Energy XXI Gulf Coast Announces Second Quarter 2018 Financial and Operational Results

HOUSTON, Aug. 09, 2018 (GLOBE NEWSWIRE) -- Energy XXI Gulf Coast, Inc. (“EGC” or the “Company”) (NASDAQ: EGC) today reported financial and operational results for the second quarter of 2018. 

Second Quarter 2018 Highlights and Recent Key Items:

  • Announced definitive agreement to be acquired by affiliates of Cox Oil LLC (“Cox”) for approximately $322 million, or $9.10 per fully diluted share
  • Produced an average of approximately 25,300 barrels of oil equivalent (“BOE”) per day, of which 83% was oil
  • Incurred a net loss of $34.0 million, or $1.02 per share, which included a $26.0 million loss on derivative financial instruments
  • Generated Adjusted EBITDA of $27.8 million
  • Initiated production from two successful development wells drilled in 2018 following the completion of the replaced pipeline at West Delta. The West Delta 74 C-41 ST01 Cato development well was brought online with initial production averaging approximately 600 BOE per day. The West Delta 73 C-27 ST02 McCloud development well is currently being brought online.
  • Currently drilling the South Timbalier 54 G-25 ST01 Koala well

For the second quarter of 2018, EGC reported a net loss of $34.0 million, or $1.02 loss per diluted share, which included a $26.0 million loss on derivative financial instruments. In the first quarter of 2018, the Company reported a net loss of $33.1 million, or $0.99 loss per diluted share, which included a $12.8 million loss on financial derivative instruments.

Adjusted EBITDA totaled $27.8 million for the second quarter 2018, compared to $13.6 million in the first quarter of 2018.

Adjusted EBITDA is a Non-GAAP financial measure and is described and reconciled to net loss in the attached table under “Reconciliation of Non-GAAP Measures.”

Douglas E. Brooks, President and Chief Executive Officer commented, “Strategically, we continue to advance the previously-announced merger with affiliates of Cox Oil LLC and we are pleased with the progress. Details on the transaction are in our proxy statement, which has been finalized and was distributed earlier this week. In the meantime, our focus is to continue to deliver results and maintain the value of our assets for all EGC stockholders. During the first half of the year we worked diligently to address the Company’s financial and operational challenges, while maintaining our commitment to safety.”

Production and Pricing
In the second quarter of 2018, the Company produced and sold approximately 25,300 net BOE per day, within its previously-provided guidance range of 24,500 to 26,000 BOE per day.  EGC continued to benefit from the impact of higher realized oil prices (before the effect of derivatives) that were about 2% higher than average WTI prices during the quarter due to the positive differentials that EGC receives on its oil sales.

                   
    Quarter Ended
    June 30,   March 31,   June 30, 
    2018   2018   2017
    (In thousands, except per unit amounts)
Sales volumes per day                  
Oil (MBbls)     21.1     21.1     26.8
Natural gas liquids (MBbls)     0.3     0.4     1.0
Natural gas (MMcf)     23.6     30.6     48.9
Total (MBOE)     25.3     26.6     35.9
Percent of sales volumes from oil     83%     79%     75%
                   
Average sales price before hedging impact                  
Oil per Bbl   $  69.54   $  65.09   $ 48.57
Natural gas liquid per Bbl      34.98      37.01      27.37
Natural gas per Mcf      2.92      3.04      3.09
                   

When compared with the first quarter of 2018, second quarter higher realized prices were offset by higher production downtime primarily related to continued production equipment maintenance, pipeline shut-ins, third-party operator downtime, EGC facility-related unscheduled downtime, and natural decline. In late July, EGC restored production through the previously-shut in pipeline at West Delta, bringing online the first two development wells of the 2018 drilling program. The Company continues to focus on preventative maintenance and production optimization in order to mitigate future downtime. 

Costs and Expenses
Total lease operating expenses (“LOE”) in the second quarter of 2018 were $79.3 million, or $34.42 per BOE, which consisted of $72.1 million in direct lease operating expense, $2.1 million in workovers and $5.2 million in insurance expense. Total LOE for the second quarter of 2017 was $83.7 million, or $25.60 per BOE, and in the first quarter of 2018 was $82.0 million, or $34.22 per BOE.  Lease operating expense decreased quarter-over-quarter due to implemented cost savings initiatives and lower weather-related costs than in previous quarters.

