Printer Friendly Version View printer-friendly version
<< Back
Continental Resources Reports Record Results for 2008 Second Quarter

President Announces Plans to Retire October 31, 2008

ENID, Okla., July 29 /PRNewswire-FirstCall/ -- Continental Resources, Inc. (NYSE: CLR) reported strong growth in oil and gas sales and earnings for the three months ended June 30, 2008, generating record financial results. Based on its strong cash flows, the Company is planning to expand the number of drilling rigs that it will deploy in the second half of the year, positioning the Company for accelerated growth in late 2008.

The Company reported net income of $127.3 million, or $0.75 per diluted share, for the second quarter of 2008. This represents a 188 percent increase over pro forma net income of $44.2 million, or $0.27 per share, for the second quarter of 2007. This comparison includes pro forma adjustments to provide for income taxes as if the Company had been a subchapter C corporation in the second quarter last year and to eliminate a $198.4 million charge in connection with the conversion from a subchapter S to a subchapter C corporation at the time of its initial public offering of stock in May 2007. The Company's reported net loss in last year's second quarter was $142.5 million, or $0.87 per share.

Total revenues for the second quarter of 2008 were $303.4 million, an increase of 109 percent over total revenues of $145.3 million for the second quarter of 2007.

Oil and natural gas sales were $297.6 million for the second quarter of 2008, an increase of 113 percent over oil and gas sales for the second quarter last year. The Company's average sales price per barrel of crude oil equivalent was $102.86 for the most recent quarter, compared with $54.44 for the second quarter last year.

EBITDAX for the second quarter of 2008 was $245.0 million, an increase of 125 percent over EBITDAX of $108.7 million for the second quarter of 2007. For the Company's definition and reconciliation of EBITDAX to GAAP measures, see "Non-GAAP Financial Measures" at the end of this press release.

"Strong operating results and high commodity prices resulted in record financial results for the second quarter," said Harold Hamm, Chairman and Chief Executive Officer. "Our cash flow outlook continues to strengthen, and consequently we plan to exit 2008 with approximately 35 operated drilling rigs, rather than the target of 30 that we projected three months ago." The Company currently has 26 operated drilling rigs, up from 13 as of January 1, 2008.

Operations Update

The following table contains financial and operational highlights for the three and six months ended June 30, 2008 compared to the same periods in 2007.

                             Three months ended          Six months ended
                                  June 30,                  June 30,
                             2008         2007         2008         2007

    Average daily
      Crude oil (bopd)      24,117       23,674       24,080       23,391
      Natural gas (Mcfd)    45,035       29,618       41,098       29,229
      Crude oil equivalent
       (boepd)              31,623       28,610       30,930       28,262

    Average prices: (1)
      Crude oil ($ / bbl)  $118.28       $58.25      $104.43       $53.44
      Natural gas
       ($ / Mcf)              8.82         6.07         8.25         6.11
      Crude oil equivalent
       ($ / boe)            102.86        54.44        92.34        50.52
    Production expense
     ($ / boe) (1)            9.32         8.42         8.83         7.43

     ($ in thousands)     $244,950     $108,659     $426,738     $199,655
    Net income
     ($ in thousands) (2)  127,307       44,200      215,278       77,565
      Diluted net
       income per share       0.75         0.27         1.27         0.48

    (1) Crude oil sales exceeded production in the second quarter and first
        half of 2008 by 16 MBbls and 35 MBbls, respectively. Crude oil
        production volumes exceeded oil sales in the second quarter and first
        half of 2007 by 31 MBbls and 47 MBbls, respectively.

    (2) Second quarter and first half 2007 net income and diluted net income
        per share are after pro forma adjustments (i) to provide for income
        taxes as if the Company had been a subchapter C corporation prior to
        the completion of its initial public offering and (ii) to eliminate
        the $198.4 million charge recorded to recognize deferred taxes upon
        its conversion from a nontaxable subchapter S corporation to a taxable
        subchapter C corporation in conjunction with the Company's May 2007
        initial public offering.

