StockSelector.com
  Research, Select, & Monitor Sunday, September 23, 2018 11:43:59 AM ET  
Trade Ideas The Market Industries Stocks Portfolio

 
Ticker Lookup
EV Energy Partner LP$0.13   

  Quote | Ranking | Chart | Valuations | Sentiment | Industry | News | Earnings | Analysts | More...

Your Target?

 EV Energy Partners Announces Fourth Quarter and Full Year 2016 Results, Additional Commodity Hedges, Year-end Proved Reserves and 2017 Guidance
   Wednesday, March 01, 2017 6:22:07 AM ET

EV Energy Partners, L.P. (EVEP ) today announced results for the fourth quarter and full year 2016 and the filing of its Form 10-K with the Securities and Exchange Commission. In addition, EVEP announced its 2016 year-end proved reserves and 2017 guidance.

Highlights

-- Overall operating results for the year in line with 2016 guidance

-- Completed divestment of certain gas-weighted assets in the Barnett Shale for $52.1 million on December 1, 2016 (before post-closing purchase price adjustments)

-- Completed $58.7 million asset purchase on January 31, 2017 (before post-closing purchase price adjustments) in the Eagle Ford and Austin Chalk in Karnes County, TX using proceeds from the Barnett Shale divestiture through a like-kind exchange transaction and $6.6 million of borrowings under the credit facility

-- Repurchased $82.7 million of outstanding Senior Secured Notes due April 2019 for $35 million

-- Increased capital spending budget to $30 to $45 million for 2017 from $10.7 million in 2016

-- Maintained significant liquidity, which is currently over $175 million, between borrowing base capacity and cash on hand

Fourth Quarter 2016 Results

For the fourth quarter 2016, EVEP reported a net loss of $165.7 million, or $(3.31) per basic and diluted weighted average limited partner unit outstanding compared to a net loss of $19.2 million, or $(0.38) per basic and diluted weighted average limited partner unit outstanding for the third quarter of 2016. Included in net loss were the following items:

-- $127.9 million of impairment charges primarily related to the write-down of certain oil and natural gas properties due to the effects of commodity prices on expected future net cash flows and the disposition of oil and natural gas properties,

-- $27.5 million of non-cash losses on commodity and interest rate derivatives, and

-- $1.8 million of non-cash costs contained in general and administrative expenses.

For the fourth quarter of 2015, EVEP reported a net loss of $71.3 million, or $(1.43) per basic and diluted weighted average limited partner unit outstanding.

Production for the fourth quarter of 2016 was 11 Bcf of natural gas, 278 Mbbls of oil and 547 Mbbls of natural gas liquids, or 173.6 million cubic feet equivalent per day (Mmcfe/day). This represents a 17 percent decrease from fourth quarter 2015 production of 209.8 Mmcfe/d and an 11 percent decrease from third quarter 2016 production of 195.3 Mmcfe/day. The decreases were primarily due to reduced drilling activity and the divestitures completed on December 1, 2016.

Adjusted EBITDAX for the fourth quarter of 2016 was $28.5 million, a 46 percent decrease from the fourth quarter of 2015 and a 10 percent increase over the third quarter of 2016. Distributable Cash Flow for the fourth quarter of 2016 was $7.9 million, a 70 percent decrease from the fourth quarter of 2015 and a 24 percent increase over the third quarter of 2016. The decreases in Adjusted EBITDAX and Distributable Cash Flow from the fourth quarter of 2015 were attributable to lower realized hedge gains and lower production, partially offset by higher realized oil, natural gas and natural gas liquids prices. The increases in Adjusted EBITDAX and Distributable Cash Flow over the third quarter of 2016 were primarily due to higher realized oil, natural gas and natural gas liquids prices and lower operating expenses, partially offset by lower production. Adjusted EBITDAX and Distributable Cash Flow are Non-GAAP financial measures and are described in the attached table under "Non-GAAP Measures."