Gathering and Transportation (“G&T”) expense for the second quarter of 2018 totaled $3.1 million, or $1.35 per BOE, compared to $2.7 million, or $0.82 per BOE, in second quarter of 2017, and $4.1 million, or $1.69 per BOE, in the first quarter of 2018.  EGC did not receive any additional refunds from the Office of Natural Resources Revenue (“ONRR”) during the quarter. The decline in G&T expense in the second quarter of 2018 compared with the prior quarter was primarily due to timing of project spending.

Second quarter 2018 Pipeline Facility Fee expense was $10.5 million, or $4.55 per BOE, compared to $10.5 million, or $3.21 per BOE, in the second quarter of 2017 and $10.5 million, or $4.38 per BOE, in the first quarter of 2018.

General and administrative (“G&A”) expense in the second quarter of 2018 was $15.6 million, or $6.76 per BOE, which includes $4.0 million in transaction fees.  During the second quarter of 2017, G&A expense totaled $20.7 million, $6.34 per BOE, which included $2.5 million in severance and separation costs.   First quarter 2018 G&A expense totaled $15.1 million, or $6.31 per BOE. G&A includes non-cash compensation costs of $2.9 million, or $1.24 per BOE, in the second quarter 2018 compared with $2.9 million, or $0.89 per BOE, in the second quarter of 2017, and $2.8 million, or $1.15 per BOE, in the first quarter of 2018. 

Depreciation, depletion and amortization (“DD&A”) expense was $27.6 million, or $11.96 per BOE, compared to $38.7 million, or $11.84 per BOE, in the second quarter of 2017.  First quarter 2018 DD&A was $27.4 million, or $11.44 per BOE.

Accretion of asset retirement obligation was $11.2 million, or $4.86 per BOE, during the second quarter of 2018, compared to $10.0 million, or $3.06 per BOE, in the second quarter of 2017.  First quarter 2018 accretion of asset retirement obligation expense was $11.1 million, or $4.64 per BOE.

EGC recorded no income tax expense or benefit during the second quarter 2018 or during prior comparable periods.

Commodity Hedging
During the second quarter of 2018, with no cash outlay, EGC unwound 3,000 BOPD fixed price swap contracts benchmarked to NYMEX-WTI for the period of April 2018 to June 2018 and added 3,000 BOPD costless collars benchmarked to ICE Brent with a floor price of $60.00 and a ceiling price of $82.00 for the same period. In addition, the Company entered into a fixed price swap contract benchmarked to ICE Brent to hedge 3,000 BOPD for the period of January 2019 to December 2019 with a contract price of $61.00.  As of June 30, 2018, EGC had fixed price swap contracts benchmarked to NYMEX-WTI to hedge a total of 8,000 BOPD of production for the remainder of the 2018 with an average fixed price swap of $50.68.  EGC does not have any hedges in place on natural gas production.

Operational Update and Capital Expenditure Program
During the second quarter of 2018, the Company incurred capital costs totaling $45.5 million of which $25.8 million was related to drilling, development and recompletion activities, $14.6 million related to plugging and abandonment (“P&A”) and $5.1 million related to capitalized G&A and other. Capital expenditures for the first quarter of 2018 totaled $21.8 million, of which $4.1 million was spent on drilling, development and recompletion activities, $12.8 million on P&A and $4.9 million on capitalized G&A and other.

During the second quarter of 2018, EGC spud and successfully completed two development wells and one rig recompletion.  The West Delta 74 C-41 ST01 Cato development well was brought online with initial production averaging approximately 600 BOE per day.  The West Delta 73 C-27 ST02 McCloud development well is currently being brought online. After a recompletion in the West Delta field, the rig moved to the South Timbalier field where EGC is currently drilling the South Timbalier 54 G-25 ST01 Koala well, that will be drilled to a total depth of 14,080 feet.  EGC has a 100% working interest in all of the wells mentioned above.