During the second quarter, Continental continued to expand its undeveloped acreage positions in the Bakken, Anadarko Woodford, Atoka, Rhinestreet, Marcellus, Huron and Haynesville shale plays. The Company has added approximately 325,000 net acres to its lease holdings since the beginning of 2008, increasing its acreage position to almost one million acres in U.S. shale resource plays.

"We continue to see opportunities to add significant additional acreage in these plays," Mr. Hamm said. "We are planning to ask our board of directors for a second increase in the 2008 lease acquisition budget that would raise it by $100 million, bringing the total 2008 land budget to approximately $178 million."

Continental's production averaged 31,623 boepd for the second quarter of 2008, an increase of five percent over the first quarter of 2008 and 11 percent over the second quarter of 2007. June 2008 production averaged just over 33,000 boepd, showing significant acceleration of production within the second quarter.

The following table presents average daily production for the Company's principal operating areas for the three months ended June 30, 2008 compared to the three months ended March 31, 2008 and June 30, 2007.

    (boe per day)                   Q2 2008         Q1 2008       Q2 2007
    Red River Units (1)              13,551          13,620        12,615
    Montana Bakken                    6,363           6,678         7,890
    North Dakota Bakken               2,082           1,532           924
    Other Rockies (1)                 2,484           2,060         1,839
    Oklahoma Woodford                 2,125           1,900           586
    Other Mid-Continent               4,419           3,831         4,320
    Gulf Coast                          599             616           436
    Total                            31,623          30,237        28,610

    (1) Daily production of 65 boe in the second quarter of 2007 has been
        reclassified from the Red River Units to Other Rockies to conform to
        the current period presentation.

Red River Units

Continental continued to implement its increased density drilling and secondary recovery programs in the Red River Units during the second quarter of 2008, drilling new infield production wells and converting producing wells to water-injectors. During the quarter, the Company determined that additional water source wells were needed to achieve the planned water volume injection rate in the Units. The delay related to the drilling of the additional water source wells is expected to move the Company's previously announced peak production target for the Units of 21,000 net boepd to late 2009.

Second quarter production in the Red River Units was also negatively affected by a late winter storm that struck South Dakota in the first week of May, cutting electrical power to significant parts of the Units for most of that month. Continental estimates that the power outage reduced production in the Units and in the "Other Rockies" segment by an aggregate of approximately 500 barrels per day for the quarter.

Bakken Shale

In the second quarter of 2008, Continental increased its lease acreage position in the Bakken Shale play to approximately 525,000 net acres, with 153,000 net acres in Montana and 372,000 net acres in North Dakota.

In the Montana Bakken, drilling and production results have been consistent with expectations of approximately 300,000 gross barrels of reserves per well from Continental's 320-acre infield and 640-acre tri-lateral, field-extension program. Reduced second quarter production in the field reflected a combination of normal production declines and interrupted production in wells that were shut in while adjacent, new infield wells were being fracture-stimulated.

Notable second quarter well completions in Richland County in the Montana Bakken included the LeaJoe 1-1H (63% WI), Swenseid 3-9H (95% WI) and the Constance 3-7H (73% WI). The wells had average seven-day initial production rates of 609, 336 and 315 gross boepd, respectively.

In the North Dakota Bakken, average seven-day initial production rates continued to improve in the second quarter of 2008, with wells averaging 513 boepd, an increase of 13 percent over initial daily production for wells completed in the first quarter this year.

