Nov. 5, 2009 (PR Newswire) --

ENID, Okla., Nov. 5 /PRNewswire-FirstCall/ -- Continental Resources, Inc. (NYSE: CLR) today announced that it doubled operating earnings and net income for the third quarter of 2009, compared with results for the second quarter of 2009, based on higher crude oil prices and lower production costs. Compared with the third quarter of 2008, when crude oil and natural gas prices peaked, operating and net income were lower for the quarter ended September 30, 2009.

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Based on strong third quarter cash flow and its positive outlook, Continental announced plans to accelerate drilling operations in the fourth quarter of 2009 and in 2010.

Continental has increased its 2009 capital expenditure budget to $415 million from $390 million, with expected cash flow sufficient to cover its increased capex budget. The Company now plans to exit 2009 with 12 operated drilling rigs, compared with the previous target of six. Of its 12 rigs at year end, six additional rigs will be deployed in the North Dakota Bakken and one in the Montana part of the play.

The Company announced a 2010 capital expenditure budget of $650 million. Continental expects to have up to 23 operated drilling rigs deployed by mid-2010.

"Consistent with our growth strategy, we are accelerating drilling operations in response to the improved crude oil market," said Harold Hamm, Chairman and Chief Executive Officer. "Our shareholders value Continental's capital discipline and focus on operating costs. We aggressively reduced drilling and other spending as prices fell in late 2008. We are ramping up operations in anticipation of strong cash flows in 2010, although we will continue to adapt to pricing trends and cash flow.

"We expect this budget to drive 2010 production growth of approximately 10 percent," he said. "Along with strong execution and cost management, our focus will be to accelerate production growth momentum by mid-year and then sustain that growth in 2011."

The Company now expects 2009 total production will be approximately 13.3 MMBoe (million barrels of oil equivalent), which would exceed its guidance of 12.5-to-13 MMBoe.

For the third quarter of 2009, Continental reported net income of $34.9 million, or $0.21 per diluted share, compared with net income of $105.3 million, or $0.62 per diluted share, for the third quarter of 2008. On a consecutive-quarter basis, third quarter 2009 net income represented a 159 percent increase over net income of $13.5 million for the second quarter of 2009.

Net income for the third quarter of 2009 included a pre-tax leasehold property impairment charge of $11.8 million and mark-to-market losses on natural gas fixed price and basis swaps of $2.1 million. Apart from these non-cash items, Continental's net income was $44.4 million, or $0.26 per diluted share, for the third quarter of 2009. In the third quarter of 2008, the Company recorded a $9.9 million pre-tax leasehold property impairment charge.

Average daily production was 37,384 Boepd (barrels of oil equivalent per day) for the third quarter of 2009, 12 percent higher than production of 33,297 Boepd in the third quarter of 2008.

Average realized sales price per Boe was $48.19 for the third quarter of 2009, a decline of 48 percent from the average realized sales price of $93.21 per Boe for the third quarter of 2008.

Crude oil accounted for 74 percent of Continental's third quarter 2009 total production. The average realized price for crude oil was $58.78 per barrel in the third quarter of 2009, while the average realized natural gas price was $2.98 per Mcf. Average realized prices were $108.37 per barrel and $7.97 per Mcf in the third quarter last year.

Crude oil price differentials averaged $9.39 per barrel for the third quarter of 2009, compared with $6.02 in the second quarter of 2009 and $9.68 for the third quarter of 2008.

Total oil and natural gas sales were $168.4 million for the third quarter of 2009, compared with $286.2 million for the third quarter of 2008. Sales exceeded production in the third quarter as the Company sold 55 MBbls of crude oil from storage. The Company sold 124 MBbls of crude oil in storage in October 2009. Minimum pipeline line fill requirements resulted in inventory balances of 341 MBbls of crude oil at September 30, 2009.

Continental reduced production expenses during the third quarter. Production expense was $6.50 per Boe for the third quarter of 2009, compared with $7.14 for the second quarter of 2009 and $8.22 for the third quarter of 2008.

Income from operations was $59.3 million for the third quarter of 2009, compared with $171.2 million for the third quarter last year. On a consecutive-quarter basis, third quarter 2009 income from operations represented a 126 percent increase over operating income of $26.2 million for the second quarter of 2009.

EBITDAX was $128.7 million for the third quarter of 2009, compared with $238.3 million for the third quarter last year. For the Company's definition and reconciliation of EBITDAX to net income, see "Non-GAAP Financial Measures" at the end of this press release.

At September 30, 2009, the Company's balance sheet included $5.3 million in cash and $546.3 million in long-term debt. As of November 5, 2009, $235 million was drawn against its revolving credit facility, leaving available borrowing capacity at $515 million, based on commitments of $750 million.

Company Announces 2010 Capital Expenditure Budget

Continental's 2010 capital expenditures budget of $650 million will primarily focus on increased development in the North Dakota Bakken, the Arkoma and Anadarko Woodford shale natural gas plays in Oklahoma and the Red River Units, with total operated drilling rigs increasing to as many as 23 by mid-2010.

Operational capital expenditures - investment in drilling, work-over and related facilities - account for $563 million, or 87 percent, of the Company's 2010 capex budget. In addition, the Company plans $73 million in land capex for new leases and lease retention, primarily in the Bakken and Woodford plays.

Continental has allocated $373 million, or 66 percent, of its 2010 operational capex to accelerate development in the Bakken shale play of North Dakota and Montana. The Company expects to complete 193 gross (61.9 net) wells in North Dakota and 11 gross (4.6 net) wells in Montana in 2010. Starting with seven operated rigs on January 1, the Company plans to have up to 15 operated drilling rigs by mid-2010, with all but one in North Dakota.

In Oklahoma, Continental plans to complete 62 gross (13.2 net) wells in the Arkoma Woodford and 11 gross (5.6 net) wells in the Anadarko Woodford during 2010. A total of $84 million, or 15 percent, of its operating capex is allocated to the Woodford plays in 2010. The Company plans to have an average of three operated rigs in the Woodford plays in 2010.

In the Red River Units, Continental plans to complete pattern drilling on its water flood project in the Cedar Hills Units and to resume development activity in the Medicine Pole Hills and Buffalo units in 2010. It has allocated $66 million, or 12 percent, of its operational capex to the Units, which will support one operated rig and significant investment in facilities and infrastructure. Production in the units is expected to peak mid-year in a range of 15,000 Boepd to 15,500 Boepd and then level off through the remainder of 2010.

Continental's regional allocations of capital expenditures in 2010 are listed below.

Dollars in millions            2010 Capex          Net
Budget            Wells
------             ------
North Dakota Bakken              $341               61.9
Montana Bakken                     32                4.6
Arkoma Woodford                    52               13.2
Anadarko Woodford                  32                5.6
Red River Units                    66               14.6
Other                              40               11.5
---               ----
Operational capex               $563              111.4
Land, seismic and other            87
---
Total capex                     $650

Additional 2010 Guidance

Continental expects to achieve 2010 operating and financial performance as follows. As forward-looking information, this guidance is subject to a variety of risks and uncertainties, including adjustments related to fluctuations in commodity prices. Risk factors are discussed further at the end of this press release and in the Company's filings with the Securities and Exchange Commission.