SOURCE: Venoco, Inc.

Venoco, Inc.

August 20, 2015 06:00 ET

Venoco, Inc. Announces 2nd Quarter 2015 Financial and Operational Results

DENVER, CO--(Marketwired - August 20, 2015) - Venoco, Inc. ("Venoco" or the "Company") today reported financial and operational results for the second quarter of 2015. The Company reported a net loss of $119.8 million for the quarter on total revenues of $19.9 million.

Adjusted losses, which adjusts for unrealized derivative gains and losses, and the recognition of an impairment of oil and gas properties, as well as certain other items, were $5.3 million for the quarter, compared to a $10.8 million loss in the first quarter of 2015. Adjusted EBITDA was $ 26.0 million in the second quarter of 2015, compared to $13.5 million in the first quarter. Please see the end of this release for definitions of Adjusted Earnings and Adjusted EBITDA and a reconciliation of those measures to net income/loss.

Highlights include the following:

  • Production of 416,000 barrels of oil equivalent (MBOE) for the quarter, or 4,554 BOE per day (BOE/d).
  • Lease operating expenses were $13.2 million for the quarter, down from $14.9 million during the first quarter of 2015 and $15.6 million during the second quarter of 2014, pro forma for asset sales.

"Although our production overall for the second quarter was materially impacted by the May 19 shut down of the South Ellwood field due to a third-party pipeline failure, production from our other assets remains strong. Production from our producing wells actually increased quarter over quarter without the support of any recent development projects. In addition, I am pleased to report that we remain vigilant on cost reduction and continued a trend of operating expense reductions quarter over quarter. This is quite impressive given that a significant portion of our expenses are fixed," said Mark DePuy, Venoco's CEO.

Second Quarter Production

Production in the second quarter of 2015 was 4,554 BOE/d compared to 6,016 BOE/d in the first quarter of 2015. Second quarter production was down 24% compared to the first quarter of 2015, primarily as a result of cessation of production on Platform Holly at the South Ellwood field following the May 19th, 2015 rupture of the common carrier pipeline that transports oil from the field. The pipeline is operated and owned by Plains All American Pipeline, L.P. ("Plains"). The company estimates that the pipeline rupture resulted in the loss of approximately 1,200-1,500 BOE/d for the quarter.

"Production was off to a very strong start for the year prior to the events in May," stated Mark DePuy, Venoco's CEO. "While it is disappointing that Platform Holly remains shut-in, looking across the portfolio, we're tracking above plan at many of our other fields, especially at Platform Gail. Between the pipeline failure and low commodities prices, we're faced with as stiff a headwind as I can recall," Mr. DePuy continued. "But we're resilient and sharply focused on managing the factors within our control. We maintain a strong hedging portfolio, and I am optimistic we can continue to control costs. Together, these will go a long way towards managing our liquidity and bottom-line."

"I am further encouraged that we've been able to achieve these milestones while maintaining outstanding operational commitment to the environment," Mr. DePuy added. "The events in May highlight the importance of operating safely, and I'm reminded that we're routinely recognized by local jurisdictions and the state of California for our commitment to the community, safety and the environment. It is a testament to the hard work, dedication, and professionalism of a great many employees that we continue in that tradition."

The following table details the Company's daily production by region (BOE(1)/d):

  Quarter Ended  Six Months Ended
Region 6/30/14 3/31/15 6/30/15  6/30/14 6/30/15
Southern California (Excl. W. Montalvo) 6,447 6,016 4,554  6,382 5,285
West Montalvo (2) 1,460 - -  1,459 -
Total 7,907 6,016 4,554  7,841 5,285
            
(1) Barrel of oil equivalent (BOE) is calculated using the ratio of six Mcf of natural gas to one barrel of crude oil, condensate or natural gas liquids.
(2) Relates to production from the West Montalvo asset which was sold in October, 2014.
 

Second Quarter Costs

Venoco's second quarter 2015 lease operating expenses of $31.75 per BOE were up compared to $27.55 per BOE in the first quarter of 2015, and $25.26 per BOE in the second quarter of 2014. Pro forma for the West Montalvo field sale, lease operating expenses were $26.55 per BOE in the second quarter of 2014.

