopes to recover an additional $12.5 million by year end. *April's oil production was 695 net barrels a day, or 17% above the first quarter's average. *By April 30, debt had decreased $9.0 million from its March 31 level to $86.0 million. Operational Discussion Winter Impact on Production–Oil and gas production was negatively impacted, primarily in the Cherokee Basin, from December through early March due to the extreme winter. The Company estimates that first quarter production was reduced by approximately 1.1 net MMcf per day and 40 net barrels of oil per day, or 1.9 net MMcfe per day at a 19:1 economic equivalency, due to weather. By April 30, gas production had nearly returned to expected rates, and oil production was above expectations. On an economic equivalency basis, April production averaged 50.1 net MMcfe per day, a 5% increase over the first quarter and 2% above the year earlier period. Central Oklahoma – Oil production for the first quarter averaged 356 net barrels per day. While modest, this was a 120% increase over the prior-year period. During the quarter, the Company worked over three wells targeting the Hunton Carbonate. Since March 31, an additional seven workovers have been performed. Initial results have been positive, as the initial eight development workovers, now online, have increased production by approximately 190 net barrels of oil per day, and, collectively, are expected to generate in excess of 100% IRR. As a result, production for the month of April averaged 461 net barrels a day, 29% higher than the first quarter's average. The remaining two workovers were put on production on May 7. The Company is also currently drilling a horizontal well targeting the Hunton formation. On January 31, the Company purchased additional interests in producing properties it acquired in November 2013. The additional interests were purchased for $1.8 million, including $900,000 cash and 725,806 shares of common stock. For the balance of the year, the Company plans to spend $20 million on new horizontal and vertical wells targeting multiple formations, including the Hunton Carbonate and the Woodford Shale. We also expect to perform additional development workovers throughout the year. Cherokee Basin–Gas and oil production for the first quarter averaged 34.8 net MMcf per day and 212 net barrels per day, respectively. On an economic equivalency basis, production declined 9% from the prior-year period to an average of 38.8 net MMcfe per day. The decline in gas volume was largely due to weather and the lack of ongoing development in the Basin. One of the Company's most significant and challenging projects over the last 18 months has been the reconfiguration of its Cherokee Basin compression system. The project was designed to improve energy efficiency and reduce gathering costs. The project was completed on May 6 at a total cost of $8.5 million. It is expected to result in annual rental savings of $4.6 million and to reduce fuel consumption by approximately 1.6 MMcf a day, which should add approximately $2.6 million in revenues and cash flow on an annual basis at current gas prices. Financial Discussion Revenues increased 36% from the prior-year period to $21.8 million. Despite lower volumes, gas revenue increased 28% to $16.0 million, due to a 47% increase in realized prices to $4.90 per Mcf. Oil revenue increased 73% to $5.1 million, as production grew 64% and the realized price of $95.27 per barrel was 5% higher than the prior-year period. Gas gathering revenue increased 12% to $735,000, as higher gas pricing more than offset lower third-party volumes. Total production costs, which consist of lease operating expenses ("LOE"), gathering expenses, and severance and ad valorem taxes ("production taxes") increased 5% from the prior-year period to $10.3 million. The increase was largely due to lower capitalized labor and equipment costs of $666,000, as a result of a lower number of development projects in 2014. Also contributing to the increase were higher repair and maintenance costs of $320,000, largely due to the wells drilled in the Company's 2013 development program which increased well count by approximately 5%, and higher production taxes of $177,000 due to higher gas pricing and increased oil production. Partially offsetting the increase were compressor rental savings resulting from the compressor reconfiguration project, of approximately $600,000, coupled with a reduction of labor and equipment costs of $250,000. General and administrative expenses increased 10%, or $363,000, from the prior-year period to $3.9 million. Excluding expenses of $29,000 associated with the CEP litigation and a one-time payroll tax expense of $62,000 for executive deferred compensation, G&A increased by 8%. Of the increase, $144,000 was related to higher licensing and implementation costs for new accounting, planning and technical software. Additionally, $128,000 was due to an increase in wages as the average employee headcount at the Company's headquarters increased by five due to the Company's production and leasehold acquisitions in Oklahoma. Going forward, both license/software implementation costs and wages should moderate as expected system cost savings and the impact of recent employee departures are realized throughout the year. Due to the accounting treatment of the Series A mandatorily redeemable preferred stock, an additional $2.6 million of non-cash