Magnum Hunter Resources Corp (NYSE:MHR) announced today financial and operating results for the three and six months ended June 30, 2015. The Company plans to file its Form 10-Q for the quarter ended June 30, 2015 with the Securities and Exchange Commission later today, Friday, August 7, 2015. Highlights of the Company’s financial and operating results include the following:
- Mid-year proved reserves grew to 801.8 Bcfe, an increase of 60% from year-end 2014
- Reported production of 126.0 MMcfe/d (21.0 MBoe/d) and pro-forma production(a) of 144.0 MMcfe/d (24.0 MBoe/d) for second quarter 2015; pro-forma production increased 37% over actual reported production for the prior year comparable quarter
- Second quarter 2015 production mix of 68% natural gas, 17% NGLs and 15% oil
- Average realized natural gas price for second quarter 2015 was $1.67 per Mcf (a $1.06 per Mcf negative differential to the average NYMEX price for the period)
- Recent record throughput volumes on Eureka Hunter Pipeline System of approximately 700,000 MMBtu/d
- Production costs per Mcfe for second quarter 2015 declined 8.2% to $0.82, compared to the prior year comparable quarter
- Recurring general and administrative expenses(b) for second quarter 2015 were $0.39 per Mcfe, a 64% decrease over the prior year comparable quarter
- Adjusted EBITDAX(b) for second quarter 2015 was $7.5 million
- Net loss of ($0.15) per diluted share reported for second quarter 2015
- Closed on the sale of ~5,210 net leasehold acres in Tyler County, West Virginia, resulting in net cash proceeds of $37.6 million including post-closing adjustments
- ~201,000 net leasehold acres in two core plays, of which ~76,000 net acres located in the Marcellus Shale and ~125,000 net acres located in the Utica Shale
(a) Pro-forma production includes approximately 18.0 MMcfe/d associated with previously shut in production which was turned to sales in late June 2015, relating primarily to the Company’s WVDNR pad.
(b) See Non-GAAP Financial Measures and Reconciliations below.
Financial and Operating Results for the Three Months Ended June 30, 2015
Oil and gas production increased 20% for the three months ended June 30, 2015 to ~11.5 Bcfe (~1.9 MMBoe), or an average of ~126.0 MMcfe (~21.0 MBoe) per day (68% natural gas, 17% NGLs and 15% oil), compared with production of ~9.6 Bcfe (~1.6 MMBoe), or an average of ~105.3 MMcfe (~17.5 MBoe) per day (58% natural gas, 27% oil and 15% NGLs) for the three months ended June 30, 2014. The increase in production was attributable primarily to the Company’s expanded 2014 drilling program in its core areas of operations and higher production volumes from its Marcellus Shale and Utica Shale wells.
Magnum Hunter reported a decrease in oil and gas revenues of 60% to $33.4 million for the three months ended June 30, 2015, compared with $83.8 million for the three months ended June 30, 2014. Revenues decreased during the quarter ended June 30, 2015 due primarily to decreases in the prices received for oil, natural gas and NGLs, partially offset by higher production volumes from the Company’s Marcellus Shale and Utica Shale wells.
The Company reported a net loss of ($30.5) million attributable to common shareholders, or ($0.15) per basic and diluted common shares outstanding, for the three months ended June 30, 2015, compared with a net loss of ($80.0) million, or ($0.43) per basic and diluted common shares outstanding, for the three months ended June 30, 2014. When adjusted for a combination of non-cash expenses and non-recurring gains on asset sales, the Company’s adjusted net loss attributable to common shareholders for the three months ended June 30, 2015 was ($0.23) per basic and diluted common shares outstanding (See Non-GAAP Financial Measures and Reconciliations below).
For the three months ended June 30, 2015, Magnum Hunter’s Adjusted Earnings Before Interest, Taxes, Depreciation, Amortization and Exploration Expense (“Adjusted EBITDAX”) was $7.5 million, compared with $52.3 million for the three months ended June 30, 2014 (See Non-GAAP Financial Measures and Reconciliations below), a decrease of 86%. The decrease in Adjusted EBITDAX was due primarily to the continued dramatic downturn in commodity prices for the quarter ended June 30, 2015. Recurring general and administrative expenses per Mcfe for the three months ended June 30, 2015 decreased 64% to $0.39 per Mcfe from $1.09 per Mcfe for the three months ended June 30, 2014, due primarily to (i) reduced professional services, (ii) reduced reliance on external consultants and (iii) decreased salaries and personnel expenses (See Non-GAAP Financial Measures and Reconciliations below). The Company anticipates that its reliance on third-party consultants will continue to substantially decrease, which, combined with reductions in corporate offices and headcount, will further reduce its recurring general and administrative expenses per Mcfe during the remainder of fiscal year 2015.
