Cimarex Reports Fourth-Quarter and Full-Year 2017 Results

Actualizado el 14 de febrero, 2018 - 22.15hs.

Cimarex Reports Fourth-Quarter and Full-Year 2017 Results

PR Newswire

DENVER, Feb. 14, 2018 /PRNewswire/ --

  • Total company production averaged 1,204 MMcfe (201 MBOE) per day in the fourth quarter
    • Oil production up 36 percent year-over-year
  • Proved Reserves increased 16% to 3.4 Tcfe (559 MMBOE); Cimarex replaced 211% of 2017 production

Cimarex Energy Co. (PRNewsFoto/Cimarex Energy Co.) (PRNewsfoto/Cimarex Energy Co.)

Cimarex Energy Co. (NYSE: XEC) today reported fourth quarter 2017 net income of $174.7 million, or $1.83 per share, compared to fourth quarter 2016 net income of $47.8 million, or $0.50 per share.  Adjusted fourth quarter net income (non-GAAP) was $140.0 million, or $1.47 per share, compared to fourth quarter 2016 adjusted net income (non-GAAP) of $66.4 million, or $0.70 per share1.  Cash flow from operations was $340.8 million in the fourth quarter compared to $185.1 million in the fourth quarter of 2016.  Adjusted cash flow from operations (non-GAAP) totaled $357.1 million in the fourth quarter, a 63 percent increase from 2016 levels1

For the year, net income totaled $494.3 million, or $5.19 per share.  The adjusted net income (non-GAAP) for the full year was $443.2 million, or $4.65 per share1.  Cash flow from operations totaled $1,096.6 million in 2017 compared to $625.8 million in 2016.  Adjusted cash flow from operations (non-GAAP) totaled $1,185.6 million in 2017, an 88 percent increase from 2016 levels1.  Revenues in 2017 totaled $1.9 billion, a 53 percent increase from 2016.  The increase in revenues and cash flow was the result of higher production and higher realized product prices.

In the fourth quarter, total company production volumes averaged 1,204 million cubic feet equivalent (MMcfe) per day (201 thousand barrels of oil equivalent (MBOE) per day), up 25 percent from a year ago.  Fourth quarter oil production averaged 61,771 barrels per day, an increase of 36 percent from 2016 levels.  For the full year, Cimarex reported daily production volumes of 1,142 MMcfe per day (190 MBOE per day), up 19 percent from our 2016 average daily output of 963 MMcfe per day.

Cimarex invested $1.28 billion in exploration and development (E&D) in 2017, including $344 million in the fourth quarter.  Investments made in 2017 were funded with cash flow and cash on hand.  E&D capital exceeded the company's estimate for 2017 of $1.2 billion due to higher infrastructure spending, higher working interest and costs in outside operated wells, land acquisition and acceleration of activity. 

Proved reserves at December 31, 2017 were 3.4 trillion cubic feet equivalent (Tcfe) or 559 million barrels of oil equivalent (MMBOE), up 16 percent year over year.  Proved developed reserves increased 21 percent to 2.8 Tcfe.  Cimarex added 941 Bcfe through extensions and discoveries and deducted 60 Bcfe through net revisions resulting in reserve replacement of 211 percent of 2017 production.  Proved reserves are 83 percent proved developed.

Realized oil prices averaged $51.68 per barrel in the fourth quarter, 16 percent higher than the same period a year ago.  Realized natural gas prices were lower in the fourth quarter and averaged $2.58 per Mcf versus $2.86 a year ago.  Realized NGL prices averaged $25.88 per barrel up 43 percent compared to fourth quarter 2016.  For the full year, realized oil prices averaged $47.06, up 23 percent from 2016.  Realized natural gas prices averaged $2.76 per Mcf, a 19 percent increase from 2016.  Realized NGL prices averaged $21.61 per barrel, up 54 percent from 2016 levels.

