Cimarex Reports Second-Quarter 2011 Net Income of $166.7 Million

Aug 04, 2011, 06:00 ET from Cimarex Energy Co.

DENVER, Aug. 4, 2011 /PRNewswire/ -- Cimarex Energy Co. (NYSE: XEC) today reported second-quarter 2011 net income of $166.7 million, or $1.94 per diluted share.  This compares to second-quarter 2010 earnings of $124.6 million, or $1.46 per diluted share.  

Second-quarter 2011 net income includes an unrealized non-cash gain on derivative instruments associated with 2011 oil and gas hedges of $14.2 million after-tax, or $0.16 per share. Second-quarter 2010 results had an $8.5 million ($0.10 per share) after-tax non-cash loss on derivative instruments.  

Oil, gas and natural gas liquids (NGLs) revenue in the second quarter of 2011 totaled $452.3 million, a 24% increase compared to $364.9 million in the same period of 2010.  Second-quarter 2011 cash flow from operations was $343.4 million versus $259.9 million a year ago(1).    

The increase in second-quarter 2011 revenues and cash flow is a result of higher realized oil, gas and NGL prices, which were slightly offset by lower production.  Second-quarter 2011 production volumes averaged 585.7 million cubic feet equivalent (MMcfe) per day, a 1% decrease as compared to second-quarter 2010 output of 594.4 MMcfe per day.  Second-quarter 2011 Permian and Mid-Continent volumes grew 17% and 15%, respectively over the same period in 2010.  Growth in these regions was offset by a 38% decrease in Gulf Coast volumes. Gulf Coast production decreased as a result of declines in highly-profitable large wells drilled over the last two years near Beaumont, Texas. Second-quarter 2011 production volumes were 55% gas, 28% oil and 17% NGLs.

Second-quarter 2011 realized oil and NGL prices increased 33% and 35% to $100.12 and $45.06 per barrel, respectively over second-quarter 2010. Gas prices gained 6% to $4.75 per thousand cubic feet (Mcf) as compared to the same period of 2010.  

For the six months ended June 30, 2011, net income totaled $284.9 million, or $3.31 per diluted share, as compared to $329.0 million, or $3.84 per share, for the first six months of 2010.  First-half 2011 cash flow from operations totaled $648.0 million versus $573.1 million for 2010 (1).  

2011 Outlook

Third-quarter 2011 production is projected to range between 585-605 MMcfe/d.  Full-year 2011 production is now projected to be in the range of 595-610 MMcfe/d, down from previous guidance of 605-635 MMcfe/d.  The reduction is largely due to lower volume expectations in the Gulf Coast stemming from mechanical problems and year to date drilling results.

Full-year 2011 exploration and development (E&D) capital investment is expected to be in the range of $1.5-$1.6 billion. The current year E&D capital investment is expected to be funded from cash on hand, cash flow and non-core property sales.    As compared to previous guidance of $1.3-$1.5 billion, the increase in capital investment is primarily directed to our Cana-Woodford program and also reflects higher service costs.

Expenses for 2011 are expected to fall within the following ranges:

Expenses ($/Mcfe):

Production expense

$1.02 -  $1.22

Transportation expense

0.30  -  0.35

DD&A and ARO accretion

1.75  -  1.90

General and administrative expense

0.22  -  0.28

Taxes other than income (% of oil and gas revenue)

7.5%  -  8.5%

Other

Cimarex's commodity hedge position comprised of natural gas swaps and oil collars remains unchanged as summarized below:

Natural Gas Contracts

Weighted Average

Period

Type

Volume (2)

Index(3)

Swap Price

Jul 11 – Dec 11

Swap

20,000

PEPL

$

5.05

Oil Contracts

Weighted Average Price

Period

Type

Volume (2)

Index(3)

Floor

Ceiling

Jul 11 – Dec 11

Collar

12,000

WTI

$

65.00

$

105.44

Cimarex accounts for these commodity contracts using the mark-to-market (through income) accounting method.  Second-quarter 2011 net cash settlements for gas were $1.7 million in receipts offset by $1.7 million in payments on oil collars.   Non-cash unrealized market-to-market gain for the quarter totaled $22.4 million.

