Cimarex Reports Third Quarter 2016 Results

News provided by

Cimarex Energy Co.

Nov 02, 2016, 04:01 ET

DENVER, Nov. 2, 2016 /PRNewswire/ -- Cimarex Energy Co. (NYSE: XEC) today reported third quarter 2016 operational and financial results and provided guidance for the fourth quarter and full-year 2016.  Cimarex also provided initial production guidance for 2017.  Highlights include:

  • Third quarter production of 947 MMcfe/day, slightly below company's guidance
  • Full-year 2016 production estimate lowered to 960-970 MMcfe/day due to well completion timing and the duration of larger than anticipated completions
  • 2017 production estimated to be 1,050 – 1,100 MMcfe/day; up 11 percent year-over-year at the mid-point
  • Initial estimate of 2017 drilling and completion capital is $600 million; in line with 2016 levels
  • Eight operated rigs currently working in core areas; nine planned by year-end

Tom Jorden, Cimarex Chairman and CEO said, "Our confidence in our well performance, Cimarex's operational excellence and the quality of our assets remains steadfast.  During the third quarter, we faced delays in our completion schedule, driven mostly by stimulations that were upsized beyond our original plans.  These upsized stimulations lengthened the time required for our pad completions.  The resultant production ramps slipped later into the fourth quarter, with peak production moving into first quarter 2017.  We will enter 2017 with great momentum." 

Cimarex reported a third quarter 2016 net loss of $12.8 million, or $0.14 per diluted share, including a non-cash impairment of oil and gas properties.  The adjusted third quarter net income (non-GAAP) was $38.2 million, or $0.41 per diluted share(1).  Third quarter 2016 net cash provided by operating activities was $215.6 million versus $206.0 million a year ago.  Adjusted cash flow from operations (non-GAAP) was $181.9 million versus $178.6 million a year ago(1). 

Total company production averaged 947 million cubic feet equivalent (MMcfe) per day during the third quarter, slightly below the low end of company guidance of 950 – 980 MMcfe per day.  Lower-than-expected third quarter production was caused by several factors including higher than anticipated ethane rejection, which accounted for seven MMcfe per day, and the timing of new well completions and subsequent production as well as production shut in during completion operations (13 MMcfe per day).  Natural gas production averaged 447 MMcf per day (47 percent of total), oil production averaged 44,532 barrels per day (28 percent of total) and natural gas liquids (NGL) production averaged 38,786 barrels per day (25 percent of total).  Compared to the same period in 2015, year-over-year natural gas volumes decreased four percent, oil volumes decreased 11 percent and NGL volumes were up eight percent.  In total, third quarter production was three percent lower than third quarter 2015 production.

Oil prices continued to negatively impact Cimarex's year-over-year quarterly financial results. Realized oil prices averaged $40.54 per barrel, down three percent versus a year ago. Natural gas prices were essentially flat year-over-year and averaged $2.66 per thousand cubic feet (Mcf) compared to $2.68 per Mcf a year ago.  Higher NGL prices partially offset lower oil prices and averaged $14.14 per barrel, up 16 percent from the third quarter of 2015.  (See table of Average Realized Price by Region below.)

Cimarex invested $489 million in exploration and development year-to-date, including $175 million during the third quarter, which was funded with cash flow from operations. Total debt at September 30, 2016 remained at $1.5 billion of long-term notes.  Cimarex had no borrowings under its revolving credit facility and a cash balance of $699 million at September 30, 2016. Debt was 39 percent of total capitalization (non-GAAP)(2). 

Outlook
The aforementioned timing of completions continues to have an impact on our production, with first production from significant infill projects in both the Permian Basin and Mid-Continent region now projected to come on later in the fourth quarter than previously planned.  As such, we have lowered our estimated fourth quarter production to 945 – 985 MMcfe per day to reflect these delays, resulting in projected average production for the full year of 960 - 970 MMcfe per day, down slightly from both our previous guidance of 980 – 1,000 MMcfe and from 2015 production of 985 MMcfe per day.   Our current completion schedule moves 10 net well completions previously scheduled for the fourth quarter into early 2017 which brings the total net wells completed in 2016 to 62 from our previous expectation of 72 net wells. 

