Production averaged 1.0 Bcfe per day; Up 22% Year-over-Year Wolfcamp A well in Reeves County, TX averages 3,309 BOE/day Long Lateral Bone Spring well produces 2,753 BOE/day
DENVER, Aug. 4, 2015 /PRNewswire/ -- Cimarex Energy Co. (NYSE: XEC) today reported a second quarter 2015 net loss of $600.2 million, or $6.47 per diluted share, including a non-cash impairment of oil and gas properties. The adjusted second quarter net income was $14.4 million, or $0.15 per diluted share(1). Second quarter 2015 adjusted cash flow from operations was $252.4 million versus $443.1 million a year ago(1).
Total company production averaged 1.0 billion cubic feet equivalent (Bcfe) per day during the second quarter, a 22 percent increase from second quarter 2014. Year-over-year natural gas volumes increased 14 percent, oil volumes grew 35 percent and NGL volumes were up 25 percent.
Commodity prices impacted Cimarex's financial results for the quarter. Realized oil prices averaged $50.66 per barrel, down 46 percent versus a year ago but up 19 percent sequentially. Natural gas prices were down 46 percent year-over-year and averaged $2.51 per Mcf compared to $4.62 per Mcf. NGL prices averaged $14.67 per barrel, down 59 percent from the second quarter of 2014 and seven percent sequentially. (See table of Average Realized Price by Region below.)
Cimarex invested $190 million in exploration and development during the second quarter, which was funded with cash flow from operations. Total debt at June 30, 2015, remained at $1.5 billion of long-term notes. Cimarex had no borrowings under its revolving credit facility and a cash balance of $857 million. Debt was 26 percent of total capitalization(2).
Cimarex Chairman, President and CEO, Tom Jorden, said, "In May, Cimarex issued 6.9 million shares of common stock to increase drilling in our exceptional portfolio of projects in the Delaware Basin and Mid-Continent region. These projects continue to provide highly attractive returns despite the negative commodity price backdrop." He went on to say, "We received $730 million of net offering proceeds that will supplement our exploration and development activities in 2015/16 including infill development in the Woodford Shale, our first infill development in the Wolfcamp D in the Delaware Basin, as well as continued activity in the Bone Spring and emerging Meramec plays." Cimarex plans to invest $100 million of the capital from the equity offering in the second half of 2015 with the remainder to be invested as part of the 2016 capital program.
Cimarex now estimates total production volumes for 2015 to average 960-980 MMcfe per day, a midpoint increase of 12 percent over 2014 volumes. Oil volumes are expected to grow 17-19 percent and gas volumes 6-8 percent. Total company production for the third quarter 2015 is projected to average 920-940 MMcfe per day which includes a reduction of 20 MMcfe per day for facilities maintenance. Capital investment for exploration and development is estimated to be $1.0 billion in 2015, which includes an additional $100 million of drilling and completion capital to be funded from the May equity offering.
Expenses per Mcfe of production for the remainder of 2015 are estimated to be:
Production expense
$0.90 - $1.05
Transportation, processing and other expense
0.47 - 0.57
DD&A and ARO accretion*
2.00 - 2.10
General and administrative expense
0.18 - 0.22
Taxes other than income (% of oil and gas revenue)
*Excludes the potential impact of any future ceiling test writedown.
6.0 - 6.5%
Operations Update Cimarex invested $190 million in exploration and development during the second quarter, bringing the total for the first half of 2015 to $498 million. Year-to-date, 66 percent has been invested in the Permian Basin and 33 percent in the Mid-Continent. We completed 45 gross (24 net) wells during the quarter. At June 30, 61 gross (24 net) wells were awaiting completion. Cimarex is currently operating seven drilling rigs.
WELLS BROUGHT ON PRODUCTION BY REGION
For the Three Months Ended
For the Six Months Ended
June 30,
June 30,
2015
2014
2015
2014
Gross wells
Permian Basin
26
47
68
81
Mid-Continent
19
37
30
76
Other
—
1
-
2
45
85
98
159
Net wells
Permian Basin
18
30
48
51
Mid-Continent
6
21
9
35
Other
—
-
-
1
24
51
57
87
Permian Region Production from the Permian region averaged 595.1 MMcfe per day in the second quarter, a 51 percent increase over second quarter 2014. Quarterly oil volumes increased 45 percent year-over-year to 48,448 barrels per day and accounted for 49 percent of the region's total production for the quarter.
Cimarex completed and brought on production 26 gross (18 net) wells in the Permian region during the second quarter. The 26 gross wells completed include five Second Bone Spring wells and 20 Wolfcamp wells (12 in Culberson area and eight in Reeves County). On June 30, there were three gross (two net) wells waiting on completion in the Delaware Basin.