Mid-Year 2015 Proved Reserves
As of June 30, 2015, the Company’s estimated total proved reserves were 801.8 Bcfe, compared with estimated total proved reserves at year-end 2014 of 502.5 Bcfe, an increase of approximately 60%. The proved reserves growth was attributable primarily to an increase in proved undeveloped (“PUD”) reserves, resulting from the addition by the Company of 17 new Utica Shale PUD locations and 23 new Marcellus Shale PUD locations. These new PUD locations were the result of recent significant production results from the Company’s Utica Shale and Marcellus Shale acreage positions in Ohio, completion of new drilling units offsetting existing proved developed producing (“PDP”) wells and additional locations within existing PDP units. The Company expects to continue to increase its proved reserves in the Utica Shale, where it presently owns ~125,000 net leasehold acres. The Company continues to work to complete the formation of approximately 54 additional drilling units within its core Utica Shale and Marcellus Shale acreage positions. At June 30, 2015, the Appalachian Basin (including properties in the Marcellus Shale and Utica Shale in West Virginia and Ohio and properties in Kentucky) accounted for approximately 96% of Magnum Hunter’s total proved reserves volumes, and the Williston Basin in North Dakota accounted for the remaining approximately 4% of the Company’s total proved reserves volumes. The proved reserves information for the second quarter of 2015 contained in this press release is estimated based on evaluations conducted by the Company’s internal geological and engineering team, and such information has not been audited or reviewed by the Company’s third-party independent engineering consultants or any other third party.
Capital Expenditures and Existing Liquidity
The Company’s upstream capital expenditure budget for fiscal year 2015 is $100 million. The Company’s upstream capital expenditure budget may be reduced or increased depending on realized prices for its natural gas, NGLs and oil, investment opportunities, continued effective implementation of cost reduction initiatives, including reduction of oil and gas field service costs, and funding allocations. The Company has allocated approximately $70 million of its upstream capital expenditure budget to its Marcellus Shale and Utica Shale exploration and development drilling program in West Virginia and Ohio, approximately $10 million to its properties in the Williston Basin/Bakken Shale in North Dakota (substantially all of which are non-operated) and approximately $20 million for additional leasehold acreage acquisitions in the Marcellus Shale and Utica Shale plays.
For the three months ended June 30, 2015, total upstream capital expenditures were $13.0 million, of which $7.0 million and $2.0 million constituted drilling and completion capital for the Appalachian and Williston Basins, respectively. Leasehold acquisition expenditures for the three months ended June 30, 2015 were $4.0 million, predominately all of which were in the Utica Shale and Marcellus Shale plays. For the six months ended June 30, 2015, total upstream capital expenditures were $60.0 million, of which $26.0 million and $13.0 million constituted drilling and completion capital for the Appalachian and Williston Basins, respectively. Leasehold acquisition expenditures for the six months ended June 30, 2015 were $21.0 million, predominately all of which were in the Utica Shale and Marcellus Shale plays.
Magnum Hunter believes that its internally generated cash flows and additional liquidity sources, including but not limited to proceeds from non-core asset sales, the sale of 100% of its equity interest in Eureka Hunter, potential capital markets transactions and planned strategic initiatives that the Company is actively pursuing, will provide it with sufficient liquidity to fund its fiscal 2015 capital expenditure budget.
On May 7, 2015, the Company terminated certain open “in the money” commodity derivatives positions. Following the May 2015 borrowing base redetermination under the Company’s Senior Revolving Credit Facility, which redetermination took into account the termination of all such open commodity derivatives positions, the Company’s borrowing base under its Senior Revolving Credit Facility was maintained at $50 million. The Company received approximately $11.8 million in cash proceeds from the termination of its open commodity derivatives positions.
Subsequent to June 30, 2015, the Company has entered into a series of new commodity derivatives contracts. As of August 7, 2015, the Company has entered into natural gas costless collars covering 80,000 MMBtu/d with an average floor and ceiling price of $2.66 per MMBtu and $3.15 per MMBtu, respectively, for the remainder of calendar year 2015. In addition, the Company has entered into oil costless collars covering 1,500 Bbl/d with an average floor and ceiling price of $45.00 per Bbl and $48.00 per Bbl, respectively, for the remainder of calendar year 2015. The Company has also entered into a fixed priced swap for August 2015 for 1,500 barrels of oil per day at a price of $44.65 per Bbl.
2015 Liquidity Events
As previously disclosed, the Company has recently completed a leasehold acreage sale and is actively working on a number of other strategic initiatives to enhance the Company’s overall liquidity throughout 2015.
- On June 18, 2015, the Company closed on the sale of certain non-core undeveloped and unproven leasehold acreage located in Tyler County, West Virginia to an independent oil and gas exploration company. At closing, the Company received total consideration of approximately $33.6 million in cash, subject to post-closing adjustments for any title defects and for remediation of asserted title defects. These post-closing adjustments resulted in a net increase in the cash sales price of approximately $4.0 million, which increased the total cash sales price to approximately $37.6 million. The properties sold consisted of ownership interests in approximately 5,210 net leasehold acres and included no existing production or proved reserves.
