UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

For the quarterly period ended September 30, 2016

or

For the transition period from _______________ to ________________

Commission File Number 1-32414

W&T OFFSHORE, INC.

(Exact name of registrant as specified in its charter)

(713) 626-8525

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days.    Yes  ☑    No  ☐  

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  ☑    No  ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Indicate by check mark whether the registrant is a shell company.    Yes  ☐    No  ☑  

As of October 31, 2016, there were 137,082,824 shares outstanding of the registrant’s common stock, par value $0.00001.

W&T OFFSHORE, INC. AND SUBSIDIARIES

TABLE OF CONTENTS

PART I – FINANCIAL INFORMATION

Item 1.  Financial Statements

W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

See Notes to Condensed Consolidated Financial Statements.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN SHAREHOLDERS’ DEFICIT

See Notes to Condensed Consolidated Financial Statements.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

See Notes to Condensed Consolidated Financial Statements.

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)

1.  Basis of Presentation

Operations.  W&T Offshore, Inc. (with subsidiaries referred to herein as “W&T,” “we,” “us,” “our,” or the “Company”) is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico.  The Company is active in the exploration, development and acquisition of oil and natural gas properties.  Our interest in fields, leases, structures and equipment are primarily owned by W&T Offshore, Inc. (on a stand-alone basis, the “Parent Company”) and its 100%-owned subsidiary, W & T Energy VI, LLC (“Energy VI”).  On October 15, 2015, a substantial amount of our interest in onshore acreage was sold, which is described in Note 2.  

Interim Financial Statements.  The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) for interim periods and the appropriate rules and regulations of the Securities and Exchange Commission (“SEC”).  Accordingly, the condensed consolidated financial statements do not include all of the information and footnote disclosures required by GAAP for complete financial statements for annual periods.  In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included.

Operating results for interim periods are not necessarily indicative of the results that may be expected for the entire year.  These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015.

Use of Estimates.  The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods.  Actual results could differ from those estimates.

Recent Events.  The price we receive for our crude oil, natural gas liquids (“NGLs”) and natural gas production directly affects our revenues, profitability, cash flows, liquidity, access to capital, proved reserves and future rate of growth.  The prices of these commodities began falling in the second half of 2014, continued to generally decline in 2015, and declined further in the first nine months of 2016 on an average basis.  Steps taken during 2015 and the first nine months of 2016 to mitigate the effects of these lower prices include: (i) significantly reducing the budgeted capital spending for 2015 and 2016 from historical levels; (ii) continuing the suspension of our drilling and completion activities at several locations; (iii) continued suspension of the regular quarterly common stock dividend; (iv) selling our interests in the Yellow Rose field in the fourth quarter of 2015; (v) reducing our headcount of employees and contractors; (vi) consummating the Exchange Transaction, as defined and described below; and (vii) continuing the implementation of numerous projects to reduce our operating costs.  See our Annual Report on Form 10-K for the year ended December 31, 2015 concerning risks related to our business and events occurring during 2015 and other information and the Notes herein for additional information.

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

On September 7, 2016, we consummated a transaction whereby we exchanged approximately $710.2 million, or 79%, of our 8.500% Senior Notes due 2019 (the “Unsecured Senior Notes”) for new secured notes and common stock.  At the same time, we closed on a new $75.0 million, 11.00% 1.5 Lien Term Loan (the “1.5 Lien Term Loan”), and in conjunction; two amendments were made effective under our Credit Agreement.  See Note 5 for a full description of the transaction, the new debt instruments and the accounting for the transaction.

