May 22, 2017 - 6:45 AM EDT
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Energy XXI Gulf Coast Announces First Quarter 2017 Results

HOUSTON, May 22, 2017 (GLOBE NEWSWIRE) -- Energy XXI Gulf Coast, Inc. (“EGC” or the “Company”) (NASDAQ:EXXI) today reported operational and financial results for the first quarter of 2017.

First Quarter 2017 Highlights and Recent Key Items:

  • Produced an average of approximately 41,000 barrels of oil equivalent (“BOE”) per day in the first quarter of 2017, of which 71% was oil
  • Reported strong cash and cash equivalents of $160.5 million at March 31, 2017
  • Reestablished a commodity hedging program in February 2017 by entering into costless collars for 10,000 barrels of oil per day from March 2017 to December 2017
  • Commenced trading on the NASDAQ Global Select Market on February 28, 2017
  • Contracted a rig to begin development drilling program, spudding first well in early June
  • Retained Morgan Stanley to assist with the evaluation of strategic alternatives

For the first quarter of 2017, EGC reported a net loss of $65.3 million, or ($1.97) per diluted share while Adjusted EBITDA totaled $42.6 million. The first quarter loss includes a non-cash ceiling test impairment charge of $44.1 million primarily related to the decrease in SEC proved reserves and the present value of those SEC proved reserves discounted at 10% (“PV-10 Value”) relative to the estimated reserves prepared by EGC’s internal reservoir engineers as of year-end 2016.  EGC recently received the final results of its independently engineered reserves report prepared by Netherland Sewell and Associates as of March 31, 2017.  

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, EGC’s Chief Executive Officer and President commented, “Our first quarter results demonstrate our continued focus on the base business which generated $42.6 million of Adjusted EBITDA. After over a year of minimal capital spending on drilling projects, we will soon spud our first development well in 2017 and remain confident in our strong, oil-weighted asset base. While we continue to develop our long-term strategic plan, our near-term commitment to HSE excellence, minimizing base production decline and reducing operating and overhead expenses remains unchanged. Through the effective execution of this commitment, EGC will look to add value in a recovering price environment.”

Revenue, Production and Pricing

Total revenues for the first quarter of 2017 were $157.9 million, which includes a $3.7 million gain on derivative financial instruments.

During the first quarter of 2017, EGC produced and sold approximately 41,000 net BOE per day which was comprised of 29,100 barrels of oil (“BBL”) at an average realized price of $51.04 per BBL (before the effect of derivatives), 900 barrels of natural gas liquids (NGL’s) at an average realized price of $27.52 per BBL, and 65.9 million cubic feet of gas (“MMCF”) at an average realized price of $3.10 per thousand cubic feet (“MCF”).  EGC operates approximately 90% of its reserves, substantially all of which are located in the U.S. Gulf of Mexico.

First Quarter 2017 Costs and Expenses

Total lease operating expenses (“LOE”) were $75.2 million, or $20.39 per BOE, which consisted of $58.9 million in direct lease operating expense, $10 million in workover and maintenance and $6.3 million in insurance expense. The Company continues to evaluate additional cost saving opportunities that will not impact health, safety or operational integrity. EGC successfully completed over 100 expense workover and maintenance projects during the quarter.

Gathering and Transportation expense was $21.7 million, or $5.89 per BOE for the first quarter of 2017 and included increased commodity marketing deductions, inclusion of gathering and transportation expenses that were historically included in lease operating expenses of $5.1 million and expenses incurred on pipeline storage facility repairs of approximately $2.4 million.

General and administrative (“G&A”) expense was $23.8 million, or $6.47 per BOE. While the Company has taken significant steps to reduce overall G&A costs over the past 12 months, with decreases in personnel costs, the first quarter of 2017 included additional costs related to severance and restructuring costs totaling approximately $6.2 million. General and administrative expense includes $0.9 million of non-cash expense primarily related to stock based compensation.

Depreciation, depletion and amortization (“DD&A”) expense was $42.0 million, or $11.39 per BOE.  As discussed previously, there was a ceiling test impairment charge of $44.1 million during the quarter.