Capital investment for exploration and development in 2016 is now estimated to be approximately $785 million, up $35 million from previous guidance.   The increase is primarily the result of higher planned drilling activity in the fourth quarter and acreage purchases made in the third quarter.  Cimarex has recently added three operated drilling rigs bringing the total gross operated rigs working in its core areas to eight with plans to increase that number to nine by yearend.


Expenses per Mcfe of production for the fourth quarter of 2016 are estimated to be: 


Production expense

$0.60 -  $0.70

Transportation, processing and other expense

  0.50  -  0.60

DD&A and ARO accretion*

  1.15  -  1.35

General and administrative expense

  0.20  -  0.25

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

   5.3  -  5.8%

*Excludes the potential impact of any future ceiling test writedown.


In 2017, capital investment associated with drilling and completions is currently expected to be approximately $600 million (compared to the estimated $600 million in 2016) and is estimated to generate average production of 1,050 – 1,100 MMcfe per day in 2017. 

Operations Update
Cimarex invested $175 million in exploration and development during the third quarter, bringing the year-to-date total to $489 million. Year-to-date, 61 percent has been invested in the Permian Basin and 38 percent in the Mid-Continent. Companywide, we completed 42 gross (17 net) wells during the quarter.   At September 30, 104 gross (45 net) wells were waiting on completion.  

Wells Brought on Production by Region:



For the Three Months Ended

For the Nine Months Ended


September 30,

September 30,


2016

2015

2016

2015

Gross wells










Permian Basin

17

4

37

72

Mid-Continent

25

52

61

82


42

56

98

154

Net wells










Permian Basin

10

4

22

52

Mid-Continent

7

10

14

19


17

14

36

71

Permian Region
Production from the Permian region averaged 517 MMcfe per day in the third quarter, an eight percent decrease compared to third quarter 2015 and a two percent increase sequentially. Quarterly oil volumes decreased 15 percent year-over-year to 35,930 barrels per day and accounted for 42 percent of the region's total production for the quarter.

Cimarex completed and brought on production 17 gross (ten net) wells in the Permian region during the third quarter. The gross operated wells completed include 13 Wolfcamp wells (ten in Culberson County and three in Reeves County) and two New Mexico Bone Spring wells.

On September 30, there were 25 gross (18 net) wells waiting on completion in the Delaware Basin including 11 gross (nine net) wells associated with multi-well infill and spacing projects that are expected to be completed in the fourth quarter of 2016.  Cimarex currently is operating five drilling rigs in the Delaware Basin.

Mid-Continent
Production from the Mid-Continent region averaged 427 MMcfe per day for the third quarter, a five percent increase over third quarter 2015 and an eight percent decrease sequentially.  Natural gas production grew two percent year-over-year, and crude oil volumes were up 22 percent over third quarter 2015.  NGL volumes increased six percent over third quarter 2015.

During the third quarter, Cimarex completed and brought on production 25 gross (seven net) wells in the Mid-Continent. At the end of the quarter, 79 gross (27 net) wells were waiting on completion including 47 gross (22 net) wells associated with the multi-well infill in the East Cana Core.  Cimarex currently is operating three drilling rigs in the Mid-Continent region with plans to go to four rigs by yearend.

Daily Production by Region:




For the Three Months Ended

For the Nine Months Ended


September 30,

September 30,


2016

2015

2016

2015

Permian Basin







Gas (MMcf)

178.4

197.6

177.7

179.3

Oil (Bbls)

35,930

42,367

35,939

44,632

NGL (Bbls)

20,549

18,430

17,952

16,938

Total Equivalent (MMcfe)

517.2

562.4

501.1

548.7









Mid-Continent







Gas (MMcf)

266.7

260.8

281.3

272.6

Oil (Bbls)

8,486

6,981

8,889

7,197

NGL (Bbls)

18,194

17,093

21,009

17,823

Total Equivalent (MMcfe)

426.8

405.3

460.7

422.7









Total Company







Gas (MMcf)

446.7

464.3

460.5

458.9

Oil (Bbls)

44,532

49,951

45,020

52,480

NGL (Bbls)

38,786

35,815

39,002

35,056

Total Equivalent (MMcfe)

946.6

978.9

964.6

984.1

Average Realized Price by Region:



For the Three Months Ended

For the Nine Months Ended


September 30,

September 30,


2016

2015

2016

2015

Permian Basin







Gas ($ per Mcf)

2.69

2.75

2.18

2.66

Oil ($ per Bbl)

40.65

42.04

36.32

45.31

NGL ($ per Bbl)

12.49

10.80

11.11

12.28









Mid-Continent







Gas ($ per Mcf)

2.63

2.63

2.10

2.63

Oil ($ per Bbl)

40.07

40.74

35.31

44.32

NGL ($ per Bbl)

16.00

13.66

14.07

15.88









Total Company







Gas ($ per Mcf)

2.66

2.68

2.13

2.65

Oil ($ per Bbl)

40.54

41.89

36.13

45.22

NGL ($ per Bbl)

14.14

12.19

12.70

14.13

Other

The following table summarizes the company's current open hedge positions:

Gas:

4Q16

1Q17

2Q17

3Q17

4Q17

Total

PEPL Collars (3)






Volume (MMBtu/d)

90,000

80,000

80,000

60,000

30,000

67,921

 Wtd Avg Floor 

$       2.42

$       2.38

$       2.38

$       2.47

$       2.68

$         2.43

 Wtd Avg Ceiling 

$       2.93

$       2.94

$       2.94

$       3.02

$       3.13

$         2.96








Perm EP Collars (3)






Volume (MMBtu/d)

70,000

70,000

70,000

40,000

20,000

53,895

 Wtd Avg Floor 

$       2.47

$       2.47

$       2.47

$       2.51

$       2.73

$         2.50

 Wtd Avg Ceiling 

$       2.96

$       3.01

$       3.01

$       3.04

$       3.15

$         3.01








Total Natural Gas Collars






Volume (MMBtu/d)

160,000

150,000

150,000

100,000

50,000

121,816








Oil:






WTI Three-Way Collars (4)






Volume (Bbl/d)

3,000

-

-

-

-

604

 Floor sold (put)  

$     40.00

$          -

$          -

$          -

$          -

$       40.00

 Floor purchased (put)  

$     50.00

$          -

$          -

$          -

$          -

$       50.00

 Ceiling sold (call)  

$     60.00

-

-

-

-

$       60.00








WTI  Collars (4)






Volume (Bbl/d)

14,000

14,000

14,000

10,000

5,000

11,383

 Wtd Avg Floor 

$     41.25

$     41.25

$     41.25

$     43.75

$     45.00

$       42.02

 Wtd Avg Ceiling 

$     50.24

$     50.24

$     50.24

$     53.34

$     54.42

$       51.16








Total Crude Oil Collars






Volume (Bbl/d)

17,000

14,000

14,000

10,000

5,000

11,987

Conference call and webcast
Cimarex will host a conference call Thursday, November 3, 2016, at 11:00 a.m. EDT. The call will be webcast and accessible on the company's website at www.cimarex.com. To participate in the live, interactive call, please dial 866-367-3053 ten minutes before the scheduled start time (international callers dial 1-412-902-4216).  The replay will be available on the Cimarex website or via the Cimarex App.

Investor Presentation
For more details on Cimarex's third quarter 2016 results, please refer to the company's investor presentation available at 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 Permian Basin and Mid-Continent areas of the U.S.

This press release contains forward-looking statements, including statements regarding projected results and future events. In particular, the company is providing a revised "2016 Outlook", which contains projections for certain 2016 operational and financial metrics.  These forward-looking statements are based on management's judgment as of the date of this press release and include certain risks and uncertainties.  Please refer to the company's Annual Report on Form 10-K for the year ended December 31, 2015, filed with the SEC, and other filings including our Current Reports on Form 8-K and Quarterly Reports on Form 10-Q, for a description of certain risk factors and other disclosures that may affect these forward-looking statements.

