CIMAREX ENERGY CO - FORM 8-K - EX-99.1 - EXHIBIT 99.1

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8-K - FORM 8-K - CIMAREX ENERGY CO	v432039_8k.htm
EX-99.2 - EXHIBIT 99.2 - CIMAREX ENERGY CO	v432039_ex99-2.htm

Exhibit 99.1

Cimarex Reports Fourth-Quarter and Full-Year 2015 Results

- 2015 Capex down 53% from 2014 levels

- Full-year Production up 13% to 985 MMcfe per day

DENVER, Feb. 16, 2016 /PRNewswire/ -- Cimarex Energy Co. (NYSE: XEC) today reported a fourth quarter 2015 net loss of $630.5 million, or $6.78 per share. The adjusted fourth quarter net loss was $23.0 million, or $0.25 per share, compared to fourth-quarter 2014 adjusted net income of $76.4 million, or $0.87 per diluted share⁽¹⁾. For the year, Cimarex recorded a net loss of $2.4 billion, or $25.92 per share. The adjusted net loss for the full year was $0.60 per share⁽¹⁾. Adjusted cash flow from operations totaled $744 million in 2015, a 54 percent drop from 2014 levels⁽¹⁾. Revenues in 2015 totaled $1.5 billion, a 40 percent decrease from 2014. The decrease in revenues, earnings and cash flow was the result of substantially lower product prices received. (See table of Average Realized Price by Region below.)

Total company production volumes averaged 986 million cubic feet equivalent (MMcfe) per day in the fourth quarter, up four percent from a year ago. Weather and facilities disruptions negatively impacted fourth quarter production by approximately 30 MMcfe per day. For the full year, Cimarex reported daily production volumes of 985 MMcfe per day, up 13 percent from our 2014 average daily output of 869 MMcfe per day.

Cimarex invested $877 million in exploration and development in 2015. This was down significantly from the amount Cimarex invested in 2014 when E&D capital investment totaled $1.9 billion. Investments made in 2015 were funded with cash flow and cash on hand.

Proved reserves at December 31, 2015 were 2.9 trillion cubic feet equivalent (Tcfe), down seven percent year over year. Cimarex added 429 Bcfe through extensions and discoveries and had 142 Bcfe in net performance revisions. As a result, the company replaced 159 percent of 2015 production (excludes negative price and operating cost revisions of 399 Bcfe and 19 Bcfe, respectively). Proved reserves are 75 percent proved developed. Prices used for 2015 proved reserve reporting for oil, gas and NGLs were down 47 percent, 40 percent and 53 percent, respectively, from 2014. (See table of Proved Reserves below.)

Continued declines in oil and natural gas prices impacted the company's financial results for both the fourth quarter and full year. Realized oil prices averaged $37.32 per barrel in the fourth quarter and $43.38 per barrel for the full year, down 43 percent and 48 percent, versus the respective periods a year ago. In the fourth quarter, natural gas prices averaged $2.20 per Mcf and NGL prices averaged $12.72 per barrel compared to $3.95 and $25.32, respectively, in the fourth quarter of 2014. For the full year, natural gas prices averaged $2.53 per Mcf and NGL prices averaged $13.75 per barrel compared to $4.43 and $33.14, respectively, in 2014. Total debt at December 31, 2015 consisted of $1.5 billion of long-term notes, with $750 million maturing in 2022 and $750 million maturing in 2024. Cimarex had no borrowings under its revolving credit facility and had a cash balance of $779 million. Debt was 35 percent of total capitalization⁽²⁾.

Operations Update

During 2015, Cimarex participated in the drilling and completion of 219 gross (99 net) wells, 123 of which we operate. Total exploration and development investment was $877 million. Of the total, 55 percent was invested in Permian projects and 45 percent in the Mid-Continent.

At year-end, 49 gross (20 net) wells were drilled and awaiting completion – 37 gross (13 net) in the Mid-Continent and 12 gross (seven net) in the Permian.

