EV Energy Partners Announces First Quarter 2016 Results

HOUSTON, May 10, 2016 (GLOBE NEWSWIRE) -- EV Energy Partners, L.P. (NASDAQ:EVEP) today announced results for the first quarter of 2016 and the filing of its Form 10-Q with the Securities and Exchange Commission.  In addition, EVEP provided an update of its commodity hedge positions.

First Quarter 2016 Results

Adjusted EBITDAX for the first quarter of 2016 was $20.2 million, a 62 percent decrease from the first and fourth quarters of 2015.  EVEP reported Distributable Cash Flow of $(1.2) million for the first quarter of 2016.  The decreases in Adjusted EBITDAX and Distributable Cash Flow were primarily attributable to lower realized commodity prices, lower realized hedge gains and the sale of midstream interests in the second quarter of 2015. The decreases were partially offset by the addition of producing properties acquired on October 1, 2015.  Adjusted EBITDAX and Distributable Cash Flow are Non-GAAP financial measures and are described in the attached table under “Non-GAAP Measures.”

Production for the first quarter of 2016 was 12.8 Bcf of natural gas, 317 Mbbls of oil and 602 Mbbls of natural gas liquids, or 201.4 million cubic feet equivalent per day (Mmcfe/day). This represents a 17 percent increase over first quarter 2015 production of 172.5 Mmcfe/day and a 4 percent decrease from fourth quarter 2016 production of 209.8 Mmcfe/day.  The increase over the first quarter 2015 was due to the addition of producing properties acquired on October 1, 2015.  The decrease from the fourth quarter 2015 is primarily due to the reduction in drilling activity.

EVEP reported a net loss of $29.0 million, or $(0.58) per basic and diluted weighted average limited partner unit outstanding, for the first quarter of 2016. Included in net loss were the following items:

  • $10.0 million of non-cash losses on commodity and interest rate derivatives,
  • $3.2 million of gain on settlement of contract,
  • $1.6 million of non-cash costs contained in general and administrative expenses,
  • $0.7 million of impairment charges related to the write down of certain oil and natural gas properties due to a change in the development plans for acreage in the Utica Shale, and
  • $0.1 million of dry hole and exploration costs.

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. For the first quarter of 2015, EVEP reported a net loss of $61.7 million, or $(1.25) per basic and diluted weighted average limited partner unit outstanding.

“Despite the challenging commodity price environment, production and operating costs for the first quarter were in line with our expectations, and we generated positive free cash flow after interest expense and capital expenditures.  At current strip prices, we expect free cash flow to increase for the remainder of the year as our actual quarterly capital expenditures are projected to decline from first quarter levels.  We plan to use free cash flow to further reduce debt. 

“Additionally, our recently announced $73 million Senior Notes repurchase reduces our annualized interest expense by $4.8 million.  These Senior Notes were purchased at an average price to par of 41.2 percent.  Currently, our total debt is $638 million, and we have over $170 million of liquidity between balance sheet cash and available borrowing base capacity," said Michael Mercer, President and CEO.

Additional Commodity Hedges

EVEP has recently entered into the following additional commodity hedges since its press release on April 4, 2016.  EVEP’s current hedge position, including these new hedges, is presented at the end of this press release under Total Hedge Position.

     Swap  Swap  Collar  Collar  Collar
Period Index  Volume  Price  Volume  Floor  Ceiling
Natural Gas (Mmmbtus)                  
May - Dec 2016 NYMEX  3,430  $2.28          
2017 NYMEX        10,950  $2.75  $3.27
Crude (Mbbls)                  
May - Sep 2016 WTI  153  $41.95          

Quarterly Report on Form 10-Q

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

Conference Call

As announced on April 27, 2016, EV Energy Partners, L.P. will host an investor conference call on May 10, 2016, at 9 a.m. Eastern Standard Time (8 a.m. Central).  Investors interested in participating in the call may dial 1-888-510-1765 (quote conference ID 4054817) 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 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 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 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 Securities and Exchange Commission.  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
March 31,
  2016 2015
Production data:    
Oil (Mbbls)  317   241 
Natural gas liquids (Mbbls)  602   582 
Natural gas (Mmcf)  12,818   10,588 
Net production (Mmcfe)  18,331   15,525 
Average sales price per unit: (1)    
Oil (Bbl) $29.12  $44.02 
Natural gas liquids (Bbl)  12.22   15.12 
Natural gas (Mcf)  1.65   2.55 
Mcfe  2.06   2.99 
Average unit cost per Mcfe:    
Production costs:    
Lease operating expenses $1.58  $1.52 
Production taxes  0.09   0.11 
Total  1.67   1.63 
Depreciation, depletion and amortization  1.54   1.67 
General and administrative expenses  0.46   0.80 
(1) Prior to $19.8 million and $31.4 million of net hedge gains on settlements of commodity derivatives for the three months ended March 31, 2016 and March 31, 2015, respectively.