Full Year 2016 Results

For 2016, EVEP reported a net loss of $242.9 million, or $(4.85) per basic and diluted weighted average limited partner unit outstanding as compared to net income of $21.3 million, or $0.41 per basic and diluted weighted average limited partner unit outstanding for 2015. Included in net loss were the following items:

-- $131.3 million of impairment charges primarily related to the write-down of certain oil and natural gas properties due to the effects of commodity prices on expected future net cash flows and the disposition of oil and natural gas properties,

-- $93.8 million of non-cash losses on commodity and interest rate derivatives,

-- $47.7 million of gain on early extinguishment of debt related to repurchases of Senior Notes at a discount to par,

-- $6.6 million of non-cash costs contained in general and administrative expenses,

-- $3.2 of gain on settlement of contract, and

-- $0.7 million of dry hole and exploration costs.

Production for 2016 was 49.3 Bcf of natural gas, 1.2 Mmbbls of oil and 2.3 Mmbbls of natural gas liquids, or 192.9 Mmcfe/day, which is a 10 percent increase over 2015 production of 174.8 Mmcfe/day. The increase over 2015 production was primarily due to the addition of producing properties acquired on October 1, 2015.

Adjusted EBITDAX and Distributable Cash Flow for 2016 of $101.3 million and $18.7 million decreased 50 percent and 81 percent, respectively, versus 2015. The decreases in Adjusted EBITDAX and Distributable Cash Flow as compared to 2015 are primarily due to lower realized hedge gains and lower realized oil and natural gas prices, partially offset by the addition of producing properties acquired on October 1, 2015, lower operating expenses and higher realized natural gas liquids prices.

"In 2016, our overall results were in line with guidance, we continued to reduce operating costs through the hard work of our asset teams, and we reduced debt by $83 million. In December, we sold some of our Barnett Shale natural gas assets, and in January, redeployed the proceeds in an oil-weighted Karnes County acquisition that we believe has significantly more drilling opportunities at attractive rates of return in the current commodity price environment. In 2017, we plan to increase our capital spending, while remaining focused on our cost structure and maintaining sufficient liquidity," said Michael Mercer, President and CEO.

Additional Commodity Hedges

EVEP entered into the following additional commodity hedges in 2016 subsequent to its press release on November 9, 2016. EVEP’s current hedge position, including these new hedges, is presented at the end of this press release under Total Current Hedge Position.

                                   Swap    Swap
Period                 Index       Volume  Price
Natural Gas (Mmmbtus)
Jan - Mar 2018         NYMEX       4,500   $3.46
Ethane (Mbbls)
2017                   Mt Belvieu  511.0   $11.66
Propane (Mbbls)
2017                   Mt Belvieu  255.5   $25.10

Year-end 2016 Estimated Net Proved Reserves

EVEP’s year-end 2016 estimated net proved reserves were 851 Bcfe. Approximately 68 percent were natural gas, 23 percent were natural gas liquids and 9 percent were crude oil. In addition, 90 percent were categorized as proved developed. Year-end 2016 estimated net proved reserves decreased by 22 percent or 246 Bcfe from year-end 2015 estimated net proved reserves due to reduced commodity pricing, asset divestitures, and volumes produced and sold during 2016. The prices used in determining estimated net proved reserves at December 31, 2016 were $42.75 per Bbl of oil and $2.48 per Mmbtu of natural gas as compared to $50.28 per Bbl of oil and $2.59 per Mmbtu of natural gas at December 31, 2015.

At December 31, 2016, the present value of future net pre-tax cash flows discounted at 10 percent ("PV 10") was $373.6 million (a non-GAAP measure) and the standardized measure of estimated net proved reserves was $371.1 million. Standardized measure is the present value of estimated future net revenues to be generated from the production of proved reserves, determined in accordance with the rules and regulations of the Securities and Exchange Commission (the "SEC"), without giving effect to non-property related expenses such as certain general and administrative expenses, debt service and future federal income tax expenses or to depreciation, depletion and amortization and discounted using an annual discount rate of 10 percent. Our standardized measure includes approximately $2.5 million of present value of future obligations under the Texas gross margin tax, but it does not include future federal income tax expenses because we are a partnership and are not subject to federal income taxes. We have included PV 10 because we believe it is a measure frequently utilized by investors.

