Petrohawk Announces First Quarter 2010 Financial and Operating Results
HOUSTON, May 5 /PRNewswire-FirstCall/ — Petrohawk Energy Corporation (“Petrohawk” or the “Company”) (NYSE: HK) today announced first quarter 2010 operating and financial results, including updated production and cost detail associated with recently announced divestitures and updated liquidity estimates, as well as the Company’s forecast for increased oil and liquids production from the Eagle Ford Shale.
Quarterly Financial and Operational Performance
During the first quarter, Petrohawk reported production of approximately 625 million cubic feet of natural gas equivalent per day (Mmcfe/d) versus a guidance midpoint of 620 Mmcfe/d and fourth quarter 2009 production of 598 Mmcfe/d. Of the 56,269 Mmcfe produced during the quarter, approximately 97% was natural gas. Second quarter production is expected to range between 610 and 620 Mmcfe/d, adjusted for asset sales scheduled to close during the quarter. Full year 2010 guidance remains unchanged at average production of 650 to 660 Mmcfe/d.
During the first quarter, Petrohawk generated operating revenues of $440 million and cash flows from operations before changes in working capital of approximately $184 million, or $0.61 per fully diluted common share (cash flow from operations before changes in working capital is a non-GAAP financial measure).
At the wellhead and before the effect of hedges, Petrohawk realized 97% of NYMEX for natural gas production and 96% of NYMEX for crude oil production. Cash flows were also bolstered by the Company’s hedging program. First quarter revenues included a realized cash derivative gain of $25 million. During the quarter, Petrohawk gained $0.46 per million cubic feet of natural gas (Mcf) from hedging, bringing realized natural gas prices to $5.61 per Mcf. The Company lost $2.13 per barrel of oil from hedges during the quarter, bringing realized oil prices to $73.16 per barrel.
After adjusting for the effects of an unrealized gain on derivatives, net income for the quarter was $0.13 per fully diluted share, or $39.9 million after tax (see Selected Item Review and Reconciliation table for additional information). Before excluding selected items, the Company reported net income of $156.1 million, or $0.52 per fully diluted share, for the quarter.
Cash costs (including lease operating, gathering and transportation, production taxes, workover, general and administrative, and interest expense) were $2.72 per Mcfe for the quarter. Lease operating expense was $0.31 per Mcfe, a $0.10 per Mcfe decrease from the prior quarter, partially due to divestitures. General and administrative expenses of $0.50 per Mcfe included a $5 million accrual for legal expenses. Taxes other than income of $0.23 per Mcfe included state tax rebates that brought this item below guidance levels for the quarter. Gathering and transportation expense was $0.52 per Mcfe for the quarter, and depletion, depreciation and amortization (DD&A) expense, a non-cash item, was $1.89 per Mcfe during the quarter.
Capital Expenditure and Liquidity Update
Petrohawk spent $376 million, or approximately 28% of its $1.35 billion budget, on drilling, completions and workovers during the quarter. Petrohawk closed approximately $306 million in leasehold acquisitions during the first quarter, including: 1) acreage in Red Hawk and Black Hawk prospects in the Eagle Ford Shale, primarily funded through 2009 like-kind exchange proceeds; 2) Haynesville Shale acreage, most of which was contracted during 2009, and also funded through 2009 like-kind exchange proceeds; 3) tack-on acreage in Hawkville Field in the Eagle Ford Shale; and 4) additional acreage outside of the Company’s current core operating areas. Based on current prospects and greater than expected proceeds from asset sales, Petrohawk expects its total 2010 expenditures on leasehold and related acquisitions to be approximately $500 million.
During the fourth quarter of 2009, Petrohawk announced plans to sell approximately $1 billion in assets. To date, the Company has announced agreements to sell approximately $1.37 billion in properties, including its interests in WEHLU and Terryville Fields, as well as a 50% interest in the Haynesville Shale midstream business of Hawk Field Services to Kinder Morgan Energy Partners, LP, creating the new entity KinderHawk Field Services. The process to sell additional non-core properties in the mid-continent region will begin during the third quarter of 2010. Both the midstream transaction and the sale of Terryville Field are expected to close by May 28, 2010. The sale of interests in WEHLU Field, for $155 million, closed on April 30, 2010. Proceeds for divestitures announced during 2010 to date, net of tax, are currently estimated to be approximately $1.27 billion.
