August 9, 2011

EV Energy Partners Announces Second Quarter 2011 Results and Utica Shale Update

HOUSTON, TX -- (MARKET WIRE) -- 08/09/11 -- EV Energy Partners, L.P. (NASDAQ: EVEP) today announced results for the second quarter 2011 and filed its Form 10-Q with the Securities and Exchange Commission.

Second Quarter 2011 Results

Adjusted EBITDAX for the quarter was $55.1 million, a 49 percent increase over the second quarter of 2010 and a 9 percent increase versus the first quarter of 2011. Distributable Cash Flow for the quarter was $33.1 million, a 43 percent increase over the second quarter of 2010 and a 5 percent increase versus the first quarter of 2011. The increases in Adjusted EBITDAX and Distributable Cash Flow, which are described in the attached table under "Non-GAAP Measures," are primarily related to acquisitions completed during the second half of 2010 as well as improved commodity pricing.

For the quarter ended June 30, 2011, EVEP produced 7.0 Bcf of natural gas, 241 MBbls of crude oil and 272 MBbls of natural gas liquids, or 10.1 Bcfe. This represents a 48 percent increase from the second quarter 2010 production of 6.8 Bcfe, primarily due to acquisitions completed during the second half of 2010, and a 2 percent increase over the first quarter 2011 production of 9.9 Bcfe.

EVEP reported net income of $39.2 million, or $1.03 per basic and diluted weighted average limited partner unit outstanding, for the second quarter of 2011. Included in net income were $17.4 million of non-cash net unrealized gains on commodity and interest rate derivatives and $1.7 million of non-cash costs contained in general and administrative expenses. General and administrative expenses also included $0.2 million of acquisition-related due diligence and other related transaction costs. Also included in net income was a $5.1 million impairment charge relating to a recent divestiture of non-core oil and natural gas properties and a $3.3 million non-cash realized gain on derivatives related to term extensions on certain interest rate swaps and to derivatives acquired in conjunction with a 2010 property acquisition. For the second quarter of 2010, net income was $16.3 million, or $0.50 per basic and diluted weighted average limited partner unit outstanding, which included $2.2 million of non-cash net unrealized losses on commodity and interest rate derivatives and $1.0 million of non-cash costs contained in general and administrative expenses. For the first quarter of 2011, net loss was $34.0 million, or ($1.14) per basic and diluted weighted average limited partner unit outstanding. Included in net loss were $54.6 million of non-cash net unrealized losses on commodity and interest rate derivatives and $2.1 million of non-cash costs contained in general and administrative expenses. General and administrative expenses also included $0.3 million of acquisition-related due diligence and other related transaction costs and $1.0 million of costs related to the annual vesting of phantom units during the first quarter of 2011. Also included in net loss was a $1.6 million impairment charge relating to a divestiture of non-core oil and natural gas properties.

The $17.4 million non-cash net unrealized gain on derivatives for the second quarter of 2011 was primarily due to the decrease in future commodity prices that occurred from March 31, 2011 to June 30, 2011 and the effect of such decreased prices on the mark-to-market valuation of EVEP's outstanding commodity derivatives.

Utica Shale Update

EnerVest partnerships, including EVEP, are uniquely positioned in Ohio with a combined 780,000 net acres of mostly held-by-production (HBP) acreage. Approximately 60% of this acreage is operated by EnerVest. EVEP has a total of approximately 159,000 net working interest acres in Ohio, along with the equivalent of a 7.5% overriding royalty interest on approximately 240,000 net acres.

John Walker, Chairman and CEO, said, "The EnerVest partnerships, including EVEP, recently finalized an agreement with Chesapeake (CHK) on a long-term joint venture to develop the emerging Utica shale of Eastern Ohio. We believe that CHK is a recognized worldwide leader in all the complex technical, regulatory, relational and logistical skills necessary to rapidly and efficiently develop a major liquids-rich shale play. CHK will operate about 40% of EnerVest's 780,000 net acres. EVEP retains the equivalent of a 7.5% override on 80,000 net acres and has approximately 22,000 net working interest acres in this joint venture. As announced by CHK in late July, they have five rigs drilling in the Utica, a few producing wells and several awaiting completion. The wells are testing all three legs of the play (oil, NGL and dry gas windows) as well as areas both within and outside the core of the play.

