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Petrohawk Energy Corp. Reports Operating Results (10-Q)
Posted by: gurufocus (IP Logged)
Date: May 5, 2011 06:20AM
Petrohawk Energy Corp. (HK) filed Quarterly Report for the period ended 2011-03-31.
Highlight of Business Operations:
Our 2011 capital budget is focused on the development of non-proved reserve locations in our Haynesville, Lower Bossier, and Eagle Ford Shale plays so that we can hold our acreage in these areas. Capital spending for 2011 was initially estimated at $2.3 billion, of which $1.9 billion was allocated for drilling and completions, $200 million was allocated for midstream operations and $200 million was allocated for potential acquisitions. Our estimated capital expenditures for drilling and completions is increasing to $2.0 billion, our budget for potential acquisitions will increase to $600 million due to our addition of the Permian Basin as a new core operating area as discussed above, and our budget for midstream operations will increase 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 will enable us to fulfill our held-by-production 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.
Our future capital resources and liquidity depend, in part, on our success in developing our leasehold interests. Cash is required to fund capital expenditures necessary to offset inherent declines in our production and proven reserves, which is typical in the capital-intensive oil and natural gas industry. Future success in growing reserves and production will be highly dependent on our capital resources and our success in finding additional reserves. During the third quarter of 2010, we issued our initial 2018 Notes which consisted of $825 million aggregate principal amount of our 7.25% senior notes due 2018. On January 31, 2011, we completed the issuance of the additional 2018 Notes which were issued in an aggregate principal amount of $400 million. The additional 2018 Notes were a subsequent aggregate principal issue of the initial 2018 Notes. The additional 2018 Notes together with the initial 2018 Notes are collectively referred to as the 2018 Notes. The proceeds from the initial 2018 Notes were utilized to redeem our outstanding 9.125% $775 million senior notes due 2013. A portion of the proceeds of the additional 2018 Notes were utilized to redeem our 7.125% $275 million senior notes due 2012. Together, these issuances of our 2018 Notes allowed us to reduce our future interest expense as a result of a lower interest rate and also extended the maturity of our outstanding term debt. On April 1, 2011, we repaid the remaining $0.2 million of our 2011 Notes outstanding.
Our Senior Credit Agreement provides for a $2.0 billion credit facility. As of March 31, 2011, the borrowing base was approximately $1.6 billion, $1.5 billion of which relates to our oil and natural gas properties and $100 million of which relates to our midstream assets (currently limited as described below). The portion of the borrowing base which relates to our oil and natural gas properties is redetermined on a semi-annual basis (with the Company 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 March 31, 2011, the midstream component of the borrowing base was limited to approximately $95.2 million based on the midstream EBITDA limitation. 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. Our Senior Credit Agreement contains customary financial and other covenants, including minimum working capital levels (the ratio of current assets plus the unused commitment under the Senior Credit Agreement to current liabilities) of not less than 1.0 to 1.0 and minimum coverage of interest expenses (as defined in the Senior Credit Agreement) of not less than 2.5 to 1.0. We are subject to additional covenants limiting
During the second quarter of 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 relates to our oil and natural gas properties and $100 million relates 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 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. Borrowings under the Senior Credit Agreement are secured by first priority liens on substantially all of our assets, including pursuant to the terms of the Fifth Amended and Restated Guarantee and Collateral Agreement, all of the assets of, and equity interests in, our subsidiaries. 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.
On May 21, 2010, our wholly owned subsidiary, Hawk Field Services, and Kinder Morgan entered into a joint venture arrangement to create a new entity, KinderHawk, which engages in the natural gas midstream business in Northwest Louisiana, focused on the Haynesville and Lower Bossier Shales. Hawk Field Services contributed to KinderHawk our Haynesville Shale gathering and treating business in Northwest Louisiana, and Kinder Morgan contributed approximately $917 million in cash ($875 million for a 50% membership interest in KinderHawk and $42 million for certain closing adjustments including 2010 capital expenditures through the closing date) to KinderHawk. We, along with Kinder Morgan, own a 50% membership interest in KinderHawk. KinderHawk distributed the approximate $917 million to us. During the first three months of 2011, we have made no cash contributions to KinderHawk and have received distributions of $16.1 million, which are recorded in cash flows from operating activities.
We pay KinderHawk negotiated gathering and treating fees, subject to an annual inflation adjustment factor. The gathering fee is currently equal to $0.34 per thousand cubic feet (Mcf) of 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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