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Cimarex Energy Reports 2013 Third Quarter Results

              Cimarex Energy Reports 2013 Third Quarter Results

- Record Daily Production Averages 716.8 MMcfe/d Up 13% Year-over-Year

- Wolfcamp A Long Lateral in Reeves County averages 1,816 BOE/d over 30 days

- Upsized Frac Yields Higher IP in Culberson County Wolfcamp

PR Newswire

DENVER, Nov. 6, 2013

DENVER, Nov. 6, 2013 /PRNewswire/ --Cimarex Energy Co. (NYSE: XEC) today
reported third quarter 2013 net income of $138.4 million, or $1.59 per diluted
share. This compares to 2012 third quarter net income of $84.3 million, or
$0.97 per diluted share. Excluding the mark-to-market of open derivative
positions, third quarter 2013 earnings were $1.62 per diluted share versus
$1.01 per diluted share in the third quarter of 2012^(1).

Revenue from the sale of oil, natural gas and natural gas liquids (NGL)
totaled $549.6 million in the third quarter of 2013 compared to $397.4 million
in the same period of 2012. Third quarter 2013 adjusted cash flow from
operations was $394.0 million versus $291.2 million a year ago^(2).

Production volumes averaged a record 716.8 million cubic feet equivalent
(MMcfe) per day in the third quarter, a 13 percent increase over third quarter
2012 output of 635.1 MMcfe per day. Oil production grew 21 percent over the
same period last year to a record 39,292 barrels per day. Permian oil
production reached 31,993 barrels per day. Third quarter 2013 production
volumes were 48 percent natural gas, 33 percent oil and 19 percent NGL.

The increase in third quarter revenue and cash flow was the result of higher
production volumes and improved commodity prices. For the third quarter of
2013 natural gas prices averaged $3.72 per thousand cubic feet (Mcf) up 33
percent year-over-year and oil prices for the quarter averaged $102.88 per
barrel up 17 percent from the third quarter a year ago.

Long-term debt at September 30, 2013, was $900 million comprised of $750
million of senior notes and $150 million of borrowings under the company's
senior unsecured revolving credit facility. Debt to total capitalization at
quarter-end was 19 percent^(3).

Cimarex Chairman and CEO, Tom Jorden, said, "The third quarter not only
produced excellent financial results, it was also a period of strong technical
momentum in the Texas Delaware Basin Wolfcamp shale. We completed a Reeves
County Wolfcamp A horizontal well using a 10,000-foot lateral and have also
tested upsized frac stages on our traditional 5,000-foot lateral, increasing
the number from 12 stages to 20. Both were operational and economic
successes. These new completion techniques will most certainly play into our
future development plans for this large, stacked-pay resource."

Cimarex invested $388 million on exploration and development during the third
quarter bringing the total invested year-to-date to $1.2 billion.The Permian
Basin accounts for 65 percent of the capital investment in 2013.

Cimarex drilled a total of 112 gross (52 net) wells during the quarter, of
which 111 were completed as producers. At quarter-end, 50 gross (22 net)
wells were awaiting completion.

Wells Drilled and Completed by Region
                                     For the Three Months  For the Nine Months
                                     Ended September 30,   Ended September 30,
                                     2013       2012       2013      2012
Gross wells
Permian Basin                        42         37         132       131
Mid-Continent                        67         55         154       119
Gulf Coast/Other                     3          1          5         3
                                     112        93         291       253
Net wells
Permian Basin                        28         24         87        88
Mid-Continent                        21         23         56        49
Gulf Coast/Other                     3          -          4         1
                                     52         47         147       138
% Gross wells completed as           99%        99%        99%       97%
producers

Permian Basin Update
Production from the Permian Basin averaged 352.0 MMcfe per day for the third
quarter, an increase of 28 percent over third quarter 2012 and a ten percent
increase sequentially. Quarterly oil volumes increased 28 percent
year-over-year to 31,993 barrels per day and accounted for 55 percent of the
region's total production for the quarter.

Cimarex drilled and completed 42 gross (28 net) Permian Basin wells during the
third quarter, bringing the total for 2013 to 132 gross wells (87 net). All
wells drilled in the region during the third quarter were completed as
producers. At September 30, 15 gross (10 net) wells were awaiting
completion. Drilling took place in the Delaware Basin of Texas and southeast
New Mexico, mainly targeting the Bone Spring and Wolfcamp formations.

Year-to-date, 60 gross (35 net) New Mexico Bone Spring wells have been drilled
and completed. Per well first 30-day average gross production from these
wells averaged approximately 670 barrels of oil equivalent (BOE) per day (84
percent oil). Year-to-date Ward County, Texas, Third Bone Spring drilling
totaled 33 gross (24 net) wells with per well first 30-day average gross
production rates of approximately 1,000 BOE per day (80 percent oil).