"These improved production rates and increased consistency show the significant advances we've made in our completion techniques," Mr. Hamm said. "We've gained valuable experience in the play over the past 18 months. We are now fracture stimulating wells in 10 segments and plan to test the impact of 12 or more segments. "

Recent notable completions in the North Dakota Bakken are shown below with average seven-day initial gross production rates:

-- Mathistad 1-35H (40% WI) in McKenzie Co. -- 1,260 boepd;
-- Dodge 1-17H (20% WI) McKenzie Co. -- 989 boepd;
-- Whitman 11-34H (32% WI) in Dunn Co. -- 765 boepd;
-- Bice 1-29H (44% WI) in Dunn Co. -- 693 boepd;
-- Cleo 1-12H (26% WI) McKenzie Co. -- 654 boepd;
-- Carson Peak 44-2H (33% WI) in Dunn Co. -- 601 boepd;
-- Kermit 1-32H (45% WI) McKenzie Co. -- 596 boepd;
-- Bridger 44-14H (45% WI) in Dunn Co. -- 383 boepd;
-- Bonneville 31-23H (45% WI) in Dunn Co. -- 362 boepd;
-- Mountain Gap 31-10H (44% WI) in Dunn Co. -- 331 boepd.

Eight of the 10 wells listed above were completed in the Middle Bakken formation, which has typically been the drilling target in the North Dakota Bakken play. The Bice 1-29H and Mathistad 1-35H were Continental's first two wells to be targeted for the Three Forks/Sanish (TFS) formation, which is typically found 50-to-100 feet beneath the base of the Upper Bakken. Since the Bice 1-29H completion in late May, Continental has adjusted most of its drilling program to target specifically the TFS and determine its potential to add incremental reserves to the play.

The Company has drilled to total depth seven other TFS wells in North Dakota, all of which should be completed by mid-September. Continental also plans to drill its first TFS test well in the Montana Bakken later this year.

Continental currently has 12 operated drilling rigs in the Bakken Shale play, with four in Montana and eight in North Dakota. By year-end, the Company plans to have three operated drilling rigs in the Montana Bakken and 13 in North Dakota.

Other Rockies

In Richland County, Montana, just north of the main Bakken fairway, Continental recently completed its second successful vertical well in the Red River formation. The Smart 1-23H (89% WI) had an average seven-day initial production rate of 442 gross boepd. The Company plans to start drilling its next Red River test well in August and has identified 19 gross (11 net) prospective Red River locations on 88 square miles of 3D seismic that it has interpreted. Continental is currently processing an additional 128 square miles of 3D seismic data to identify additional Red River opportunities.

The Company noted that early results from the initial two Red River B test wells drilled this year in one localized area of the Haley prospect in South Dakota have been disappointing, with higher than expected volumes of water production. Efforts to isolate the water source and to increase oil production are underway. Continental remains optimistic about the play and is currently testing its third well and drilling a fourth in the Haley prospect.

During the second quarter, the Company drilled two vertical wells in its East Lustre prospect. The wells penetrated Lodgepole reef mounds, as expected, but encountered low rock porosity and were plugged after open-hole log evaluation.

Arkoma Woodford

Continental's drilling program in the Arkoma Woodford Shale play in southeastern Oklahoma continued to have good results in the second quarter of 2008. During the quarter, the Company completed a two-well simultaneous fracture stimulation involving the Arlan 2-15H (21% WI) and 3-15H (21% WI) in Hughes Co., OK. The two wells' average seven-day initial production rates were 6.2 gross MMcfd and 7.2 gross MMcfd of natural gas, significantly above average production rates for most of the Company's other wells in the play. After separately being fracture stimulated, the Arlan 4-15H (21% WI) averaged 7.1 gross MMcfd of natural gas during its seven-day initial production period. During the third quarter, the Company plans to perform four separate two-well simultaneous fracture stimulation completions in the same general area.

In addition, the Company acquired 18 square miles of 3D seismic in the Salt Creek prospect during the second quarter of 2008 and is currently acquiring an additional eight square miles of 3D seismic in this part of the play. In its East McAlester prospect of the Woodford, Continental expects to acquire 55 square miles of 3D seismic within the next six months. Continental uses seismic data to attempt to identify and avoid faults and other geological features that could reduce the productivity of its Woodford wells.