Accretion of asset retirement obligation was $12.4 million. In conjunction with the adoption of fresh start accounting, the discount rate used for ARO decreased to 6.5%.

EGC recorded no income tax expense or benefit during the quarter due to its inability to currently record any additional net deferred tax assets.

Commodity Hedging 

EGC did not have any commodity hedges in place prior to February 2017 when it entered into oil contracts (costless collars) benchmarked to Argus-LLS, to hedge 10,000 barrels of oil per day of production for the period from March 2017 to December 2017 with an average floor price of $52.30 and an average ceiling price of $57.43 per barrel. The Company does not have any hedges in place on natural gas production.  No additional hedges have been put in place since February but EGC expects to consider additional derivative arrangements in the future.

Capital Expenditure Program

During the three months ended March 31, 2017, the Company incurred capital costs, excluding acquisitions but including abandonment activities, totaling $19.4 million.  The Company did not drill any new wells during that period, but did incur capital expenditures for the successful execution of several well recompletions and facility improvements in the Company’s core properties.  EGC spent approximately $9.3 million related to abandonment activities.

The Company recently contracted a rig to drill its first 2017 development well beginning in early June. EGC continues to expect its capital expenditure program for 2017 to be in the range of $140 to $170 million, including $50 to $70 million for abandonment activities.  The 2017 capital program is expected to be fully funded with available cash and internal cash flow.

Balance Sheet and Liquidity

The Company’s estimate of its asset retirement obligations was revised downward by $135.4 million during the three months ended March 31, 2017, primarily due to changes in estimated timing of settlements for its plugging and abandonment liabilities. Asset retirement obligations totaled $623 million at the end of the first quarter 2017.

As of March 31, 2017, EGC had $74 million drawn on its three-year secured credit facility, the same amount drawn as of year-end 2016.  At year-end 2016, the remaining $228 million under the $302 million facility was utilized to maintain outstanding letters of credit, primarily in favor of ExxonMobil to secure certain abandonment obligations.  On March 10, 2017, the letters of credit issued in favor of ExxonMobil were reduced to $200 million.  Under the terms of the credit facility, the commitments under the facility were permanently reduced by $12.5 million to $289.5 million.

At March 31, 2017, liquidity totaled $173 million which is comprised of cash and cash equivalents totaling $160.5 million and $12.5 million available for borrowing under its three-year credit facility.

Conference Call

As previously announced, the Company will hold a conference call to discuss its first quarter financial and operating results this morning, Monday, May 22, 2017, at 10:00 a.m. Central Time (11:00 a.m. Eastern Time). Interested parties may participate by dialing (877) 794-3620.  International parties may dial (631) 813-4724.  The confirmation code is 22507001.  This call will also be webcast on EGC’s website at A replay of the call will be archived and available on the web site shortly after the live call.     

Fresh Start Accounting

Upon emergence from the Company’s Chapter 11 restructuring, EGC elected to adopt fresh start accounting as of December 31, 2016. As a result of the application of fresh start accounting and the effects of the implementation of the plan of reorganization, the financial statements on or after December 31, 2016 are not comparable with the financial statements prior to that date. References to “Successor” refer to the reorganized EGC subsequent to the adoption of fresh start accounting. References to “Predecessor” refer to Energy XXI Ltd. prior to the adoption of fresh start accounting.

Non-GAAP Measures

The Company refers to “PV-10” as the present value of estimated future net revenues of estimated proved reserves using a discount rate of 10%. This amount includes projected revenues less estimated production costs, abandonment costs and development costs but does not include effects, if any, of income taxes, which is included in standardized measure of discounted future net cash flows, which is the most directly comparable U.S. GAAP financial measure. PV-10 is not a financial measure prescribed under accounting principles generally accepted in the U.S. (“U.S. GAAP”). Management believes that the non-U.S. GAAP financial measure of PV-10 is relevant and useful for evaluating the relative monetary significance of oil and natural gas properties. PV-10 is used internally when assessing the potential return on investment related to oil and natural gas properties and in evaluating acquisition opportunities. EGC believes the use of this pre-tax measure is valuable because there are unique factors that can impact an individual company when estimating the amount of future income taxes to be paid. Management believes that the presentation of PV-10 provides useful information to investors because it is widely used by professional analysts and sophisticated investors in evaluating oil and natural gas companies. PV-10 is not a measure of financial or operating performance under U.S. GAAP, nor is it intended to represent the current market value of our estimated oil and natural gas reserves. PV-10 should not be considered in isolation or as a substitute for the standardized measure of discounted future net cash flows as defined under U.S. GAAP.