In the Culberson area, Cimarex is drilling both horizontal Bone Spring and
Wolfcamp wells. Year-to-date 13 gross (nine net) Bone Spring wells have been
drilled and completed with per well first 30-day average gross production of
820 BOE per day (60 percent oil). Cimarex has also drilled 12 gross (8 net)
horizontal Wolfcamp wells in Culberson County in 2013, bringing total Wolfcamp
wells in the area to 41 gross (36 net). Per well first 30-day production
rates on the 41 Wolfcamp wells drilled-to-date in the Wolfcamp C and D have
averaged 6.2 MMcfe per day, comprised of 42 percent gas, 28 percent oil and 30
percent NGL (assuming full NGL recovery).

Cimarex completed two wells in Culberson County using an upsized frac design.
The Tim Tam 24 Fee #1H was completed to the Wolfcamp D using 20 frac stages
with a 5,000-foot lateral and had first 30-day average gross production of 7.8
MMcfe per day, higher than the average 12-stage completion rate of 6.2 MMcfe
per day. In addition, Cimarex completed a Wolfcamp A well in Culberson County
using a 20-stage completion. That well is currently undergoing production
testing.

In Reeves County, Texas, Cimarex has drilled and completed three gross (three
net) horizontal Wolfcamp A wells. The most recent well was drilled and
completed using a 10,000-foot lateral and had a first 30-day average gross
production rate of 1,816 BOE per day (56 percent oil, 23 percent gas and 21
percent NGL).Cimarex currently has a second long lateral well drilling and
two wells waiting on completion in Reeves County.

During the third quarter, Cimarex added 10,000 net prospective Wolfcamp acres
in Ward County, Texas, bringing its total net prospective Wolfcamp acreage in
the Delaware Basin to 180,000 acres. The company currently has one rig
drilling Wolfcamp wells in Ward County.

Cimarex also reported a successful well in the Avalon shale in Lea County, New
Mexico. The well had first 30-day average gross production of 1,038 BOE per
day (60 percent oil) and was completed using an upsized frac (22 stages). The
Avalon shale represents further opportunity for Cimarex in the Delaware
Basin. The company has approximately 13,700 net prospective acres in Lea
County.

Mid-Continent Update
Mid-Continent production averaged 337.6 MMcfe per day for the third quarter of
2013, a four percent increase over the third quarter 2012 average of 324.3
MMcfe per day. Our Cana-Woodford area represented 216.9 MMcfe per day of the
third quarter 2013 total, an 18 percent increase versus the same period last
year. Year-to-date Cimarex has drilled and completed 154 gross (56 net) wells
in the Mid-Continent region, 134 gross (49 net) of which were in the
Cana-Woodford shale play. All were completed as producers. At September 30,
35 gross (12 net) wells were awaiting completion.

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

                            For the Three Months      For the Nine Months
                            Ended                     Ended
                            September 30,             September 30,
                            2013          2012        2013          2012
Gas (Mcf per day)
Permian Basin               102,543       79,502      93,944        78,007
Mid-Continent               230,217       224,009     232,600       218,411
Gulf Coast/Other            14,062        20,735      13,799        24,110
                            346,822       324,246     340,343       320,528
Oil (Barrels per day)
Permian Basin               31,993        25,000      29,343        22,839
Mid-Continent               5,801         6,120       5,944         5,802
Gulf Coast/Other            1,498         1,336       1,177         1,602
                            39,292        32,456      36,464        30,243
NGL (Barrels per day)
Permian Basin               9,575         7,501       7,643         6,523
Mid-Continent               12,090        10,598      13,129        9,934
Gulf Coast/Other            708           1,261       778           1,487
                            22,373        19,360      21,550        17,944
Total Equivalent (Mcfe per
day)
Permian Basin               351,951       274,508     315,860       254,179
Mid-Continent               337,563       324,317     347,038       312,827
Gulf Coast/Other            27,299        36,318      25,527        42,644
                            716,813       635,143     688,425       609,650

2013 Outlook
Cimarex estimates fourth quarter 2013 total company volumes to average 714-734
MMcfe per day.As a result, 2013 total company volumes are now projected to
average 695-700 MMcfe/d, 11 to 12 percent growth over 2012 with oil volumes
projected to grow 18 percent. Adjusted for property sales in 2012, production
is expected to grow 14 percent.

Capital investment in exploration and development is now expected to be
between $1.55 and $1.6 billion, the result of slightly higher acreage
acquisition and somewhat higher activity levels.