"EnerVest acts as the operator for EVEP and an EnerVest institutional partnership on over 400,000 net acres in Ohio separate from CHK, most of which are HBP. Within this acreage position EVEP has, on average, an approximate 33% interest (137,000 net working interest acres) and holds the equivalent of a 7.5% overriding royalty interest in approximately 160,000 net acres. Because of its proximity to the CHK joint venture, we believe that there will be meaningful cooperation with CHK's joint venture in forming drilling units and contracting for oilfield services and mid-stream operations, which involves maximizing value from ethane and other NGLs. EnerVest has permitted or is permitting ten wells and plans to drill two to three Utica laterals later this year and early next year.

"We are optimistic about the Utica shale, where Ohio records indicate 25 horizontal permits have been granted. We are awaiting more sustained test and production results from the spread of wells in various stages of drilling, completion, testing and production before we can assess the near-term value to EVEP. We expect these results to be released within 30 to 60 days.

"We are very fortunate that the EnerVest partnerships, including EVEP, are the largest conventional oil and gas producer in Ohio, a state recognized for its well-established and strictly-enforced regulations. The state's government leaders, led by Governor John Kasich, are very supportive of responsible development of the Utica shale and the thousands of jobs that we will directly and indirectly create there. Our long-established community, business and government relationships will play an important role as this massive project unfolds."

EVEP's financial statements and related footnotes are available on our second quarter 2011 Form 10-Q, which was filed today and is available through the Investor Relations/SEC Filings section of the EVEP web site at http://www.evenergypartners.com.

Conference Call

As announced on July 28, 2011, EV Energy Partners, L.P. will host an investor conference call Wednesday, August 10, 2011 at 10 a.m. EDT. Investors interested in participating in the call may dial 1-480-629-9722 (quote conference ID 4462519) at least five minutes prior to the start time, or may listen live over the Internet through the Investor Relations section of the EVEP web site at http://www.evenergypartners.com.

EV Energy Partners, L.P., is a master limited partnership engaged in acquiring, producing and developing oil and gas properties. More information about EVEP is available on the Internet at http://www.evenergypartners.com.

(code #: EVEP/G)

This press release may include "forward-looking statements" as defined by the Securities and Exchange Commission. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the partnership expects, believes or anticipates will or may occur in the future are forward-looking statements. These statements are based on certain assumptions made by EVEP based on its experience and perception of historical trends, current conditions, expected future developments and other factors it believes are appropriate in the circumstances. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of EVEP, which may cause our actual results to differ materially from those implied or expressed by the forward-looking statements. These include risks relating to financial performance and results, availability of sufficient cash flow to pay distributions and execute our business plan, prices and demand for natural gas and oil, our ability to replace reserves and efficiently develop our current reserves and other important factors that could cause actual results to differ materially from those projected as described in EVEP's reports filed with the Securities and Exchange Commission.

Any forward-looking statement speaks only as of the date on which such statement is made and EVEP undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise.






Operating Statistics



                                   Three Months Ended     Six Months Ended

                                        June 30,              June 30,

                                  --------------------  --------------------

                                     2011       2010       2011       2010

                                  ---------  ---------  ---------  ---------

Production data:

  Oil (MBbls)                           241        171        449        297

  Natural gas liquids (MBbls)           272        178        542        360

  Natural gas (MMcf)                  6,999      4,734     14,003      8,719

  Net production (MMcfe)             10,080      6,831     19,951     12,665

Average sales price per unit: (1)

  Oil (Bbl)                       $   98.63  $   73.20  $   94.58  $   73.73

  Natural gas liquids (Bbl)           54.80      40.23      51.45      42.91

  Natural gas (Mcf)                    4.20       4.16       4.10       4.66

  Mcfe                                 6.76       5.77       6.40       6.16

Average unit cost per Mcfe:

  Production costs:

    Lease operating expenses (2)  $    1.78  $    2.18  $    1.77  $    2.08

    Production taxes                   0.31       0.24       0.29       0.30

                                  ---------  ---------  ---------  ---------

    Total                              2.09       2.42       2.06       2.38

Asset retirement obligations

 accretion expense                     0.10       0.11       0.10       0.10

Depreciation, depletion and

 amortization                          1.83       1.97       1.80       2.02

General and administrative

 expenses                              0.71       0.85       0.79       0.83



(1) Prior to $12.8 and $16.0 million of net hedge gains and settlements on

 commodity derivatives for the three months ended June 30, 2011 and June 30,

 2010, respectively and $30.0 and $26.2 million for the six months ended

 June 30, 2011 and June 30, 2010.