Venoco's G&A costs, excluding non-cash share-based compensation, were $18.05 per BOE in the second quarter of 2015 compared to $12.24 per BOE in the first quarter of 2015 and $8.33 per BOE in the second quarter of 2014. When further adjusted to also exclude restructuring costs and production contributions from the West Montalvo field, second quarter 2015 G&A costs were $14.24 per BOE, compared to $8.68 per BOE in the first quarter of 2015, and $10.22 per BOE in the second quarter of 2014.

The following table details the Company's operating costs on a per BOE basis (BOE/d):

  Quarter Ended  Six Months Ended
UNAUDITED (per BOE) 6/30/14 3/31/15 6/30/15  6/30/14 6/30/15
Lease Operating Expenses $25.26 $27.55 $31.75  $26.53 $29.40
Property and Production Taxes  3.15  3.93  4.87   2.82  4.35
DD&A Expense  16.38  16.27  17.39   16.19  16.78
G&A Expense (1)  8.33  12.24  18.05   9.85  14.77
Adjusted G&A Expense (2)  10.22  8.68  14.24   12.10  11.10
                 
(1) Net of amounts capitalized and excluding non-cash share-based compensation costs. See the end of this release for a reconciliation of G&A per BOE.
(2) Net of amounts capitalized and excluding (i) non-cash share-based compensation costs, (ii) restructuring costs, and (iii) production contributions from sold assets. See the end of this release for a reconciliation of G&A per BOE.
 

Capital Investment Second Quarter 2015

Venoco's second quarter capital expenditures for exploration, development and other spending were $4.5 million, including $0.9 million on drilling and rework, which was primarily in preparation for an impending Sockeye development drilling program off Platform Gail, $0.6 million for facilities, and the remaining $3.0 million for land, seismic and capitalized G&A.

In the second quarter of 2015, the Company spent $3.7 million or 84% of its capital expenditures on its Southern California legacy fields, primarily on operational improvements, regulatory, health, safety and environmental compliance and progressing other long lead-time projects.

The Company also incurred onshore Monterey capital expenditures of $0.7 million or 16% of its total second quarter capital expenditures, primarily for land and capitalized G&A.

The Company began a drilling program at its Sockeye field in July of 2015, which is expected to continue into the fourth quarter of the year.

"After a fairly quiet start to the year, we've ramped up activity levels, in particular at our Sockeye field, where we recently spud the first well in a two-well program," Mr. DePuy commented. "This well was drilled into a zone we understand quite well and where we already have significant data. As expected, we've seen some excellent hydrocarbon shows, and we're encouraged it will be completed as a solid producer."

"The second well in our program targets the same producing reservoir but in a less developed section of the field," Mr. DePuy continued. "If successful, it could not only add new reserves but significantly improve our development drilling inventory."

About the Company

Venoco is an independent energy company primarily engaged in the acquisition, exploitation and development of oil and natural gas properties primarily in California. Venoco operates three offshore platforms in the Santa Barbara Channel, has non-operated interests in three other platforms and operates several onshore properties in Southern California.

Forward-looking Statements

Statements made in this news release relating to Venoco's future capital expenditures and development projects, anticipated results from new wells, future cost savings, and all other statements except statements of historical fact, are forward-looking statements. These statements are based on assumptions and estimates that management believes are reasonable based on currently available information; however, management's assumptions and the company's future performance are both subject to a wide range of business risks and uncertainties and there is no assurance that these goals and projections can or will be met. Any number of factors could cause actual results to differ materially from those in the forward-looking statements, including, but not limited to, the timing and extent of changes in oil and gas prices, the timing and results of drilling and other development activities, the availability and cost of obtaining drilling equipment and technical personnel, risks associated with the availability of acceptable transportation arrangements and the possibility of unanticipated operational problems, delays in completing production, treatment and transportation facilities, higher than expected production costs and other expenses, pipeline curtailments by third parties, and a potential inability to complete transactions as anticipated. The company's projects are subject to numerous operating, geological and other risks and may not be successful. All forward-looking statements are made only as of the date hereof and the company undertakes no obligation to update any such statement. Further information on risks and uncertainties that may affect the company's operations and financial performance, and the forward-looking statements made herein, is available in the company's filings with the Securities and Exchange Commission, which are incorporated by this reference as though fully set forth herein.