EVEP’s year-end 2016 estimated net proved reserves and standardized measure are net of the recently announced divestiture of 74 Bcf of proved natural gas properties in the Barnett Shale on December 1, 2016 and prior to the acquisition of estimated net proved reserves of 35 Bcfe of Eagle Ford and Austin Chalk oil and natural gas properties in Karnes County, TX which closed on January 31, 2017.

                  Estimated Net Proved Reserves
                  Crude Oil  Natural    NGL’s     Natural      PV 10
                  (MMBbls)   Gas (Bcf)  (MMBbls)  Gas          ($mm)
                                                  Equivalents
                                                  (Bcfe)
Barnett Shale     0.4        239.1      21.0      367.8        $  128.6
San Juan Basin    1.1        94.9       7.1       144.0           46.3
Appalachia Basin  7.2        91.7       0.3       136.4           98.4
Michigan          -          74.7       0.4       77.8            29.1
Central Texas     2.4        20.5       2.4       49.1            44.0
Monroe Field      -          27.9       -         27.9            (1.2  )
Mid-Continent area1.1        18.9       0.4       27.8            18.9
Permian Basin     0.4        7.6        1.8       20.4            9.5
Total             12.6       575.3      33.4      851.2           373.6

For comparative purposes, utilizing NYMEX forward closing prices for oil and natural gas on December 30, 2016 (the last trading day of 2016), total NYMEX strip-based proved reserves at December 31, 2016 were 1,277 Bcfe (69 percent proved developed), with a PV 10 of $790 million, an increase of 426 Bcfe over SEC reserves and $416 million over SEC PV 10. Also at these prices, our January 2017 Karnes County, TX acquisition had strip-based proved reserves of 38 Bcfe (21 percent proved developed), with a PV 10 of $87 million. NYMEX strip-based proved reserves are calculated based on the SEC proved reserves estimation methodology, but applying NYMEX strip prices rather than SEC prices. We believe that the PV 10 of NYMEX strip-based reserves is useful to investors to illustrate the potential value of proved reserves that are economically recoverable in the current commodity price environment rather than SEC prices. Neither the PV 10 of our SEC reserves, the PV 10 of our NYMEX strip-based reserves nor the standardized measure represents an estimate of fair market value of our oil and natural gas properties.

2017 Guidance

 ($ in millions)                                     Full Year 2017
 Net Production
 Natural Gas (Mmcf)                                  40,720      -            45,005
 Crude Oil (Mbbls)                                   1,325       -            1,465
 Natural Gas Liquids (Mbbls)                         2,055       -            2,270
 Total Mmcfe                                         61,000      -            67,415
 Average Daily Production (Mmcfe/d)                  167         -            185
 Net Transportation Margin (a)            $0.5                   - $1.0
 Average Price Differential vs NYMEX
 Natural Gas ($/Mcf)                      ($0.37)                - ($0.25)
 Crude Oil ($/Bbl)                        ($5.40)                - ($3.90)
 NGL (% of NYMEX Crude Oil)                          34%         -            38%
 Expenses
 Operating Expenses:
 LOE and other                            $98.1                  - $108.5
 Production Taxes (as % of revenue)                  4.2%        -            5.2%
                                                                 -
 General and administrative expense (b)   $22.0                  - $26.0
 Capital Expenditures (c)                 $30.0                  - $45.0
 (a)  Represents estimated transportation and marketing-related revenues less cost of purchased natural gas.
 (b)  Excludes non-cash general and administrative expense, of which non-cash unit based compensation is a part, also
 excludes any amounts for future acquisition related due diligence and transaction costs.
 (c)  Represents estimates for drilling and related capital expenditures. Does not include any amounts for acquisitions of
 oil and gas properties.

Annual Report on Form 10-K and Unitholders’ Schedule K-1

EVEP’s financial statements and related footnotes are available on our 2016 Form 10-K, which was filed today and is available through the Investor Relations/SEC Filings section of the EVEP website at http://www.evenergypartners.com .