Balance Sheet and Liquidity
At June 30, 2018, EGC had approximately $58.4 million in borrowings and $201.5 million in letters of credit issued under its Exit Credit Facility and remained in compliance with the financial covenants under that facility.  During the quarter, the Company made a prepayment of $5.5 million toward the balance of the Exit Term Loan portion of its credit facility.  Liquidity at June 30, 2018 totaled approximately $110 million, which consists of cash and cash equivalents totaling $97.9 million and $12.5 million in borrowing capacity available under certain conditions.

Merger of Energy XXI Gulf Coast, Inc. and affiliates of Cox Oil LLC (“Cox”)
As previously announced on June 18, 2018, the EGC Board of Directors unanimously approved a merger transaction with affiliates of Cox, an independent, privately-held entity that owns and operates assets in the Gulf of Mexico.  Pursuant to the terms of the merger agreement, Cox will acquire all the outstanding shares of EGC common stock for $9.10 per fully diluted share in cash, for a total consideration of approximately $322 million. This represents a 21% premium to EGC’s closing share price on June 15, 2018. EGC reached this agreement after evaluating multiple transactions.

The closing of the transaction is subject to customary conditions, including obtaining the required vote from EGC’s stockholders. Obtaining financing is not a closing condition under the Cox merger agreement. The special stockholder meeting to vote on the adoption of the Cox merger agreement has been scheduled for September 6, 2018, at 9:00 a.m. Houston time.  The transaction is anticipated to close in the third quarter of 2018.

Conference Call
Due to the pending merger transaction between EGC and Cox, the Company will not be hosting a conference call this quarter.  An updated investor presentation in conjunction with this earnings release is available on the Company’s website at www.energyxxi.com under the Investor Relations section.

Non-GAAP Measures
Adjusted EBITDA is a supplemental non-GAAP financial measure.  Adjusted EBITDA is not a measure of net income or cash flows as determined by United States Generally Accepted Accounting Principles (“U.S. GAAP”).  EGC believes that Adjusted EBITDA is useful because it allows EGC to more effectively evaluate its operating performance and compare the results of its operations from period to period without regard to its financing methods or capital structure. EGC excludes items such as asset retirement obligation accretion, unrealized derivative gains and losses, non-cash share-based compensation expense, non-cash deferred rent expense, severance expense and transaction costs from the calculation of Adjusted EBITDA. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income or cash flows from operating activities as determined in accordance with U.S. GAAP or as an indicator of its operating performance or liquidity. EGC’s computations of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies.

Cautionary Note Regarding Forward-Looking Statements

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995.  These forward-looking statements relate to the pending merger transaction with Cox, as well as to EGC’s financial and operating performance on a stand-alone basis prior to the consummation of the merger or if the merger is not consummated.  These statements, including those relating to the intent, beliefs, plans, or expectations of EGC are based upon current expectations and are subject to a number of risks, uncertainties, and assumptions that could cause actual results to differ materially from the projections, anticipated results or other expectations expressed.  It is not possible to predict or identify all such factors and the following lists of factors should not be considered a complete statement of all potential risks and uncertainties.

With respect to the pending merger transaction between EGC and Cox, those factors include, but are not limited to: (i) the risk that the transaction may not be completed in the third quarter of 2018 or at all, which may adversely affect EGC’s business and the price of EGC’s stock; (ii) the failure to satisfy the conditions to the consummation of the transaction, including the adoption of the merger agreement by the EGC’s stockholders; (iii) the occurrence of any event, change or other circumstance that could give rise to the termination of the merger agreement; (iv) the effect of the announcement or pendency of the transaction, as well as the merger agreement’s limitations on EGC’s conduct of business, on EGC’s business relationships, operating results, and business generally; (v) risks that the proposed transaction disrupts EGC’s current plans and operations; (vi) the possibility that competing offers or acquisition proposals for EGC will be made; (vii) risks regarding the failure to obtain the necessary financing to complete the proposed transaction; and (viii) lawsuits related to the pending merger.