        
OIL AND NATURAL GAS PRODUCTION AND PRICES
 
   Quarter Ended   Quarter Ended   Six Months Ended  
UNAUDITED  3/31/15  6/30/15  % Change   6/30/14   6/30/15  % Change   6/30/14   6/30/15  % Change  
Production Volume:                                       
Oil (MBbls) (1)   515   396  -23 %  681    396  -42 %  1,336    911  -32 %
Natural Gas (MMcf)   160   118  -26 %  231    118  -49 %  500    278  -44 %
MBOE   542   416  -23 %  720    416  -42 %  1,419    957  -33 %
Daily Average Production Volume:                                       
Oil (Bbls/d)   5,718   4,337  -24 %  7,484    4,337  -42 %  7,381    5,028  -32 %
Natural Gas (Mcf/d)   1,785   1,303  -27 %  2,538    1,303  -49 %  2,762    1,544  -44 %
BOE/d   6,016   4,554  -24 %  7,907    4,554  -42 %  7,841    5,285  -33 %
Oil Price per Barrel Produced (in dollars):                                       
Realized price before hedging  $38.17  $49.50  30 % $95.63   $49.50  -48 % $95.10   $43.09  -55 %
Realized hedging gain (loss)   28.86   68.76  138 %  (6.65 )  68.76  -1134 %  (6.03 )  46.21  -866 %
Net realized price  $67.03  $118.26  76 % $88.98   $118.26  33 % $89.07   $89.30  0 %
Natural Gas Price per Mcf (in dollars):                                       
Realized price before hedging  $3.18  $3.04  -4 % $5.35   $3.04  -43 % $5.73   $3.12  -46 %
Realized hedging gain (loss)   -   -  0 %  -    -  0 %  -    -  0 %
Net realized price  $3.18  $3.04  -4 % $5.35   $3.04  -43 % $5.73   $3.12  -46 %
Expense per BOE (in dollars):                                       
Lease operating expenses  $27.55  $31.75  15 % $25.26   $31.75  26 % $26.53   $29.40  11 %
Production and property taxes  $3.93  $4.87  24 % $3.15   $4.87  55 % $2.82   $4.35  54 %
Transportation expenses  $0.09  $0.11  22 % $0.07   $0.11  57 % $0.07   $0.10  43 %
Depreciation, depletion and amortization  $16.27  $17.39  7 % $16.38   $17.39  6 % $16.19   $16.78  4 %
General and administrative (2)  $12.31  $16.92  37 % $12.49   $16.92  35 % $12.44   $14.32  15 %
Interest expense  $21.05  $47.90  128 % $18.54   $47.90  158 % $18.53   $32.75  77 %
                              
(1) Amounts shown are oil production volumes for offshore properties and sales volumes for onshore properties (differences between onshore production and sales volumes are minimal). Revenue accruals are adjusted for actual sales volumes since offshore oil inventories can vary significantly from month to month based on pipeline inventories, oil pipeline sales nominations.
(2) Net of amounts capitalized.
 