Also available for download on our website by March 6, 2016 will be unitholders’ Schedule K-1’s for the tax year 2016. For any questions regarding their Schedule K-1, unitholders are invited to call the Tax Package Support helpline at 1-800-973-7551.

Conference Call

As announced on January 31, 2016, EV Energy Partners, L.P. will host an investor conference call on March 1, 2016, at 9 a.m. Eastern Standard Time (8 a.m. Central). Investors interested in participating in the call may dial 1-888-245-0988 (quote conference ID 9028703) at least 5 minutes prior to the start time, or may listen live over the Internet through the Investor Relations section of the EVEP website at http://www.evenergypartners.com .

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

(code #: EVEP/G)

Forward Looking Statements

This press release may include statements that are not historical facts which are "forward-looking statements" within the meaning of the U.S. Private Securities Litigation Reform Act of 1995. These statements include information about future plans, our reserve quantities and the present value of our reserves, estimates of maintenance capital and production amounts, the information under the heading "2017 Guidance" and other statements which include words such as "anticipates," "plans," "projects," "expects," "intends," "believes," "should," and similar expressions of forward-looking information. Forward-looking statements are inherently uncertain and necessarily involve risks that may affect the business prospects and performance of EVEP. 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. Actual results may differ materially from those contained in the press release. Such risks and uncertainties include, but are not limited to, changes in commodity prices, changes in reserve estimates, requirements and actions of purchasers of properties, exploration and development activities, the availability and cost of financing, the returns on our capital investments and acquisition strategies, the availability of sufficient cash flow to pay distributions and execute our business plan and general economic conditions. Additional information on risks and uncertainties that could affect our business prospects and performance are provided in the most recent reports of EVEP with the SEC. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this press release. All forward-looking statements included in this press release are expressly qualified in their entirety by the foregoing cautionary statements.