Condensed Consolidated Balance Sheets     
(In $ thousands, except number of units)     
   March 31, 2016 December 31, 2015
Current assets:     
Cash and cash equivalents  $3,868  $20,415 
Accounts receivable:     
Oil, natural gas and natural gas liquids revenues   18,226   24,285 
Other   2,084   7,137 
Derivative asset   55,136   60,662 
Other current assets   3,112   3,057 
Total current assets   82,426   115,556 
Oil and natural gas properties, net of accumulated     
depreciation, depletion and amortization; March 31,     
2016, $999,704; December 31, 2015, $971,449   1,766,188   1,790,455 
Other property, net of accumulated depreciation     
and amortization; March 31, 2016, $978;     
December 31, 2015, $970   1,029   1,019 
Long–term derivative asset   8,096   10,741 
Other assets   5,644   5,831 
Total assets  $1,863,383  $1,923,602 
Current liabilities:     
Accounts payable and accrued liabilities:     
Third party  $45,118  $43,135 
Related party   6,526   5,952 
Income taxes   339   11,657 
Total current liabilities   51,983   60,744 
Asset retirement obligations   174,974   174,003 
Long–term debt   665,792   688,614 
Long–term derivative liability   1,820   - 
Other long–term liabilities   1,523   1,682 
Commitments and contingencies     
Owners’ equity:     
Common unitholders - 49,055,214 units and     
48,871,399 units issued and outstanding as of     
March 31, 2016 and December 31, 2015, respectively   980,864   1,011,509 
General partner interest   (13,573)  (12,950)
Total owners' equity   967,291   998,559 
Total liabilities and owners' equity  $1,863,383  $1,923,602 

Condensed Consolidated Statements of Operations    
(In $ thousands, except per unit data)    
  Three Months Ended 
March 31,
Oil, natural gas and natural gas liquids revenues $37,739  $46,425 
Transportation and marketing–related revenues  511   817 
Total revenues  38,250   47,242 
Operating costs and expenses:    
Lease operating expenses  28,915   23,524 
Cost of purchased natural gas  336   574 
Dry hole and exploration costs  130   414 
Production taxes  1,671   1,748 
Accretion expense on obligations  2,040   1,201 
Depreciation, depletion and amortization  28,205   25,896 
General and administrative expenses  8,378   12,415 
Impairment of oil and natural gas properties  687   58,173 
Gain on settlement of contract  (3,185)  - 
Gain on sales of oil and natural gas properties  -   (537)
Total operating costs and expenses  67,177   123,408 
Operating loss  (28,927)  (76,166)
Other (expense) income, net:    
Gain on derivatives, net  9,834   23,610 
Interest expense  (10,821)  (14,135)
Other income (expense), net  755   (196)
Total other (expense) income, net  (232)  9,279 
Loss from continuing operations before income taxes  (29,159)  (66,887)
Income taxes  159   150 
Loss from continuing operations  (29,000)  (66,737)
Income from discontinued operations  -   5,070 
Net loss $(29,000) $(61,667)
Basic and diluted earnings per limited partner unit:    
Loss from continuing operations $(0.58) $(1.35)
Income from discontinued operations  -  $0.10 
Net loss $(0.58) $(1.25)
Weighted average limited partner units outstanding (basic and diluted)  49,027   48,795 
Distributions declared per unit $-