 
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

   Quarter Ended   Quarter Ended   Six Months Ended  
UNAUDITED (In thousands)  3/31/15   6/30/15   6/30/14   6/30/15   6/30/14  6/30/15  
REVENUES:                              
Oil and natural gas sales  $19,749   $19,317   $66,563   $19,317   $129,101  $39,066  
Other   669    553    476    553    935   1,222  
Total revenues   20,418    19,870    67,039    19,870    130,036   40,288  
EXPENSES:                              
Lease operating expense   14,932    13,206    18,185    13,206    37,653   28,138  
Property and production taxes   2,132    2,027    2,270    2,027    4,006   4,159  
Transportation expense   47    46    49    46    106   93  
Depletion, depreciation and amortization   8,821    7,234    11,794    7,234    22,970   16,055  
Impairment   -    146,030    817    146,030    817   146,030  
Accretion of asset retirement obligation   497    514    556    514    1,223   1,011  
General and administrative   6,670    7,037    8,990    7,037    17,652   13,707  
Total expenses   33,099    176,094    42,661    176,094    84,427   209,193  
Income from operations   (12,681 )  (156,224 )  24,378    (156,224 )  45,609   (168,905 )
FINANCING COSTS AND OTHER:                              
Interest expense   11,411    19,926    13,351    19,926    26,291   31,337  
Amortization of deferred loan costs   607    1,480    863    1,480    1,696   2,087  
Loss (gain) on extinguishment of debt   -    (67,515 )  -    (67,515 )  -   (67,515 )
Commodity derivative realized (gains) losses   (14,865 )  (27,228 )  4,530    (27,228 )  8,055   (42,093 )
Commodity derivative unrealized (gains) losses and amortization of derivative premiums   1,960    36,933    14,380    36,933    8,760   38,893  
Total financing costs and other   (887 )  (36,404 )  33,124    (36,404 )  44,802   (37,291 )
Income (loss) before taxes   (11,794 )  (119,820 )  (8,746 )  (119,820 )  807   (131,614 )
Income tax provision (benefit)   -    -    -    -    -   -  
Net income (loss)  $(11,794 ) $(119,820 ) $(8,746 ) $(119,820 ) $807  $(131,614 )
                        
 
CONDENSED CONSOLIDATED BALANCE SHEET INFORMATION

UNAUDITED ($ in thousands) 12/31/14   6/30/15  
ASSETS          
 Cash and cash equivalents $15,455   $114,009  
 Restricted Funds  -    79,595  
 Accounts receivable  14,912    9,039  
 Inventories  3,370    3,299  
 Other current assets  4,715    2,272  
 Commodity derivatives  48,298    30,545  
  Total current assets  86,750    238,759  
  Net property, plant and equipment  488,514    334,885  
  Total other assets  40,990    25,245  
TOTAL ASSETS $616,254   $598,889  
LIABILITIES AND STOCKHOLDERS' EQUITY          
 Accounts payable and accrued liabilities $20,535   $15,019  
 Interest payable  17,329    15,926  
 Share based compensation  2,236    176  
  Total current liabilities  40,100    31,121  
LONG-TERM DEBT  565,000    685,346  
ASSET RETIREMENT OBLIGATIONS  30,351    33,150  
SHARE BASED COMPENSATION  648    235  
  Total liabilities  636,099    749,852  
  Total stockholders' equity  (19,845 )  (150,963 )
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY $616,254   $598,889  
        

GAAP RECONCILIATIONS

Adjusted Earnings and Adjusted EBITDA

In addition to net income (loss) determined in accordance with GAAP, we have provided in this release our Adjusted Earnings and Adjusted EBITDA for recent periods. Both Adjusted Earnings and Adjusted EBITDA are non-GAAP financial measures that we use as supplemental measures of our performance.

We define Adjusted Earnings as net income (loss) before the effects of the items listed in the table below. We calculate the tax effect of reconciling items by re-performing our period-end tax calculation excluding the reconciling items from earnings. The difference between this calculation and the tax expense/benefit recorded for the period results in the tax effect disclosed below. We believe that Adjusted Earnings facilitates comparisons to earnings forecasts prepared by stock analysts and other third parties. Such forecasts generally exclude the effects of items that are difficult to predict or to measure in advance and are not directly related to our ongoing operations.

We define Adjusted EBITDA as net income (loss) before the effects of the items listed in the table below. Because the use of Adjusted EBITDA facilitates comparisons of our historical operating performance on a more consistent basis, we use this measure for business planning and analysis purposes, in assessing acquisition opportunities and in determining how potential external financing sources are likely to evaluate our business.

We present Adjusted Earnings and Adjusted EBITDA because we consider them to be important supplemental measures of our performance. Neither Adjusted Earnings nor Adjusted EBITDA is a measurement of our financial performance under GAAP and neither should be considered as an alternative to net income (loss), operating income or any other performance measure derived in accordance with GAAP, as an alternative to cash flow from operating activities or as a measure of our liquidity. You should not assume that the Adjusted Earnings or Adjusted EBITDA amounts shown are comparable to similarly named measures disclosed by other companies.

