SOURCE: Venoco, Inc.

Venoco, Inc.

May 16, 2015 10:28 ET

Venoco, Inc. Announces First Quarter 2015 Financial and Operational Results

Net Loss of $11.8 Million and Adjusted EBITDA of $13.5 Million for the Quarter; Lease Operating Expenses Down 9% From the Fourth Quarter 2014

DENVER, CO--(Marketwired - May 16, 2015) - Venoco, Inc. ("Venoco", the "company", "we", or "us") today reported financial and operational results for the first quarter 2015. The company reported a net loss of $11.8 million for the quarter on total revenues of $20.4 million.

Adjusted losses, which adjusts for unrealized derivative gains and losses and certain other items, were $10.8 million for the quarter. Adjusted EBITDA was $13.5 million in the quarter, compared to $22.2 million in the fourth quarter of 2014. Realized oil price before hedging was down 38% from $61.37 per barrel in the fourth quarter of 2014 to $38.17 per barrel in the first quarter of 2015, while oil hedging gains increased 77% from $16.26 per barrel in the fourth quarter of 2014 to $28.86 per barrel in the first quarter of 2015. 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 542,000 barrels of oil equivalent (BOE) for the quarter, or 6,016 BOE per day (BOE/d).
  • Lease operating expenses were $14.9 million for the quarter, down from $15.9 million during the fourth quarter of 2014 and down from $16.6 million during the first quarter of 2014, pro forma for asset sales.

"Our focus for 2015 has been on production optimization and cost reduction, advancement of long-lead time projects, and continued efforts to improve our balance sheet," said Mark DePuy, Venoco's CEO. "I am pleased to say we have had a very busy and successful start to the year in all of those aspects despite continued downward pressure on commodities prices during the quarter. We've reacted quickly to the challenging market, have been able to realize meaningful lease operating expense reductions on an absolute basis, and have maintained relatively flat lease operating expenses on a per barrel of oil equivalent basis compared to last quarter, despite a limited capital program that did not involve drilling new wells."

"We'll look ahead in the coming quarters to continue executing on our production optimization-focused capital plan while also remaining focused on advancing our long-lead projects that will be critical towards achieving future growth," Mr. DePuy added. "We'll also continue working with our advisors to further evaluate organic and non-organic growth opportunities, and additional balance sheet optimization."

First Quarter Production

Production in the first quarter of 2015 was 6,016 BOE/d compared to 6,158 BOE/d in the fourth quarter of 2014 and 6,316 BOE/d in the first quarter of 2014, pro forma for the West Montalvo sale.

"Daily production has held relatively stable through the start of the year compared to the fourth quarter of last year, particularly at the South Ellwood field, which is encouraging as it appears field decline as a result of the downhole wellbore communication continues to moderate," Mr. DePuy said.

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

   
   Quarter Ended
Region  3/31/2014  12/31/2014  3/31/2015
Southern California (Excl. W. Montalvo)  6,316  6,158  6,016
West Montalvo  1,460  454  -
 Total  7,776  6,612  6,016
  
(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.
  

First Quarter Costs

Venoco's first quarter 2015 lease operating expenses were $27.55 per BOE compared to $ 27.07 per BOE in the fourth quarter of 2014, and $27.81 per BOE in the first quarter of 2014. Pro forma for the West Montalvo field sale, lease operating expenses were $28.07 per BOE in the fourth quarter of 2014 and $29.27 per BOE in the first quarter of 2014.

Venoco's first quarter 2015 G&A costs, excluding non-cash share-based compensation, was $12.24 per BOE, compared to $6.18 per BOE in the fourth quarter of 2014, and $11.40 per BOE in the first quarter of 2014. When further adjusted to also exclude restructuring costs and production contributions from the West Montalvo field, first quarter 2015 G&A costs were $8.68 per BOE, compared to $5.69 per BOE in the fourth quarter of 2014 and $14.07 per BOE in the first quarter of 2014.

   
   Quarter Ended
UNAUDITED (per BOE)  3/31/14  12/31/14  3/31/15
 Lease Operating Expenses  $27.81  $ 27.07  $27.55
 Property and Production         
Taxes  2.48  2.44  3.93
 DD&A Expense  15.97  15.35  16.27
 G&A Expense (1)  11.40  6.18  12.24
 Adjusted G&A Expense (2)  14.07  5.69  8.68
  
(1)Net of amounts capitalized and excluding non-cash share-based compensation costs and severance costs associated with property sales. 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 First Quarter 2015

Venoco's first quarter capital expenditures for exploration, development and other spending were $3.8 million, including $0.5 million for drilling and rework activities requiring long-lead preparation, $0.4 million for facilities, and the remaining $1.9 million for land, geological and geophysical studies, and capitalized G&A.