interest expense was added during the quarter. Excluding this expense, net interest expense was $965,000, an increase of 50% over the prior-year period, as debt outstanding increased. The Company had a $2.5 million realized hedging loss in the quarter compared to a loss of $873,000 in the prior-year period, as a result of rising gas and oil prices. Due to appreciation of the market price of CEP units during the first quarter, a mark-to-market gain of $1.6 million was recorded. Hedges The Company's natural gas and crude oil swaps cover an average of 28.2 MMcf and 317 barrels per day for the remaining nine months of 2014 at weighted average prices of $4.01 per Mcf and $95.19 per barrel. Compared to the Company's 2014 PDP production forecast and total proved reserves production forecast in its December 31, 2013 reserve report, this represents approximately 82% and 81% of gas production, respectively, and 64% and 49% of oil production, respectively. The following table summarizes the Company's derivative positions at March 31, 2014. The Company has no Southern Star basis swaps outstanding. April - Dec. 2014 2015 2016 NYMEX Gas Swaps Volume (MMBtu) 7,745,679 8,983,560 7,814,028 Weighted Average Price ($/MMBtu) $ 4.01 $ 4.01 $ 4.01 NYMEX Oil Swaps Volume (Bbls) 87,057 71,568 65,568 Weighted Average Price ($/Bbl) $ 95.19 $ 92.73 $ 90.33 Debt At March 31, $95.0 million was borrowed under the revolving credit facility, an increase of $3.0 million from year end. As of April 30, the Company had $86.0 million drawn on the facility and $1.4 million in letters of credit outstanding, resulting in $27.6 million remaining available on the facility. The initial payment of $8.3 million received from the CEP lawsuit settlement, discussed below, was used to reduce debt. At March 31, PostRock elected to pay in-kind its quarterly dividend on its Series A preferred stock, increasing the liquidation value of the preferred by $3.1 million to $105.9 million. As part of the dividend, White Deer also received 2.4 million additional warrants with a weighted average strike price of $1.27 a share. At March 31, White Deer held a total of 22.6 million warrants exercisable at an average price of $1.51 a share and 11.0 million common shares. December 31, March 31, 2013 2014 Capitalization (in thousands) Long-term debt $ 92,000 $ 95,000 Mandatorily redeemable preferred stock 64,523 64,933 Redeemable preferred stock 23,828 26,098 Stockholders' deficit (30,034) (34,715) Total capitalization $ 150,317 $ 151,316 Capital Expenditures During the quarter, capital expenditures totaled $6.8 million. This included $2.0 million spent on development projects which include the three Central Oklahoma development workovers. Maintenance related projects, primarily the Company's compressor reconfiguration project, were $2.7 million, producing property acquisition costs in Central Oklahoma, discussed above, were $1.8 million and leasehold costs were approximately $300,000. CEP Settlement On March 31, a settlement of the Company's CEP lawsuit was reached. The Company expects to recover a target of $21.6 million. At the time of settlement, all of the Company's CEP Class A units and 414,938 Class B units were transferred to SEPI. Simultaneously, PostRock received an initial payment of approximately $8.3 million. Over the next nine to twelve months, the Company intends to sell its remaining 5,503,956 Class B units in orderly block and other market transactions, subject to minimum price, volume and other limitations set forth in the settlement agreement. As of April 30, the Company had sold 291,767 Class B units at an average price of $2.52. Webcast and Conference Call PostRock will host a webcast and conference call tomorrow, May 14, 2014, at 10:00 a.m. Central Time. The 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 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. Production for the Current and Prior-Year Periods The following table represents total period production for the current and prior-year periods: Total Period Production Three Month Ended March 31, 2013 2014 Production Natural gas (MMcf) Cherokee Basin 3,587 3,131 Central Oklahoma — 9 Appalachian Basin 133 118 Total natural gas 3,720 3,258 Crude oil (Bbls) Cherokee Basin 13,782 19,061 Central Oklahoma 14,606 32,056 Appalachian Basin 4,291 2,469 Total crude oil 32,679 53,586 Total Production - Natural Gas Equivalent (MMcfe) Economic equivalent, 19:1 oil-to-gas basis ^(1) Cherokee Basin 3,849 3,493 Central Oklahoma 278 618 Appalachian Basin 215 165 Total natural gas equivalent 4,342 4,276 Energy equivalent, 6:1 oil-to-gas basis ^(2) Cherokee Basin 3,670 3,245 Central Oklahoma 88 201 Appalachian Basin 159 133 Total natural gas equivalent 3,917 3,579 Realized price (excluding hedges) Crude oil (per Bbl) $ 90.49 $ 95.27 Natural gas (per Mcf) $ 3.34 $ 4.90 (1) Oil and natural gas are converted at the rate of one barrel equals 19 Mcfe based upon the approximate revenue per unit of production (Mcf or Bbl) realized during the period; $95.27 per barrel of oil and $4.90 per Mcf of gas factors down to a 19:1 ratio. (2) Oil and natural gas are converted at the rate of one barrel equals six Mcfe based upon the approximate relative energy content of oil to natural gas. 