- As previously disclosed on June 25, 2015, the Company announced its intention to pursue the sale of 100% of its equity ownership interest in Eureka Hunter Holdings, LLC. Based upon current market conditions, the Company believes that a sale of all of its equity interest in Eureka Hunter Holdings could generate approximately $460 – $600 million in cash proceeds to Magnum Hunter. The Company is in discussions with a number of third parties regarding this potential sale transaction.
- Magnum Hunter is currently negotiating with a third party regarding a joint venture pursuant to which the Company would contribute certain Utica Shale unproved, undeveloped leasehold acreage located in Ohio and in return would receive a combination of up-front cash and funding for future capital expenditures to develop the acreage in the total amount of approximately $450 million.
- The Company is working to establish an asset management agreement for the marketing by a third party of certain of the Company’s natural gas production whereby the third party will also agree to provide credit support to certain interstate pipeline companies in replacement of the Company’s firm transportation letters of credit, resulting in the cancellation of the letters of credit and a corresponding increase in borrowing capacity under the Company’s Senior Revolving Credit Facility of ~$39.0 million.
- The Company maintains a shelf registration statement on Form S-3 that was declared effective by the Securities and Exchange Commission on April 22, 2015. As of August 6, 2015 the Company has raised approximately $31.1 million in net proceeds from the issuance of common stock.
2015 Production and Capital Guidance Update
As previously disclosed in connection with Magnum Hunter’s 2015 production guidance, the Company expects average daily production for 2015 of approximately 174 – 198 MMcfe/d (29.0 – 33.0 MBoe/d). Contingent on closing of the liquidity initiatives referred to above, along with anticipated further service cost reductions, the Company plans to begin certain completion operations in West Virginia and Ohio.
During the second quarter of 2015, the Company had a significant amount of production shut-in as it removed temporary production facilities and installed permanent facilities on certain pads. The notable shut-in pads during the second quarter included the WVDNR Pad #6, located in Wetzel County, West Virginia, which was shut-in for the majority of the second quarter and returned to sales on June 27, 2015. This shut-in affected seven of the Company’s Marcellus Shale wells, and associated production of approximately 31,800 Mcfe/d. In addition, several wells on the Company’s Stalder Pad, located in Monroe County, Ohio, were shut-in from mid-May 2015 until early June 2015. These dry Utica Shale wells could account for approximately 28,000 Mcfe/d of production. Furthermore, the Stalder #2MH and #3UH were shut in for the entire second quarter of 2015 and are planned to return to sales in the third quarter of 2015.
Magnum Hunter currently has approximately 44 net horizontal wells producing from the Marcellus Shale. As of January 1, 2015, Magnum Hunter chose to stop all drilling and completion operations in the Marcellus Shale play due to the drop in commodity prices and the expectation that a significant reduction in service related costs would occur. The Company has five new Marcellus Shale wells which have been top hole drilled in West Virginia but not yet completed.
Magnum Hunter currently has four net horizontal wells producing from the Utica Shale. As of January 1, 2015, Magnum Hunter chose to stop all drilling and completion operations due to the drop in commodity prices and the expectation that a significant reduction in service related costs would occur. Two net Utica Shale wells have been drilled, and three net Utica Shale wells are in various stages of the drilling and completion phase. The Company anticipates these wells will be put on production prior to year-end 2015.
Magnum Hunter’s average realized natural gas price for the second quarter of 2015 was $1.67 per Mcf, a $1.06 per Mcf negative differential to the average NYMEX price for the period. Magnum Hunter’s average realized oil price for the second quarter of 2015 was $52.31 per barrel, a $7.51 per barrel negative differential to the average WTI price for the period. Magnum Hunter’s average realized NGLs price for the second quarter of 2015 was $16.51 per barrel, or ~28% of the average WTI price for the period.
Eureka Hunter Pipeline
Eureka Hunter Pipeline is currently gathering approximately 650,000 MMBtu per day of natural gas. Eureka Hunter is continuing to expand the pipeline infrastructure throughout Monroe and Washington Counties in Ohio and Ritchie County, West Virginia. Also, an additional compressor station installed at Tallgrass’s REX pipeline has given Eureka Hunter the ability to move approximately 600,000 MMBtu at this pipeline interconnect. Eureka Hunter anticipates gathering volumes to approximate 900,000 MMBtu per day by the end of 2015. As previously disclosed, the Company has announced its intention to pursue the sale of 100% of its equity ownership interest in Eureka Hunter Holdings. Offers have been received and negotiations with third parties are continuing.