With respect to EGC’s financial and operating performance on a stand-alone basis prior to the consummation of the merger or if the merger is not consummated, those factors include, but are not limited to: (i) our ability to maintain sufficient liquidity and/or obtain adequate additional financing necessary to (A) maintain our infrastructure, particularly in light of its maturity, high fixed costs, and required level of maintenance and repairs compared to other GoM Shelf producers, (B) fund our operations and capital expenditures, (C) execute our business plan, develop our proved undeveloped reserves within five years and (D) meet our other obligations, including plugging and abandonment and decommissioning obligations; (ii) disruption of operations and damages due to maintenance or repairs of infrastructure and equipment and our ability to predict or prevent excessive resulting production downtime within our mature field areas; (iii) our future financial condition, results of operations, revenues, expenses and cash flows; (iv) our current or future levels of indebtedness, liquidity, compliance with financial covenants and our ability to continue as a going concern; (v) recent changes in the composition of our board of directors; (vi) our inability to retain and attract key personnel; (vii) our ability to post collateral for current or future bonds or comply with any new regulations or Notices to Lessees and Operators imposed by the Bureau of Ocean Energy Management; (viii) our ability to comply with covenants under the three-year secured credit facility; and (ix) sustained declines in the prices we receive for our oil and natural gas production.

These risks and uncertainties could cause actual results, to differ materially from those described in the forward-looking statements. For a more detailed discussion of risk factors, please see the risk factors discussed in EGC’s periodic reports filed with the SEC. While EGC makes these statements and projections in good faith, EGC assumes no obligation and expressly disclaims any duty to update the information contained herein except as required by law.

About the Company

Energy XXI Gulf Coast, Inc. (EGC) is an exploration and production company headquartered in Houston, Texas that is engaged in the development, exploitation and acquisition of oil and natural gas properties in conventional assets in the U.S. Gulf Coast region, both offshore in the Gulf of Mexico and onshore in Louisiana and Texas.  To learn more, visit EGC’s website at www.energyxxi.com.

Investor Relations Contact
Al Petrie
Investor Relations Coordinator
713-351-3171
apetrie@energyxxi.com

Argelia Hernandez
Investor Relations Specialist
713-351-3175
ahernandez@energyxxi.com



ENERGY XXI GULF COAST, INC.
CONSOLIDATED BALANCE SHEETS
(In Thousands, except share information)

  June 30,   December 31, 
  2018    2017 
ASSETS (Unaudited)      
Current Assets          
Cash and cash equivalents $  97,900     $  151,729  
Accounts receivable          
Oil and natural gas sales    55,413        55,598  
Joint interest billings, net    4,004        6,336  
Other    19,920        15,726  
Prepaid expenses and other current assets    11,873        21,602  
Restricted cash    6,432        6,392  
Total Current Assets    195,542        257,383  
Property and Equipment          
Oil and natural gas properties, net - full cost method of accounting, including $192.3 million and $200.2 million of unevaluated properties not being amortized at June 30, 2018 and December 31, 2017, respectively    773,153        764,922  
Other property and equipment, net    8,269        10,120  
Total Property and Equipment, net of accumulated depreciation, depletion, amortization and impairment    781,422        775,042  
Other Assets          
Restricted cash    25,814        25,712  
Other assets    29,468        18,845  
Total Other Assets    55,282        44,557  
Total Assets $  1,032,246     $  1,076,982  
LIABILITIES AND STOCKHOLDERS' EQUITY          
Current Liabilities          
Accounts payable $  79,154     $  85,122  
Accrued liabilities    52,111        45,494  
Asset retirement obligations    55,952        51,398  
Derivative financial instruments    36,793        32,567  
Current maturities of long-term debt    17        21  
Total Current Liabilities    224,027        214,602  
Long-term debt, less current maturities    58,413        73,952  
Asset retirement obligations    625,496        613,453  
Derivative financial instruments    6,305        -  
Other liabilities    14,932        10,783  
Total Liabilities    929,173        912,790  
Commitments and Contingencies          
Stockholders’ Equity          
Preferred stock, $0.01 par value, 10,000,000 shares authorized and no shares outstanding at June 30, 2018 and December 31, 2017    -        -  
Common stock, $0.01 par value, 100,000,000 shares authorized and 33,396,563 and 33,254,963 shares issued and outstanding at June 30, 2018 and December 31, 2017, respectively    334        333  
Additional paid-in capital    916,525        911,144  
Accumulated deficit    (813,786 )      (747,285 )
Total Stockholders’ Equity    103,073        164,192  
Total Liabilities and Stockholders’ Equity $  1,032,246     $  1,076,982  
 