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. Three Months Ended March 31, 2013 2014 (in thousands) Net (loss) $ (7,894) $ (6,323) Adjusted for: Interest expense, net 641 3,530 Depreciation, depletion and amortization 6,428 6,902 EBITDA $ (825) $ 4,109 Other income, net (13) — Gain from equity investment (3,582) (1,619) Unrealized loss from derivative financial 6,248 2,608 instruments (Gain) loss on disposal of assets 31 (19) Non-cash compensation 928 979 Acquisition costs — 34 CEPM legal fees — 29 Adjusted EBITDA $ 2,787 $ 6,121 Although EBITDA and adjusted EBITDA are not measures of performance calculated in accordance with generally accepted accounting principles ("GAAP"), management considers them important measures of performance. Neither EBITDA nor adjusted EBITDA are a substitute for the GAAP measures of earnings or cash flow or 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. EBITDA and adjusted EBITDA have material limitations as a performance measure because they exclude, 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 their limitations, neither EBITDA nor adjusted EBITDA should be considered a measure of discretionary cash available to us to invest in the growth of PostRock's business. PostRock Energy Corporation Condensed Consolidated Statements of Operations (Unaudited) Three Months Ended March 31, 2013 2014 (in thousands, except per share data) Revenues Natural gas sales $ 12,442 $ 15,963 Crude oil sales 2,957 5,105 Gathering 654 735 Total 16,053 21,803 Costs and expenses Production 9,775 10,272 General and administrative 3,546 3,911 Depreciation, depletion and amortization 6,428 6,902 (Gain) loss on disposal of assets 31 (19) Acquisition costs — 34 Total 19,780 21,100 Operating income (loss) (3,727) 703 Other income (expense) Realized loss from derivative financial (873) (2,507) instruments Unrealized loss from derivative (6,248) (2,608) financial instruments Gain on investment 3,582 1,619 Other income (expense), net 13 — Interest expense, net (641) (3,530) Total (4,167) (7,026) Loss before income taxes (7,894) (6,323) Income taxes — — Net loss (7,894) (6,323) Preferred stock dividends (2,740) (929) Accretion of redeemable preferred stock (778) (370) Net loss attributable to common $ (11,412) $ (7,622) stockholders Net loss per common share Basic loss per share $ (0.50) $ (0.25) Diluted loss per share $ (0.50) $ (0.25) Weighted average common shares outstanding Basic 22,763 31,015 Diluted 22,763 31,015 PostRock Energy Corporation Condensed Consolidated Balance Sheets December 31, March 31, 2013 2014 (Unaudited) (in thousands) ASSETS Current assets Cash and equivalents $ 37 $ 151 Restricted cash — 23 Accounts receivable—trade, net 7,722 9,332 Other receivables 194 8,446 Inventory 886 838 Other 820 1,753 Derivative financial instruments 54 4 Total 9,713 20,547 Oil and natural gas properties, full cost method of 141,911 142,462 accounting, net Other property and equipment, net 14,180 13,780 Investment, net 14,588 7,873 Derivative financial instruments 652 469 Other, net 2,038 1,920 Total assets $ 183,082 $ 187,051 LIABILITIES AND STOCKHOLDERS' DEFICIT Current liabilities Accounts payable $ 7,406 $ 7,449 Revenue payable 4,397 4,921 Accrued expenses and other 4,055 3,881 Derivative financial instruments 1,937 4,917 Total 17,795 21,168 Derivative financial instruments 1,796 1,191 Long-term debt 92,000 95,000 Mandatorily redeemable preferred stock 64,523 64,933 Asset retirement obligations 13,099 13,345 Other 75 31 Total liabilities 189,288 195,668 Commitments and contingencies Series A Cumulative Redeemable Preferred Stock 23,828 26,098 Stockholders' deficit Preferred stock 1 1 Common stock 299 316 Additional paid-in capital 397,170 399,900 Treasury stock, at cost (512) (1,617) Accumulated deficit (426,992) (433,315) Total stockholders' deficit (30,034) (34,715) Total liabilities and stockholders' deficit $ 183,082 $ 187,051 PostRock Energy Corporation Condensed Consolidated Statements of Cash Flows (Unaudited) Three Months Ended March 31, 2013 2014 (in thousands) Cash flows from operating activities Net loss $ (7,894) $ (6,323) Adjustments to reconcile net loss to net cash flows from (used in) operating activities Depreciation, depletion and amortization 6,428 6,902 Share-based and other compensation 928 968 Amortization of deferred loan costs 104 129 Change in fair value of derivative financial 6,248 2,608 instruments (Gain) loss on disposal of assets 31 (19) Gain on investment (3,582) (1,619) Other non-cash changes to items affecting net (15) 2,566 loss Changes in operating assets and liabilities Accounts receivable 153 (1,528) Accounts payable (5,559) (1,128) Other 329 (1,037) Net cash flows from (used in) operating (2,829) 1,519 activities Cash flows from investing activities Restricted cash — (23) Expenditures for equipment, development and (9,211) (4,430) leasehold Proceeds from sale of assets 12 59 Net cash flows used in investing activities (9,199) (4,394) Cash flows from financing activities Proceeds from debt 23,500 19,000 Repayments of debt (15,000) (16,000) Debt and equity financing costs (224) (11) Proceeds from issuance of common stock 3,292 — Net cash flows from financing activities 11,568 2,989 Net increase (decrease) in cash and cash (460) 114 equivalents Cash and equivalents beginning of period 525 37 Cash and equivalents end of period $ 65 $ 151 CONTACT: Company Contact: Stephen L. DeGiusti EVP, General Counsel & Secretary firstname.lastname@example.org (405) 702-7420 PostRock Energy Corporation Logo
PostRock Reports First Quarter Results
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