Actual results may differ materially from company projections and other forward-looking statements and can be affected by a variety of factors outside the control of the company including, among other things: oil, NGL and natural gas price volatility; declines in the values of our oil and gas properties resulting in impairments; costs and availability of third party facilities for gathering, processing, refining and transportation; the potential for production decline rates to be greater than expected; development drilling and testing results; performance of acquired properties and newly drilled wells; regulatory approvals, including regulatory restrictions on federal lands; legislative or regulatory changes, including initiatives related to air quality, produced water disposal and hydraulic fracturing; higher than expected costs and expenses, including the availability and cost of services and materials; unexpected future capital expenditures; the ability to receive drilling and other permits and rights-of-way in a timely manner; economic and competitive conditions; the ability to obtain industry partners to jointly explore certain prospects, and the willingness and ability of those partners to meet capital obligations when requested; changes in estimates of proved reserves; compliance with environmental and other regulations; environmental liabilities; derivative and hedging activities; risks associated with operating in one major geographic area; the success of the company's risk management activities; title to properties; litigation; the ability to complete property sales or other transactions; and other factors discussed in the company's reports filed with the SEC. Cimarex Energy Co. encourages readers to consider the risks and uncertainties associated with projections and other forward-looking statements. In addition, the company assumes no obligation to publicly revise or update any forward-looking statements based on future events or circumstances.

_________________________________

(1)

Adjusted net income (loss) and adjusted cash flow from operations are non-GAAP financial measures.  See below for a reconciliation of the related amounts.


(2)

Reconciliation of debt to total capitalization, which is a non-GAAP measure, is:  long-term debt of $1.5 billion divided by long-term debt of $1.5 billion plus stockholders' equity of $2.3 billion. Management believes this non-GAAP measure is useful information as it is a common statistic used in the investment community to assist with analysis of the financial condition of an entity.



(3)

PEPL refers to Panhandle Eastern Pipe Line Tex/OK Mid-Continent index.  Perm EP refers to El Paso Natural Gas Company, Permian Basin Index as quoted in Platt's Inside FERC.


(4)

WTI refers to West Texas Intermediate oil price as quoted on the New York Mercantile Exchange.

Reconciliation of Adjusted Net Income (Loss) and Adjusted Earnings (Loss) Per Share:

The following table provides a reconciliation from generally accepted accounting principles (GAAP) measures of net income (loss) and earnings (loss) per share to adjusted net income (loss) and adjusted earnings (loss) per share (non-GAAP) for the periods indicated








For the Three Months Ended

For the Nine Months Ended


September 30,

September 30,


2016

2015

2016

2015


(in thousands, except per share data)












Net income (loss)

$

(12,818)

$

(763,284)

$

(469,239)

$

(1,778,440)

Impairment of oil and gas properties

89,816

1,180,649

719,142

2,751,535

Mark-to-market (gain) loss on open derivative positions

(8,967)

(1,968)

32,769

(1,968)

Tax impact

(29,824)

(429,755)

(274,061)

(1,002,802)

Adjusted net income (loss)

$

38,207

$

(14,358)

$

8,611

$

(31,675)

Diluted earnings (loss) per share*

$

(0.14)

$

(8.21)

$

(5.04)

$

(19.14)

Adjusted diluted earnings (loss) per share*

$

0.41

$

(0.15)

$

0.09

$

(0.34)













Adjusted net income (loss) and adjusted diluted earnings (loss) per share excludes the noted items because management believes these items affect the comparability of operating results. The company discloses these non-GAAP financial measures as a useful adjunct to GAAP earnings because:

a)

Management uses adjusted net income (loss) to evaluate the company's operational trends and performance relative to other oil and gas exploration and production companies.


b)

Adjusted net income (loss) is more comparable to earnings estimates provided by research analysts.


*

Earnings (loss) per share are based on actual figures rather than the rounded figures presented

Reconciliation of Adjusted Cash Flow from Operations:

The following table provides a reconciliation from generally accepted accounting principles (GAAP) measures of net cash provided by operating activities to adjusted cash flows from operations (non-GAAP) for the periods indicated.











For the Three Months Ended

For the Nine Months Ended



September 30,

September 30,



2016

2015

2016

2015



(in thousands)

Net cash provided by operating activities

$

215,627

$

206,001

$

429,331

$

576,546

Change in operating assets and liabilities

(33,684)

(27,448)

(18,933)

41,310

Adjusted cash flow from operations

$

181,943

$

178,553

$

410,398

$

617,856














Management believes that the non-GAAP measure of adjusted 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 and dividends, without fluctuations caused by changes in current assets and liabilities, which are included in the GAAP measure of cash flow from operating activities.  It is also used by professional research analysts in providing investment recommendations pertaining to companies in the oil and gas exploration and production industry.