In July 2011, Cimarex closed on a new five-year senior unsecured revolving credit facility. The new facility has bank commitments of $800 million and an initial borrowing base of $2 billion.  At June 30, 2011 Cimarex had no bank debt outstanding.  Long-term debt at June 30, 2011 was $350 million. Debt to total capitalization ratio at quarter-end was 11% (4).  

On August 1, 2011, Cimarex completed the sale of its entire interest in the Riley Ridge Federal Unit and gas processing facility located in southwestern Wyoming.  At closing Cimarex received $176 million, plus customary closing adjustments.  The sales contract also provides for a $15 million contingent payment to be paid by the buyer at the time the gas processing facility is operational and certain other performance standards are met, which is expected to occur in the fourth quarter of this year.  In the accompanying balance sheet as of June 30, 2011, Riley Ridge processing facility is included in assets held for sale.

Exploration and Development Activity

Cimarex's drilling activities are conducted within three main areas:  Permian Basin, Mid-Continent and Gulf Coast.  Permian activity is currently primarily directed to the Delaware Basin of southeast New Mexico and West Texas.  Majority of Mid-Continent drilling is in the western Oklahoma Cana-Woodford shale and Texas Panhandle Granite Wash.  Gulf Coast operations are currently focused in southeast Texas, near Beaumont.  

Cimarex drilled and completed 160 gross (90 net) wells during the first half of 2011, investing $757 million on exploration and development.  Of total expenditures, 48% were invested in projects located in the Mid-Continent area; 46% in the Permian Basin; and 6% in the Gulf Coast and other.

Wells Drilled and Completed by Region

For the Three Months

For the Six Months

Ended June 30,

Ended June 30,

2011

2010

2011

2010

Gross wells

Permian Basin

45

22

71

33

Mid-Continent

49

27

86

49

Gulf Coast

1

3

3

7

95

52

160

89

Net wells

Permian Basin

36

16

56

25

Mid-Continent

19

14

32

24

Gulf Coast

-

3

2

7

55

33

90

56

% Gross wells completed as producers

96%

96%

96%

94%

At the end of the second quarter, 16 net wells were awaiting completion: eight Permian Basin and eight Mid-Continent.  Cimarex currently has 27 operated rigs running; 14 in the Permian Basin, 11 in the Mid-Continent, and two in southeast Texas Gulf Coast.  

Permian Basin

Cimarex drilled and completed 71 gross (56 net) Permian Basin wells during the first six months of 2011, completing 94% as producers.  At quarter-end, 10 gross (8 net) wells were awaiting completion.  Drilling principally occurred in the Delaware Basin of Texas and southeast New Mexico, mainly targeting Bone Spring, Paddock, Abo and Wolf Camp formations.  Second-quarter 2011 Permian production averaged 182.3 MMcfe/d, an increase of 17% over second-quarter 2010, which included over 21% growth in oil volumes to 15,780 barrels per day.

Recent notable horizontal Bone Spring wells brought on production (30-day gross average) this quarter include the Irwin 13 Federal 2H (100% working interest) at 810 barrels equivalent per day (Boe/d), KHC 33-24 2H (96% working interest) at 750 barrels equivalent per day and the Parkway State 17 Com 3H (94% working interest) at 710 barrels equivalent per day.

Cimarex is also in the early evaluation of unconventional liquids-rich gas plays targeting Wolfcamp, Avalon and Cisco/Canyon shale formations in the Delaware Basin.  During 2011 five new horizontal Wolfcamp wells have been drilled and completed, bringing total wells in the play to 12.  First 30-day production from the horizontal Wolfcamp wells has averaged 6.3 MMcfe/d, comprised of 48% gas, 31% NGL and 21% oil.

Mid-Continent

First-half 2011 Mid-Continent wells drilled and completed totaled 86 gross (32 net), completing 100% as producers.  At quarter-end, 22 gross (8 net) wells were awaiting completion.  Mid-Continent production averaged 284.7 MMcfe/d for the second quarter of 2011, a 15% increase over second-quarter 2010 average of 248.4 MMcfe/d.

The majority of the current year drilling activity has been in the Anadarko Basin, Cana-Woodford shale play, where Cimarex drilled and completed 71 gross (23 net) wells. At quarter-end 22 gross (8 net) wells were being completed or awaiting completion in this area.  