Condensed Consolidated Statements of Cash Flows     
(In $ thousands)     
   Three Months Ended 
March 31,
Cash flows from operating activities:     
Net loss  $(29,000) $(61,667)
Adjustments to reconcile net loss to net cash flows provided by operating activities:     
Income from discontinued operations   -   (5,070)
Amortization of volumetric production payment liability   (1,020)  - 
Accretion expense on obligations   2,040   1,201 
Depreciation, depletion and amortization   28,205   25,896 
Equity–based compensation cost   1,600   4,952 
Impairment of oil and natural gas properties   687   58,173 
Gain on sales of oil and natural gas properties   -   (537)
Gain on derivatives, net   (9,834)  (23,610)
Cash settlements of matured derivative contracts   18,350   30,533 
Other   413   355 
Changes in operating assets and liabilities:     
Accounts receivable   10,909   9,151 
Other current assets   (178)  82 
Accounts payable and accrued liabilities   3,520   5,799 
Income taxes   (11,318)  - 
Other, net   (138)  - 
Net cash flows provided by operating activities   14,236   45,258 
Cash flows from investing activities:     
Additions to oil and natural gas properties   (7,828)  (25,577)
Proceeds from sale of oil and natural gas properties   2,420   774 
Cash settlements from acquired derivative contracts   1,475   - 
Other   18   18 
Net cash flows used in investing activities   (3,915)  (24,785)
Cash flows from financing activities:     
Repayment of long-term debt borrowings   (28,000)  - 
Long-term debt borrowings   5,000   10,000 
Loan costs incurred   -   (3,277)
Contributions from general partner   -   91 
Distributions paid   (3,868)  (25,274)
Net cash flows used in financing activities   (26,868)  (18,460)
(Decrease) increase in cash and cash equivalents   (16,547)  2,013 
Cash and cash equivalents – beginning of period   20,415   8,255 
Cash and cash equivalents – end of period  $3,868  $10,268 

Non GAAP Measures

We define Adjusted EBITDAX as net 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), gain on derivatives, net, cash settlements of matured derivative contracts, non-cash equity-based compensation, impairment of oil and natural gas properties,  non-cash inventory write down expense, dry hole and exploration costs, gain on sales of oil and natural gas properties, gain on settlement of contract, and loss on sale of investment in unconsolidated affiliates, contained in Other (expense) 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 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 Loss to Adjusted EBITDAX and Distributable Cash Flow
(In $ thousands)    
  Three Months Ended 
March 31,
   2016   2015  
Net loss $(29,000) $(61,667) 
Income from discontinued operations    -   (5,070) 
EBITDAX from discontinued operations    -   8,297  
Income taxes  (159)  (150) 
Interest expense, net  10,816   14,135  
Cash settlements of matured interest rate swaps    -   864  
Depreciation, depletion and amortization  28,205   25,896  
Accretion expense on obligations  2,040   1,201  
Amortization of VPP  (1,020)    -  
Gain on derivatives, net  (9,834)  (23,610) 
Cash settlements of matured derivative contracts  19,825   30,533  
Non-cash equity-based compensation  1,600   4,952  
Impairment of oil and natural gas properties  687   58,173  
Non-cash inventory write down expense  123   149  
Dry hole and exploration costs  130   414  
Gain on sales of oil and natural gas properties    -   (537) 
Gain on settlement of contract  (3,185)    -  
Loss on sale of investment in unconsolidated affiliates, contained in Other (expense) income, net    -   358  
Adjusted EBITDAX $20,228  $53,938  
Cash income taxes    -     -  
Cash interest expense, net  10,399   13,577  
Realized losses on interest rate swaps    -   864  
Estimated maintenance capital expenditures (1)  11,000   13,415  
Distributable Cash Flow $(1,171) $26,082  
(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 Hedge Position

EVEP’s total hedge position as of May 9, 2016, including the recent additional hedges mentioned above, is as follows:

   Swap  Swap  Collar  Collar  Collar
PeriodIndex Volume  Price  Volume  Floor  Ceiling
Natural Gas (Mmmbtus)                
Apr - Dec 2016NYMEX 33,405  $3.44          
2017NYMEX 32,850  $3.07  10,950  $2.75   $3.27
Crude (Mbbls)                
Apr 2016WTI 30  $90.14          
May - Sep 2016WTI 612  $53.75          
Oct - Dec 2016WTI 92  $90.14          
Ethane (Mbbls)                
Apr - Dec 2016Mt Belvieu 2.8  $9.14          

  Notional Amount Fixed Rate
Interest Rate Swap Agreements ($ mill)  
Jan 2017 - Dec 2017 100  1.039%
Jan 2018 - Sep 2020 100  1.795%


Contact Data