Total debt at December 31, 2017 consisted of $1.5 billion of long-term notes, with $750 million maturing in 2024 and $750 million maturing in 2027. Cimarex had no borrowings under its revolving credit facility and had a cash balance of $401 million. Debt was 37 percent of total capitalization2

Operations Update
Cimarex invested $1.28 billion in exploration and development in 2017, 59 percent in the Permian region and 39 percent in the Mid-Continent.  An additional $45 million was invested in midstream operations in 2017.  During 2017, Cimarex participated in the drilling and completion of 319 gross (98 net) wells.

At year-end, 91 gross (34 net) wells were waiting on completion, of which 60 gross (16 net) are in the Mid-Continent and 31 gross (18 net) in the Permian.   Cimarex currently is operating 14 drilling rigs.  


WELLS COMPLETED BY REGION










For the Three Months Ended


For the Twelve Months Ended


December 31,


December 31,


2017


2016


2017


2016

Gross wells








Permian Basin

32


11


97


48

Mid-Continent

85


44


222


105


117


55


319


153

Net wells








Permian Basin

14


8


55


30

Mid-Continent

10


17


43


31


24


25


98


61

Permian Basin
Production from the Permian Basin averaged 673 MMcfe per day in the fourth quarter, a 32 percent increase over fourth quarter 2016, and a seven percent increase sequentially.  Oil volumes averaged 47,642 barrels per day and represented 42 percent of the region's total equivalent production.  For the full year, production averaged 631 MMcfe per day, up 25 percent year over year.

Cimarex brought 32 gross (14 net) wells on production in the Permian region during the fourth quarter, bringing the total for the year to 97 gross (55 net) wells.  Cimarex currently operates ten rigs in the Permian region. 

Activity in the Permian region in the fourth quarter included the completion of 14 wells in the Wolfcamp, Avalon and Bone Spring formations.  Cimarex also began drilling operations on two multi-well Wolfcamp developments.  The Animal Kingdom project, located in Culberson County, Texas, consists of eight wells targeting multiple landings in the Lower Wolfcamp and the Snowshoe project, located in Reeves County, Texas, is an eight-well project targeting multiple landings in the Upper Wolfcamp.  Both are long lateral developments with first production expected during the third quarter of 2018. 

As of year-end, Cimarex has completed 70 10,000-foot lateral Wolfcamp wells including 23 in the Lower Wolfcamp and 47 in the Upper Wolfcamp.  In addition to the multiple spacing pilots drilled in the Wolfcamp in 2017, another highlight of the year's program was the completion of four 10,000-foot lateral Upper Wolfcamp wells on the western half of our Culberson County acreage, an area that was previously untested.  These wells had an average 30-day peak initial production of 2,587 BOE per day (56 percent oil, 26 percent gas, 18 percent NGL).  A fifth well is currently flowing back.  Cimarex has additional activity planned in this area in 2018 including a development project with drilling scheduled to begin in the third quarter.

Mid-Continent
Production from the Mid-Continent region averaged 529 MMcfe per day in the fourth quarter, a 19 percent increase over fourth-quarter 2016, and a three percent increase sequentially.  Oil volumes averaged 13,999 barrels per day and represented 16 percent of the region's total equivalent production. For the full year, production averaged 509 MMcfe per day, up 11 percent year over year.

Wells brought on production during the fourth quarter totaled 85 gross (10 net) in the Mid-Continent region, bringing the total wells in 2017 to 222 gross (43 net).  As planned, drilling to hold company's Meramec acreage was completed in 2017. 

Activity in the region continues to focus on the Woodford and Meramec shale plays in western Oklahoma.  Recent highlights include the completion of a three-well, stacked Woodford/Meramec test in the 14N-10W township in Canadian County, Oklahoma.  This test confirms results of our previous wells in the area.  Cimarex operates nearly all of the 24,000 gross acres leased in the 14N-10W area with an average 62 percent working interest.  Drilling activity continues in the high return Lone Rock area where Cimarex has six long lateral Woodford wells on production with average 30-day peak initial production of 1,806 BOE per day (35 percent oil, 36 percent gas, 29 percent NGL).  The company is currently drilling the Shelly spacing pilot in Lone Rock with first production expected mid-summer.