ENERGY XXI GULF COAST, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
(In Thousands, except per share information)
(Unaudited)

  Three Months Ended   Three Months Ended   Three Months Ended
  June 30,   March 31,   June 30,
  2018   2018   2017
Revenues                
Oil sales $  133,180     $  123,788     $  118,484  
Natural gas liquids sales    1,076        1,343        2,370  
Natural gas sales    6,261        8,382        13,753  
Other revenue    2,267        1,492        -  
Gain (loss) on derivative financial instruments    (26,045 )      (12,834 )      9,412  
Total Revenues    116,739        122,171        144,019  
Costs and Expenses                
Lease operating    79,296        82,022        83,655  
Production taxes    371        1,206        482  
Gathering and transportation    3,119        4,056        2,678  
Pipeline facility fee    10,494        10,494        10,494  
Depreciation, depletion and amortization    27,555        27,411        38,685  
Accretion of asset retirement obligations    11,197        11,118        9,984  
General and administrative expense    15,568        15,132        20,716  
Reorganization items    113        236        -  
Total Costs and Expenses    147,713        151,675        166,694  
Operating Loss    (30,974 )      (29,504 )      (22,675 )
                 
Other Income (Expense)                
Other income, net    191        143        80  
Interest expense    (3,252 )      (3,694 )      (3,642 )
Total Other Expense, net    (3,061 )      (3,551 )      (3,562 )
Loss Before Income Taxes    (34,035 )      (33,055 )      (26,237 )
Income Tax Benefit    -        -        -  
Net Loss $  (34,035 )   $  (33,055 )   $  (26,237 )
                 
Loss per Share                
Basic and Diluted $  (1.02 )   $  (0.99 )   $  (0.79 )
                 
Weighted Average Number of Common Shares Outstanding                
Basic and Diluted    33,427        33,296        33,237  
                       



ENERGY XXI GULF COAST, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In Thousands)
(Unaudited)

  Three Months Ended   Three Months Ended   Three Months Ended
  June 30,   March 31,   June 30,
  2018   2018   2017
Cash Flows From Operating Activities                
Net loss $  (34,035 )   $  (33,055 )   $  (26,237 )
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:                
Depreciation, depletion and amortization    27,555        27,411        38,685  
Change in fair value of derivative financial instruments    10,744        (213 )      (7,061 )
Accretion of asset retirement obligations    11,197        11,118        9,984  
Amortization and write off of debt issuance costs and other    6        5        6  
Deferred rent    2,239        1,930        2,016  
Provision for loss on accounts receivable    -        -        300  
Stock-based compensation    2,859        2,758        2,870  
Changes in operating assets and liabilities                
Accounts receivable    (3,621 )      1,944        11,849  
Prepaid expenses and other assets    (4,888 )      3,680        4,165  
Settlement of asset retirement obligations    (15,913 )      (18,804 )      (18,175 )
Accounts payable, accrued liabilities and other    14,427        (13,574 )      6,834  
Net Cash Provided by (Used in) Operating Activities    13,631        (13,238 )      28,798  
Cash Flows from Investing Activities                
Capital expenditures    (18,977 )      (12,977 )      (5,391 )
Insurance payments received    -        -        (2,010 )
Proceeds from the sale of other property and equipment    38        250        10  
Net Cash Used in Investing Activities    (18,939 )      (12,727 )      (7,391 )
Cash Flows from Financing Activities                
Payments on long-term debt    (5,554 )      (10,002 )      (126 )
Other    (160 )      (75 )      (61 )
Net Cash Used in Financing Activities    (5,714 )      (10,077 )      (187 )
Net Increase (Decrease) in Cash and Cash Equivalents    (11,022 )      (36,042 )      21,220  
Cash, Cash Equivalents and Restricted Cash, beginning of period    144,229        183,833        193,199  
Cash, Cash Equivalents and Restricted Cash, end of period $  133,207     $  147,791     $  214,419  



ENERGY XXI GULF COAST, INC.
RECONCILIATION OF NON-GAAP MEASURES
(In Thousands, except per share information)
(Unaudited)