Cimarex now has 11 long-lateral Wolfcamp D wells producing in the Culberson County, Texas. These wells were completed using 10,000-foot laterals and had an average 30-day initial gross peak production rate of 2,255 BOE per day (25 percent oil, 45 percent gas, 30 percent NGL). Also in the Culberson area, Cimarex completed a 7,000-foot lateral in the Bone Spring sand, which had an average 30-day initial gross peak production rate of 2,753 BOE per day including 1,870 barrels of oil per day.
In Reeves County, Texas, Cimarex has now completed seven long lateral (10,000-foot) Wolfcamp A wells. These wells had an average 30-day initial gross peak production rate of 1,646 BOE per day (50 percent oil, 28 percent gas, 22 percent NGL). Of note in this group is the recently completed Big Timber 57-25 Unit#1-H, which was completed in the upper Wolfcamp A and had an average 30-day initial gross peak production rate of 3,309 BOE per day (49 percent oil, 30 percent gas, 21 percent NGL).
Mid-Continent Activity in the Mid-Continent region was focused in the Cana area in western Oklahoma, where 18 gross (five net) Cimarex wells were completed and brought on production during the second quarter. At the end of the quarter, 58 gross (22 net) wells were waiting on completion. Second quarter production from the Cana area averaged 333.5 MMcfe per day, representing 33 percent of total company production. Total Mid-Continent production averaged 419.1 MMcfe per day for the second quarter of 2015.
Cimarex completed three additional Meramec wells in the second quarter bringing the total Meramec wells on production to ten. Average 30-day initial gross peak production from these ten wells was 9.3 MMcfe per day, with oil yields ranging from 15 barrels per MMcf to over 330 barrels per MMcf. Cimarex is currently flowing back its first 10,000-foot long lateral in the Meramec formation and has commenced drilling a second long lateral Meramec test.
Average daily production and commodity price for Cimarex by region are summarized below:
DAILY PRODUCTION BY REGION
For the Three Months Ended
For the Six Months Ended
June 30,
June 30,
2015
2014
2015
2014
Permian Basin
Gas (MMcf)
189.4
123.6
170.0
113.1
Oil (Bbls)
48,448
33,317
45,783
32,475
NGL (Bbls)
19,169
11,633
16,180
10,386
Total Equivalent (MMcfe)
595.1
393.3
541.8
370.3
Mid-Continent
Gas (MMcf)
270.2
276.6
278.6
260.3
Oil (Bbls)
7,181
7,259
7,308
6,662
NGL (Bbls)
17,633
17,543
18,194
16,376
Total Equivalent (MMcfe)
419.1
425.5
431.6
398.5
Total Company
Gas (MMcf)
466.3
410.1
456.1
382.8
Oil (Bbls)
56,261
41,759
53,765
40,471
NGL (Bbls)
37,070
29,680
34,670
27,367
Total Equivalent (MMcfe)
1,026.2
838.7
986.7
789.9
AVERAGE REALIZED PRICE BY REGION
For the Three Months Ended
For the Six Months Ended
June 30,
June 30,
2015
2014
2015
2014
Permian Basin
Gas ($ per Mcf)
2.50
4.82
2.61
5.00
Oil ($ per Bbl)
50.69
91.73
46.85
91.64
NGL ($ per Bbl)
12.88
32.21
13.13
34.32
Mid-Continent
Gas ($ per Mcf)
2.51
4.53
2.64
4.93
Oil ($ per Bbl)
49.98
99.78
46.06
97.41
NGL ($ per Bbl)
16.60
37.47
16.94
39.52
Total Company
Gas ($ per Mcf)
2.51
4.62
2.63
4.94
Oil ($ per Bbl)
50.66
93.39
46.79
92.82
NGL ($ per Bbl)
14.67
35.35
15.15
37.43
Other
The following table summarizes the company's current open hedge positions:
Gas Contracts
Weighted Avg. Price
Period
Type
MMBTU/day
Index(3)
Floor
Ceiling
Jan 16 – Dec 16
Collar
10,000
PEPL
$
2.70
$
2.85
Conference call and webcast Cimarex will host a conference call Wednesday, August 5, 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 five minutes before the scheduled start time (international callers dial 1-412-902-4216). A replay will be available for one week following the call by dialing 877-344-7529 (international callers dial 1-412-317-0088); conference I.D. 10068474. The replay will also be available on the company's website or via the Cimarex App.
Investor Presentation For more details on Cimarex's second quarter 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. In particular, the company is providing revised "2015 Outlook", which contains projections for certain 2015 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/A for the year ended December 31, 2014, 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 volatility; declines in the values of our oil and gas properties resulting in impairments; the ability to receive drilling and other permits and rights-of-way in a timely manner; development drilling and testing results; 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; 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 (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 $4.2 billion.
(3)
PEPL refers to Panhandle Eastern Pipe Line Tex/OK Mid-Continent index.