Cimarex currently operates four rigs in the Mid-Continent.  

Please see the latest Corporate Presentation on our website www.cimarex.com for further details. 

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

DAILY PRODUCTION BY REGION












For the Three Months Ended


For the Twelve Months Ended



December 31,


December 31,



2017


2016


2017


2016

Permian Basin









Gas (MMcf)

232.6


179.3


217.9


178.1


Oil (Bbls)

47,642


36,253


44,577


36,018


NGL (Bbls)

25,747


19,114


24,269


18,244


Total Equivalent (MMcfe)

672.9


511.5


630.9


503.7


Total Equivalent (BOE)

112,157


85,250


105,157


83,945










Mid-Continent









Gas (MMcf)

300.3


276.3


294.4


280.1


Oil (Bbls)

13,999


9,205


12,457


8,969


NGL (Bbls)

24,176


19,036


23,296


20,513


Total Equivalent (MMcfe)

529.3


445.8


508.9


456.9


Total Equivalent (BOE)

88,225


74,291


84,822


76,165










Total Company









Gas (MMcf)

534.0


457.2


513.6


459.6


Oil (Bbls)

61,771


45,567


57,153


45,158


NGL (Bbls)

49,954


38,184


47,600


38,797


Total Equivalent (MMcfe)

1,204.4


959.7


1,142.1


963.4


Total Equivalent (BOE)

200,729


159,951


190,354


160,555



















AVERAGE REALIZED PRICE BY REGION












For the Three Months Ended


For the Twelve Months Ended



December 31,


December 31,



2017


2016


2017


2016

Permian Basin









Gas ($ per Mcf)

2.56


2.85


2.72


2.35


Oil ($ per Bbl)

51.38


44.75


46.96


38.45


NGL ($ per Bbl)

25.07


15.71


20.25


12.32










Mid-Continent









Gas ($ per Mcf)

2.60


2.86


2.78


2.29


Oil ($ per Bbl)

52.72


44.36


47.42


37.65


NGL ($ per Bbl)

26.73


20.58


23.02


15.59










Total Company









Gas ($ per Mcf)

2.58


2.86


2.76


2.31


Oil ($ per Bbl)

51.68


44.67


47.06


38.30


NGL ($ per Bbl)

25.88


18.15


21.61


14.05

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



1Q18

2Q18

3Q18

4Q18

1Q19

2Q19

3Q19

Gas Collars:

PEPL³









Volume (MMBtu/d)

130,000

120,000

90,000

60,000

50,000

50,000

20,000


Wtd Avg Floor

2.57

2.39

2.33

2.28

2.23

2.23

1.98


Wtd Avg Ceiling

2.93

2.70

2.56

2.49

2.46

2.46

2.16











El Paso Perm³









Volume (MMBtu/d)

90,000

90,000

70,000

50,000

40,000

40,000

20,000


Wtd Avg Floor

2.52

2.22

2.14

2.06

1.98

1.98

1.65


Wtd Avg Ceiling

2.84

2.48

2.32

2.23

2.14

2.14

1.80










Oil Collars:

WTI









Volume (Bbl/d)

29,000

29,000

25,000

19,000

13,000

13,000

6,000


Wtd Avg Floor

47.28

47.83

47.48

48.63

48.92

48.92

50.00


Wtd Avg Ceiling

56.33

57.93

57.76

58.80

61.04

61.04

66.82










Oil Basis Swaps:

WTI Midland









Volume (Bbl/d)

13,000

14,000

14,000

9,000

6,000

6,000

1,000


Weighted Avg Differential⁶

(0.72)

(0.72)

(0.72)

(0.59)

(0.51)

(0.51)

(0.70)

Conference call and webcast
Cimarex will host a conference call tomorrow, February 15, at 11:00 a.m. EST (9:00 a.m. MST).  The call will be webcast and accessible on the Cimarex website at www.cimarex.com.  To participate in the live, interactive call, please dial 866-367-3053 ten minutes before the scheduled start (callers in Canada dial 855-669-9657 and international callers dial 412-902-4216).  A replay will be available on the company's website. 