Expenses for 2013 are expected to fall within the following ranges:

$/Mcfe
 Production expense                                 $1.11 - $1.16
 Transportation & other operating expense            0.40 - 0.45
 DD&A and ARO accretion                              2.35 - 2.45
 General and administrative expense                  0.28 - 0.32
 Taxes other than income (% of oil and gas revenue) 5.8% - 6.2%

Other
Cimarex has oil swaps and collars covering 12,000 barrels per day through
December 2013 and collars covering 6,000 barrels per day from January through
December 2014. The company has Mid-Continent natural gas collars on 80,000
MMBTU per day through December 2014. The following table summarizes the
current open hedge positions:

Oil Contracts

                                       Weighted Average Price
                                                           
Period        Type    Bbls/day  Index  Floor    Ceiling
                                                           Swap
Oct - Dec 13  Swap    6,000     WTI      NA       NA     $ 96.13
Oct - Dec 13  Collar  6,000     WTI    $ 85.00  $ 102.31 $ NA
Jan – Dec 14  Collar  6,000     WTI    $ 85.00  $ 105.68 $ NA

Gas Contracts

                                                Weighted Ave. Price
Period            Type    MMBTU/day  Index^(4)  Floor      Ceiling
Oct 13 – Dec 14  Collar  80,000     PEPL       $  3.51    $  4.57

Cimarex accounts for commodity derivative contracts using the mark-to-market
(through income) accounting method.

Conference call and webcast
Cimarex will host a conference call and webcast today at 11:00 a.m. Mountain
Time (1:00 p.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 877-270-2148 five minutes before the scheduled start time
(international callers dial 1-412-902-6510). A replay will be available for
one week following the call and can be accessed by dialing 877-344-7529
(international callers dial 1-412-317-0088); conference I.D. 10034791.

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.

Forward-Looking Statements

This press release contains forward-looking statements, including statements
regarding projected results and future events. In particular, the Company is
providing revised "2013 guidance", which contains projections for certain 2013
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, 2012, 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; the ability to complete property sales or other
transactions; 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; declines in the values of our oil and gas properties resulting in
impairments; 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; 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.

    The reconciliation of earnings per diluted share adjusted for the impact
    of open mark-to-market derivative positions, which is a non-GAAP measure,
    is as follows: For the third quarter of 2013, diluted earnings per share
    of $1.59 plus the per share tax-effected loss related to open derivative
(1) positions of $0.03 equals $1.62 diluted earnings per share. For the third
    quarter of 2012, diluted earnings per share of $0.97 plus the per share
    tax-effected loss related to open derivative positions of $0.04 equals
    $1.01 diluted earnings per share. Management believes that this non-GAAP
    measure is useful information for investors and it is a common statistic
    referred to by the investment community.
(2) Adjusted cash flow from operations is a non-GAAP financial measure. See
    below for a reconciliation of the related amounts.
    Reconciliation of debt to total capitalization, which is a non-GAAP
    measure, is: long-term debt of $900 million divided by long-term debt of
(3) $900 million plus stockholders' equity of $3,816 million. Management
    believes that this non-GAAP measure is useful information for investors
    and it is a common statistic referred to by the investment community.
(4) PEPL refers to Panhandle Eastern Pipe Line, Tex/OK Mid-Continent Index as
    quoted in Platt's Inside FERC.