(2) Lease operating expenses for the three and six months ended June 30,

 2010 include $2.3 million or $0.34 per mcfe and $2.5 million or $0.20 per

 mcfe, respectively of non-cash charges related to oil in tanks purchased in

 connection with the Appalachian Basin acquisitions closed during the fourth

 quarter of 2009 and the first quarter of 2010.









Condensed Consolidated Balance Sheets

 (Unaudited)

(In $ thousands, except number of units)



                                                   June 30,    December 31,

                                                     2011          2010

                                                 ------------  ------------

                     ASSETS

Current assets:

  Cash and cash equivalents                      $     26,392  $     23,127

  Accounts receivable:

    Oil, natural gas and natural gas liquids

     revenues                                          36,600        27,742

    Related party                                       3,967             -

    Other                                                 300           441

  Derivative asset                                     51,215        55,100

  Assets held for sale                                 11,402             -

  Other current assets                                  1,047         1,158

                                                 ------------  ------------

    Total current assets                              130,923       107,568



Oil and natural gas properties, net of

 accumulated depreciation, depletion and

 amortization; June 30, 2011, $210,073; December

 31, 2010, $176,897                                 1,300,294     1,324,240

Other property, net of accumulated depreciation

 and amortization; June 30, 2011, $536; December

 31, 2010, $465                                         1,495         1,567

Long-term derivative asset                             26,576        51,497

Other assets                                            7,533         1,885

                                                 ------------  ------------

Total assets                                     $  1,466,821  $  1,486,757

                                                 ============  ============





         LIABILITIES AND OWNERS' EQUITY

Current liabilities:

  Accounts payable and accrued liabilities

    Third party                                  $     27,642  $     20,678

    Related party                                           -           182

  Liabilities related to assets held for sale           2,895             -

  Derivative liability                                  1,178         1,943

                                                 ------------  ------------

    Total current liabilities                          31,715        22,803



Asset retirement obligations                           68,266        67,175

Long-term debt                                        480,183       619,000

Long-term liabilities                                     988         3,048

Long-term derivative liability                          6,594           784



Commitments and contingencies



Owners' equity:

  Common unitholders - 34,173,650 units and

   30,510,313 units issued and outstanding as of

   June 30, 2011 and December 31, 2010,

   respectively                                       887,843       779,327

  General partner interest                             (8,768)       (5,380)

                                                 ------------  ------------

    Total owners' equity                              879,075       773,947

                                                 ------------  ------------

Total liabilities and owners' equity             $  1,466,821  $  1,486,757

                                                 ============  ============









Condensed Consolidated Statements of Operations (Unaudited)

(In $ thousands, except per unit data)



                                  Three Months Ended     Six Months Ended

                                       June 30,              June 30,

                                 --------------------  --------------------

                                    2011       2010       2011       2010

                                 ---------  ---------  ---------  ---------

Revenues:

  Oil, natural gas and natural

   gas liquids revenues          $  68,109  $  39,431  $ 127,730  $  78,027

  Transportation and

   marketing-related revenues        1,484      1,476      2,885      3,054

                                 ---------  ---------  ---------  ---------

    Total revenues                  69,593     40,907    130,615     81,081

                                 ---------  ---------  ---------  ---------



Operating costs and expenses:

  Lease operating expenses          17,949     14,869     35,311     26,301

  Cost of purchased natural gas      1,120      1,095      2,170      2,315

  Dry hole and exploration costs       441          -        844          -

  Production taxes                   3,119      1,673      5,770      3,800

  Asset retirement obligations

   accretion expense                   970        764      1,936      1,274

  Depreciation, depletion and

   amortization                     18,443     13,436     36,007     25,520

  General and administrative

   expenses                          7,132      5,825     15,725     10,549

  Impairment of oil and natural

   gas properties                    5,078          -      6,666          -

  Gain on sale of oil and

   natural gas properties                -     (4,388)         -     (3,824)