Adjusted EBITDA is a supplemental non‑GAAP financial.  Adjusted EBITDA is not a measure of net income or cash flows as determined by United States generally accepted accounting principles, or US GAAP. EGC believes that Adjusted EBITDA is useful because it allows it 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 property and inventory impairments, asset retirement obligation accretion, unrealized derivative gains and losses, non‑cash share‑based compensation expense, non-cash deferred rent expense and restructuring and severance expense. 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 US 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 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. It is not possible to predict or identify all such factors and the following list should not be considered a complete statement of all potential risks and uncertainties relating to emergence from Chapter 11, the recent change in EGC’s senior management team, or EGC’s oil and gas reserves, including, but not limited to: (i) the PV-10 and reserve volumes reported in the final NSAI reserve report, (ii) the level of potential upside actually realized by EGC from its non-proved resource base, (iii) the effects of the departure of EGC’s senior leaders on the Company’s employees, suppliers, regulators and business counterparties, (iv) the impact of restrictions in the exit financing on EGC’s ability to make capital investments and pursue strategic growth opportunities and (v) other risks and uncertainties. These risks and uncertainties could cause actual results, including project plans and related expenditures and resource recoveries, to differ materially from those described in the forward-looking statements. For a more detailed discussion of risk factors, please see Part I, Item 1A, “Risk Factors” of the Transition Report on Form 10-K for the transition period ended December 31, 2016 filed by EGC for more information.  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. is an independent oil and natural gas development and production company whose assets are primarily located in the U.S. Gulf of Mexico waters offshore Louisiana and Texas.  The Company’s near-term strategy emphasizes exploitation of key assets, enhanced by its focus on financial discipline and operational excellence. To learn more, visit EGC’s website at   

(In Thousands, except share information)
 March 31, December 31,
ASSETS (Unaudited)   
Current Assets     
Cash and cash equivalents$160,479  $165,368 
Accounts receivable     
Oil and natural gas sales 67,952   68,143 
Joint interest billings, net 5,687   5,600 
Other 2,321   17,944 
Prepaid expenses and other current assets 21,449   25,957 
Restricted cash 7,114   32,337 
Derivative financial instruments 3,409   - 
Total Current Assets 268,411   315,349 
Property and Equipment     
Oil and natural gas properties, net - full cost method of accounting, including $283.9 million and $376.1 million of unevaluated properties not being amortized at March 31, 2017 and December 31, 2016, respectively 893,360   1,097,479 
Other property and equipment, net 16,277   18,807 
Total Property and Equipment, net of accumulated depreciation, depletion, amortization and impairment 909,637   1,116,286 
Other Assets     
Restricted cash 25,606   25,583 
Other assets 25,681   28,244 
Total Other Assets 51,287   53,827 
Total Assets$1,229,335  $1,485,462 
Current Liabilities     
Accounts payable$70,706  $101,117 
Accrued liabilities 33,827   63,660 
Asset retirement obligations 73,073   56,601 
Current maturities of long-term debt 3,616   4,268 
Total Current Liabilities 181,222   225,646 
Long-term debt, less current maturities 73,996   74,229 
Asset retirement obligations 549,938   696,763 
Other liabilities 14,299   14,481 
Total Liabilities 819,455   1,011,119 
Stockholders’ Equity      
Preferred stock, $0.01 par value, 10,000,000 shares authorized and no shares outstanding at March 31, 2017 and December 31, 2016 -   - 
Common stock, $0.01 par value, 100,000,000 shares authorized and 33,211,594 shares     
issued and outstanding at March 31, 2017 and December 31, 2016 332   332 
Additional paid-in capital 881,138   880,286 
Accumulated deficit (471,590)  (406,275)
Total Stockholders’ Equity 409,880   474,343 
Total Liabilities and Stockholders’ Equity$1,229,335  $1,485,462 