WELLS BROUGHT ON PRODUCTION BY REGION

		For the Three Months Ended		For the Twelve Months Ended
		December 31,		December 31,
		2015	2014	2015	2014
	Gross wells
	Permian Basin	13	54	85	171
	Mid-Continent	52	33	134	139
	Other	—	—	—	2
		65	87	219	312
	Net wells
	Permian Basin	8	39	60	117
	Mid-Continent	20	14	39	57
	Other	—	—	—	1
		28	53	99	175

Permian Basin

Production from the Permian Basin averaged 520 MMcfe per day in the fourth quarter, a 16 percent increase over fourth-quarter 2014 and a decrease of eight percent sequentially. Quarterly oil volumes averaged 38,423 barrels per day, flat year-over-year, and accounted for 44 percent of the region's total production for the quarter.

Cimarex completed and brought on production 13 gross (eight net) Permian Basin wells during the fourth quarter, bringing the total for 2015 to 85 gross (60 net) wells.

One highlight of the 2015 Permian program was the drilling and completion of 19 gross (13 net) New Mexico Bone Spring wells. Average 30-day gross peak production from these wells was 1,404 barrels of oil equivalent (BOE) per day (63 percent oil).

In Culberson County, Texas, Cimarex has completed 27 long lateral Wolfcamp wells to date including 18 in the Wolfcamp D (Lower Wolfcamp) and nine in the Wolfcamp A (Upper Wolfcamp). Of note were two 7,500-foot Upper Wolfcamp laterals completed during the fourth quarter using a larger stimulation. Average 30-day gross peak production from these two wells was 1,879 BOE per day (51 percent oil, 30 percent gas, 19 percent NGL).

Mid-Continent

Cimarex drilled and completed 134 gross (39 net) wells in the Mid-Continent area in 2015. The majority of the activity was in the Cana-Woodford and Meramec shale plays in western Oklahoma. At the end of the fourth quarter, 37 gross (13 net) wells were awaiting completion; 30 gross (10 net) Cana-Woodford wells and seven gross (three net) Meramec wells. Mid-Continent production averaged 461.1 MMcfe per day for the fourth quarter of 2015 and 432.4 MMcfe per day for the full year.

Cimarex completed its second 10,000-foot lateral well in the Meramec formation in the fourth quarter. Initial gross 30-day peak production from the first two long lateral Meramec wells averaged 15.0 MMcfe per day (53 percent gas, 24 percent oil, 23 percent NGL). A third Meramec long lateral is flowing back. In addition, Cimarex now has 17 5,000-foot Meramec wells on production that have an average 30-day initial peak production rate of 8.4 MMcfe per day (33 percent oil, 44 percent gas, 23 percent NGL) with oil yields ranging from 11 bbl/MMcf to 486 bbl/MMcf.

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,
		2015	2014	2015	2014
Permian Basin
	Gas (MMcf)	185.4	142.2	180.8	123.8
	Oil (Bbls)	38,423	38,246	43,067	34,390
	NGL (Bbls)	17,350	12,444	17,042	11,471
	Total Equivalent (MMcfe)	520.0	446.4	541.5	399.0

Mid-Continent
	Gas (MMcf)	286.8	314.5	276.2	292.4
	Oil (Bbls)	8,490	7,889	7,523	7,348
	NGL (Bbls)	20,561	21,044	18,513	19,122
	Total Equivalent (MMcfe)	461.1	488.0	432.4	451.2

Total Company
	Gas (MMcf)	475.2	464.6	463.0	425.0
	Oil (Bbls)	47,133	46,990	51,132	42,846
	NGL (Bbls)	37,964	33,830	35,789	31,078
	Total Equivalent (MMcfe)	985.7	949.5	984.5	868.6




AVERAGE REALIZED PRICE BY REGION

		For the Three Months Ended		For the Twelve Months Ended
		December 31,		December 31,
		2015	2014	2015	2014
Permian Basin
	Gas ($ per Mcf)	2.24	3.96	2.55	4.48
	Oil ($ per Bbl)	37.64	64.38	43.58	82.44
	NGL ($ per Bbl)	10.97	22.23	11.94	30.04

Mid-Continent
	Gas ($ per Mcf)	2.16	3.94	2.51	4.42
	Oil ($ per Bbl)	35.80	66.91	41.90	88.23
	NGL ($ per Bbl)	14.19	27.18	15.41	35.03