During 2015, we were notified by the BOEM that the Company was no longer eligible for any exemptions set forth in the regulations and then-current supplemental bonding procedures of the BOEM related to decommissioning obligations.  In February and March 2016, we received several orders from the Bureau of Ocean Energy Management (“BOEM”) ordering the Company to provide additional security in the aggregate of $260.8 million.  We filed appeals with the Interior Board of Land Appeals (“IBLA”) and the IBLA has agreed to stay the effectiveness of the orders.  This is the third stay that we have received from the IBLA, and their latest stay extends the effectiveness to January 31, 2017.  We submitted a proposal for a tailored plan of compliance in May 2016 under the BOEM’s then-current supplemental bonding procedures in NTL #2008-N07. Subsequently, the BOEM issued NTL #2016-N01 to replace NTL #2008-N07, effective September 2016, and we submitted a revised proposed tailored plan of compliance to the BOEM incorporating requirements of the new NTL.  We continue to have discussions with the BOEM regarding these matters.  See Note 11 for additional information.    

We have assessed our financial condition, the current capital markets and options given different scenarios of commodity prices.  We believe we will have adequate liquidity to fund our operations through September 30, 2017, the period of assessment to qualify as a going concern.  However, we cannot predict how an extended period of low commodity prices or the impact of future bonding requirements will affect our operations, liquidity levels and compliance with debt covenants.  

Ceiling Test Write-Down.  Under the full cost method of accounting, each quarter we are required to perform a “ceiling test,” which determines a limit on the book value of our oil and natural gas properties.  If the net capitalized cost of oil and natural gas properties (including capitalized asset retirement obligations (“ARO”)) net of related deferred income taxes exceeds the ceiling test limit, the excess is charged to expense on a pre-tax basis and separately disclosed.  Any such write downs are not recoverable or reversible in future periods.  The ceiling test limit is calculated as: (i) the present value of estimated future net revenues from proved reserves, less estimated future development costs, discounted at 10%; plus (ii) the cost of unproved oil and natural gas properties not being amortized; plus (iii) the lower of cost or estimated fair value of unproved oil and natural gas properties included in the amortization base; and less (iv) related income tax effects.  Estimated future net revenues used in the ceiling test for each period are based on current prices for each product, defined by the SEC as the unweighted average of first-day-of-the-month commodity prices over the prior twelve months for that period.  All prices are adjusted by field for quality, transportation fees, energy content and regional price differentials.

Due primarily to declines in the unweighted rolling 12-month average of first-day-of-the-month commodity prices for oil and natural gas, we recorded ceiling test write-downs in each of the first three quarters of 2016 and in every quarter of 2015, which are reported as a separate line in the Consolidated Statements of Operations.  The average price using the SEC required methodology at September 30, 2016 was $38.17 per barrel for West Texas Intermediate (“WTI”) crude oil and $2.28 per million British Thermal Unit  (“MMBtu”) for Henry Hub natural gas before adjustments.  Ceiling test write-downs of the carrying value of our oil and natural gas properties for the three months ended September 30, 2016 and 2015 were $57.9 million and $441.7 million, respectively, and for nine months ended September 30, 2016 and 2015 were $279.1 million and $954.9 million, respectively.  The ceiling test write-down for the full year of 2015 was $987.2 million.    

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Prepaid Expenses and Other.  Amounts recorded in Prepaid expenses and other on the Condensed Consolidated Balance Sheets are expected to be realized within one year.  Major categories are disclosed in the following table (in thousands):

Recent Accounting Developments.  In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-09 (“ASU 2014-09”), Summary and Amendments That Create Revenue from Contracts and Customers (Subtopic 606).  ASU 2014-09 amends and replaces current revenue recognition requirements, including most industry-specific guidance.  The revised guidance establishes a five step approach to be utilized in determining when, and if, revenue should be recognized.  ASU 2014-09 is effective for annual and interim periods beginning after December 15, 2017.  Upon application, an entity may elect one of two methods, either restatement of prior periods presented or recording a cumulative adjustment in the initial period of application.  We have not fully determined or quantified the effect ASU 2014-09 will have on the recognition of our revenue, if any, nor have we determined the method we will utilize upon adoption, which would be in the first quarter of 2018.