Since the Cana play began in late 2007, Cimarex has participated in 257 gross (100 net) wells.  Of total wells, 214 gross (79 net) were on production at quarter-end and the remainder were either in the process of being drilled or awaiting completion.  Second-quarter 2011 net production from the Cana play averaged 115 MMcfe/d, a 53% increase versus the second-quarter 2010 average of 75 MMcfe/d.  

Gulf Coast

During the first six months of 2011 Cimarex drilled three gross (2.3 net) Yegua/Cook Mountain wells, of which one gross (1.0 net) was successful.  Gulf Coast production average 116.9 MMcfe/d for the second quarter of 2011, a 38% decrease as compared to the second-quarter 2010 average of 190.0 MMcfe/d.  The decreased output is a result of production interruptions, reservoir management and natural decline in highly-productive wells drilled near Beaumont, Texas over the last two years.

Production by Region

Cimarex's average daily production by commodity and region is summarized below:

Production by region

For the Three Months

For the Six Months

Ended June 30,

Ended June 30,

2011

2010

2011

2010

Gas (Mcf per day)

Permian Basin

70,655

69,414

69,750

71,576

Mid-Continent

194,038

195,796

191,705

191,922

Gulf Coast

58,605

105,434

63,346

116,687

Other

1,443

706

1,374

852

324,741

371,350

326,175

381,037

NGL (barrels per day)

Permian Basin

2,820

1,210

2,880

689

Mid-Continent

9,144

4,194

8,348

4,071

Gulf Coast

4,878

5,387

5,666

2,809

Other

2

1

1

1

16,844

10,792

16,895

7,570

Oil (barrels per day)

Permian Basin

15,780

13,080

15,164

13,185

Mid-Continent

5,960

4,575

5,601

4,547

Gulf Coast

4,833

8,705

5,907

9,420

Other

77

21

47

18

26,650

26,381

26,719

27,170

Total Equivalent (Mcfe per day)

Permian Basin

182,255

155,154

178,014

154,820

Mid-Continent

284,662

248,410

275,399

243,630

Gulf Coast

116,871

189,986

132,784

190,061

Other

1,917

838

1,662

966

585,705

594,388

587,859

589,477

Conference call and web cast

Cimarex will also host a conference call today at 11:00 a.m. Mountain Time (1:00 p.m. Eastern Time).  To access the live, interactive call, please dial (877) 789-9039 and reference call # 82976141 ten minutes before the scheduled start time.  A digital replay will be available for one week following the live broadcast at (855) 859-2056 and by using the conference ID # 82976141.  The listen-only web cast of the call will be accessible via www.cimarex.com.

About Cimarex Energy

Denver-based Cimarex Energy Co. is an independent oil and gas exploration and production company with principal operations in the Mid-Continent, Permian Basin and Gulf Coast areas of the U.S.

This communication contains statements that constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995.  These statements are based on current expectations and beliefs and are subject to a number of risks, uncertainties and assumptions that could cause actual results to differ materially from those described in the forward-looking statements. These risks and uncertainties are more fully described in SEC reports filed by Cimarex. While Cimarex makes these forward-looking statements in good faith, management cannot guarantee that anticipated future results will be achieved. Cimarex assumes no obligation and expressly disclaims any duty to update the information contained herein except as required by law.  

  1. Cash flow from operations is a non-GAAP financial measure.  See below for a reconciliation of the related amounts.
  2. Gas volume in MMBtu per day and oil volume in barrels per day.
  3. PEPL refers to Panhandle Eastern Pipe Line, Tex/Ok Mid-Continent index as quoted in Platt's Inside FERC.  WTI refers to West Texas Intermediate oil price as quoted on the New York Mercantile Exchange.
  4. Reconciliation of debt to total capitalization, which is a non-GAAP measure, is:  long-term debt of $350 million divided by long-term debt of $350 million plus stockholders' equity of $2,887.6 million.

RECONCILIATION OF CASH FLOW FROM OPERATIONS

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2011

2010

2011

2010

(in thousands)

Net cash provided by operating activities

$

373,814

$

273,153

$

639,091

$

572,260

Change in operating assets

   and liabilities

(30,451)

(13,259)

8,892

841

Cash flow from operations

$

343,363

$

259,894

$

647,983

$

573,101

Management believes that the non-GAAP measure of cash flow from operations is useful information for investors because it is used internally and is accepted by the investment community as a means of measuring the company's ability to fund its capital program.  It is also used by professional research analysts in providing investment recommendations pertaining to companies in the oil and gas exploration and production industry.