Investor Presentation
For more details on Cimarex's 2017 results, please refer to the company's investor presentation available at www.cimarex.com.

This press release contains forward-looking statements, including statements regarding projected results and future events. 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/A for the year ended December 31, 2016, filed with the SEC, in the 2017 Annual Report and Form 10-K to be filed with the SEC, and other filings including our Current Reports on Form 8-K and Quarterly Reports on Form 10-Q, for a list of certain risk factors 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 levels and volatility; higher than expected costs and expenses, including the availability and cost of services and materials; compliance with environmental and other regulations; risks associated with operating in one major geographic area; environmental liabilities; the ability to receive drilling and other permits and rights-of-way in a timely manner; development drilling and testing results; declines in the values of our oil and gas properties resulting in impairments; the potential for production decline rates to be greater than expected; performance of acquired properties and newly drilled wells; costs and availability of third party facilities for gathering, processing, refining and transportation; regulatory approvals, including regulatory restrictions on federal lands; legislative or regulatory changes, including initiatives related to hydraulic fracturing, emissions and disposal of produced water; unexpected future capital expenditures; economic and competitive conditions; the availability and cost of capital; 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; derivative and hedging activities; the success of the company's risk management activities; title to properties; litigation; the ability to complete property sales or other transactions; the effectiveness of controls over financial reporting; 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 and adjusted cash flow from operations are non-GAAP financial measures.  See below for reconciliations of the related GAAP amounts.



2

Debt to total capitalization is calculated by dividing long-term debt by long-term debt plus stockholders' equity. 



3

PEPL refers to Panhandle Eastern Pipe Line Tex/OK Mid-Continent index and El Paso Perm is El Paso Permian Basin index both as quoted in Platt's Inside FERC.



4

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



5

Index price on basis swaps is WTI Midland as quoted by Argus Americas Crude.



6

Index price on basis swaps is WTI NYMEX less the weighted average differential shown in table.

 

RECONCILIATION OF ADJUSTED NET INCOME AND ADJUSTED EARNINGS 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 and adjusted earnings per share (non-GAAP) for the periods indicated.





For the Three Months Ended



For the Twelve Months Ended




December 31,



December 31,




2017



2016



2017



2016




(in thousands, except per share data)














Net income (loss)

$

174,696


$

47,783


$

494,329


$

(408,803)


Impairment of oil and gas properties








757,670


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


30,160



30,417



(22,843)



63,186


Loss on early extinguishment of debt


18





28,187




Asset Retirement Obligation


10,460





10,460




Impact of reduction in Federal statutory tax rate


(61,146)





(61,146)




Tax impact*


(14,142)



(11,832)



(5,768)



(298,867)

Adjusted net income

$

140,046


$

66,368


$

443,219


$

113,186

Diluted earnings (loss) per share**

$

1.83


$

0.50


$

5.19


$

(4.38)

Adjusted diluted earnings per share**

$

1.47


$

0.70


$

4.65


$

1.19














Diluted shares attributable to common stockholders and participating securities













95,363



95,175



95,265



95,176














Adjusted net income and adjusted diluted earnings 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 to evaluate the company's operating performance between periods and to compare the company's performance to other oil and gas exploration and production companies.
















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














*

The tax impact of the 2016 periods is calculated using a tax rate that excludes the effects of tax adjustments recorded in the fourth quarter primarily related to the revision of previous tax balances.