In August 2014, the FASB issued Accounting Standards Update No. 2014-15 (“ASU 2014-15”), Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (Subtopic 205-40).  The guidance addresses management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures.  ASU 2014-15 is effective for the annual period ending after December 15, 2016, and for annual and interim periods thereafter.  We do not expect the revised guidance to materially affect our evaluation as to being a going concern, or have an effect on our financial statements or related disclosures.

In February 2016, the FASB issued Accounting Standards Update No. 2016-02 (“ASU 2016-02”), Leases (Subtopic 842).  Under the new guidance, a lessee will be required to recognize assets and liabilities for leases with lease terms of more than 12 months. Consistent with current GAAP, the recognition, measurement and presentation of expenses and cash flows arising from a lease by a lessee primarily will depend on its classification as a finance or operating lease.  However, unlike current GAAP, which requires only capital leases to be recognized on the balance sheet, ASU 2016-02 will require both types of leases to be recognized on the balance sheet.  ASU 2016-02 also will require disclosures to help investors and other financial statement users to better understand the amount, timing and uncertainty of cash flows arising from leases.  These disclosures include qualitative and quantitative requirements, providing additional information about the amounts recorded in the financial statements.  ASU 2016-02 does not apply to leases for oil and gas properties, but does apply to equipment used to explore and develop oil and gas resources.  Our current operating leases that will be impacted by ASU 2016-02 when it is effective are leases for office space in Houston and New Orleans, although ASU 2016-02 may impact the accounting for leases related to operations equipment depending on the term of the lease.  We currently do not have any leases classified as financing leases.  ASU 2016-02 is effective for annual and interim periods beginning after December 15, 2018 and is to be applied using the modified retrospective approach.  We have not fully determined or quantified the effect ASU 2016-02 will have on our financial statements.

In March 2016, the FASB issued Accounting Standards Update No. 2016-09 (“ASU 2016-09”), Compensation – Stock Compensation (Subtopic 718).  The objective of ASU 2016-09 is for simplification involving several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows.  ASU 2016-09 is effective for annual and interim periods beginning after December 15, 2016 and early adoption is permitted.  We have not yet fully determined or quantified the effect of ASU 2016-09, but do not anticipate the revised guidance will have a material effect on our financial statements.  

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

In June 2016, the FASB issued Accounting Standards Update No. 2016-13, (“ASU 2016-13”), Financial Instruments – Credit Losses (Subtopic 326).  The new guidance eliminates the probable recognition threshold and broadens the information to consider past events, current conditions and forecasted information in estimating credit losses.  ASU 2016-13 is effective for fiscal years beginning after December 15, 2019 and early adoption is permitted for fiscal years beginning after December 15, 2018.  We have not yet fully determined or quantified the effect ASU 2016-13 will have on our financial statements.

In August 2016, the FASB issued Accounting Standards Update No. 2016-15, (“ASU 2016-15”), Statement of Cash Flows (Topic 230) – Classification of Certain Cash Receipts and Cash Payments.  ASU 2016-15 addresses the classification of several items that previously had diversity in practice.  Items identified in the new standard which were incurred by us in the past are (a) debt prepayment or extinguishment costs (b) contingent consideration made after a business acquisition and (c) proceeds from settlement of insurance claims.  The item described in clause (b) would be the only such item changed under our historical classification in the Statement of Cash Flows (financing vs. investing) and the amount of such change would not be material; therefore, we do not anticipate the new standard will have a material effect on our Statement of Cash Flows.   ASU 2016-15 is effective for fiscal years beginning after December 15, 2017 and early adoption is permitted.    