The capital budget of Petrohawk’s midstream subsidiary, Hawk Field Services, has been adjusted to $280 million for 2010. Adjustments take into consideration the announced sale of a 50% stake in the Company’s Haynesville Shale midstream business as well as additional infrastructure in the Eagle Ford Shale, including the construction of liquids gathering lines and condensate stabilizing plants to service the Hawkville and Black Hawk areas.
On April 30, Petrohawk concluded the approval process for its credit facility redetermination, which provides for a borrowing base of approximately $1.1 billion allocated to oil and gas reserves and the Company’s gathering business in the Fayetteville and Eagle Ford Shales. This amount accounts for divestitures announced during 2010, and an estimated reduction for the Haynesville Shale midstream business, which is expected to have its own credit facility. Petrohawk’s liquidity at the end of the first quarter was approximately $600 million. Liquidity at the end of 2010 is expected to be approximately $1.2 billion.
During the first quarter, Petrohawk drilled 169 gross wells, of which 36 were operated, with a ~99% success rate. Of the total, 71 were in the Haynesville Shale, 11 in the Eagle Ford Shale and 73 in the Fayetteville Shale.
Q1 2010 Operational Statistics
Fayetteville Haynesville Shale Eagle Ford Shale Shale Operated Wells Drilled 25 10 1 Non-operated Wells Drilled 46 1 72 Total Wells Drilled 71 11 73 Average Operated Rigs Running 17 8 1 2.7 Mmcf/d + 930 Average Bo/d on a 12/64" (1 Operated Well 7.7 Mmcf/d on 14/ well) IP (Mmcfe/d) 64" (13 wells) 6.4 Mmcf/d on WOPL 13.5 Mmcf/d on 18/ a 17/64" (1 well) 64" (3 wells) 7.5 Mmcf/d on 22.7 Mmcf/d on 24/ 24/64" 64" (3 wells) (2 wells) 2010 Target Cost per Operated Well (Drill & Complete) ($MM) $9.0-9.5 $6.0 $3.0
In the first quarter the Company continued to execute its plan of lease capture in the Haynesville Shale. Continued efficiencies are driving down the spud to spud days, which have resulted in more flexibility in its Haynesville Shale drilling program. Petrohawk intends to utilize fourteen operated rigs for the balance of 2010. The forecasted number of operated wells, approximately 110, is expected to remain the same as under the previous budget due to the increased drilling efficiencies.
Additionally, the Company continues to experience positive results from its completion program. A sample set of wells in the Coushatta area in Red River Parish shows a definitive trend of declining completion cost per Mcf of Estimated Ultimate Recovery (EUR) in conjunction with an improving Mcf of EUR per foot of lateral length. Petrohawk will continue to test all aspects of the completion design in the attempt to optimize both performance and cost.
The Company’s expanded restricted rate program, including both newly drilled wells and wells drilled prior to 2010, continues to yield positive results that indicate improvement in both first year production totals and EUR. As of the end of the first quarter all newly completed wells will be produced at a restricted rate, typically between 7 and 13 Mmcfe/d. The trend noted in the decline curves from the older wells that have been producing on restricted rate, the oldest of which is now over nine months, suggests potential increases in EUR, some significant, as compared to nearby wells produced using conventional production practices.
A companion program of the restricted rate program is an initiative to restrict production from already-producing Haynesville Shale wells. A group of test wells were selected, typically producing on a 24/64″ choke, and placed on a 14/64″ choke. The results from these wells show flatter decline curves that not only model to a potentially higher EUR, but in aggregate also model a flatter overall PDP decline for the Company in future years. Petrohawk now plans to restrict the rates of all Haynesville Shale wells.
Lower Bossier Shale
The first Petrohawk operated Lower Bossier Shale well, the Whitney Corp 19 #1H, will spud during May in Section 19-T10N-R13W, Sabine Parish, Louisiana. This well is located in proximity to a number of recently completed wells which tested the Lower Bossier Shale at rates and pressures comparable to many of the field’s better Haynesville Shale wells. Hawk Field Services is in the final stages of completing a pipeline into this area and the Company expects to place the well on production upon completion.
Eagle Ford Shale
Petrohawk has expanded its position in the Eagle Ford trend, where it is currently operating 8 rigs, to include three distinct areas of development: Hawkville, Black Hawk and Red Hawk. Each of these areas has different production profiles which all provide the opportunity for large scale development. The Company forecasts that with the current capital budget allocation in 2010, and a modest increase in drilling capital allocated to the Eagle Ford Shale in 2011, oil and natural gas liquids production is expected to increase significantly to approximately 15%-20% of total production by the end of 2011. Currently, oil and natural gas liquids production is approximately 3% of Petrohawk’s total production.