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                                                                        Twelve Months Ended
                                           December 31,                                                                              December 31,
                                                                 2016                                         2015                                         2016                                         2015
 Production data:
 Oil (Mbbls)                                                     278                                          351                                          1,216                                        1,041
 Natural gas liquids (Mbbls)                                     547                                          655                                          2,331                                        2,326
 Natural gas (Mmcf)                                              11,029                                       13,266                                       49,333                                       43,592
 Net production (Mmcfe)                                          15,975                                       19,301                                       70,612                                       63,792
 Average sales price per unit: (1)
 Oil (Bbl)                                 $45.42                                       $38.69                                       $38.78                                       $43.67
 Natural gas liquids (Bbl)                                       19.33                                        13.86                                        15.32                                        14.04
 Natural gas (Mcf)                                               2.60                                         1.86                                         2.02                                         2.23
 Mcfe                                                            3.25                                         2.45                                         2.59                                         2.74
 Average unit cost per Mcfe:
 Production costs:
 Lease operating expenses                  $1.43                                        $1.54                                        $1.46                                        $1.56
 Production taxes                                                0.12                                         0.11                                         0.10                                         0.11
 Total                                                           1.55                                         1.65                                         1.56                                         1.67
 Depreciation, depletion and amortization                        1.73                                         1.62                                         1.69                                         1.66
 General and administrative expenses                             0.55                                         0.52                                         0.48                                         0.62
 (1) Prior to $8.8 million and $44.9 million of net hedge gains on settlements of commodity derivatives for the three months ended December 30, 2016 and 2015, respectively, and $57.9 million and $143.3 million for the twelve months ended December 31, 2016 and 2015, respectively.
Consolidated Balance Sheets
(In $ thousands, except number of units)
                                                        December 31, 2016 December 31, 2015
ASSETS
Current assets:
Cash and cash equivalents                               $5,557            $20,415
Accounts receivable:
Oil, natural gas and natural gas liquids revenues             39,629            24,285
Related party                                                 745               -
Other                                                         2,451             7,137
Derivative asset                                              201               60,662
Other current assets                                          3,718             3,057
Total current assets                                          52,301            115,556
Oil and natural gas properties, net of accumulated
depreciation, depletion and amortization; December 31,
2016, $1,051,600; December 31, 2015, $971,499                 1,497,211         1,790,455
Other property, net of accumulated depreciation
and amortization; December 31, 2016, $1,002;
December 31, 2015, $970                                       996               1,019
Restricted cash                                               52,076            -
Long-term derivative asset                                    -                 10,741
Other assets                                                  4,186             5,831
Total assets                                            $1,606,770        $1,923,602
LIABILITIES AND OWNERS’ EQUITY
Current liabilities:
Accounts payable and accrued liabilities:
Third party                                             $31,700           $43,135
Related party                                                 5,797             5,952
Derivative liability                                          21,679            -
Income taxes                                                  -                 11,657
Total current liabilities                                     59,176            60,744
Asset retirement obligations                                  180,241           174,003
Long-term debt, net                                           606,948           688,614
Long-term derivative liability                                955               -
Other long-term liabilities                                   1,043             1,682
Commitments and contingencies
Owners’ equity:
Common unitholders - 49,055,214 units and
48,871,399 units issued and outstanding as of
December 31, 2016 and 2015, respectively                      776,158           1,011,509
General partner interest                                      (17,751)          (12,950)
Total owners’ equity                                          758,407           998,559
Total liabilities and owners’ equity                    $1,606,770        $1,923,602
Consolidated Statements of Operations
(In $ thousands, except per unit data)
                                                                        Three Months Ended                 Twelve Months Ended
                                                                        December 31,                       December 31,
                                                                              2016             2015              2016             2015
Revenues:
Oil, natural gas and natural gas liquids revenues                       $51,842           $47,354          $182,696          $175,088
Transportation and marketing-related revenues                                 599              598               2,198            2,883
Total revenues                                                                52,441           47,952            184,894          177,971
Operating costs and expenses:
Lease operating expenses                                                      22,839           29,793            103,371          99,626
Cost of purchased natural gas                                                 421              400               1,497            1,988
Dry hole and exploration costs                                                (544)            1,975             651              3,695
Production taxes                                                              1,885            2,076             7,386            6,784
Accretion expense on obligations                                              2,079            2,050             8,225            5,598
Depreciation, depletion and amortization                                      27,679           31,251            119,171          105,969
General and administrative expenses                                           8,775            10,026            33,637           38,994
Impairment of oil and natural gas properties                                  127,889          14,423            131,260          136,667
Impairment of goodwill                                                        -                65,924            -                65,924