(In Thousands, except per share information)
 Successor   Predecessor
 Three Months    Three Months
 Ended   Ended
 March 31,    March 31,
Oil sales$133,621    $92,192 
Natural gas liquids sales 2,227     2,889 
Natural gas sales 18,368     14,430 
Gain on derivative financial instruments 3,698     6,774 
Total Revenues 157,914     116,285 
Costs and Expenses       
Lease operating 75,157     82,044 
Production taxes 239     221 
Gathering and transportation 21,716     14,155 
Depreciation, depletion and amortization 42,006     53,847 
Accretion of asset retirement obligations 12,397     15,057 
Impairment of oil and natural gas properties 44,054     340,469 
General and administrative expense 23,848     28,358 
Total Costs and Expenses 219,417     534,151 
Operating Loss (61,503)    (417,866)
Other (Expense) Income       
Other income, net 22     388 
Gain on early extinguishment of debt -     777,022 
Interest expense (3,834)    (198,768)
Total Other (Expense) Income , net (3,812)    578,642 
(Loss) Income Before Income Taxes (65,315)    160,776 
Income Tax Expense (Benefit) -     - 
Net (Loss) Income (65,315)    160,776 
Preferred Stock Dividends -     2,378 
Net (Loss) Income Attributable to Common Stockholders$(65,315)   $158,398 
(Loss) Income per Share       
Basic$(1.97)   $1.65 
Diluted$(1.97)   $1.55 
Weighted Average Number of Common Shares Outstanding       
Basic 33,228     95,916 
Diluted 33,228     104,001 

(In Thousands)
 Successor   Predecessor
 Three Months    Three Months
 Ended   Ended
 March 31,   March 31,
Cash Flows From Operating Activities       
Net (loss) Income$(65,315)   $160,776 
Adjustments to reconcile net (loss) income to net cash provided by       
(used in) operating activities:       
Depreciation, depletion and amortization 42,006     53,847 
Impairment of oil and natural gas properties 44,054     340,469 
Gain on early extinguishment of debt -     (777,022)
Change in fair value of derivative financial instruments (3,409)    61,325 
Accretion of asset retirement obligations 12,397     15,057 
Amortization and write off of debt issuance costs and other -     126,475 
Deferred rent 2,015     2,362 
Stock-based compensation 852     186 
Changes in operating assets and liabilities       
Accounts receivable 15,727     (37,276)
Prepaid expenses and other assets 6,969     (1,918)
Restricted cash 25,201     - 
Settlement of asset retirement obligations (9,316)    (21,313)
Accounts payable, accrued liabilities and other (59,683)    (31,946)
Net Cash Provided by (Used in) Operating Activities 11,498     (108,978)
Cash Flows from Investing Activities       
Capital expenditures (19,105)    (18,047)
Insurance payments received 2,051     - 
Transfer to restricted cash -     (9,537)
Proceeds from the sale of other property and equipment 1,269     - 
Other -     (21)
Net Cash Used in Investing Activities (15,785)    (27,605)
Cash Flows from Financing Activities       
Proceeds from the issuance of common and preferred stock, net of offering costs -     22 
Payments on long-term debt (602)    (2,880)
Fees related to debt extinguishment -     (1,446)
Debt issuance costs -     (1,531)
Other -     (25)
Net Cash Used in Financing Activities (602)    (5,860)
Net Decrease in Cash and Cash Equivalents (4,889)    (142,443)
Cash and Cash Equivalents, beginning of period 165,368     325,890 
Cash and Cash Equivalents, end of period$160,479    $183,447 

            (In Thousands, except per share information)

As required under Regulation G of the Securities Exchange Act of 1934, provided below is a reconciliation of net loss to Adjusted EBITDA, a non-GAAP financial measure. 