The Hawkville Field, in La Salle and McMullen Counties, Texas, is expected to continue its role as the core commercial production area for natural gas and liquids. With approximately 25 wells on production, the bounds of Hawkville Field production are expanding to the east and north. The initial well in the Joint Venture with Swift Energy was successfully completed during the first quarter. The Bracken JV #1H initially tested at a rate of 9.0 Mmcfe/d on a 24/64″ choke. The well’s production rate was subsequently restricted temporarily, awaiting the installation of further production facilities, to a choke setting of 17/64″ at a rate of 6.4 Mmcfe/d with a stable flowing casing pressure (“FCP”) of 5500#. The second well in the Joint Venture is waiting on completion and the third well is drilling.
The third well in the Black Hawk prospect in Dewitt County, Texas, the Kickendahl #1H, was recently completed at a rate of 3.1 Mmcf/d and 745 Bc/d on a 12/64″ choke with 7,550# flowing casing pressure. This result is very similar to the first two wells that have been completed, even though the well was still cleaning up and the rate was increasing at the time of the report. The fourth well to be completed will be the Krause #2H. Its lateral length is approximately 5900′, and it is the first well in the prospect with an extended lateral length. Its completion is scheduled for mid-May.
In the Red Hawk prospect in Zavala County, Texas, the Company is drilling ahead on its second well, the Mustang Ranch “C” #1H. It is anticipated that the well will be completed within the next 30 days.
To date, Hawk Field Services has completed construction of approximately 65 miles of primarily 16″ pipe in the Eagle Ford Shale. An additional 100 miles of gas gathering line, 15 miles of condensate gathering line and 60 miles of liquids gathering lines are budgeted for construction during the remainder of 2010. The Company also expects to increase treating capacity in the Hawkville Field area by installing another 150 gallons per minute (GPM) amine plant, increasing Petrohawk’s total treating capacity to 250 GPM in the Eagle Ford Shale. An additional 12,500 barrels of condensate stabilization capacity are scheduled to be added to plant sites in both the Black Hawk and Hawkville areas during 2010.
Petrohawk Analyst Day
Petrohawk will host an analyst day on Monday, May 24, 2010. To access the live webcast and accompanying slide presentation, visit the Company’s website at www.petrohawk.com at 8:00 AM CDT (9:00 AM EDT) on May 24. For those unable to listen to the live webcast, a replay will be available following the conference and can also be accessed at www.petrohawk.com. Materials to accompany the management presentation will be posted to Petrohawk’s website on the morning of May 24.
Petrohawk Earnings Conference Call and Webcast
Petrohawk will host a conference call tomorrow, Wednesday, May 5, 2010, at 11:30 a.m. EDT (10:30 a.m. CDT) to discuss first quarter 2010 financial and operating results. To access, dial 888-686-9685 five to ten minutes before the call begins. Please reference Petrohawk Energy Conference ID 4561087. International callers may also participate by dialing 913-312-1497. A replay of the call will be available approximately two hours after the live broadcast ends and will be accessible until May 12, 2010. To access the replay, please dial 888-203-1112 and reference conference ID 4561087. International callers may listen to a playback by dialing 719-457-0820. In addition, the call will be webcast live on Petrohawk’s website at http://www.petrohawk.com. A replay of the call will be available at that site through May 12, 2010.
Petrohawk Energy Corporation is an independent energy company engaged in the acquisition, production, exploration and development of natural gas and oil with properties concentrated in North Louisiana, Arkansas, East Texas and South Texas.
For more information contact Joan Dunlap, Vice President – Investor Relations, at 832-204-2737 or firstname.lastname@example.org. For additional information about Petrohawk, please visit our website at www.petrohawk.com.