2.  Divestitures

2015 Divestiture

On October 15, 2015, we sold certain onshore oil and natural gas property interests to Ajax Resources, LLC (“Ajax”) for approximately $370.9 million in cash, which includes certain customary post effective date price adjustments, and Ajax assumed responsibility for the related ARO and other associated liabilities.  The effective date of the sale was January 1, 2015. A net purchase price adjustment of $0.9 million for final customary effective date adjustments was recorded during the nine months ended September 30, 2016.  Ajax acquired all of our interest in the Yellow Rose field in the Permian Basin, covering approximately 25,800 net acres in Andrews, Martin, Gaines and Dawson counties in West Texas.  We retained a non-expense bearing overriding royalty interest (“ORRI”) equal to a variable percentage in production from the working interests assigned to Ajax, which percentage varies on a sliding scale from one percent for each month that the New York Mercantile Exchange (“NYMEX”) prompt month contract trading price for light sweet crude oil is at or below $70.00 per barrel to a maximum of four percent for each month that such NYMEX trading price is greater than $90.00 per barrel.  

Under the full cost method, sales or abandonments of oil and natural gas properties, whether or not being amortized, are accounted for as adjustments of capitalized costs, with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to the cost center.  The sale to Ajax did not represent greater than 25% of the Company’s proved reserves of oil and natural gas attributable to the full cost pool.  As a result, alteration in the relationship between capitalized costs and proved reserves of oil and natural gas attributable to the full cost pool was not deemed significant and no gain or loss was recognized from the sale.        

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

3.  Asset Retirement Obligations

Our ARO primarily represents the estimated present value of the amount we will incur to plug, abandon and remediate our producing properties at the end of their productive lives in accordance with applicable laws.  

A summary of the changes to our ARO is as follows (in thousands):  

4.  Derivative Financial Instruments

Our market risk exposure relates primarily to commodity prices and, from time to time, we use various derivative instruments to manage our exposure to this commodity price risk from sales of our oil and natural gas.  All of the derivative counterparties are also lenders or affiliates of lenders participating in our revolving bank credit facility.  We are exposed to credit loss in the event of nonperformance by the derivative counterparties; however, we currently anticipate that each of our derivative counterparties will be able to fulfill their contractual obligations.  Additional collateral is not required by us due to the derivative counterparties’ collateral rights as lenders, and we do not require collateral from our derivative counterparties.

We have elected not to designate our commodity derivative contracts as hedging instruments; therefore, all changes in the fair value of derivative contracts were recognized currently in earnings during the periods presented.  The cash flows of all of our commodity derivative contracts are included in Net cash provided by operating activities on the Condensed Consolidated Statements of Cash Flows.

For information about fair value measurements, refer to Note 6.

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Commodity Derivatives

As of September 30, 2016, we have open crude oil and natural gas derivative contracts for a portion of our anticipated future production for the remainder of 2016.  These contracts were entered into during the second quarter of 2015.  The open oil derivative contracts are known as “two-way collars” consisting of a purchased put option and a sold call option.  These two-way collars provide price risk protection if crude oil prices fall below certain levels, but may limit incremental income from favorable price movements above certain limits.  The oil contracts are based on WTI crude oil prices as quoted off the NYMEX.  The open natural gas derivative contracts are known as “three-way collars” consisting of a purchased put option, a sold call option and a purchased call option, each at varying strike prices.  The three-way collar contracts are structured to provide price risk protection if the commodity price falls below the strike price of the put option and provides us the opportunity to benefit if the commodity price rises above the strike price of the purchased call option.  These contracts may have the effect of reducing some of our incremental income from favorable price movements if the commodity price is above certain levels, but have unlimited upside potential if prices rise above those levels.  The natural gas contracts are based on Henry Hub natural gas prices as quoted off the NYMEX.  The strike prices of both the oil and natural gas contracts were set so that the contracts were premium neutral (“costless”), which means no net premium was paid to or received from a counterparty.    