Total Company
	Gas ($ per Mcf)	2.20	3.95	2.53	4.43
	Oil ($ per Bbl)	37.32	64.94	43.38	83.70
	NGL ($ per Bbl)	12.72	25.32	13.75	33.14

Other

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

	First	Second	Third	Fourth
	Quarter	Quarter	Quarter	Quarter	Total
Gas:
2016
PEPL Collars ⁽³⁾
Volume (MMBtu)	910,000	2,730,000	2,760,000	2,760,000	9,160,000
Wtd Avg Floor	$ 2.70	$ 2.32	$ 2.32	$ 2.32	$ 2.35
Wtd Avg Ceiling	$ 2.85	$ 2.75	$ 2.75	$ 2.75	$ 2.76

El Paso Perm Collars ⁽³⁾
Volume (MMBtu)	1,820,000	3,030,000	2,760,000	2,760,000	10,370,000
Wtd Avg Floor	$ 2.75	$ 2.45	$ 2.42	$ 2.42	$ 2.48
Wtd Avg Ceiling	$ 3.12	$ 2.90	$ 2.87	$ 2.87	$ 2.92

2017
PEPL Collars ⁽³⁾
Volume (MMBtu)	1,800,000	1,820,000	-	-	3,620,000
Wtd Avg Floor	$ 2.13	$ 2.13	$ -	$ -	$ 2.13
Wtd Avg Ceiling	$ 2.70	$ 2.70	$ -	$ -	$ 2.70

El Paso Perm Collars⁽³⁾
Volume (MMBtu)	2,700,000	2,730,000	-	-	5,430,000
Wtd Avg Floor	$ 2.42	$ 2.42	$ -	$ -	$ 2.42
Wtd Avg Ceiling	$ 2.97	$ 2.97	$ -	$ -	$ 2.97

	First	Second	Third	Fourth
Oil:	Quarter	Quarter	Quarter	Quarter	Total

2016
WTI Oil Three-Way Collars ⁽⁴⁾
Volume (Bbl)	273,000	273,000	276,000	276,000	1,098,000
Floor sold (put) $	$ 40.00	$ 40.00	$ 40.00	$ 40.00	$ 40.00
Floor purchased (put) $	$ 50.00	$ 50.00	$ 50.00	$ 50.00	$ 50.00
Ceiling sold (call) $	$ 60.00	$ 60.00	$ 60.00	$ 60.00	$ 60.00

Conference call and webcast

Cimarex will host a conference call tomorrow, February 17, at 9:00 a.m. Mountain Time (11:00 a.m. Eastern Time). 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 five 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 2015 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 Mid-Continent and Permian Basin areas of the U.S.

This press release contains forward-looking statements, including statements regarding projected results and future events. Please refer to the company's Annual Report on Form 10-K for the year ended December 31, 2015, to be filed with the SEC, 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 volatility; 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; higher than expected costs and expenses, including the availability and cost of services and materials; unexpected future capital expenditures; 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; 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; environmental liabilities; 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 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 $2.8 billion.
(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.

RECONCILIATION OF ADJUSTED NET INCOME (LOSS)

			For the Three Months Ended					For the Twelve Months Ended
			December 31,					December 31,
			2015			2014		2015			2014
			(in thousands, net of tax, except per share data)

Net income (loss)		$	(630,508)		$	75,792	$	(2,408,948)		$	507,204
	Impairment of oil and gas properties		613,382			—		2,361,406			—
	Mark-to-market (gain) loss on open derivative positions		(5,910)			587		(7,164)			2,440
	Gain on sale of midstream assets		—			—		—			(4,276)
Adjusted net income (loss)		$	(23,036)		$	76,379	$	(54,706)		$	505,368
Diluted earnings (loss) per share,*		$	(6.78)		$	0.86	$	(25.92)		$	5.78
Adjusted diluted earnings (loss) per share ,*		$	(0.25)		$	0.87	$	(0.60)		$	5.76

Diluted shares attributable to common stockholders and participating securities			92,992	**		87,695		92,992	**		87,732
Estimated tax rates utilized			36.5%			37.1%		36.5%			37.1%


Adjusted net income (loss) and adjusted diluted earnings (loss) per share excludes the noted item because management believes this item affects 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

**	Participating securities and other dilutive shares are not included in the diluted share computation when a loss exists.