                                 ---------  ---------  ---------  ---------

    Total operating costs and

     expenses                       54,252     33,274    104,429     65,935

                                 ---------  ---------  ---------  ---------



Operating income                    15,341      7,633     26,186     15,146



Other income (expense), net:

  Realized gains on derivatives,

   net                              14,242     13,901     27,784     21,866

  Unrealized gains (losses) on

   derivatives, net                 17,422     (2,158)   (35,633)    30,502

  Interest expense                  (8,124)    (3,269)   (13,283)    (5,372)

  Other income, net                    313        252        233        393

                                 ---------  ---------  ---------  ---------

    Total other income

     (expense), net                 23,853      8,726    (20,899)    47,389

                                 ---------  ---------  ---------  ---------



Income before income taxes          39,194     16,359      5,287     62,535

Income taxes                           (31)       (79)      (113)      (131)

                                 ---------  ---------  ---------  ---------

Net income                       $  39,163  $  16,280  $   5,174  $  62,404

                                 =========  =========  =========  =========

General partner's interest in

 net income, including incentive

 distribution rights             $   3,728  $   2,624  $   5,982  $   5,836

                                 =========  =========  =========  =========

Limited partners' interest in

 net income (loss)               $  35,435  $  13,656  $    (808) $  56,568

                                 =========  =========  =========  =========



Net income (loss) per limited

 partner unit:

  Basic                          $    1.03  $    0.50  $   (0.02) $    2.14

                                 =========  =========  =========  =========

  Diluted                        $    1.03  $    0.50  $   (0.02) $    2.14

                                 =========  =========  =========  =========



Weighted average limited partner

 units outstanding:

  Basic                             34,294     27,210     33,002     26,403

                                 =========  =========  =========  =========

  Diluted                           34,534     27,264     33,002     26,438

                                 =========  =========  =========  =========



Distributions declared per unit  $   0.761  $   0.757  $   1.521  $   1.513

                                 =========  =========  =========  =========









Condensed Consolidated Statements of Cash Flows (Unaudited)

(In $ thousands)



                                                         Six Months Ended

                                                             June 30,

                                                       --------------------

                                                          2011       2010

                                                       ---------  ---------

Cash flows from operating activities:

  Net Income                                           $   5,174  $  62,404

  Adjustments to reconcile net income to net cash

   flows provided by operating activities:

    Asset retirement obligations accretion expense         1,936      1,274

    Depreciation, depletion and amortization              36,007     25,520

    Equity-based compensation cost                         3,877      2,103

    Impairment of oil and natural gas properties           6,666          -

    Gain on sale of oil and natural gas properties             -     (3,824)

    Non-cash derivative activity                          30,951    (30,502)

    Amortization of discount on long-term debt               183          -

    Amortization of deferred loan costs                      554        275

    Other, net                                                56         (1)

    Changes in operating assets and liabilities:

      Accounts receivable                                (12,866)    (4,098)

      Other current assets                                   111      2,625

      Accounts payable and accrued liabilities             7,630        879

      Long-term liabilities                                    -       (734)

      Other, net                                            (149)      (119)

                                                       ---------  ---------

Net cash flows provided by operating activities           80,130     55,802

                                                       ---------  ---------



Cash flows from investing activities:

  Acquisition of oil and natural gas properties            3,101   (147,769)

  Development of oil and natural gas properties          (33,686)    (8,170)

  Proceeds from sale of oil and natural gas properties     1,170      4,471

  Settlements from acquired derivatives                    2,834          -

  Earnest money received for sale of oil and natural

   gas properties                                            900          -

                                                       ---------  ---------

Net cash flows used in investing activities              (25,681)  (151,468)

                                                       ---------  ---------



Cash flows from financing activities:

  Long-term debt borrowings                                    -    138,000

  Repayment of long-term debt borrowings                (431,500)   (95,000)

  Proceeds from debt offering                            292,500          -

  Loan costs incurred                                     (6,202)        (8)

  Proceeds from public equity offering                   147,108     92,770

  Offering costs                                            (308)      (154)

  Contributions from general partner                       3,191      1,977

  Distributions paid                                     (55,973)   (43,433)