**

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 Twelve Months Ended




December 31,



December 31,




2017



2016



2017



2016




(in thousands)

Net cash provided by operating activities

$

340,759


$

185,061


$

1,096,564


$

625,849


Change in operating assets and liabilities


16,339



33,679



89,067



3,289

Adjusted cash flow from operations

$

357,098


$

218,740


$

1,185,631


$

629,138














Management uses the non-GAAP financial measure of adjusted cash flow from operations as a means of measuring our ability to fund our capital program and dividends, without fluctuations caused by changes in current assets and liabilities, which are included in the GAAP measure of net cash provided by operating activities.  Management believes this non-GAAP financial measure provides useful information to investors for the same reason, and that it is also used by professional research analysts in providing investment recommendations pertaining to companies in the oil and gas exploration and production industry.

 

PROVED RESERVES














Gas


Oil


NGL


Total


Total



(Bcf)


(MBbls)


(MBbls)


(Bcfe)


(MBOE)












December 31, 2016

1,471


105,878


130,633


2,890.5


481,748


Revisions of previous estimates

(40)


(1,225)


(2,099)


(59.7)


(9,951)


Extensions and discoveries

364


53,464


42,692


940.7


156,786


Purchase of reserves

1


42


78


1.4


227


Production

(187)


(20,861)


(17,374)


(416.9)


(69,479)


Sale of properties

(1)


(60)


(70)


(1.8)


(294)

December 31, 2017

1,608


137,238


153,860


3,354.2


559,037












Proved developed reserves










Year-end 2016

1,145


92,032


99,176


2,292.0


381,995

Year-end 2017

1,335


114,116


126,227


2,776.6


462,761














2017


2016


% Change
















Pre-tax PV-10 ($ in millions) *

3,725


2,122


76 %





Standardized Measure ($ in millions)

3,285


1,893


74 %
















Average prices used in Standardized Measure

2017


2016


% Change
















Gas ($ per Mcf)

2.98


2.48


20 %





Oil ($ per Bbl)

51.34


42.75


20 %





NGL ($ per Bbl)

19.09


14.37


33 %
















* Pre-tax PV-10 is a non-GAAP financial measure. Pre-tax PV-10 is comparable to the standardized measure, which is the most directly comparable GAAP financial measure. Pre-tax PV-10 is computed on the same basis as the standardized measure but without deducting future income taxes. As of December 31, 2017 and 2016, Cimarex's discounted future income taxes were $439.8 million and $229.3 million, respectively. Cimarex's standardized measure of discounted future net cash flows was $3,285.0 million at year-end 2017 and $1,892.6 million at year-end 2016. Management uses pre-tax PV-10 as one measure of the value of the company's proved reserves and to compare relative values of proved reserves to other exploration and production companies without regard to income taxes. Management believes pre-tax PV-10 is a useful measure for comparison of proved reserve values among companies because, unlike standardized measure, it excludes future income taxes that often depend on the unique income tax characteristics of the owner of the reserves rather than on the nature, location and quality of the reserves themselves. Management further believes that professional research analysts and rating agencies use pre-tax PV-10 in similar ways. However, pre-tax PV-10 is not a substitute for the standardized measure of discounted future net cash flows. Cimarex's pre-tax PV-10 and the standardized measure of discounted future net cash flows do not purport to present the fair value of its oil and natural gas reserves.























PROVED RESERVES BY REGION
















Gas


Oil


NGL


Total


Total



(Bcf)


(MBbls)


(MBbls)


(Bcfe)


(MBOE)













Mid-Continent

1,033


31,853


85,292


1,735.6


289,261


Permian Basin

574


105,198


68,530


1,616.1


269,354


Other

1


187


38


2.5


422



1,608


137,238


153,860


3,354.2


559,037

 

OIL AND GAS CAPITALIZED EXPENDITURES















For the Three Months Ended



For the Twelve Months Ended



December 31,



December 31,



2017



2016



2017



2016



(in thousands)

Acquisitions:












Proved

$

678


$

60


$

938


$

2,678

Unproved


2,590



319



6,853



11,865



3,268



379



7,791



14,543













Exploration and development:












Land and seismic


17,157



16,260



140,516



61,870

Exploration and development


326,855



229,603



1,140,548



672,882



344,012



245,863



1,281,064



734,752













Sale proceeds:












Proved


(1,947)



(2,473)



(2,032)



(15,078)

Unproved


(1,597)



(1)



(9,648)



(9,609)



(3,544)



(2,474)



(11,680)



(24,687)














$

343,736


$

243,768


$

1,277,175


$

724,608

 

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (unaudited)



















For the Three Months Ended



For the Twelve Months Ended





December 31,



December 31,





2017



2016



2017



2016


















(in thousands, except per share data)















Revenues:













Oil sales

$

293,686


$

187,277


$

981,646


$

632,934


Gas sales


126,810



120,285



516,936



388,786


NGL sales


118,918



63,743



375,421



199,498


Gas gathering and other, net


11,526



10,850



44,246



36,127





550,940



382,155



1,918,249



1,257,345

Costs and expenses:













Impairment of oil and gas properties








757,670


Depreciation, depletion, amortization, and accretion


142,482



91,096



461,655



400,176


Production


71,771



51,111



262,180



232,002


Transportation, processing, and other operating


59,606



51,140



231,640



190,725


Gas gathering and other


9,910



8,308



35,840



31,785


Taxes other than income


26,760



18,067



89,864



61,946


General and administrative


21,161



18,462



79,996



73,901


Stock compensation


6,637



5,741



26,256



24,523


(Gain) loss on derivative instruments, net


29,051



32,699



(21,210)



55,749


Other operating expense, net


337



462



1,314



755





367,715



277,086



1,167,535



1,829,232















Operating income (loss)


183,225



105,069



750,714



(571,887)















Other (income) and expense:













Interest expense


16,836



20,712



74,821



83,272


Capitalized interest


(5,492)



(5,290)



(22,948)



(21,248)


Loss on early extinguishment of debt


18





28,187




Other, net


(2,338)



(3,218)



(11,342)



(10,707)















Income (loss) before income tax


174,201



92,865



681,996



(623,204)

Income tax expense (benefit)


(495)



45,082



187,667



(214,401)















Net income (loss)

$

174,696


$

47,783


$

494,329


$

(408,803)















Earnings (loss) per share to common stockholders:













Basic

$

1.83


$

0.50


$

5.19


$

(4.38)


Diluted

$

1.83


$

0.50


$

5.19


$

(4.38)















Dividends declared per share

$

0.08


$

0.08


$

0.32


$

0.32















Shares attributable to common stockholders:













Unrestricted common shares outstanding


93,569



93,379



93,466



93,379


Diluted common shares


93,612



93,422



93,509



93,379















Comprehensive income (loss):













Net income (loss)

$

174,696


$

47,783


$

494,329


$

(408,803)


Other comprehensive income:














Change in fair value of investments, net of tax


394



(64)



1,254



504


Total comprehensive income (loss)

$

175,090


$

47,719


$

495,583


$

(408,299)

 

CONDENSED CONSOLIDATED CASH FLOW STATEMENTS (unaudited)




















For the Three Months Ended



For the Twelve Months Ended





December 31,



December 31,






2017



2016



2017



2016





(in thousands)
















Cash flows from operating activities:













Net income (loss)

$

174,696


$

47,783


$

494,329


$

(408,803)


Adjustments to reconcile net income (loss) to net cash provided by operating activities:














Impairment of oil and gas properties








757,670



Depreciation, depletion, amortization, and accretion


142,482



91,096



461,655



400,176



Deferred income taxes


2,311



45,082



190,479



(213,286)



Stock compensation


6,637



5,741



26,256



24,523



(Gain) loss on derivative instruments, net


29,051



32,699



(21,210)



55,749



Settlements on derivative instruments


1,109



(2,281)



(1,633)