In the first quarter of 2015, the company spent $3.0 million or 79% 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.

For the first quarter of the year, the company spent $0.3 million and $0.6 million at the South Ellwood and Sockeye fields respectively. The expenditures relate primarily to operational and facilities improvements and on long lead-time projects. The company also continues to advance the environmental impact review process related to the South Ellwood lease line adjustment project.

The company also incurred onshore Monterey capital expenditures of $0.8 million, primarily for land and capitalized G&A.

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 onshore properties in Southern California.

Forward-looking Statements

Statements made in this news release relating to Venoco's future capital expenditures and development projects, and all other statements except statements of historical fact, are forward-looking statements. Forward-looking statements herein include those relating to future development and other opportunities and capital expenditure plans. 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
             %             %
UNAUDITED  12/31/14  3/31/15  Change  3/31/14   3/31/15  Change
Production Volume:                           
Oil (MBbls) (1)    578    515  -11%    655     515  -21%
Natural Gas (MMcf)    181    160  -12%    269     160  -41%
MBOE    608    542  -11%    700     542  -23%
Daily Average Production Volume:                           
Oil (Bbls/d)    6,283    5,719  -9%    7,278     5,719  -21%
Natural Gas (Mcf/d)    1,976    1,784  -10%    2,989     1,784  -40%
BOE/d    6,612    6,016  -9%    7,776     6,016  -23%
 
 
Oil Price per Barrel Produced (in dollars):                           
Realized price before hedging  $ 61.37  $ 38.17  -38%  $ 94.55   $ 38.17  -60%
Realized hedging gain (loss)    16.26    28.86  77%    (5.38 )   28.86  -636%
Net realized price  $ 77.63  $ 67.03  -14%  $ 89.17   $ 67.03  -25%
 
 
Natural Gas Price per Mcf (in dollars):                           
Realized price before hedging  $ 4.45  $ 3.18  -29%  $ 6.06   $ 3.18  -48%
Realized hedging gain (loss)    0.52    -  -100%    -     -  0%
Net realized price  $ 4.97  $ 3.18  -36%  $ 6.06   $ 3.18  -48%
Expense per BOE (in dollars):                           
Lease operating expenses  $ 27.07  $ 27.55  2%  $ 27.81   $ 27.55  -1%
Production and property taxes  $ 2.44  $ 3.93  61%  $ 2.48   $ 3.93  58%
Transportation expenses  $ 0.07  $ 0.09  29%  $ 0.08   $ 0.09  13%
 
Depreciation, depletion and amortization  $ 15.35  $ 16.27  6%  $ 15.97   $ 16.27  2%
General and administrative (2)  $ 1.52  $ 12.31  710%  $ 12.37   $ 12.31  0%
Interest expense  $ 20.86  $ 21.05  1%  $ 18.49   $ 21.05  14%
 
(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  
UNAUDITED (In thousands)  3/31/14   12/31/14   3/31/15  
REVENUES:                   
Oil and natural gas sales  $ 62,538   $ 35,709   $ 19,749  
Other    459     613     669  
Total revenues    62,997     36,322     20,418  
EXPENSES:                   
Lease operating expense    19,468     16,459     14,932  
Property and production taxes    1,736     1,481     2,132  
Transportation expense    57     44     47  
Depletion, depreciation and amortization    11,176     9,335     8,821  
Accretion of asset retirement obligation    667     639     497  
General and administrative    8,662     922     6,670  
Total expenses    41,766     28,880     33,099  
Income from operations    21,231     7,442     (12,681 )
FINANCING COSTS AND OTHER:                   
Interest expense    12,940     12,683     11,411  
Amortization of deferred loan costs    833     685     607  
Loss on extinguishment of debt    -     2,347     -  
Commodity derivative realized (gains) losses    3,525     (9,493 )   (14,865 )
Commodity derivative unrealized (gains) losses and                   
amortization of derivative premiums    (5,620 )   (78,885 )   1,960  
Total financing costs and other    11,678     (72,663 )   (887 )
Income (loss) before taxes    9,553     80,105     (11,794 )
Income tax provision (benefit)    -     -     -  
Net income (loss)  $ 9,553   $ 80,105   $ (11,794 )
             
             
  
CONDENSED CONSOLIDATED BALANCE SHEET INFORMATION 
  
UNAUDITED ($ in thousands)  12/31/14   3/31/15  
ASSETS             
 Cash and cash equivalents  $ 15,455   $ 7,921  
 Accounts receivable    14,912     12,307  
 Inventories    3,370     3,386  
 Other current assets    4,715     3,333  
 Commodity derivatives    48,298     49,484  
  Total current assets    86,750     76,431  
  Net property, plant and equipment    488,514     481,924  
  Total other assets    40,990     37,691  
TOTAL ASSETS  $ 616,254   $ 596,046  
   