Additional Information for Investors
This press release contains forward-looking information regarding Petrohawk that is intended to be covered by the safe harbor “forward-looking statements” provided by the Private Securities Litigation Reform Act of 1995, based on Petrohawk’s current expectations and forward-looking statements include statements regarding estimates of future production, capital expenditures and results of operations, and other statements reflecting expectations, beliefs, plans, objectives, assumptions, strategies or statements about future events or performance (often, but not always, using words such as “expects”, “anticipates”, “plans”, “estimates”, “potential”, “possible”, “probable”, or “intends”, or stating that certain actions, events or results “may”, “will”, “should”, or “could” be taken, occur or be achieved) and include, without limitation, estimated production for and 2010 and estimated and 2010 capital expenditures. Management’s assumptions and future performance are subject to a wide range of business risks, uncertainties and actual levels of capital expenditures, and there is no assurance that these projections can or will be met. Forward-looking statements are based on current expectations, estimates and projections that involve a number of risks and uncertainties, which could cause actual results to differ materially from those reflected in these statements. These risks include, but are not limited to: the risks of the oil and gas industry (for example, operational risks in exploring for, developing and producing crude oil and natural gas; risks and uncertainties involving geology of oil and gas deposits; risks associated with the timing of potential proceeds from divestitures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to future production, costs and expenses; potential delays or changes in plans with respect to exploration or development projects or capital expenditures; health, safety and environmental risks and risks related to weather such as hurricanes and other natural disasters); uncertainties as to the availability and cost of financing; fluctuations in oil and gas prices; uncertainties related to acquisitions and divestitures; risks associated with derivative positions; inability of our management team to execute its plans to meet its goals, shortages of drilling equipment, oil field personnel and services, unavailability of gathering systems, pipelines and processing facilities and the possibility that government policies may change or governmental approvals may be delayed or withheld. Additional information on these and other factors which could affect Petrohawk’s operations or financial results are included in the section entitled “Risk Factors” in Petrohawk’s Annual Report on Form 10-K and its reports on Form 10-Q on file with the SEC. Investors are cautioned that any forward-looking statements are not guarantees of future performance and actual results or developments may differ materially from the expectations in the forward-looking statements. Forward-looking statements are based on the estimates and opinions of management at the time the statements are made. Petrohawk does not assume any obligation to update forward-looking statements should circumstances or management’s estimates or opinions change.
PETROHAWK ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (In thousands, except per share amounts)
Three Months Ended March 31, ---------------------------- 2010 2009 ---- ---- Operating revenues: Oil and natural gas $300,591 $167,554 Marketing 130,119 89,693 Midstream 9,606 6,208 Total operating revenues 440,316 263,455 ------- ------- Operating expenses: Marketing 136,622 84,844 Production: Lease operating 17,395 16,411 Workover and other 2,378 723 Taxes other than income 12,843 12,180 Gathering, transportation and other: Oil and natural gas 22,289 17,738 Midstream 7,091 2,756 General and administrative: General and administrative 28,119 16,829 Stock-based compensation 4,089 2,810 Depletion, depreciation and amortization 106,074 114,256 Full cost ceiling impairment - 1,732,486 Total operating expenses 336,900 2,001,033 ------- --------- Income (loss) from operations 103,416 (1,737,578) Other income (expenses): Net gain on derivative contracts 214,703 181,922 Interest expense and other (62,846) (56,068) Total other income (expenses) 151,857 125,854 ------- ------- Income (loss) before income taxes 255,273 (1,611,724) Income tax (provision) benefit (99,138) 611,971 ------- ------- Net income (loss) $156,135 $(999,753) ======== ========= Net income (loss) per share: Basic $0.52 $(3.87) ===== ====== Diluted $0.52 $(3.87) ===== ====== Weighted average shares outstanding: Basic 300,157 258,055 ======= ======= Diluted 302,668 258,055 ======= =======
PETROHAWK ENERGY CORPORATION CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (In thousands)
