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Petrohawk Energy Corp. Reports Operating Results (10-Q)
Posted by: gurufocus (IP Logged)
Date: August 3, 2011 07:02AM

Petrohawk Energy Corp. (HK) filed Quarterly Report for the period ended 2011-06-30. Petrohawk Energy Corp. has a market cap of $11.59 billion; its shares were traded at around $38.14 with a P/E ratio of 79.5 and P/S ratio of 7.3.



Highlight of Business Operations:

allocated for potential acquisitions. Our estimated capital expenditures for drilling and completions was increased to $2.0 billion, our budget for potential acquisitions was increased to $600 million due to our addition of acreage in the Permian Basin as discussed above, and our budget for midstream operations was increased to $250 million to accomodate accelerated operations in the Eagle Ford Shale. Of the $2.0 billion budget for drilling and completions, $950 million is planned for the Haynesville and Lower Bossier Shales, which we expect will fulfill our lease-holding goals, $950 million is budgeted for the Eagle Ford Shale, $75 million is planned for the Permian Basin and $25 million is planned for various other projects. Our 2011 drilling and completion budget contemplates an increase in drilling activity in the Eagle Ford Shale throughout the year, a significant decrease in the Haynesville Shale operated rig count in the second half of the year as our lease-holding activities are substantially completed, and the beginning of the development of our new Permian Basin acreage. Our 2011 program will emphasize the development of our extensive condensate-rich properties, largely in the Eagle Ford Shale, and a shift away from dry gas development in our core areas. Our drilling and completion budget for 2011 is based on our current view of market conditions, our objective of accelerating development of certain areas of our Eagle Ford Shale position, and our desire to reduce capital allocated to pure natural gas drilling once our Haynesville Shale lease-holding activities are effectively completed.

On April 29, 2011, we amended our Senior Credit Agreement, the Fifth Amended and Restated Senior Revolving Credit Agreement, as amended on November 8, 2010 and December 22, 2010, by entering into the Third Amendment to the Fifth Amended and Restated Senior Revolving Credit Agreement (the Third Amendment), among us, each of the lenders from time to time party thereto (the Lenders), BNP Paribas, as administrative agent for the Lenders, Bank of America, N.A. and Bank of Montreal as co-syndication agents for the Lenders, and JPMorgan Chase Bank, N.A. and Wells Fargo Bank, N.A., as co-documentation agents for the Lenders. Among other things, the Third Amendment: (a) increased our borrowing base to $1.9 billion, $1.8 billion of which related to our oil and natural gas properties and $100 million of which related to our midstream assets (limited as described below); (b) reduced interest rates such that amounts outstanding under the Senior Credit Agreement will bear interest at specified margins over the London Interbank Offered Rate (LIBOR) of 1.50% to 2.50% for Eurodollar loans or at specified margins over the Alternate Base Rate (ABR) of 0.50% to 1.50% for ABR loans, which margins will fluctuate based on the utilization of the facility; (c) extended the maturity date of the facility from July 1, 2014 to July 1, 2016; and (d) increased the amount of the facility from $2.0 billion to $2.5 billion. The portion of the Senior Credit Agreement's borrowing base which relates to our oil and natural gas properties is redetermined on a semi-annual basis (with us and the lenders each having the right to one annual interim unscheduled redetermination) and adjusted based on our oil and natural gas properties, reserves, other indebtedness and other relevant factors. The component of the borrowing base related to our midstream assets is limited to the lesser of $100 million or 3.5 times midstream EBITDA and is calculated quarterly. As of June 30, 2011, the full capacity of the midstream component of the borrowing base was available. Our ability to utilize the full amount of our borrowing capacity is influenced by a variety of factors, including redeterminations of our borrowing base, and covenants under our Senior Credit Agreement and our senior unsecured debt indentures. Additionally, our borrowing base is subject to a reduction equal to the product of $0.25 multiplied by the stated principal amount (without regard to any initial issue discount) of any unsecured senior or senior subordinated notes that we may issue. In connection with the issuance of our 6.25% $600 million senior notes due 2019, as described above, our lenders waived the automatic reduction of our borrowing base. As a result, our borrowing base under the Senior Credit Agreement remained at $1.9 billion upon the issuance of the 2019 Notes.

On December 22, 2010, we completed the sale of our interest in natural gas properties and other operating property and equipment in the Fayetteville Shale for $575 million in cash, before customary closing adjustments. Proceeds from the sale of the interest in natural gas properties were recorded as a reduction to the carrying value of our full cost pool with no gain or loss recorded. In conjunction with the sale of the other operating property and equipment, we recorded a loss of approximately $0.5 million in the year ended December 31, 2010. On January 7, 2011, we completed the sale of our midstream assets in the Fayetteville Shale for approximately $75 million in cash, before customary closing adjustments. Both transactions had an effective date of October 1, 2010. During the first six months of 2011, we have made no cash contributions to KinderHawk and have received distributions of $36.2 million, which are recorded in cash flows from operating activities.

On January 31, 2011, we completed the issuance of an additional $400 million aggregate principal amount of our 7.25% senior notes due 2018. The additional 2018 Notes are a subsequent aggregate principal issue of our outstanding 7.25% senior notes due 2018 which were issued in an aggregate principal amount of $825 million on August 17, 2010, the initial 2018 Notes. The net proceeds from the sale of the additional 2018 Notes were approximately $400.5 million, after deducting offering fees and expenses. A portion of the proceeds of the additional 2018 Notes were utilized to redeem our 7.125% $275 million senior notes due 2012 on March 17, 2011.

During the six months ended June 30, 2011, we capitalized approximately $24.9 million of certain direct costs associated with the issuance of our long-term debt. We capitalized approximately $10.9 million in costs associated with the issuance of the 2019 Notes. We capitalized approximately $7.4 million of debt issuance costs in conjunction with the issuance of the additional 2018 Notes. We also capitalized approximately $6.6 million of direct costs associated with the amendments to our Senior Credit Agreement.

natural gas delivered at KinderHawk's receipt points. The treating fee is charged for gas delivered containing more than 2% by volume of carbon dioxide. For gas delivered containing between 2% and 5.5% carbon dioxide, the treating fee is between $0.030 and $0.345 per Mcf, and for gas containing over 5.5% carbon dioxide, the treating fee starts at $0.365 per Mcf and increases on a scale of $0.09 per Mcf for each additional 1% of carbon dioxide content. In the event that annual natural gas deliveries are ever less than the minimum annual quantity per contract year set forth in the table above, our true-up fee obligation would be determined by subtracting the volumes delivered from the minimum annual quantity for the applicable contract year and multiplying the positive difference by the sum of the gathering fee in effect on the last day of such year plus the average monthly treating fees for such year. For example, if the quantity of natural gas delivered in 2011 were 50 Bcf less than the minimum annual quantity for such year and the year-end gathering fee was $0.34 per Mcf and the average treating fee for the period was $0.345 per Mcf, the true-up fee would be $34.3 million.

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