                                                       ---------  ---------

Net cash flows (used in) provided by financing

 activities                                              (51,184)    94,152

                                                       ---------  ---------



Increase (decrease) in cash and cash equivalents           3,265     (1,514)

Cash and cash equivalents - beginning of period           23,127     18,806

                                                       ---------  ---------

Cash and cash equivalents - end of period              $  26,392  $  17,292

                                                       =========  =========





Non-GAAP Measures

We define Adjusted EBITDAX as net income plus income tax provision, interest expense, net, realized losses on interest rate swaps, depreciation, depletion and amortization, asset retirement obligation accretion expense, non-cash realized (gains) on derivatives, non-cash unrealized (gains) losses on derivatives, non-cash equity compensation, impairment of oil and natural gas properties, gain on sale of oil and natural gas properties, write down of crude oil inventory, and dry hole and exploration costs. Distributable Cash Flow is defined as Adjusted EBITDAX less income tax provision, cash interest expense, net, realized losses on interest rate swaps and estimated maintenance capital expenditures.

Adjusted EBITDAX and Distributable Cash Flow are used by our management to provide additional information and statistics relative to the performance of our business, including (prior to the creation of any reserves) the cash available to pay distributions to our unitholders. These financial measures indicate to investors whether or not we are generating cash flow at a level that can sustain or support an increase in our quarterly distribution rates. Adjusted EBITDAX and Distributable Cash Flow are also quantitative standards used throughout the investment community with respect to performance of publicly-traded partnerships. Adjusted EBITDAX and Distributable Cash Flow should not be considered as alternatives to net income, operating income, cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Adjusted EBITDAX and Distributable Cash Flow exclude some, but not all, items that affect net income and operating income and these measures may vary among companies. Therefore, our Adjusted EBITDAX and Distributable Cash Flow may not be comparable to similarly titled measures of other companies.






Reconciliation of Net Income to Adjusted EBITDAX and Distributable Cash

 Flow

(In $ thousands)



                                  Three Months Ended     Six Months Ended

                                       June 30,              June 30,

                                 --------------------  --------------------

                                    2011       2010       2011       2010

                                 ---------  ---------  ---------  ---------



Net income                       $  39,163  $  16,280  $   5,174  $  62,404

Add:

Income taxes                            31         79        113        131

Interest expense, net                8,118      3,264     13,272      5,340

Realized losses on interest rate

 swaps                               1,828      2,143      3,967      4,301

Depreciation, depletion and

 amortization                       18,443     13,436     36,007     25,520

Asset retirement obligation

 accretion expense                     970        764      1,936      1,274

Non-cash realized (gains) on

 derivatives                        (3,279)         -     (1,784)         -

Non-cash unrealized (gains)

 losses on derivatives             (17,422)     2,158     35,633    (30,502)

Non-cash equity compensation

 expense                             1,739      1,037      3,877      2,103

Impairment of oil and natural

 gas properties                      5,078          -      6,666          -

Gain on sale of oil and natural

 gas properties                          -     (4,388)         -     (3,824)

Non-cash inventory expense from

 2009 Appalachian Basin

 acquisition included in lease

 operating expense                       -      2,302          -      2,542

Dry hole and exploration costs         441          -        844          -

                                 ---------  ---------  ---------  ---------

Adjusted EBITDAX                    55,110     37,075    105,705     69,289

                                 ---------  ---------  ---------  ---------



Less:

Income taxes                            31         79        113        131

Cash interest expense, net           7,600      3,126     12,535      5,065

Realized losses on interest rate

 swaps                               1,828      2,143      3,967      4,301

Estimated maintenance capital

 expenditures (1)                   12,600      8,539     24,446     16,414

                                 ---------  ---------  ---------  ---------

Distributable Cash Flow          $  33,051  $  23,188  $  64,644  $  43,378

                                 =========  =========  =========  =========



(1) Estimated maintenance capital expenditures are those expenditures

 estimated to be necessary to maintain the production levels of our oil and

 gas properties over the long term and the operating capacity of our other

 assets over the long term.