       
   Quarter Ended   Six Months Ended  
UNAUDITED ($ in thousands)  6/30/14   3/31/15   6/30/15   6/30/14  6/30/15  
Adjusted Earnings Reconciliation                         
Net Income  $(8,746 ) $(11,794 ) $(119,820 ) $807  $(131,614 )
Plus:                         
Unrealized commodity (gains) losses   13,176    1,044    36,017    6,352   37,062  
Impairment   -    -    146,030    -   146,030  
Loss (gain) on extinguishment of debt   -    -    (67,515 )  -   (67,515 )
Tax effects   -    -    -    -   -  
Adjusted Earnings  $4,430   $(10,750 ) $(5,288 ) $7,159  $(16,037 )
                    
       
   Quarter Ended   Six Months Ended  
UNAUDITED ($ in thousands)  6/30/14   3/31/15   6/30/15   6/30/14  6/30/15  
Adjusted EBITDA Reconciliation                         
Net income  $(8,746 ) $(11,794 ) $(119,820 ) $807  $(131,614 )
Interest expense   13,351    11,411    19,926    26,291   31,337  
DD&A   11,794    8,821    7,234    22,970   16,055  
Impairment   817    -    146,030    817   146,030  
Accretion of asset retirement obligation   556    497    514    1,223   1,011  
Amortization of deferred loan costs   863    607    1,480    1,696   2,087  
Loss (gain) on extinguishment of debt   -    -    (67,515 )  -   (67,515 )
Non-cash share-based compensation expense   16    60    (362 )  910   (302 )
Restructuring Costs   -    1,930    1,585    -   3,515  
One-time severance costs   3,024    -    -    3,024   -  
Amortization of derivative premiums   1,204    915    916    2,408   1,831  
Unrealized commodity derivative (gains) losses   13,176    1,044    36,017    6,352   37,062  
Adjusted EBITDA  $36,055   $13,491   $26,005   $66,498  $39,497  

We also provide per BOE G&A expenses excluding the items set forth in the table below. We believe that these non-GAAP measures are useful in that the items excluded do not represent cash expenses directly related to our ongoing operations. These non-GAAP measures should not be viewed as an alternative to per BOE G&A expenses as determined in accordance with GAAP.

       
UNAUDITED ($ in thousands, except per BOE amounts)  Quarter Ended   Six Months Ended  
   6/30/14   3/31/15   6/30/15   6/30/14   6/30/15  
G&A per BOE Reconciliation                          
                           
G&A expense  $8,990   $6,670   $7,037   $17,652   $13,707  
Less:                          
Non-cash share-based compensation expense   35    (38 )  470    (650 )  432  
One-Time Severance Costs   (3,024 )  -    -    (3,024 )  -  
G&A Expense Excluding Share-Based Comp and Severance Costs   6,001    6,632    7,507    13,978    14,139  
MBOE   720    542    416    1,419    957  
G&A Expense per BOE Excluding Share-Based Comp and Severance Costs  $8.33   $12.24   $18.05   $9.85   $14.77  
MBOE excluding production from sold assets   587    542    416    1,155    957  
G&A Expense per BOE Excluding Non-Cash Share-Based Comp -Excluding Production from Sold Assets  $10.22   $12.24   $18.05   $12.10   $14.77  
                           
G&A Expense Excluding Share-Based Comp and Severance Costs   6,001    6,632    7,507    13,978    14,139  
Less:                          
Restructuring Costs   -    (1,930 )  (1,585 )  -    (3,515 )
G&A Expense Excluding Share-Based Comp and Severance Costs and Restructuring Costs   6,001    4,702    5,922    13,978    10,624  
MBOE excluding production from sold assets   587    542    416    1,155    957  
G&A Expense per BOE Excluding Non-Cash Share-Based Comp and Restructuring Costs-Excluding Production from Sold Assets  $10.22   $8.68   $14.24   $12.10   $11.10  

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