As of September 30, 2016, our open commodity derivative contracts were as follows:

The following balance sheet line items included amounts related to the estimated fair value of our open commodity derivative contracts as indicated in the following table (in thousands):

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Changes in the fair value and settlements of our commodity derivative contracts were as follows (in thousands):

Cash receipts, net, on commodity derivative contract settlements are included within Net cash provided by operating activities on the Condensed Consolidated Statements of Cash Flows and were as follows (in thousands):

Offsetting Commodity Derivatives

During 2016 and 2015, all our commodity derivative contracts permit netting of derivative gains and losses upon settlement.  In general, the terms of the contracts provide for offsetting of amounts payable or receivable between us and the counterparty, at the election of both parties, for transactions that occur on the same date and in the same commodity.  If an event of default were to occur causing an acceleration of payment under our revolving bank credit facility, that event may also trigger an acceleration of settlement of our derivative instruments.  If we were required to settle all of our open derivative contracts, we would be able to net payments and receipts per counterparty pursuant to the derivative contracts.  Although our derivative contracts allow for netting, which would allow for recording assets and liabilities per counterparty on a net basis, we have historically accounted for our derivative contracts on a gross basis per contract as either an asset or liability.  

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

5.  Long-Term Debt

Our long-term debt was as follows (in thousands):

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Exchange Transaction

On September 7, 2016, we consummated a transaction whereby we exchanged approximately $710.2 million in aggregate principal amount, or 79%, of our Unsecured Senior Notes, due June 15, 2019 for: (i) $159.8 million in aggregate principal amount of 9.00%/10.75% Senior Second Lien PIK Toggle Notes, due May 2020, (the “Second Lien PIK Toggle Notes”); (ii) $142.0 million in aggregate principal amount of 8.50%/10.00% Senior Third Lien PIK Toggle Notes, due June 2021, (the “Third Lien PIK Toggle Notes”); and (iii) 60.4 million shares of our common stock (collectively, the “Debt Exchange”).  At the same time on closing on the Debt Exchange, we closed on a $75.0 million, 11.00% 1.5 Lien Term Loan, due November 2019, with the largest holder of our Unsecured Senior Notes (collectively with the Debt Exchange, the “Exchange Transaction”).  We accounted for the Exchange Transaction as a Troubled Debt Restructuring pursuant to the guidance under Accounting Standard Codification 470-60, Troubled Debt Restructuring (“ASC 470-60”).  Under ASC 470-60, the carrying value of the newly issued Second Lien PIK Toggle Notes, Third Lien PIK Toggle Notes and 1.5 Lien Term Loan (the “New Debt”) is measured using all future undiscounted payments (principal and interest); therefore, no interest expense was recorded for the New Debt in the Consolidated Statements of Operations during the three and nine month months ended September 30, 2016.  Additionally, no interest expense related to the New Debt will be recorded in future periods as payments of interest on the New Debt will be recorded as a reduction in the carrying amount; thus, our reported interest expense will be significantly less than the contractual interest payments through the terms of the New Debt.    

A gain of $124.0 million was recognized related to the Exchange Transaction. Under ASC 470-60, a gain was recognized as the sum of (i) the future undiscounted payments (principal and interest) related to the New Debt, (ii) the fair value of the common stock issued and (iii) deal transaction costs of $18.9 million was less than the sum of (iv) the carrying value of the Unsecured Senior Notes exchanged and (v) the funds received from the 1.5 Lien Term Loan.  The shares of common stock issued were valued at $1.76 per share, which was the closing price on September 7, 2016.  Transaction costs related to the Exchange Transaction of approximately $2.8 million previously recorded as General and Administrative expense were reclassified and netted against the Gain on Debt Exchange. When such costs were previously recorded, the Exchange Transaction was dependent on approvals and actions by third parties including the approval of two-thirds of our shareholders.  The effect on basic and diluted earnings per share for the three and nine months ended September 30, 2016 was a $1.33 per share and $1.52 per share, respectively, which assumes the gain would not affect income tax benefit for either time period.   