RECONCILIATION OF ADJUSTED NET INCOME (LOSS)
For the Three Months Ended
For the Six Months Ended
June 30,
June 30,
2015
2014
2015
2014
(in thousands, net of tax, except per share data)
Net income (loss)
$
(600,215)
$
148,640
$
(1,015,156)
$
287,097
Impairment of oil and gas properties
614,614
—
997,839
—
Mark-to-market loss on open derivative positions
—
904
—
7,790
Adjusted net income (loss)
$
14,399
$
149,544
$
(17,317)
$
294,887
Diluted earnings (loss) per share
$
(6.47)
$
1.70
$
(10.94)
$
3.29
Adjusted diluted earnings (loss) per share *
$
0.15
$
1.71
$
(0.19)
$
3.38
Diluted shares attributable to common stockholders and participating securities
92,831
**
87,188
92,831
**
87,178
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 Six Months Ended
June 30,
June 30,
2015
2014
2015
2014
(in thousands)
Net cash provided by operating activities
$
257,372
$
421,745
$
370,545
$
769,769
Change in operating assets and liabilities
(5,014)
21,367
68,758
82,235
Adjusted cash flow from operations
$
252,358
$
443,112
$
439,303
$
852,004
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, 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 Six Months Ended
June 30,
June 30,
2015
2014
2015
2014
(in thousands)
Acquisitions:
Proved (*)
$
(2,258)
$
144,516
$
(2,228)
$
144,516
Unproved (*)
(9,617)
114,732
(7,748)
114,732
(11,875)
259,248
(9,976)
259,248
Exploration and development:
Land and Seismic
5,275
43,869
27,965
109,194
Exploration and development
184,999
453,714
470,526
855,175
190,274
497,583
498,491
964,369
Sale proceeds:
Proved
(1,160)
(464)
(2,305)
(223)
Unproved
(6,211)
(900)
(6,211)
(900)
(7,371)
(1,364)
(8,516)
(1,123)
$
171,028
$
755,467
$
479,999
$
1,222,494
*
The negative 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 Six Months Ended
June 30,
June 30,
2015
2014
2015
2014
(in thousands, except per share data)
Revenues:
Oil sales
$
259,344
$
354,882
$
455,349
$
679,953
Gas sales
106,374
172,503
217,336
342,600
NGL sales
49,477
95,470
95,077
185,427
Gas gathering and other, net
9,088
13,814
17,523
27,905
424,283
636,669
785,285
1,235,885
Costs and expenses:
Impairment of oil and gas properties
967,287
—
1,570,886
—
Depreciation, depletion, amortization and accretion
219,493
198,639
438,007
375,788
Production
70,600
86,085
152,811
161,226
Transportation, processing, and other operating
43,713
46,478
83,355
90,726
Gas gathering and other
11,306
10,041
20,170
18,825
Taxes other than income
25,980
32,323
47,961
65,944
General and administrative
14,054
16,571
29,992
37,283
Stock compensation
4,988
3,548
10,143
7,272
(Gain) loss on derivative instruments, net
—
2,454
—
18,189
Other operating, net
260
112
784
215
1,357,681
396,251
2,354,109
775,468
Operating income (loss)
(933,398)
240,418
(1,568,824)
460,417
Other (income) and expense:
Interest expense
20,186
15,729
40,323
28,773
Amortization of deferred financing costs
1,111
995
2,230
1,993
Capitalized interest
(8,570)
(8,575)
(17,987)
(15,865)
Other, net
(3,854)
(4,129)
(7,439)
(11,084)
Income (loss) before income tax
(942,271)
236,398
(1,585,951)
456,600
Income tax expense (benefit)
(342,056)
87,758
(570,795)
169,503
Net income (loss)
$
(600,215)
$
148,640
$
(1,015,156)
$
287,097
Earnings (loss) per share to common stockholders:
Basic
$
(6.47)
$
1.71
$
(10.94)
$
3.30
Diluted
$
(6.47)
$
1.70
$
(10.94)
$
3.29
Dividends per share
$
0.16
$
0.16
$
0.32
$
0.32
Shares attributable to common stockholders:
Unrestricted common shares outstanding
92,831
85,532
92,831
85,532
Diluted common shares
92,831
85,689
92,831
85,679
Shares attributable to common stockholders and participating securities:
Basic shares outstanding
N/A*
87,031
N/A*
87,031
Fully diluted shares
N/A*
87,188
N/A*
87,178
Comprehensive income (loss):
Net income (loss)
$
(600,215)
$
148,640
$
(1,015,156)
$
287,097
Other comprehensive income (loss):
Change in fair value of investments, net of tax
(292)
(56)
(190)
(16)
Total comprehensive income (loss)
$
(600,507)
$
148,584
$
(1,015,346)
$
287,081
*
Due to the net loss, shares of 94,465, which include participating securities, are not considered in the loss per share calculation