RECONCILIATION OF ADJUSTED CASH FLOW FROM OPERATIONS

			For the Three Months Ended				For the Twelve Months Ended
			December 31,				December 31,
			2015		2014		2015		2014
			(in thousands)
Net cash provided by operating activities		$	114,954	$	347,395	$	691,500	$	1,619,365
	Change in operating assets and liabilities		10,772		(4,935)		52,082		14,847
Adjusted cash flow from operations		$	125,726	$	342,460	$	743,582	$	1,634,212


Adjusted net income (loss) and adjusted diluted earnings (loss) per share excludes the noted item because management believes this item affects 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

**	Participating securities and other dilutive shares are not included in the diluted share computation when a loss exists.


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.

PROVED RESERVES

		Gas	Oil	NGL	Total
		(Bcf)	(MBbls)	(MBbls)	(Bcfe)

December 31, 2014		1,666.7	118,992	125,273	3,132.3
	Revisions of previous estimates	(154.3)	(14,632)	(5,667)	(276.2)
	Extensions and discoveries	183.1	22,859	18,079	428.7
	Purchase of reserves	—	—	—	—
	Production	(169.0)	(18,663)	(13,063)	(359.3)
	Sale of properties	(9.5)	(758)	(345)	(16.1)
December 31, 2015		1,517.0	107,798	124,277	2,909.4

Proved developed reserves
Year-end 2014		1,264.0	100,050	89,630	2,402.0
Year-end 2015		1,129.5	89,189	87,549	2,189.9

		2015	2014	% Change

Pre-tax PV-10 ($ in millions) ^*		$2,279.0	$6,389.5	-64%
Standardized Measure ($ in millions)		$1,934.1	$4,352.8	-56%

Average prices used in Standardized Measure
Gas Price per Mcf		$2.59	$4.35	-40%
Oil price per barrel		$50.28	$94.99	-47%
NGL price per barrel		$14.41	$30.89	-53%


*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, 2015 and 2014, Cimarex's discounted future income taxes were $344.9 million and $2,036.6 million, respectively. Cimarex's standardized measure of discounted future net cash flows was $1,934.1 million at year-end 2015 and $4,352.8 million at year-end 2014. Cimarex believes pre-tax PV-10 is a useful measure for investors for evaluating the relative monetary significance of its oil and natural gas properties. Cimarex further believes investors may utilize its pre-tax PV-10 as a basis for comparison of the relative size and value of its reserves to other companies because many factors that are unique to each individual company impact the amount of future income taxes to be paid. 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
		(Bcf)	(MBbls)	(MBbls)	(Bcfe)

	Mid-Continent	1,134.4	29,048	87,639	1,834.6
	Permian Basin	378.5	78,482	36,598	1,069.0
	Other	4.1	268	40	5.8
		1,517.0	107,798	124,277	2,909.4

OIL AND GAS CAPITALIZED EXPENDITURES

			For the Three Months Ended				For the Twelve Months Ended
			December 31,				December 31,
			2015		2014		2015		2014
			(in thousands)
	Acquisitions:
	Proved	$	30	$	125	$	30	$	138,508
	Unproved		2,400		314		6,666		111,225
	Net purchase price adjustments*		350		—		(11,653)		-
			2,780		439		(4,957)		249,733

	Exploration and development:
	Land and Seismic		14,084		28,349		52,049		176,061
	Exploration and development		180,107		421,241		824,903		1,704,961
			194,191		449,590		876,952		1,881,022

	Sale proceeds:
	Proved		—		(1,038)		(26,045)		(270,766)
	Unproved		(2,528)		(38)		(15,231)		(175,341)
			(2,528)		(1,076)		(41,276)		(446,107)

		$	194,443	$	448,953	$	830,719	$	1,684,648


*	The net purchase price adjustment amounts in 2015 reflect purchase price adjustments related to an acquisition in second quarter 2014.