  Three Months 
  March 31, 
Net Loss$(65,315) 
Interest expense 3,834  
Depreciation, depletion and amortization 42,006  
Impairment of oil and natural gas properties 44,054  
Accretion of asset retirement obligations 12,397  
Change in fair value of derivative financial instruments (3,409) 
Non-cash stock-based compensation 852  
Deferred rent(1) 2,015  
Severance and restructuring costs 6,200  
Adjusted EBITDA$42,634  

(1) The deferred rent of approximately $2 million 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






Operating Highlights 2017
        (In thousands, except per unit amounts)
Operating revenues                 
Oil sales $133,621  $- $132,308  $122,732  $130,083  $92,192 
Natural gas liquids sales  2,227   -  1,389   2,144   2,996   2,889 
Natural gas sales  18,368   -  19,368   17,735   14,725   14,430 
Gain on derivative financial instruments  3,698   -  -   -   -   6,774 
Total revenues  157,914   -  153,065   142,611   147,804   116,285 
Percentage of oil revenues prior to gain                 
on derivative financial instruments  87%   -  86%   86%   88%   84% 
Operating expenses                 
Lease operating expense                 
Insurance expense  6,250   -  6,287   6,309   8,269   8,312 
Workover and maintenance  10,005   -  11,705   11,010   17,471   12,105 
Direct lease operating expense  58,902   -  56,908   51,477   55,309   61,627 
Total lease operating expense  75,157   -  74,900   68,796   81,049   82,044 
Production taxes  239   -  268   214   155   221 
Gathering and transportation  21,716   -  5,478   14,073   10,014   14,155 
Depreciation, depletion and amortization  42,006   -  29,053   31,573   40,078   53,847 
Accretion of asset retirement obligations  12,397   -  19,536   19,437   18,905   15,057 
Impairment of oil and natural gas properties  44,054   406,275  -   86,820   142,640   340,469 
General and administrative  23,848   -  12,122   15,435   23,174   28,358 
Total operating expenses  219,417   406,275  141,357   236,348   316,015   534,151 
Operating (loss) income $(61,503) $(406,275)$11,708  $(93,737) $(168,211) $(417,866)
Sales volumes per day                 
Oil (MBbls)  29.1   -  29.6   30.0   31.4   32.9 
Natural gas liquids (MBbls)  0.9   -  0.5   1.3   1.5   2.1 
Natural gas (Mmcf)  65.9   -  73.8   72.8   86.5   84.8 
Total (MBOE)  41.0   -  42.5   43.4   47.3   49.1 
Percent of sales volumes from oil  71%   -  70%   69%   66%   67% 
Average sales price                 
Oil per Bbl $51.04  $- $48.54  $44.52  $45.55  $30.80 
Natural gas liquid per Bbl  27.52     28.50   18.12   21.55   15.12 
Natural gas per Mcf  3.10   -  2.85   2.65   1.87   1.87 
Gain on derivative financial instruments per BOE  1.00   -  -   -   -   1.52 
Total revenues per BOE  42.83   -  39.19   35.73   34.32   26.01 
Operating expenses per BOE                 
Lease operating expense                 
Insurance expense  1.70   -  1.61   1.58   1.92   1.86 
Workover and maintenance  2.71   -  3.00   2.76   4.06   2.71 
Direct lease operating expense  15.98   -  14.57   12.90   12.84   13.79 
Total lease operating expense per BOE  20.39   -  19.18   17.24   18.82   18.36 
Production taxes  0.06   -  0.07   0.05   0.04   0.05 
Gathering and transportation  5.89   -  1.40   3.53   2.33   3.17 
Depreciation, depletion and amortization  11.39   -  7.44   7.91   9.31   12.05 
Accretion of asset retirement obligations  3.36   -  5.00   4.87   4.39   3.37 
Impairment of oil and natural gas properties  11.95   -  -   21.75   33.12   76.17 
General and administrative  6.47   -  3.10   3.87   5.38   6.34 
Total operating expenses per BOE  59.51   -  36.19   59.22   73.39   119.51 
Operating (loss) income per BOE $(16.68) $- $3.00  $(23.49) $(39.07) $(93.50)


Investor Relations Contact
Al Petrie
Investor Relations Coordinator 
[email protected]

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Source: GlobeNewswire (May 22, 2017 - 6:45 AM EDT)

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