7,437



Loss on early extinguishment of debt


18





28,187





Changes in non-current assets and liabilities


(253)



(254)



1,891



3,867



Other, net


1,047



(1,126)



5,677



1,805


Changes in operating assets and liabilities:














Receivables


(57,236)



(47,617)



(186,157)



(49,340)



Other current assets


1,441



(2,154)



(17,931)



20,880



Accounts payable and other current liabilities


39,456



16,092



115,021



25,171




Net cash provided by operating activities


340,759



185,061



1,096,564



625,849

Cash flows from investing activities:













Oil and gas capital expenditures


(331,177)



(214,444)



(1,233,126)



(699,558)


Sales of oil and gas assets


3,544



2,474



11,680



21,487


Sales of other assets


391



2,171



901



7,889


Other capital expenditures


(14,020)



1,785



(45,352)



(22,228)




Net cash used by investing activities


(341,262)



(208,014)



(1,265,897)



(692,410)

Cash flows from financing activities:













Borrowings of long-term debt






748,110




Repayments of long-term debt






(750,000)




Call premium, financing, and underwriting fees


(118)



(100)



(29,312)



(101)


Dividends paid


(7,789)



(7,781)



(30,532)



(38,024)


Employee withholding taxes paid upon the net settlement of equity-classified stock awards


(14,032)



(15,167)



(21,669)



(26,624)


Proceeds from exercise of stock options


168



181



394



4,804




Net cash used by financing activities


(21,771)



(22,867)



(83,009)



(59,945)

Net change in cash and cash equivalents


(22,274)



(45,820)



(252,342)



(126,506)

Cash and cash equivalents at beginning of period


422,808



698,696



652,876



779,382

Cash and cash equivalents at end of period

$

400,534


$

652,876


$

400,534


$

652,876

 

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited)




December 31,


December 31,


2017


2016

Assets


(in thousands, except share and per
share information)

Current assets:







Cash and cash equivalents

$

400,534


$

652,876


Receivables, net of allowance


460,174



274,570


Oil and gas well equipment and supplies


49,722



33,342


Derivative instruments


15,151




Other current assets


10,054



8,516



Total current assets


935,635



969,304

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







Proved properties


17,513,460



16,225,495


Unproved properties and properties under development, not being amortized


476,903



478,277





17,990,363



16,703,772


Less – accumulated depreciation, depletion, amortization, and impairment


(14,748,833)



(14,349,505)



Net oil and gas properties


3,241,530



2,354,267

Fixed assets, net of accumulated depreciation of $290,114 and $246,901, respectively


210,922



205,465

Goodwill


620,232



620,232

Derivative instruments


2,086



Deferred income taxes




55,835

Other assets


32,234



32,621




$

5,042,639


$

4,237,724

Liabilities and Stockholders' Equity






Current liabilities:







Accounts payable

$

98,386


$

74,486


Accrued liabilities


351,849



278,781


Derivative instruments


42,066



49,370


Revenue payable


187,273



119,715



Total current liabilities


679,574



522,352

Long-term debt:







Principal


1,500,000



1,500,000


Less – unamortized debt issuance costs and discount


(13,080)



(12,061)



Long-term debt, net


1,486,920



1,487,939

Deferred income taxes


101,618



Derivative Instruments


4,268



2,570

Other liabilities


201,981



181,874



Total liabilities


2,474,361



2,194,735

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, 95,437,434 and 95,123,525 shares issued, respectively


954



951


Additional paid-in capital


2,764,384



2,763,452


Retained earnings (accumulated deficit)


(199,259)



(722,359)


Accumulated other comprehensive income


2,199



945



Total stockholders' equity


2,568,278



2,042,989




$

5,042,639


$

4,237,724

 

Cision View original content with multimedia:http://www.prnewswire.com/news-releases/cimarex-reports-fourth-quarter-and-full-year-2017-results-300599015.html

SOURCE Cimarex Energy Co.

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