Loss (gain) on settlement of contract                                         -                1,210             (3,185)          1,210
Gain on sales of oil and natural gas properties                               (69)             (20)              (69)             (551)
Total operating costs and expenses                                            190,954          159,108           401,944          465,904
Operating loss                                                                (138,513)        (111,156)         (217,050)        (287,933)
Other income (expense), net:
Gain (loss) on derivatives, net                                               (18,758)         26,739            (35,950)         78,145
Interest expense                                                              (9,933)          (12,057)          (42,487)         (50,336)
Gain on early extinguishment of debt                                          -                24,024            47,695           24,024
Other income, net                                                             936              27                2,522            78
Total other income (expense), net                                             (27,755)         38,733            (28,220)         51,911
Income (loss) from continuing operations before income taxes                  (166,268)        (72,423)          (245,270)        (236,022)
Income taxes                                                                  596              1,159             2,375            1,843
Income (loss) from continuing operations                                      (165,672)        (71,264)          (242,895)        (234,179)
Income from discontinued operations                                           -                -                 -                255,512
Net income (loss)                                                       $(165,672)        $(71,264)        $(242,895)        $21,333
Earnings per limited partner unit (basic and diluted):
Income (loss) from continuing operations                                $(3.31)           $(1.43)          $(4.85)           $(4.72)
Income from discontinued operations                                           -                -                 -                5.13
Net income (loss)                                                       $(3.31)           $(1.43)          $(4.85)           $0.41
Weighted average limited partner units outstanding (basic and diluted)        49,055           48,871            49,048           48,853
Distributions declared per common unit                                  $     -           $0.075           $     -           $1.575
Consolidated Statements of Cash Flows
(In $ thousands)
                                                                                                Twelve Months Ended
                                                                                                December 31,
                                                                                                      2016           2015
Cash flows from operating activities:
Net income (loss)                                                                               $(242,895)       $21,333
Adjustments to reconcile net income (loss) to net cash flows provided by operating activities:
Income from discontinued operations                                                                   -              (255,512)
Amortization of volumetric production payment liability                                               (4,108)        (1,196)
Accretion expense on obligations                                                                      8,225          5,598
Depreciation, depletion and amortization                                                              119,171        105,969
Equity-based compensation cost                                                                        6,611          12,001
Impairment of oil and natural gas properties                                                          131,260        136,667
Impairment of goodwill                                                                                -              65,924
Gain on sales of oil and natural gas properties                                                       (69)           (551)
Loss (gain) on derivatives, net                                                                       35,950         (78,145)
Cash settlements of matured derivative contracts                                                      54,884         140,657
Gain on early extinguishment of debt                                                                  (47,695)       (24,024)
Deferred taxes                                                                                        (404)          (13,285)
Other                                                                                                 2,523          4,487
Changes in operating assets and liabilities:
Accounts receivable                                                                                   (11,403)       14,850
Other current assets                                                                                  (361)          511
Accounts payable and accrued liabilities                                                              (5,862)        (4,067)
Income taxes                                                                                          (11,657)       10,683
Other, net                                                                                            (295)          (245)
Net cash flows provided by operating activities from continuing operations                            33,875         141,655
Net cash flows used in operating activities from discontinued operations                              -              (372)
Net cash flows provided by operating activities                                                       33,875         141,283
Cash flows from investing activities:
Acquisitions of oil and natural gas properties, net of cash acquired                                  -              (250,357)
Additions to oil and natural gas properties                                                           (15,258)       (67,923)
Proceeds from sales of oil and natural gas properties                                                 54,509         1,457
Restricted cash                                                                                       (52,076)       33,768
Cash settlements from acquired derivative contracts                                                   3,003          2,615
Other                                                                                                 56             73
Net cash flows used in investing activities from continuing operations                                (9,766)        (280,367)
Net cash flows provided by investing activities from discontinued operations                          -              572,160
Net cash flows (used in) provided by investing activities                                             (9,766)        291,793
Cash flows from financing activities:
Long-term debt borrowings                                                                             57,000         295,000
Repayments of long-term debt borrowings                                                               (57,000)       (561,000)
Redemption of 8% Senior Notes due 2019                                                                (34,978)       (49,954)
Loan costs paid                                                                                       (121)          (4,074)
Contributions from general partner                                                                    -              91
Distributions paid                                                                                    (3,868)        (100,979)
Net cash flows used in financing activities                                                           (38,967)       (420,916)
(Decrease) increase in cash and cash equivalents                                                      (14,858)       12,160
Cash and cash equivalents - beginning of period                                                       20,415         8,255
Cash and cash equivalents - end of period                                                       $5,557           $20,415