RECONCILIATION OF ADJUSTED CASH FLOW FROM OPERATIONS
                        For the Three Months Ended   For the Nine Months Ended
                        September 30,                September 30,
                        2013           2012          2013           2012
                        (in thousands)
Net cash provided by $  370,962     $  261,216     $ 940,748     $  836,148
operating activities
    Change in
    operating assets
     and             23,027         29,957        91,971         (1,509)
    liabilities
Adjusted cash flow   $  393,989     $  291,173     $ 1,032,719   $  834,639
from operations
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.
PRICE AND PRODUCTION DATA
                        For the Three Months Ended   For the Nine Months Ended
                        September 30,                September 30,
                        2013           2012          2013           2012
    Total gas
    production -        31,907,621     29,830,627    92,913,719     87,824,541
    Mcf
    Gas volume -       346,822        324,246       340,343        320,528
    Mcf per day
    Gas price - per    $3.72          $2.79         $3.73          $2.71
    Mcf
    Total oil
    production -        3,614,865      2,985,956     9,954,625      8,286,503
    barrels
    Oil volume -       39,292         32,456        36,464         30,243
    barrels per day
    Oil price - per    $102.88        $88.18        $93.81         $91.67
    barrel
    Total NGL
    production -        2,058,331      1,781,139     5,883,094      4,916,753
    barrels
    NGL volume -
    barrels per         22,373         19,360        21,550         17,944
    day
    NGL price - per    $28.63         $28.55        $28.57         $31.35
    barrel
OIL AND GAS CAPITALIZED EXPENDITURES
                        For the Three Months Ended   For the Nine Months Ended
                        September 30,                September 30,
                        2013           2012          2013           2012
                        (in thousands)
    Acquisitions:
    Proved *         $  (246)       $  —           $ 677         $  —
    Unproved            1,816          4,636         5,481          11,349
                        1,570          4,636         6,158          11,349
    Exploration and
    development:
    Land and Seismic    59,035         28,226        127,064        86,613
    Exploration and     328,655        389,989       1,059,546      1,120,740
    development
                        387,690        418,215       1,186,610      1,207,353
    Sale proceeds:
    Proved *            1,212          (10,894)      (36,667)       (11,079)
    Unproved            —              —             (1,041)        (1,088)
                        1,212          (10,894)      (37,708)       (12,167)
                     $  390,472     $  411,957     $ 1,155,060   $  1,206,535
    The negative amount in the third-quarter 2013 proved acquisitions and the
*   positive amount in the third-quarter 2013 proved sales proceeds reflect
    net purchase price adjustments related to second-quarter 2013 activity.



CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
(unaudited)
                                  For the Three Months   For the Nine Months
                                  Ended                  Ended
                                  September 30,          September 30,
                                  2013        2012       2013        2012
                                  (in thousands, except per share data)
Revenues:
   Gas sales                    $ 118,824  $  83,208   $ 346,492   $ 238,102
   Oil sales                      371,881     263,315    933,879     759,609
   NGL sales                      58,922      50,860     168,106     154,160
   Gas gathering, processing      11,709      9,529      32,972      31,199
   and other, net
                                  561,336     406,912    1,481,449   1,183,070
Costs and expenses:
   Depreciation, depletion,       160,979     139,499    449,931     384,964
   amortization and accretion
   Production                     76,166      62,699     214,985     192,818
   Transportation and other       25,838      14,481     66,494      40,966
   operating
   Gas gathering and processing   6,970       5,496      18,310      15,302
   Taxes other than income        31,104      24,095     84,039      72,738
   General and administrative     19,003      14,742     57,416      41,523
   Stock compensation             3,347       8,301      10,459      17,519
   (Gain) loss on derivative      10,824      5,329      (1,233)     (661)
   instruments, net
   Other operating, net           2,507       2,236      7,804       7,295
                                  336,738     276,878    908,205     772,464
Operating income                  224,598     130,034    573,244     410,606
Other (income) and expense:
   Interest expense              12,945      12,191     38,228      32,852
   Amortization of deferred       1,009       1,032      3,044       2,718
   financing costs
   Capitalized interest           (7,286)     (9,231)    (23,868)    (26,154)
   Loss on early extinguishment   —           —          —           16,214
   of debt
   Other, net                     (2,263)     (6,159)    (13,637)    (18,714)
Income before income tax          220,193     132,201    569,477     403,690
Income tax expense                81,823      47,939     211,615     149,019
Net income                      $ 138,370  $  84,262   $ 357,862   $ 254,671
Earnings per share to common
stockholders:
   Basic                       $ 1.59     $  0.97     $ 4.12      $ 2.94
   Diluted                      $ 1.59     $  0.97     $ 4.12      $ 2.93
Dividends per share             $ 0.14     $  0.12     $ 0.42      $ 0.36
Shares attributable to common
stockholders:
   Unrestricted common shares     85,213      84,681     85,213      84,681
   outstanding
   Diluted common shares          85,347      84,997     85,330      85,021
Shares attributable to common
stockholders and participating
securities:
   Basic shares outstanding       86,847      86,589     86,847      86,589
   Fully diluted shares          86,981      86,905     86,964      86,929
Comprehensive income:
   Net income                   $ 138,370  $  84,262   $ 357,862   $ 254,671
   Other comprehensive income:
          Change in fair value
          of investments, net     302         238        401         502
          of tax
   Total comprehensive income   $ 138,672  $  84,500   $ 358,263   $ 255,173