Hedge Summary Table (as of 08/09/2011)



                                   Swap     Swap    Collar    Collar  Collar

Period     Index                  Volume   Price    Volume    Floor  Ceiling

---------- --------------------- -------- ------- ---------- ------- -------

                                 (MmmBtu/         (MmmBtu/

                                 Mbbls)           Mbbls)

Natural

 Gas

----------

3Q 2011    NYMEX                  3,793.4   $6.34      396.4   $5.90   $7.03

           Dominion Appalachia      230.0   $8.69      276.0   $9.00  $12.15

           El Paso Permian          230.0   $9.30

           Houston Ship Channel                        322.0   $8.25  $11.65

           MichCon Citygate                            414.0   $8.70  $11.85

           NGPL TX/OK                                  256.9   $5.75   $6.58



4Q 2011    NYMEX                  3,609.4   $6.43      396.4   $5.90   $7.03

           Dominion Appalachia      230.0   $8.69      276.0   $9.00  $12.15

           El Paso Permian          230.0   $9.30

           Houston Ship Channel                        322.0   $8.25  $11.65

           MichCon Citygate                            414.0   $8.70  $11.85

           NGPL TX/OK                                  256.9   $5.75   $6.58



1H 2012    NYMEX                  7,025.2   $6.64    1,016.3   $6.22   $6.94

           El Paso Permian          364.0   $9.21

           Dominion Appalachia                         910.0   $8.95  $11.45

           Houston Ship Channel                        546.0   $8.25  $11.10

           MichCon Citygate                            819.0   $8.75  $11.05



2H 2012    NYMEX                  6,550.4   $6.79    1,027.5   $6.22   $6.94

           El Paso Permian          368.0   $9.21

           Dominion Appalachia                         920.0   $8.95  $11.45

           Houston Ship Channel                        552.0   $8.25  $11.10

           MichCon Citygate                            828.0   $8.75  $11.05



2013       NYMEX                 16,607.5   $5.65

           El Paso Permian        1,095.0   $6.77

           El Paso San Juan       1,095.0   $6.66



2014       NYMEX                 14,600.0   $5.75



2015       NYMEX                 14,600.0   $6.00



Crude Oil

----------

3Q 2011    WTI                      107.5  $94.91      118.3 $105.66 $156.16

4Q 2011    WTI                      101.9  $95.12      118.3 $105.66 $156.16



1Q 2012    WTI                      167.0  $96.49      113.6 $104.54 $156.77

2Q 2012    WTI                      157.9  $96.50      113.6 $104.54 $156.77

3Q 2012    WTI                      155.0  $96.38      114.8 $104.54 $156.77

4Q 2012    WTI                      145.8  $96.43      114.8 $104.54 $156.77






                                      Swap     Swap   Collar  Collar  Collar

Period      Index                    Volume   Price   Volume   Floor Ceiling

----------- ----------------------- -------- ------- -------- ------ -------

                                    (Mmmbtu/         (Mmmbtu/

                                    Mbbls)           Mbbls)

Crude Oil

-----------

1Q 2013     WTI                        252.0  $86.74

2Q 2013     WTI                        250.3  $86.53

3Q 2013     WTI                        248.4  $86.37

4Q 2013     WTI                        243.8  $86.17



1H 2014     WTI                        452.5  $89.52

2H 2014     WTI                        444.7  $94.33



Ethane

-----------

            Mt. Belvieu(Non-TET)-

3Q 2011     OPIS                        96.6  $20.32

            Mt. Belvieu(Non-TET)-

4Q 2011     OPIS                        92.0  $19.79



Propane

-----------

            Mt. Belvieu(Non-TET)-

3Q 2011     OPIS                        57.5  $49.36

            Mt. Belvieu(Non-TET)-

4Q 2011     OPIS                        55.2  $50.20



Basis Swaps

-----------------------------------

Premium to NYMEX

2H 2011     Dominion Appalachia        174.4 $0.1975

2H 2011     Columbia Appalachia         47.7 $0.1500



Interest Rate Swap                  Notional  Fixed

Agreements                           Amount    Rate

----------------------------------- -------- -------

                                      (in $

                                      mill)

July 2011 - July 2012                   90.0  4.157%

July 2011 - Sept 2012                   40.0  2.145%

July 2012 - July 2015                  110.0  3.315%






EV Energy Partners, L.P., Houston

Michael E. Mercer

713-651-1144

http://www.evenergypartners.com



Source: EV Energy Partners, L.P.

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