Mr. Gary C. Evans, Chairman of the Board and Chief Executive Officer of Magnum Hunter, commented, “The energy industry continues to experience serious headwinds that predominantly revolve around low commodity prices. We recognized this early and subsequently stopped all drilling and completion operations at the beginning of the year. We continue in a capital preservation mode until we complete the various projects we have been working on to enhance our balance sheet and capital position. These include a Utica joint venture and the sale of our equity ownership interest in our mid-stream division, Eureka Hunter. Our goal is to substantially reduce our overall indebtedness and fixed charges. In preparation of these events, we hired a new Executive Vice President and Chief Operating Officer, Keith Yankowsky, which was announced late yesterday. We recognized that to be successful during a possible extended low commodity price environment, we have to be “best in class”. We have assembled over 200,000 net acres of high quality leases in West Virginia and Ohio. Now we must drive economics by reducing our all-in funding costs and increasing our ultimate recoveries on each well drilled. We should be able to discover reserves in this region, due to superior rock quality, at finding costs as low as any other part of the country. We are positioning ourselves to be able to accomplish this goal which will significantly add to shareholder value.”
Non-GAAP Financial Measures
This release contains certain financial measures that are non-GAAP measures. We have provided reconciliations within this release of the non-GAAP financial measures to the most directly comparable GAAP financial measures. These non-GAAP financial measures should be considered in addition to, but not as a substitute for, measures for financial performance prepared in accordance with GAAP that are presented in this release.
Magnum Hunter defines adjusted income (loss) as reported net income (loss) attributable to common shareholders, plus non-recurring and non-cash items which include (i) exploration expense, (ii) impairment of proved oil and gas properties, (iii) impairment of other operating assets, (iv) non-cash stock compensation expense, (v) non-cash 401k matching expense, (vi) non-recurring transaction and other expense, (vii) unrealized (gain) loss on investments, (viii) interest expense – fees, (ix) unrealized (gain) loss on derivatives, (x) (gain) loss on sale of assets, (xi) income tax expense (benefit), (xii) gain on dilution of interest in Eureka Hunter Holdings, (xiii) (gain) loss from sale of discontinued operations and (xiv) income from discontinued operations.
Magnum Hunter defines Adjusted EBITDAX as net income (loss) from continuing operations before (i) net interest expense, (ii) (gain) loss on sale of assets, (iii) depletion, depreciation, amortization and accretion, (iv) impairment of proved oil and gas properties, (v) impairment of other operating assets, (vi) exploration expense, (vii) non-cash stock compensation expense, (viii) non-cash 401k matching expense, (ix) non-recurring transaction and other expense, (x) unrealized (gain) loss on investments, (xi) income tax expense (benefit) and (xii) unrealized (gain) loss on derivatives. Adjusted EBITDAX is not a measure of net income or cash flows as determined by GAAP.
Magnum Hunter defines recurring cash G&A as total general and administrative expenses before (i) non-cash stock compensation and (ii) acquisition and other non-recurring expense.
Management believes these non-GAAP financial measures facilitate evaluation of the Company’s business on a “normalized” or recurring basis and without giving effect to certain non-cash expenses and other items, thereby providing management, investors and analysts with comparative information for evaluating the Company in relation to other oil and gas companies providing corresponding non-GAAP financial measures. These non-GAAP financial measures should be considered in addition to, but not as a substitute for, measures for financial performance prepared in accordance with GAAP, and the reconciliations to the closest corresponding GAAP measure should be reviewed carefully. (Original Source)
Shares of Magnum Hunter Resources closed yesterday at $0.82. MHR has a 1-year high of $6.94 and a 1-year low of $0.70. The stock’s 50-day moving average is $1.35 and its 200-day moving average is $2.00.
On the ratings front, Magnum Hunter has been the subject of a number of recent research reports. In a report issued on July 14, KeyBanc analyst David Deckelbaum maintained a Buy rating on MHR, with a price target of $2.50, which represents a potential upside of 204.9% from where the stock is currently trading. Separately, on June 9, Imperial’s Kim Pacanovsky downgraded the stock to Sell and has a price target of $1.25.
According to TipRanks.com, which ranks over 7,500 financial analysts and bloggers to gauge the performance of their past recommendations, David Deckelbaum and Kim Pacanovsky have a total average return of -31.0% and -44.3% respectively. Deckelbaum has a success rate of 10.7% and is ranked #3703 out of 3728 analysts, while Pacanovsky has a success rate of 11.9% and is ranked #3726.
The street is mostly Neutral on MHR stock. Out of 4 analysts who cover the stock, 3 suggest a Hold rating and one recommends to Buy the stock.
Magnum Hunter Resources Corporation is an oil and exploration and production company. The Company is engaged in exploration, acquisition, development and production of crude oil, natural gas and NGLs resources in the United States and Canada.