LIABILITIES AND STOCKHOLDERS' EQUITY             
 Accounts payable and accrued liabilities  $ 20,535   $ 18,073  
 Interest payable    17,329     5,535  
 Commodity derivatives    -     -  
 Share based compensation    2,236     602  
  Total current liabilities    40,100     24,210  
LONG-TERM DEBT    565,000     571,400  
COMMODITY DERIVATIVES    -     -  
ASSET RETIREMENT OBLIGATIONS    30,351     30,848  
SHARE BASED COMPENSATION    648     731  
  Total liabilities    636,099     627,189  
  Total stockholders' equity    (19,845 )   (31,143 )
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY  $ 616,254   $ 596,046  
         
         
         
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. Adjusted Earnings should not be considered a substitute for net income (loss) as reported in accordance with GAAP.

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  
UNAUDITED ($ in thousands)  3/31/14   12/31/14   3/31/15  
Adjusted Earnings Reconciliation                  
Net Income  $ 9,553   $ 80,105   $(11,794 )
Plus:                  
Unrealized commodity (gains) losses    (6,824 )   (80,088 )  1,044  
One-Time Severance Costs    -     (208 )  -  
Loss on extinguishment of debt    -     2,347    -  
Tax effects    -     -    -  
Adjusted Earnings  $ 2,729   $ 2,156   $(10,750 )
             
             
   
   Quarter Ended  
UNAUDITED ($ in thousands)  3/31/14   12/31/14   3/31/15  
Adjusted EBITDA Reconciliation                   
Net income  $ 9,553   $ 80,105   $ (11,794 )
Interest expense    12,940     12,683     11,411  
DD&A    11,176     9,335     8,821  
Accretion of asset retirement obligation    667     639     497  
Amortization of deferred loan costs    833     685     607  
Loss on extinguishment of debt    -     2,347     -  
Non-cash share-based compensation expense    894     (5,051 )   60  
Restructuring costs    -     535     1,930  
One-time severance costs    -     (208 )   -  
Amortization of derivative premiums    1,204     1,203     915  
Unrealized commodity derivative (gains) losses    (6,824 )   (80,088 )   1,044  
Adjusted EBITDA  $ 30,443   $ 22,185   $ 13,491  
             
             
             

We also provide per BOE G&A expenses excluding certain costs 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
   3/31/14  12/31/14  3/31/15
G&A per BOE Reconciliation               
 
 
 G&A expense  $ 8,662  $ 922  $ 6,670
 Less:               
 G&A Non-cash share-based compensation expense    (685)    2,837    (38)
 G&A Expense Excluding Share-Based Comp and Severance Costs    7,977    3,759    6,632
 MBOE    700    608    542
G&A Expense per BOE Excluding Share-Based Comp and Severance Costs  $ 11.40  $ 6.18  $ 12.24
 
 MBOE excluding production from sold assets    567    566    542
G&A Expense per BOE Excluding Non-Cash Share-Based Comp -Excluding Production from Sold Assets  $ 14.07  $ 6.64  $ 12.24
 
 
 G&A Expense Excluding Share-Based Comp and Severance Costs    7,977    3,759    6,632
 Less:               
 Restructuring Costs    -    (535)    (1,930)
 G&A Expense Excluding Share-Based Comp and Severance Costs and Restructuring Costs
   7,977    3,224    4,702
 MBOE excluding production from sold assets    567    566    542
G&A Expense per BOE Excluding Non-Cash Share-Based Comp and Restructuring Costs-Excluding Production from Sold Assets  $ 14.07  $ 5.69  $ 8.68
          
          
          

PV-10

The present value of future net cash flows (PV-10 value) is a non-GAAP measure because it excludes income tax effects. Management believes that before-tax cash flow amounts are useful for evaluative purposes since future income taxes, which are affected by a company's unique tax position and strategies, can make after-tax amounts less comparable. We derive PV-10 value based on the present value of estimated future revenues to be generated from the production of proved reserves, net of estimated production and future development costs and future plugging and abandonment costs, using the arithmetic twelve-month average of the first of the month prices without giving effect to hedging activities or future escalation, and costs as of the date of estimate without future escalation, non-property related expenses such as general and administrative expenses, debt service, depreciation, depletion, amortization, impairment and income taxes, and discounted using an annual discount rate of 10%.

The following table reconciles the standardized measure of future net cash flows to PV-10 value (in thousands):

        
UNAUDITED ($ in thousands)  12/31/2012  12/31/2013  12/31/2014
 
 
Standardized measure of discounted future net cash flows  $ 1,157,452  $1,153,717  $ 696,043
 
Add: Present value of future income tax discounted at 10%    352,281   304,185    38,270
 
PV-10 at year end SEC prices  $ 1,509,733  $1,457,902  $ 734,313

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