PRICE AND PRODUCTION DATA*

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2011

2010

2011

2010

Total gas production - Mcf

29,551,462

33,792,812

59,037,609

68,967,732

Gas volume - Mcf per day

324,741

371,350

326,175

381,037

Gas price - per Mcf  

$4.75

$4.48

$4.60

$5.47

Total oil production - barrels

2,425,187

2,400,661

4,836,106

4,917,701

Oil volume - barrels per day

26,650

26,381

26,719

27,170

Oil price - per barrel

$100.12

$75.26

$95.80

$75.69

Total NGL production - barrels

1,532,813

982,040

3,058,039

1,370,242

NGL volume - barrels per day  

16,844

10,792

16,895

7,570

NGL price - per barrel

$45.06

$33.45

$42.92

$35.07

*  During the first quarter of 2010 we began separately reporting NGL sales and production volumes.  The determination of whether to record and separately disclose NGL volumes is based on where title transfer occurs during processing of the well stream.  New gas processing contracts related to new drilling activity and ongoing contractual amendments have resulted in title of NGL volumes being conveyed to the Company.  As a consequence, reported gas and NGL volumes and prices between periods may not be comparable.  

OIL AND GAS CAPITALIZED EXPENDITURES

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2011

2010

2011

2010

(in thousands)

Acquisitions:

Proved

$

9,165

$

6,630

$

9,165

$

13,786

Unproved

11,606

4,022

12,047

20,066

20,771

10,652

21,212

33,852

Exploration and development:

Land and Seismic

52,499

38,258

84,925

63,161

Exploration and development

367,486

199,200

672,061

366,886

419,985

237,458

756,986

430,047

Sale proceeds:

Proved

(7,129)

(24,861)

(18,483)

(24,861)

Unproved

(1,327)

(3,917)

(1,821)

(3,917)

(8,456)

(28,778)

(20,304)

(28,778)

$

432,300

$

219,332

$

757,894

$

435,121

CONDENSED STATEMENTS OF OPERATIONS (unaudited)

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2011

2010

2011

2010

(In thousands, except per share data)

Revenues:

Gas sales

$

140,377

$

151,375

$

271,700

$

377,012

Oil sales

242,812

180,664

463,311

372,224

NGL sales

69,069

32,851

131,259

48,060

Gas gathering, processing and other, net

14,955

13,611

27,539

29,775

467,213

378,501

893,809

827,071

Costs and expenses:

Depreciation, depletion, amortization and accretion

92,554

74,787

179,518

147,141

Production

60,745

45,356

119,225

87,339

Transportation

16,387

10,825

29,833

21,992

Gas gathering and processing

4,630

6,100

9,181

12,605

Taxes other than income

34,495

28,410

68,092

60,768

General and administrative

10,617

11,817

25,344

24,862

Stock compensation, net

4,617

2,993

9,367

5,771

Gain on derivative instruments, net

(22,477)

(3,289)

(4,233)

(55,886)

Other operating, net

2,342

1,876

5,716

30

203,910

178,875

442,043

304,622

Operating income

263,303

199,626

451,766

522,449

Other (income) and expense:

Interest expense

7,638

7,387

14,913

15,133

Amortization of deferred financing costs

1,702

1,714

3,407

3,430

Capitalized interest

(7,352)

(7,285)

(14,577)

(14,709)

Other, net

(3,018)

1,851

(3,622)

(79)

Income before income tax

264,333

195,959

451,645

518,674

Income tax expense

97,584

71,339

166,734

189,693

Net income

$

166,749

$

124,620

$

284,911

$

328,981

Earnings per share to common stockholders:

Basic

$

1.95

$

1.47

$

3.33

$

3.88

Diluted

$

1.94

$

1.46

$

3.31

$

3.84

Dividends per share

$

0.10

$

0.08

$

0.20

$

0.16

Shares attributable to common stockholders:

Unrestricted common shares outstanding

83,635

82,352

83,635

82,352

Diluted common shares

84,063

83,251

84,068

83,242

Shares attributable to common stockholders and participating securities:

Basic shares outstanding

85,655

84,742

85,655

84,742

Fully diluted shares

86,083

85,641

86,088

85,632

CONDENSED CASH FLOW STATEMENTS (unaudited)

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2011

2010

2011

2010

(In thousands)

Cash flows from operating activities:

Net income 

$

166,749

$

124,620

$

284,911

$

328,981

Adjustment to reconcile net income to net cash

provided by operating activities:

Depreciation, depletion, amortization and accretion

92,554

74,787

179,518

147,141

Deferred income taxes

98,358

40,313

168,056

125,303

Stock compensation, net

4,617

2,993

9,367

5,771

Derivative instruments, net

(22,441)

13,281

(2,163)

(38,775)

Changes in non-current assets and liabilities

1,821

2,513

4,559

5,614

Amortization of deferred financing costs

and other, net

1,705

1,387

3,735

(934)

Changes in operating assets and liabilities:

Decrease in receivables, net

15,527

49,544

17,549

10,049

(Increase) decrease in other current assets

(6,689)

(1,908)

(9,694)

16,587

Increase (decrease) in accounts payable and

accrued liabilities

21,613

(34,377)

(16,747)

(27,477)

Net cash provided by operating activities

373,814

273,153

639,091

572,260

Cash flows from investing activities:

Oil and gas expenditures

(389,119)

(223,259)

(699,301)

(426,941)

Sales of oil and gas and other assets

8,609

28,850

20,646

28,905

Other expenditures

(28,383)

(6,986)

(52,889)

(14,808)

Net cash used by investing activities

(408,893)

(201,395)

(731,544)

(412,844)

Cash flows from financing activities:

Net decrease in bank debt

-

-

-

(25,000)

Financing costs incurred

(100)

(100)

(100)

(100)

Dividends paid

(8,566)

(6,766)

(15,415)

(11,835)

Issuance of common stock and other

2,749

14,623

6,992

17,032

Net cash provided by (used by) financing activities

(5,917)

7,757

(8,523)

(19,903)

Net change in cash and cash equivalents

(40,996)

79,515

(100,976)

139,513

Cash and cash equivalents at beginning of period

54,146

62,542

114,126

2,544

Cash and cash equivalents at end of period

$

13,150  

$

142,057  

$

13,150  

$

142,057  

CONDENSED BALANCE SHEETS (unaudited)

June 30,

December 31,

Assets

2011

2010

(In thousands, except share data)

Current assets:

Cash and cash equivalents

$

13,150

$

114,126

Receivables, net

293,419

310,968

Oil and gas well equipment and supplies

78,584

81,871

Deferred income taxes

4,293

4,293

Derivative instruments

2,826

5,731

Assets held for sale

112,758

-

Other current assets

48,692

44,778

Total current assets

553,722

561,767

Oil and gas properties at cost, using the full cost method of accounting:

Proved properties

9,074,629

8,421,768

Unproved properties and properties under development,

not being amortized

655,924

547,609

9,730,553

8,969,377

Less – accumulated depreciation, depletion and amortization

(6,210,882)

(6,047,019)

Net oil and gas properties

3,519,671

2,922,358

Fixed assets, net

86,539

156,579

Goodwill

691,432

691,432

Other assets, net

32,764

26,111

$

4,884,128

$

4,358,247

Liabilities and Stockholders’ Equity

Current liabilities:

Accounts payable

$

47,506

$

47,242

Accrued liabilities

398,941

320,989

Liabilities associated with assets held for sale

8,112

-

Derivative instruments

4,519

9,587

Revenue payable

139,261

134,495

Total current liabilities

598,339

512,313

Long-term debt

350,000

350,000

Deferred income taxes

787,192

619,040

Other liabilities

260,996

267,062

Stockholders’ equity:

Preferred stock, $0.01 par value, 15,000,000 shares

authorized, no shares issued

-

-

Common stock, $0.01 par value, 200,000,000 shares authorized,

85,568,583 and 85,234,721 shares issued, respectively

856

852

Paid-in capital

1,892,898

1,883,065

Retained earnings

993,415

725,651

Accumulated other comprehensive income

432

264

2,887,601

2,609,832

$

4,884,128

$

4,358,247

SOURCE Cimarex Energy Co.



RELATED LINKS

http://www.cimarex.com