Continental's lease position in the Arkoma Woodford is approximately 46,000 acres. The Company has five operated drilling rigs in the Arkoma Woodford Shale play and expects to increase to seven by year-end.


Early in the second quarter of 2008, the Company completed the Marriott 1-18 (63% WI) in Blaine County, OK, with an average seven-day initial production rate of 2.5 gross MMcfd and 45 bpd of condensate from the Springer Britt sand. Subsequently, Continental completed the Wolsey 2-9 (85% WI) in Blaine County, with an average seven-day initial production rate of 5.6 gross MMcfd of natural gas and 142 gross bpd of condensate.

Continental owns approximately 20,000 net acres that is prospective for the Morrow-Springer sands in the Watonga-Chickasha Trend. The Company plans to keep one drilling rig active in Blaine County through year-end.

Atoka Shale

The Company's initial well in the Atoka Shale play, the Shrewder 1-22H (100% WI) in Ellis County, OK, is currently drilling in the horizontal lateral. The Company has a lease position of approximately 32,000 net acres in the prospective Atoka fairway.

Anadarko Woodford Shale

The Company has a lease position of approximately 94,000 net acres in the Anadarko Woodford Shale, and is planning to drill an initial test well in the play in the third quarter of 2008.

Trenton/Black River

Continental completed four operated wells in the Trenton/Black River play in southern Michigan during the second quarter of 2008. The Boardman 1-1 and Wessel 2-6A (each 83% WI) in Hillsdale County are currently testing at rates of 150 and 110 gross barrels of crude oil per day, respectively, with plans to increase the rates to 200 bopd over the next several weeks. Initial testing of the Lindemann 1-36 (75% WI) has been encouraging. The Wessel 1-1 (83% WI) has been temporarily abandoned.

The Company has a lease position of approximately 48,000 net acres in the play. Continental has acquired 3D seismic covering approximately 15 percent of its acreage and plans to acquire an additional 25 square miles of 3D seismic by year-end. The Company plans to drill additional wells in the Trenton/Black River play by year-end.

Additional Shale Resource Plays

The Company has grown its land positions to approximately 17,000 net acres in the Haynesville Shale play in northern Louisiana and approximately 88,000 net acres in the Rhinestreet, Marcellus and Huron Shale plays in West Virginia, Ohio, Pennsylvania and New York.

Continental is currently drilling the first of four wells planned to test the Rhinestreet and Lower Huron shales in Gallia County, OH.

"We share the industry's enthusiasm for these shale plays and plan to commence drilling by year-end in the Haynesville," Mr. Hamm said.

President Announces Plans to Retire

Continental also announced that President and Chief Operating Officer Mark Monroe will retire effective October 31, 2008. Mr. Monroe joined the Company in his present positions in October 2005, but has served on the Company's Board of Directors since 2001 and plans to continue in that role. Jeff Hume, Senior Vice President of Operations, will be promoted to Chief Operating Officer, and Mr. Hamm will assume the President position.

"I joined Continental's management team in 2005 primarily to assist the Company in its transition from a private to a public company," Mr. Monroe said. "With the completion of the initial public offering in May 2007, the Company's subsequent achievements, and the hiring of several key employees over the past three years, the Company is well positioned to continue its success without my full-time involvement."

Mr. Hamm commented, "Though I will miss my daily interactions with Mark, he will continue to be available for advice and counsel. We have an excellent management team in place to lead the Company forward."