Oil and Gas Capitalized Expenditures:




For the Three Months Ended

For the Nine Months Ended



September 30,

September 30,



2016

2015

2016

2015



(in thousands)

Acquisitions:











Proved

$

—

$

—

$

3,324

$

—

Unproved

3,200

2,237

13,768

4,266

Net purchase price adjustments (*)

—

2

(2,928)

(12,003)



3,200

2,239

14,164

(7,737)














Exploration and development:











Land and Seismic

16,974

10,000

45,610

37,965

Exploration and development

157,571

174,270

443,279

644,796



174,545

184,270

488,889

682,761














Sale proceeds:











Proved

(189)

(25,405)

(12,689)

(27,804)

Unproved

(9,209)

(6,201)

(9,225)

(12,412)

Net purchase price adjustments (*)

(185)

1,374

(299)

1,468



(9,583)

(30,232)

(22,213)

(38,748)















$

168,162

$

156,277

$

480,840

$

636,276













*

The net purchase price adjustments relate to activity in prior periods.

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) (unaudited):


















For the Three Months Ended

For the Nine Months Ended




September 30,

September 30,




2016

2015

2016

2015

















(in thousands, except per share data)














Revenues:











Oil sales

$

166,079

$

192,501

$

445,657

$

647,850

Gas sales

109,278

114,649

268,501

331,985

NGL sales

50,464

40,159

135,755

135,236

Gas gathering and other, net

9,896

8,746

25,277

26,269




335,717

356,055

875,190

1,141,340

Costs and expenses:











Impairment of oil and gas properties

89,816

1,180,649

719,142

2,751,535

Depreciation, depletion, amortization and accretion

111,377

188,269

367,401

626,276

Production

52,976

69,334

180,891

222,145

Transportation, processing, and other operating

48,706

46,290

139,585

129,645

Gas gathering and other

7,905

8,429

23,477

28,599

Taxes other than income

15,974

19,717

43,879

67,678

General and administrative

20,118

20,413

55,439

50,405

Stock compensation

5,764

4,737

18,782

14,880

(Gain) loss on derivative instruments, net

(9,758)

(1,968)

23,050

(1,968)

Other operating, net

179

60

293

844




343,057

1,535,930

1,571,939

3,890,039














Operating income (loss)

(7,340)

(1,179,875)

(696,749)

(2,748,699)














Other (income) and expense:











Interest expense 

20,037

20,313

59,854

60,636

Amortization of deferred financing costs

894

1,103

2,706

3,333

Capitalized interest

(5,421)

(7,100)

(15,958)

(25,087)

Other, net

(3,828)

(2,375)

(7,489)

(9,814)














Income (loss) before income tax

(19,022)

(1,191,816)

(735,862)

(2,777,767)

Income tax expense (benefit)

(6,204)

(428,532)

(266,623)

(999,327)














Net income (loss)

$

(12,818)

$

(763,284)

$

(469,239)

$

(1,778,440)














Earnings (loss) per share to common stockholders:

























Basic 

$

(0.14)

$

(8.21)

$

(5.04)

$

(19.14)

Diluted

$

(0.14)

$

(8.21)

$

(5.04)

$

(19.14)














Dividends per share

$

0.08

$

0.16

$

0.24

$

0.48














Shares attributable to common stockholders:











Unrestricted common shares outstanding

93,221

92,969

93,221

92,969

Diluted common shares

93,221

92,969

93,221

92,969














Shares attributable to common stockholders and participating securities:











Basic shares outstanding

N/A*

N/A*

N/A*

N/A*

Fully diluted shares 

N/A*

N/A*

N/A*

N/A*














Comprehensive income (loss):











Net income (loss)

$

(12,818)

$

(763,284)

$

(469,239)

$

(1,778,440)

Other comprehensive income (loss):












Change in fair value of investments, net of tax 

287

(609)

567

(800)

Total comprehensive income (loss)

$

(12,531)

$

(763,893)

$

(468,672)

$

(1,779,240)










































*

Due to the net loss in the periods ended September 30, 2016 and 2015, shares of 94,973 and 94,568, respectively, which include participating securities, are not considered in the loss per share calculations.