The funds received from the 1.5 Lien Term Loan were used to pay transaction costs related to the Exchange Transaction and to pay down borrowings on the revolving bank credit facility.  The balance of the borrowings on the revolving bank credit facility was paid down from available cash.

The primary terms of our long-term debt following the Exchange Transaction are described below.   

Credit Agreement

The Fifth Amended and Restated Credit Agreement (as amended, the “Credit Agreement”), provides a revolving bank credit facility.  In conjunction with the Exchange Transaction, two amendments were executed for the Credit Agreement.  The primary items related to the recent amendments are:

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Availability under our revolving bank credit facility is subject to a semi-annual redetermination of our borrowing base that occurs in the spring and fall of each year (commencing in 2017) and is calculated by our lenders based on their evaluation of our proved reserves and their own internal criteria.  The spring redetermination occurred in March 2016 and the next redetermination will occur in April 2017.  Subsequent to April 2017, the lenders and the Company have the option for an additional redetermination every year.  Any determination by our lenders to change our borrowing base will result in a similar change in the availability under our revolving bank credit facility.  To the extent borrowings and letters of credit outstanding exceed the redetermined borrowing base; such excess is required to be repaid within 90 days in three equal monthly payments.  Letters of credit may be issued in amounts up to $150.0 million, provided availability under the revolving bank credit facility exists.  The revolving bank credit facility is secured and is collateralized by substantially all of our oil and natural gas properties.  The Credit Agreement terminates on November 8, 2018.

The Credit Agreement contains various customary covenants for certain financial tests, as defined in the Credit Agreement and measured as of the end of each quarter, and for customary events of default.  These financial test ratios and limits as of September 30, 2016 and thereafter are: (i) the First Lien Leverage Ratio must be less than 2.50 to 1.00 with a step down to 2.00 to 1.00 on September 30, 2017; (ii) the Current Ratio must be greater than 1.00 to 1.00; and (iii) the Asset Coverage Ratio must not be less than 1.25x measured on September 30, 2016 and December 31, 2016.  The Asset Coverage Ratio is determined using the present value of proved reserves, discounted at 10%, and using strip forward pricing (PV-10 using strip pricing) compared to the amount of first lien debt outstanding.   As of September 30, 2016, the First Lien Leverage Ratio was 0.01 to 1.00, the Current Ratio was 2.35 to 1.00 and the Asset Coverage Ratio was not meaningful, as only letters of credit were outstanding on September 30, 2016, and was well above the threshold.  The customary events of default include: (i) nonpayment of principal when due or nonpayment of interest or other amounts within three business days of when due; (ii) bankruptcy or insolvency with respect to the Company or any of its subsidiaries guaranteeing borrowings under the revolving bank credit facility; or (iii) a change of control.  The Credit Agreement contains cross-default clauses with the other long-term debt agreements, and such agreements contain similar cross-default clauses with the Credit Agreement.  We were in compliance with all applicable covenants of the Credit Agreement as of September 30, 2016.

We are required to have deposit accounts only with banks under the Credit Agreement with certain exceptions and may not have unrestricted cash balances above $35 million if outstanding balances on the revolving bank credit facility (including letters of credit) are greater than $5 million.  We are required to maintain minimum liquidity of $15 million, defined as the sum of unrestricted cash and availability under the revolving bank credit facility.

The recent amendments increased some of the margins applied to borrowings under the revolving bank credit facility.  Borrowings under the revolving bank credit facility bear interest at the applicable London Interbank Offered Rate (“LIBOR”) plus a margin that varies from 3.00% to 4.00% depending on the level of total borrowings under the Credit Agreement, or an alternative base rate equal to the greater of (a) Prime Rate, (b) Federal Funds Rate plus 0.50%, and (c) LIBOR plus 1.00%, plus applicable margin ranging from 2.00% to 3.00%.  The unused portion of the borrowing base is subject to a commitment fee of 0.50%.