Conference Call Information

Continental Resources will host a conference call on Tuesday, July 29, 2008, at 10:00 a.m. ET (9 a.m. CT) to discuss its second quarter 2008 results. Interested parties may listen to the conference call via the Company's website at or by phone:

Dial in: (888) 680-0878
Intl. dial in: (617) 213-4855
Pass code: 94076373

Replay number: (888) 286-8010
Intl. replay: (617) 801-6888
Pass code: 89826064

Conference Presentations

Continental management is currently scheduled to present at the Enercom 2008 Oil & Gas Conference in Denver on Monday, August 11; at the 2008 Lehman Brothers Energy Conference in New York on Thursday, September 4; and at the John S. Herold 17th Annual Pacesetters Energy Conference in Old Greenwich, Connecticut on Wednesday, September 24. Presentations and audio links will be posted on the Company's web site.

Continental Resources is a crude-oil concentrated, independent oil and natural gas exploration and production company with operations in the Rocky Mountain, Mid-Continent and Gulf Coast regions of the United States. The Company focuses its operations in large new and developing resource plays where horizontal drilling, advanced fracture stimulation and enhanced recovery technologies provide the means to economically develop and produce oil and natural gas reserves from unconventional formations.

This press release includes forward-looking information that is subject to a number of risks and uncertainties, many of which are beyond the Company's control. All information, other than historical facts included in this press release, regarding strategy, future operations, drilling plans, estimated reserves, future production, estimated capital expenditures, projected costs, the potential of drilling prospects and other plans and objectives of management are forward-looking information. All forward-looking statements speak only as of the date of this press release. Although the Company believes that the plans, intentions and expectations reflected in or suggested by the forward-looking statements are reasonable, there is no assurance that these plans, intentions or expectations will be achieved. Actual results may differ materially from those anticipated due to many factors, including oil and natural gas prices, industry conditions, drilling results, uncertainties in estimating reserves, uncertainties in estimating future production from enhanced recovery operations, availability of drilling rigs and other services, availability of crude oil and natural gas transportation capacity, availability of capital resources and other factors listed in reports we have filed or may file with the Securities and Exchange Commission.

CONTACT: Continental Resources, Inc.
J. Warren Henry Brian Engel
Investors Media
(580) 548-5127 (580) 249-4731

    Condensed Consolidated
     Income Statements        Three months ended        Six months ended
    (in thousands,                  June 30,                June 30,
     except per share          2008        2007         2008        2007
     amounts)                    (unaudited)               (unaudited)

      Oil and natural
       gas sales             $297,619    $140,046     $523,044    $256,030
      Loss on
       instruments             (3,358)          -       (7,966)          -
      Oil and natural
       gas service
       operations               9,173       5,280       16,007      10,419
    Total revenues            303,434     145,326      531,085     266,449

    Operating costs
     and expenses:
      Production expenses      26,953      21,655       50,026      37,640
      Production tax           17,695       7,437       30,470      13,600
      Exploration expense       5,731       1,602       10,993       3,906
      Oil and natural gas
       service operations       6,468       3,134       10,698       6,353
       amortization and
       accretion               28,062      23,330       56,708      43,738
      Property impairments      3,153       5,923        7,673       8,893
      General and
       administrative (1)      10,276       8,450       17,807      21,423
      Gain on sale of
       assets                    (133)       (339)        (212)       (400)
    Total operating costs
     and expenses              98,205      71,192      184,163     135,153

    Income from operations    205,229      74,134      346,922     131,296
    Other income (expense):
      Interest expense and
       other                   (2,617)     (2,843)      (5,729)     (6,191)
    Income before income
     taxes                    202,612      71,291      341,193     125,105
      Provision for income
       taxes                   75,305     213,789      125,915     213,789
    Net income (loss)         127,307    (142,498)     215,278     (88,684)

    Basic net income (loss)
     per share                   0.76       (0.87)        1.28       (0.55)
    Diluted net income (loss)
     per share                   0.75       (0.87)        1.27       (0.55)

    Basic weighted average
     shares outstanding       168,055     162,933      167,973     160,651
    Diluted weighted
     average shares
     outstanding              169,552     162,933      169,418     160,651

    (1) Includes non-cash charges for stock-based compensation of $2.5 million
        and $3.1 million for the three months ended June 30, 2008 and 2007,
        respectively.  Includes non-cash charges for stock-based compensation
        of $3.9 million and $10.9 million for the six months ended June 30,
        2008 and 2007, respectively.