 CONDENSED CONSOLIDATED CASH FLOW STATEMENTS (unaudited)
                             For the Three Months    For the Nine Months Ended
                             Ended
                             September 30,           September 30,
                             2013        2012        2013          2012
                             (in thousands)
Cash flows from operating
activities:
 Net income                $ 138,370   $ 84,262    $ 357,862     $ 254,671
 Adjustment to reconcile
 net income to net cash
    provided by operating
    activities:
     Depreciation,
     depletion,              160,979     139,499     449,931       384,964
     amortization and
     accretion
     Deferred income taxes   81,823      49,568      211,615       150,648
     Stock compensation      3,347       8,301       10,459        17,519
     (Gain) loss on
     derivative              10,824      5,329       (1,233)       (661)
     instruments
     Settlements on
     derivative              (6,097)     —           (4,332)       —
     instruments
     Loss on early
     extinguishment of       —           —           —             16,214
     debt
     Changes in
     non-current assets      3,312       2,815       9,102         7,930
     and liabilities
     Amortization of
     deferred financing
     costs
       and other, net        1,431       1,399       (685)         3,354
 Changes in operating
 assets and liabilities:
     Receivables, net        (33,071)    (83,436)    (88,131)      24,398
     Other current assets    (5,041)     13,673      9,799         8,763
     Accounts payable and    15,085      39,806      (13,639)      (31,652)
     accrued liabilities
       Net cash provided
       by operating          370,962     261,216     940,748       836,148
       activities
Cash flows from investing
activities:
 Oil and gas expenditures    (389,417)   (423,134)   (1,165,555)   (1,181,742)
 Sales of oil and gas        23,300      10,894      37,707        12,167
 assets
 Sales of other assets       95          142         31,252        550
 Other expenditures          (9,182)     (16,826)    (34,657)      (42,913)
       Net cash used by
       investing             (375,204)   (428,924)   (1,131,253)   (1,211,938)
       activities
Cash flows from financing
activities:
 Net bank debt borrowings    8,000       80,000      150,000       25,000
 Proceeds from other         —           —           —             750,000
 long-term debt
 Other long-term debt        —           —           —             (363,595)
 payments
                                                     
 Financing costs incurred    (100)       (1,129)                   (13,821)
                                                     (100)
 Dividends paid              (12,122)    (10,330)    (34,570)      (29,199)
 Issuance of common stock    8,463       7,646       10,168        10,410
 and other
       Net cash provided
       by financing          4,241       76,187      125,498       378,795
       activities
Net change in cash and       (1)         (91,521)    (65,007)      3,005
cash equivalents
Cash and cash equivalents    4,532       96,932      69,538        2,406
at beginning of period
Cash and cash equivalents  $ 4,531     $ 5,411     $ 4,531       $ 5,411
at end of period





CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited)
                                             September 30,       December 31,
                                             2013                2012
Assets                                       (in thousands, except share data)
Current assets:
    Cash and cash equivalents              $ 4,531           $   69,538
    Restricted cash                          818                 —
    Receivables, net                         391,105             302,974
    Oil and gas well equipment and           69,517              81,029
    supplies
    Deferred income taxes                    13,902              8,477
    Derivative instruments                   7,168               —
    Other current assets                     9,832               8,119
       Total current assets                  496,873             470,137
Oil and gas properties at cost, using the
full cost method of accounting:
    Proved properties                        12,466,073          11,258,748
    Unproved properties and properties
    under development,
       not being amortized                   597,526             645,078
                                             13,063,599          11,903,826
    Less – accumulated depreciation,         (7,318,137)         (6,899,057)
    depletion and amortization
       Net oil and gas properties            5,745,462           5,004,769
Fixed assets, net                            137,455             152,605
Goodwill                                     620,232             620,232
Derivative instruments                       2,717               —
Other assets, net                            51,625              57,409
                                           $ 7,054,364       $   6,305,152
Liabilities and Stockholders' Equity
Current liabilities:
    Accounts payable                       $ 111,082         $   103,653
    Accrued liabilities                      403,413             392,909
    Derivative instruments                   4,320               —
    Revenue payable                          187,065             149,300
       Total current liabilities             705,880             645,862
Long-term debt                               900,000             750,000
Deferred income taxes                        1,338,623           1,121,353
Other liabilities                           293,576             313,201
       Total liabilities                     3,238,079           2,830,416
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,
       86,838,423 and 86,595,976 shares      868                 866
       issued, respectively
    Paid-in capital                          1,959,160           1,939,628
    Retained earnings                        1,855,382           1,533,768
    Accumulated other comprehensive income   875                 474
                                             3,816,285           3,474,736
                                           $ 7,054,364       $   6,305,152

SOURCE Cimarex Energy Co.

Website: http://www.cimarex.com
Contact: Cimarex Energy Co., Mark Burford, VP - Capital Markets & Planning,
303.295.3995, or Karen Acierno, Director of Investor Relations, 303.285.4957,
www.cimarex.com
 
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