Condensed Consolidated Cash Flow Statements (unaudited):







For the Three Months Ended

For the Nine Months Ended






September 30,

September 30,







2016

2015

2016

2015






(in thousands)

















Cash flows from operating activities:











Net income (loss)

$

(12,818)

$

(763,284)

$

(469,239)

$

(1,778,440)

Adjustment to reconcile net income (loss) to net cash












provided by operating activities:













Impairment of oil and gas properties

89,816

1,180,649

719,142

2,751,535



Depreciation, depletion, amortization and accretion

111,377

188,269

367,401

626,276



Deferred income taxes

(5,089)

(443,469)

(265,508)

(1,014,264)



Stock compensation

5,764

4,737

18,782

14,880



(Gain) loss on derivative instruments

(9,758)

(1,968)

23,050

(1,968)



Settlements on derivative instruments

791

—

9,718

—



Changes in non-current assets and liabilities

1,573

13,401

4,121

16,343



Amortization of deferred financing costs














and other, net

287

218

2,931

3,494

Changes in operating assets and liabilities:













Receivables, net

2,604

59,310

(1,723)

151,783



Other current assets

5,706

13,513

23,034

29,634



Accounts payable and other current liabilities

25,374

(45,375)

(2,378)

(222,727)





Net cash provided by operating activities

215,627

206,001

429,331

576,546

Cash flows from investing activities:











Oil and gas expenditures

(160,056)

(171,807)

(485,114)

(771,029)

Sales of oil and gas assets

6,383

29,827

19,013

38,343

Sales of other assets

5,494

340

5,718

1,057

Other capital expenditures

(6,239)

(22,203)

(24,013)

(58,085)





Net cash used by investing activities

(154,418)

(163,843)

(484,396)

(789,714)

Cash flows from financing activities:











Proceeds from sale of common stock

—

—

—

752,100

Financing and underwriting fees

—

(100)

(1)

(22,663)

Dividends paid

(7,588)

(15,082)

(30,243)

(43,211)

Proceeds from exercise of stock options and other

3,336

15,456

4,623

20,392





Net cash provided by (used in) financing activities

(4,252)

274

(25,621)

706,618

Net change in cash and cash equivalents

56,957

42,432

(80,686)

493,450

Cash and cash equivalents at beginning of period

641,739

856,880

779,382

405,862

Cash and cash equivalents at end of period

$

698,696

$

899,312

$

698,696

$

899,312

Condensed Consolidated Balance Sheets (unaudited):




September 30,

December 31,

2016

2015

Assets

(in thousands, except share data)

Current assets:





Cash and cash equivalents

$

698,696

$

779,382

Receivables, net

226,983

225,398

Oil and gas well equipment and supplies

34,909

54,579

Derivative instruments

1,147

10,745

Other current assets

4,768

7,826


Total current assets

966,503

1,077,930

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

Proved properties

16,013,316

15,546,948

Unproved properties and properties under development,






not being amortized

447,071

440,166




16,460,387

15,987,114

Less – accumulated depreciation, depletion, amortization and impairment

(13,756,311)

(12,710,968)


Net oil and gas properties

2,704,076

3,276,146

Fixed assets, net

214,448

230,009

Goodwill

620,232

620,232

Derivative instruments

3

501

Other assets, net

33,485

38,468



$

4,538,747

$

5,243,286

Liabilities and Stockholders' Equity




Current liabilities:





Accounts payable

$

53,428

$

66,815

Accrued liabilities

258,551

247,508

Derivative instruments

21,573

—

Revenue payable

107,766

95,744


Total current liabilities

441,318

410,067

Long-term debt:





Principal

1,500,000

1,500,000

Less – unamortized debt issuance costs

(12,629)

(14,380)


Long-term debt, net

1,487,371

1,485,620

Deferred income taxes

87,523

352,705

Other liabilities 

189,253

197,216


Total liabilities

2,205,465

2,445,608

Commitments and contingencies




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,






94,964,174 and 94,820,570 shares issued, respectively

950

948

Paid-in capital

2,774,804

2,762,976

Retained earnings (Accumulated deficit)

(443,480)

33,313

Accumulated other comprehensive income

1,008

441


Total shareholders' equity

2,333,282

2,797,678



$

4,538,747

$

5,243,286

SOURCE Cimarex Energy Co.