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

				For the Three Months Ended				For the Twelve Months Ended
				December 31,				December 31,
				2015		2014		2015		2014

			(in thousands, except per share data)

Revenues:
	Oil sales		$	161,814	$	280,729	$	809,664	$	1,308,958
	Gas sales			96,242		168,791		428,227		687,930
	NGL sales			44,411		78,813		179,647		375,941
	Gas gathering and other, net			8,812		10,218		35,081		51,347
				311,279		538,551		1,452,619		2,424,176
Costs and expenses:
	Impairment of oil and gas properties			965,348		—		3,716,883		—
	Depreciation, depletion, amortization and accretion			161,768		219,536		788,044		816,103
	Production			77,229		91,994		299,374		342,304
	Transportation, processing, and other operating			52,717		50,115		182,362		195,414
	Gas gathering and other			9,539		7,700		38,138		35,113
	Taxes other than income			17,086		29,339		84,764		128,793
	General and administrative			24,283		23,637		74,688		81,160
	Stock compensation			4,679		4,126		19,559		15,001
	(Gain) loss on derivative instruments, net			(9,278)		(12,722)		(11,246)		(3,762)
	Other operating, net			12		82		856		116
				1,303,383		413,807		5,193,422		1,610,242

Operating income (loss)				(992,104)		124,744		(3,740,803)		813,934

Other (income) and expense:
	Interest expense			19,811		20,093		80,447		68,617
	Amortization of deferred financing costs			1,966		1,127		5,299		4,248
	Capitalized interest			(5,502)		(10,055)		(30,589)		(35,925)
	Other, net			(3,762)		(6,700)		(13,576)		(28,907)

Income (loss) before income tax				(1,004,617)		120,279		(3,782,384)		805,901
Income tax expense (benefit)				(374,109)		44,487		(1,373,436)		298,697

Net income (loss)			$	(630,508)	$	75,792	$	(2,408,948)	$	507,204

Earnings (loss) per share to common stockholders:

	Basic		$	(6.78)	$	0.87	$	(25.92)	$	5.79
	Diluted		$	(6.78)*	$	0.86	$	(25.92)*	$	5.78

Dividends per share			$	0.16	$	0.16	$	0.64	$	0.64

Shares attributable to common stockholders:
	Unrestricted common shares outstanding			92,992		85,679		92,992		85,679
	Diluted common shares			92,992		85,773		92,992		85,810

Shares attributable to common stockholders and participating securities:
	Basic shares outstanding			N/A*		87,601		N/A*		87,601
	Fully diluted shares			N/A*		87,695		N/A*		87,732

Comprehensive income (loss):
	Net income (loss)		$	(630,508)	$	75,792	$	(2,408,948)	$	507,204
	Other comprehensive income (loss):
		Change in fair value of investments, net of tax		138		52		(661)		(87)
	Total comprehensive income (loss)		$	(630,370)	$	75,844	$	(2,409,609)	$	507,117

Due to the net loss, shares of 94,829, which include participating securities, are not considered in the loss per share calculation

CONDENSED CONSOLIDATED CASH FLOW STATEMENTS (unaudited)

				For the Three Months Ended					For the Twelve Months Ended
				December 31,					December 31,
					2015		2014		2015		2014
				(in thousands)