Non GAAP Measures

We define Adjusted EBITDAX as net income (loss) plus income from discontinued operations, EBITDAX from discontinued operations, income taxes, interest expense, net, cash settlements of matured interest rate swaps, depreciation, depletion and amortization, accretion expense on obligations, amortization of volumetric production payment (VPP), loss (gain) on derivatives, net, cash settlements of matured derivative contracts, non-cash equity-based compensation, impairment of oil and natural gas properties, impairment of goodwill, non-cash inventory write down expense, dry hole and exploration costs, gain on sales of oil and natural gas properties, loss (gain) on settlement of contract, gain on early extinguishment of debt, and (gain) loss on sale of investment, contained in Other income, net. Distributable Cash Flow is defined as Adjusted EBITDAX less cash income taxes, 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. We believe these financial measures may indicate to investors whether or not we are generating cash flow at a level that can sustain or support quarterly distributions. 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 (Loss) to Adjusted EBITDAX and Distributable Cash Flow
(In $ thousands)
                                                                   Three Months Ended                                                            Twelve Months Ended
                                                                   Dec 31, 2016              Dec 31, 2015              Sep 30, 2016              Dec 31, 2016              Dec 31, 2015
Net income (loss)                                                  $(165,672)                $(71,264)                 $(19,230)                 $(242,895)                $21,333
Add:
Income from discontinued operations                                            -                         -                         -                         -                         (255,512)
EBITDAX from discontinued operations                                           -                         -                         -                         -                         15,941
Income taxes                                                                   (596)                     (1,159)                   (1,429)                   (2,375)                   (1,843)
Interest expense, net                                                          9,932                     12,050                    9,889                     42,476                    50,314
Cash settlements of matured interest rate swaps                                -                         -                         -                         -                         1,736
Depreciation, depletion and amortization                                       27,679                    31,251                    31,639                    119,171                   105,969
Accretion expense on obligations                                               2,079                     2,050                     2,057                     8,225                     5,598
Amortization of VPP                                                            (1,038)                   (1,196)                   (1,027)                   (4,108)                   (1,196)
Loss (gain) on derivatives, net                                                18,758                    (26,739)                  (8,559)                   35,950                    (78,145)
Cash settlements of matured derivative contracts                               8,765                     44,904                    10,117                    57,887                    143,272
Non-cash equity-based compensation                                             1,758                     2,366                     1,889                     6,611                     12,001
Impairment of oil and natural gas properties                                   127,889                   14,423                    687                       131,260                   136,667
Impairment of goodwill                                                         -                         65,924                    -                         -                         65,924
Non-cash inventory write down expense                                          (422)                     973                       -                         (299)                     1,122
Dry hole and exploration costs                                                 (544)                     1,975                     294                       651                       3,695
Gain on sales of oil and natural gas properties                                (69)                      (20)                      -                         (69)                      (551)
Loss (gain) on settlement of contract                                          -                         1,210                     -                         (3,185)                   1,210
Gain on early extinguishment of debt                                           -                         (24,024)                  -                         (47,695)                  (24,024)
(Gain) loss on sale of investment, contained in Other income, net              -                         -                         (309)                     (309)                     358
Adjusted EBITDAX                                                   $28,519                   $52,724                   $26,018                   $101,296                  $203,869
Less:
Cash income taxes                                                              -                         441                       (933)                     (933)                     441
Cash interest expense, net                                                     9,609                     11,264                    9,566                     39,558                    48,504
Realized losses on interest rate swaps                                         -                         -                         -                         -                         1,736
Estimated maintenance capital expenditures (1)                                 11,000                    14,875                    11,000                    44,000                    54,672
Distributable Cash Flow                                            $7,910                    $26,144                   $6,385                    $18,671                   $98,516
(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.

Total Current Hedge Position

                                     Swap            Swap            Collar Collar Collar
Period                Index          Volume          Price           Volume Floor  Ceiling
Natural Gas (Mmmbtus)
2017                  NYMEX          32,850          $3.07           10,950 $2.75  $3.27
Jan - Mar 2018        NYMEX          4,500           $3.46
Crude (Mbbls)
2017                  WTI            365             $52.85
Ethane (Mbbls)
2017                  Mt Belvieu     511.0           $11.66
Propane (Mbbls)
2017                  Mt Belvieu     255.5           $25.10
                                     Notional Amount     Fixed Rate
Interest Rate Swap Agreements        ($ mill)
Jan 2017 - Dec 2017                  100                 1.039%
Jan 2018 - Sep 2020                  100                 1.795%
EV Energy Partners, L.P., Houston
Nicholas Bobrowski
713-651-1144
http://www.evenergypartners.com 

https://resource.globenewswire.com/Resource/Download/f17752c1-307a-4531-bf52-f8a46388d35b?size=1

<img src="http://www.globenewswire.com/newsroom/ti?ndecode=MTUwIzY3MDU0Mzk=" alt="" width="1" height="1"/>



Register |  Password |  Feedback |  Copyright |  Usage Agreement |  Privacy Policy |  Advertising |  About Us |  Contact Us |  FAQ 

Past performance is not indicative of future results

StockSelector.com, the StockSelector.com logo, and News Selects are trademarks of StockSelector.com.
Copyright © 1998 - 2018 StockSelector.com. All rights reserved.