March 31, December 31, --------- ------------ 2010 2009 ---- ---- Assets: Current assets $550,422 $385,650 Net oil and natural gas properties 4,739,828 4,167,733 Restricted cash 36,176 213,704 Assets held for sale 387,251 - Other noncurrent assets 1,615,313 1,894,984 --------- --------- Total assets $7,328,990 $6,662,071 ========== ========== Liabilities and stockholders' equity: Current liabilities $819,039 $698,832 Long-term debt 2,977,425 2,592,544 Other noncurrent liabilities 49,720 47,023 Stockholders' equity 3,482,806 3,323,672 --------- --------- Total liabilities and stockholders' equity $7,328,990 $6,662,071 ========== ==========
PETROHAWK ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (In thousands)
Three Months Ended March 31, ---------------------------- 2010 2009 ---- ---- Cash flows from operating activities: Net income (loss) $156,135 $(999,753) Adjustments to reconcile net income (loss) to net cash provided by operating activities: Depletion, depreciation and amortization 106,074 114,256 Full cost ceiling impairment - 1,732,486 Income tax provision (benefit) 99,138 (611,971) Stock-based compensation 4,089 2,810 Net unrealized gain on derivative contracts (190,095) (100,765) Other operating 8,349 4,921 ----- ----- Cash flow from operations before changes in working capital 183,690 141,984 Changes in working capital (29,518) 14,374 ------- ------ Net cash provided by operating activities 154,172 156,358 ------- ------- Cash flows from investing activities: Oil and natural gas capital expenditures (638,999) (390,674) Proceeds received from sale of oil and natural gas properties 16,676 - Marketable securities purchased (226,000) (604,045) Marketable securities redeemed 226,000 444,016 Decrease in restricted cash 177,528 - Other operating property and equipment expenditures (72,591) (69,709) ------- ------- Net cash used in investing activities (517,386) (620,412) -------- -------- Cash flows from financing activities: Proceeds from exercise of stock options and warrants 503 657 Proceeds from issuance of common stock - 385,000 Offering costs - (8,988) Proceeds from borrowings 571,000 619,674 Repayment of borrowings (204,968) (524,324) Debt issuance costs - (13,154) Other (3,439) - ------ --- Net cash provided by financing activities 363,096 458,865 ------- ------- Net decrease in cash (118) (5,189) Cash at beginning of period 1,511 6,883 ----- ----- Cash at end of period $1,393 $1,694 ====== ======
PETROHAWK ENERGY CORPORATION SELECTED OPERATING DATA (Unaudited) (In thousands, except per share amounts)
Three Months Ended March 31, ---------------------------- 2010 2009 ---- ---- Production: Natural gas - Mmcf 54,823 34,591 Crude oil - MBbl 241 414 Natural gas equivalent - Mmcfe 56,269 37,075 Daily production - Mmcfe 625 412 Average price per unit: Realized oil price - as reported $75.29 $38.10 Realized impact of derivatives (2.13) 5.51 ----- ---- Net realized oil price (Bbl) $73.16 $43.61 Realized gas price - as reported 5.15 4.36 Realized impact of derivatives 0.46 2.28 ---- ---- Net realized gas price (Mcf) $5.61 $6.64 Cash flow from operations (1) 183,690 141,984 Cash flow from operations - per share (diluted) 0.61 0.55 Average cost per Mcfe: Production: Lease operating 0.31 0.44 Workover and other 0.04 0.02 Taxes other than income 0.23 0.33 Gathering, transportation and other: Oil and natural gas 0.40 0.48 Midstream 0.12 0.07 General and administrative: General and administrative 0.50 0.45 Stock-based compensation 0.07 0.08 Depletion 1.78 3.00
(1) Represents cash flow from operations before changes in working capital. See the Consolidated Statements of Cash Flows for a reconciliation from this non-GAAP financial measure to the most comparable GAAP financial measure.
PETROHAWK ENERGY CORPORATION SELECTED ITEM REVIEW AND RECONCILIATION (Unaudited) (In thousands, except per share amounts)
Three Months Ended March 31, ---------------------------- 2010 2009 ---- ---- Unrealized (gain) loss on derivative contracts:(1) Natural gas $(190,884) $(102,156) Crude oil 789 1,391 --- ----- Total mark-to-market noncash charge (190,095) (100,765) Full cost ceiling impairment - 1,732,486 Expense of deferred financing costs(2) - 911 --- --- Total selected items, before tax (190,095) 1,632,632 Income tax effect of selected items 73,833 (620,890) ------ -------- Selected items, net of tax (116,262) 1,011,742 Net income (loss), as reported 156,135 (999,753) Net income, excluding selected items $39,873 $11,989 ======= ======= Basic net income (loss) per share, as reported $0.52 $(3.87) Impact of selected items (0.39) 3.92 ----- ---- Basic net income per share, excluding selected items $0.13 $0.05 ===== ===== Diluted net income (loss) per share, as reported $0.52 $(3.87) Impact of selected items (0.39) 3.89 ----- ---- Diluted net income per share, excluding selected items $0.13 $0.02 ===== =====
(1) Represents the unrealized (gain) loss associated with the mark- to-market valuation of outstanding derivative positions at March 31, 2010 and 2009. (2) Represents non-cash charges related to the write-off of debt issue costs in conjunction with decreases in the Company's borrowing base under its senior revolving credit facility.
SOURCE Petrohawk Energy Corporation