Cash flows from operating activities:
	Net income (loss)			$	(630,508)	$	75,792	$	(2,408,948)	$	507,204
	Adjustment to reconcile net income (loss) to net cash provided by operating activities:
		Impairment of oil and gas properties			965,348		—		3,716,883		—
		Depreciation, depletion, amortization and accretion			161,768		219,536		788,044		816,103
		Deferred income taxes			(373,882)		44,083		(1,388,146)		298,293
		Stock compensation			4,679		4,126		19,559		15,001
		(Gain) loss on derivative instruments			(9,278)		(12,722)		(11,246)		(3,762)
		Settlements on derivative instruments			—		13,656		—		7,641
		Changes in non-current assets and liabilities			6,887		(567)		23,230		(2,440)
		Amortization of deferred financing costs and other, net			712		(1,444)		4,206		(3,828)
	Changes in operating assets and liabilities:
		Receivables, net			34,916		27,958		186,699		(35,133)
		Other current assets			8,320		682		37,954		(25,428)
		Accounts payable and other current liabilities			(54,008)		(23,705)		(276,735)		45,714
			Net cash provided by operating activities		114,954		347,395		691,500		1,619,365
Cash flows from investing activities:
	Oil and gas expenditures				(208,015)		(477,321)		(979,044)		(2,108,250)
	Sales of oil and gas assets				1,510		(1,729)		39,853		449,981
	Sales of other assets				121		235		1,178		8,413
	Other capital expenditures				(12,507)		(13,827)		(70,592)		(90,611)
			Net cash used by investing activities		(218,891)		(492,642)		(1,008,605)		(1,740,467)
Cash flows from financing activities:
	Net bank debt borrowings				—		—		—		(174,000)
	Proceeds from other long-term debt				—		—		—		750,000
	Proceeds from sale of common stock				—		—		752,100		—
	Financing and underwriting fees				(1,970)		—		(24,633)		(11,616)
	Dividends paid				(15,070)		(13,917)		(58,281)		(53,849)
	Proceeds from exercise of stock options and other				1,047		1,369		21,439		11,898
			Net cash provided by (used in) financing activities		(15,993)		(12,548)		690,625		522,433
Net change in cash and cash equivalents					(119,930)		(157,795)		373,520		401,331
Cash and cash equivalents at beginning of period					899,312		563,657		405,862		4,531
Cash and cash equivalents at end of period				$	779,382	$	405,862	$	779,382	$	405,862

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited)
			December 31,		December 31,
			2015		2014
Assets				(in thousands, except share data)
Current assets:
	Cash and cash equivalents		$	779,382	$	405,862
	Receivables, net			225,398		412,108
	Oil and gas well equipment and supplies			54,579		89,780
	Deferred income taxes			—		13,475
	Derivative instruments			10,745		—
	Other current assets			7,826		10,579
		Total current assets		1,077,930		931,804
Oil and gas properties at cost, using the full cost method of accounting:
	Proved properties			15,546,948		14,402,064
	Unproved properties and properties under development, not being amortized			440,166		759,149
				15,987,114		15,161,213
	Less – accumulated depreciation, depletion, amortization and impairment			(12,710,968)		(8,257,502)
		Net oil and gas properties		3,276,146		6,903,711
Fixed assets, net				230,009		211,031
Goodwill				620,232		620,232
Derivative instruments				501		—
Other assets, net *				38,468		41,691
			$	5,243,286	$	8,708,469
Liabilities and Stockholders' Equity
Current liabilities:
	Accounts payable		$	66,815	$	138,051
	Accrued liabilities			247,508		447,384
	Revenue payable			95,744		190,892
		Total current liabilities		410,067		776,327
Long-term debt *:
	Principal			1,500,000		1,500,000
	Less – unamortized debt issuance costs			(14,380)		(16,824)
		Long-term debt, net		1,485,620		1,483,176
Deferred income taxes				352,705		1,754,706
Other liabilities				197,216		193,628
		Total liabilities		2,445,608		4,207,837
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, 94,820,570 and 87,592,535 shares issued, respectively			948		876
	Paid-in capital			2,762,976		1,997,080
	Retained earnings			33,313		2,501,574
	Accumulated other comprehensive income			441		1,102
				2,797,678		4,500,632
			$	5,243,286	$	8,708,469


*	At December 31, 2015, we adopted the Financial Accounting Standards Board's (FASB) Accounting Standards Update (ASU) No. 2015-03, Interest - Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs. The requirements are to be applied retrospectively to prior periods presented. These changes resulted in classifying debt issuance costs as a direct deduction from the carrying amount of the related debt liability (except for those related to revolving credit facilities), rather than as an asset. As of December 31, 2015 and 2014, other assets, net and long-term debt are reduced by $14,380 and $16,824, respectively. The adoption of this ASU did not impact the Statement of Operations and Comprehensive Income (Loss) or the Cash Flow Statements.

CONTACT: Cimarex Energy Co., Karen Acierno, 303-285-4957, www.cimarex.co

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