The borrowing base reduction occurring in the first three months of 2016 resulted in a proportional reduction in the unamortized costs related to the Credit Agreement of $1.4 million for the nine months ended September 30, 2016, which is included in the line Other expense, net on the Condensed Statement of Operations.  

  The estimated annual effective interest rate was 5.6% for the nine months ended September 30, 2016 for average daily borrowings outstanding under the revolving bank credit facility.  The estimated annual effective interest rate includes amortization of debt issuance costs and excludes commitment fees and other costs.  As of both September 30, 2016 and December 31, 2015, we did not have any borrowings outstanding and had $0.9 million of letters of credit outstanding under the revolving bank credit facility at both dates.  Availability as of September 30, 2016 was $149.1 million.  

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

1.5 Lien Term Loan

As part of the Exchange Transaction, we entered into the 1.5 Lien Term Loan on September 7, 2016 with a maturity date of November 15, 2019.    The maturity date will accelerate to February 28, 2019 if the remaining Unsecured Senior Notes have not been extended, renewed, refunded, defeased, discharged, replaced or refinanced by February 28, 2019. Interest accrues at 11.00% per annum and is payable quarterly in cash.  The holder of the 1.5 Lien Term Loan was the largest holder of our Unsecured Senior Notes prior to the Exchange Transaction.  The 1.5 Lien Term Loan is secured by a 1.5 priority lien on all of our assets pledged under the Credit Agreement.  The lien securing the 1.5 Lien Term Loan is subordinate to the liens securing the Credit Agreement and has priority above the liens securing the Second Lien Term Loan, the Second Lien PIK Toggle Notes and the Third Lien PIK Toggle Notes.  All future undiscounted cash flows have been included in the carrying value under ASC 470-60.  Current maturities of long-term debt represent the cash interest payable for the 1.5 Lien Term Loan payable in the next 12 months.  The 1.5 Lien Term Loan contains various covenants that limit, among other things, our ability to: (i) pay cash dividends; (ii) repurchase our common stock; (iii) sell our assets; (iv) make certain loans or investments; (v) merge or consolidate; (vi) enter into certain liens; and (vii) enter into transactions with affiliates.  We were in compliance with those covenants as of September 30, 2016.

Second Lien Term Loan

At September 30, 2016 and December 31, 2015, our Second Lien Term Loan, which bears an annual interest rate of 9.00% and matures on May 15, 2020 (the “Second Lien Term Loan”), was recorded at its carrying value consisting of principal, unamortized discount and unamortized debt issuance costs.  Interest on the  Second Lien Term Loan is payable in arrears semi-annually on May 15 and November 15.  The estimated annual effective interest rate on the Second Lien Term Loan is 9.7%, which includes amortization of debt issuance costs and discounts.  The Second Lien Term Loan is secured by a second-priority lien on all of our assets that are secured under the Credit Agreement.  The Second Lien Term Loan is effectively subordinate to the Credit Agreement and the 1.5 Lien Term Loans (discussed above) and is effectively pari passu with the Second Lien PIK Toggle Notes (discussed below).  We are subject to various covenants under the terms governing the Second Lien Term Loan including, without limitation, covenants that limit our ability to incur other debt, pay dividends or distributions on our equity, merge or consolidate with other entities and make certain investments in other entities.  We were in compliance with those covenants as of September 30, 2016.