  Three Months Ended   Three Months Ended   Three Months Ended
  June 30,   March 31,   June 30,
  2018   2018   2017
                 
Net loss $  (34,035 )   $  (33,055 )   $  (26,237 )
Interest expense    3,252        3,694        3,642  
Depreciation, depletion and amortization    27,555        27,411        38,685  
Accretion of asset retirement obligations    11,197        11,118        9,984  
Change in fair value of derivative financial instruments    10,744        (213 )      (7,061 )
Non-cash stock-based compensation    2,859        2,758        2,870  
Deferred rent(1)    2,239        1,930        2,016  
Severance costs    -        -        2,500  
Transaction costs    3,961        -        -  
Adjusted EBITDA $  27,772     $  13,643     $  26,399  
  1. The deferred rent of approximately $2.2 million, $1.9 million and $2.0 million for the three months ended June 30, 2018, March 31, 2018 and June 30, 2017, respectively, is the non-cash portion of rent which reflects the extent to which our GAAP straight-line rent expense recognized exceeds our cash rent payments.
     

Operational Information

    Quarter Ended
      June 30,       March 31,       June 30,  
Operating Highlights     2018       2018       2017  
    (In thousands, except per unit amounts)
Operating revenues                  
Oil sales   $  133,180     $  123,788     $  118,484  
Natural gas liquids sales      1,076        1,343        2,370  
Natural gas sales      6,261        8,382        13,753  
Other revenue      2,267        1,492        -  
Gain (loss) on derivative financial instruments      (26,045 )      (12,834 )      9,412  
Total revenues      116,739        122,171        144,019  
Percentage of oil revenues prior to gain (loss) on derivative financial instruments     93%       92%       88%  
Operating expenses                  
Lease operating expense                  
Insurance expense      5,177        5,195        7,101  
Workovers      2,054        2,524        4,535  
Direct lease operating expense      72,065        74,303        72,019  
Total lease operating expense      79,296        82,022        83,655  
Production taxes      371        1,206        482  
Gathering and transportation      3,119        4,056        2,678  
Pipeline facility fee      10,494        10,494        10,494  
Depreciation, depletion and amortization      27,555        27,411        38,685  
Accretion of asset retirement obligations      11,197        11,118        9,984  
Impairment of oil and natural gas properties      -        -        -  
Goodwill impairment      -        -        -  
General and administrative      15,568        15,132        20,716  
Reorganization items      113        236        -  
Total operating expenses      147,713        151,675        166,694  
Operating loss   $  (30,974 )   $  (29,504 )   $  (22,675 )
Sales volumes per day                  
Oil (MBbls)     21.1       21.1       26.8  
Natural gas liquids (MBbls)     0.3       0.4       1.0  
Natural gas (MMcf)     23.6       30.6       48.9  
Total (MBOE)     25.3       26.6       35.9  
Percent of sales volumes from oil     83%       79%       75%  
Average sales price                  
Oil per Bbl   $  69.54     $  65.09     $  48.57  
Natural gas liquid per Bbl      34.98        37.01        27.37  
Natural gas per Mcf      2.92        3.04        3.09  
Other revenue per BOE      0.98        0.62        -  
(Loss) gain on derivative financial instruments per BOE      (11.30 )      (5.35 )      2.88  
Total revenues per BOE      50.67        50.97        44.08  
Operating expenses per BOE                  
Lease operating expense                  
Insurance expense      2.25        2.17        2.17  
Workovers      0.89        1.05        1.39  
Direct lease operating expense      31.28        31.00        22.04  
Total lease operating expense per BOE      34.42        34.22        25.60  
Production taxes      0.16        0.50        0.15  
Gathering and transportation      1.35        1.69        0.82  
Pipeline facility fee      4.55        4.38        3.21  
Depreciation, depletion and amortization      11.96        11.44        11.84  
Accretion of asset retirement obligations      4.86        4.64        3.06  
General and administrative      6.76        6.31        6.34  
Reorganization items      0.05        0.10        -  
Total operating expenses per BOE      64.11        63.28        51.02  
Operating loss per BOE   $  (13.44 )   $  (12.31 )   $  (6.94 )

 

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Source: Energy XXI Gulf Coast