    Condensed Consolidated Balance Sheets           June 30,    December 31,
    (in thousands)                                    2008           2007
    Cash and cash equivalents                        $13,190         $8,761
    Receivables                                      275,765        163,090
    Inventories and other                             32,080         33,713
    Net property and equipment, based on
     successful efforts method of accounting       1,492,000      1,157,926
    Other assets                                       1,444          1,683
    Total assets                                  $1,814,479     $1,365,173

    Liabilities and shareholders' equity:
    Current liabilities                             $350,217       $266,106
    Long-term debt                                   220,000        165,000
    Other noncurrent liabilities                     400,867        310,935
    Total shareholders' equity                       843,395        623,132
    Total liabilities and shareholders' equity    $1,814,479     $1,365,173

    Condensed Consolidated Statements of Cash Flows    Six months ended
                                                           June 30,
    (in thousands)                                    2008          2007

    Net income (loss)                               $215,278       $(88,684)
    Adjustments to reconcile net income (loss)
     to net cash provided by operating activities:
    Non-cash expenses                                140,900        278,965
    Changes in assets and liabilities                (58,208)       (26,772)
    Net cash provided by operating activities        297,970        163,509

    Net cash used in investing activities           (348,729)      (233,855)

    Net cash provided by financing activities         55,188         69,619

    Effect of exchange rate on change in cash
     and cash equivalents                                  -            102

    Net change in cash and cash equivalents            4,429           (625)
    Cash and cash equivalents at beginning of
     period                                            8,761          7,018
    Cash and cash equivalents at end of period      $ 13,190         $6,393

Non-GAAP Financial Measures

EBITDAX represents earnings before interest expense, income taxes, depreciation, depletion, amortization and accretion, property impairments, exploration expense, unrealized derivative gains or losses, and non-cash compensation expense. EBITDAX is not a measure of net income or cash flow as determined by generally accepted accounting principles (GAAP). EBITDAX should not be considered as an alternative to, or more meaningful than, net income or cash flow as determined in accordance with GAAP or as an indicator of a Company's operating performance or liquidity. Certain items excluded from EBITDAX are significant components in understanding and assessing a company's financial performance, such as a company's cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of EBITDAX. The Company's computations of EBITDAX may not be comparable to other similarly titled measures of other companies. The Company believes that EBITDAX is a widely followed measure of operating performance and may also be used by investors to measure its ability to meet future debt service requirements, if any. The Company's credit facility requires that it maintain a total debt to EBITDAX ratio of no greater than 3.75 to 1 on a rolling four-quarter basis. The credit facility defines EBITDAX consistently with the definition of EBITDAX utilized and presented by the Company. The following table represents a reconciliation of the Company's net income to EBITDAX.

    Reconciliation of Net Income to EBITDAX
                            Three months ended          Six months ended
                                 June 30,                   June 30,
    (in thousands)          2008         2007          2008         2007
                              (unaudited)                (unaudited)

    Net income (loss)     $127,307    $(142,498)    $215,278     $(88,684)
    Income tax expense      75,305      213,789      125,915      213,789
    Interest expense         2,865        3,427        6,276        7,080
     amortization and
     accretion              28,062       23,330       56,708       43,738
    Property impairments     3,153        5,923        7,673        8,893
    Exploration expense      5,731        1,602       10,993        3,906
    Equity compensation      2,527        3,086        3,895       10,933
    EBITDAX               $244,950     $108,659     $426,738     $199,655

SOURCE Continental Resources

CONTACT: Investors, J. Warren Henry, +1-580-548-5127, or Media, Brian
Engel, +1-580-249-4731, both of Continental Resources

Expand Full Navigation