Second Lien PIK Toggle Notes

As part of the Exchange Transaction, we issued Second Lien PIK Toggle Notes on September 7, 2016, with a maturity date of May 15, 2020.  Cash interest accrues at 9.00% per annum and is payable on May 15 and November 15 of each year.  The Second Lien PIK Toggle Notes contain payment-in-kind (“PIK”) interest provisions, where certain semi-annual interest is added to the principal amount instead of being paid in cash in the then current semi-annual period.  We have the option for the first 18 months to pay all or a portion of interest in kind at a rate of 10.75% per annum, except that the initial interest payment on November 15, 2016 is to be paid solely in kind.  The Second Lien PIK Toggle Notes are secured by a second-priority lien on all of our assets that are pledged under the Credit Agreement.  The Second Lien PIK Toggle Notes are effectively subordinate to the Credit Agreement and the 1.5 Lien Term Loan (discussed above) and is effectively pari passu with the Second Lien Term Loan.  For purposes of determining the gain from the Exchange Transaction under ASC 470-60, we assumed the Company will elect full use of the PIK option and these amounts will increase the principal amount.  All future undiscounted cash flows have been included in the carrying value under ASC 470-60.  The Second Lien PIK Toggle Notes contain covenants that restrict our ability and the ability of certain of our subsidiaries to: (i) incur additional debt; (ii) make payments or distributions on account of our or our restricted subsidiaries’ capital stock; (iii) sell assets; (iv) restrict dividends or other payments of our restricted subsidiaries; (v) create liens that secure debt; (vi) enter into transactions with affiliates and (vii) merge or consolidate with another company.  We were in compliance with those covenants as of September 30, 2016.      

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Third Lien PIK Toggle Notes

As part of the Exchange Transaction, we issued Third Lien PIK Toggle Notes on September 7, 2016, with a maturity date of June 15, 2021.  The maturity date will accelerate to February 28, 2019 if the remaining Unsecured Senior Notes have not been extended, renewed, refunded, defeased, discharged, replaced or refinanced by February 28, 2019.  Cash interest accrues at 8.50% per annum and is payable on June 15 and December 15 of each year.  The Third Lien PIK Toggle Notes contain PIK interest provisions, where certain semi-annual interest is added to the principal amount instead of being paid in cash in the then current semi-annual period.  We have the option for the first 24 months to pay all or a portion of interest in kind at a rate of 10.00% per annum, except that the initial interest payment on December 15, 2016 is to be paid solely in kind.  The Third Lien PIK Toggle Notes are secured by a third-priority lien on all of our assets that are secured under the Credit Agreement.  The Third Lien PIK Toggle Notes are effectively subordinate to the Second Lien Term Loan and the Second Lien PIK Toggle Notes. For purposes of determining the gain from the Exchange Transaction under ASC 470-60, we assumed the Company will elect full use of the PIK option and these amounts will increase the principal amount.  All future undiscounted cash flows have been included in the carrying value under ASC 470-60.  The Third Lien PIK Toggle Notes contain covenants that restrict our ability and the ability of certain of our subsidiaries to: (i) incur additional debt; (ii) make payments or distributions on account of our or our restricted subsidiaries’ capital stock; (iii) sell assets; (iv) restrict dividends or other payments of our restricted subsidiaries; (v) create liens that secure debt; (vi) enter into transactions with affiliates and (vii) merge or consolidate with another company.  We were in compliance with those covenants as of September 30, 2016.

Unsecured Senior Notes

At September 30, 2016 and December 31, 2015, our outstanding Unsecured Senior Notes, which bear an annual interest rate of 8.50% and mature on June 15, 2019, were recorded at their carrying value consisting of principal, unamortized premium and unamortized debt issuance costs.  For the Exchange Transaction, unamortized debt premium and unamortized debt issuance costs were allocated based on the principal values of the Unsecured Senior Notes exchanged and those not exchanged.  The Unsecured Senior Notes are effectively subordinate to all our secured debt.  Interest on the Unsecured Senior Notes is payable semi-annually in arrears on June 15 and December 15.  The estimated annual effective interest rate on the Unsecured Senior Notes is 8.4%, which includes amortization of debt issuance costs and premiums.  We are subject to various financial and other covenants under the indenture governing the Unsecured Senior Notes, and we were in compliance with those covenants as of September 30, 2016.  

For information about fair value measurements for our long-term debt, refer to Note 6.

6.  Fair Value Measurements  

We measure the fair value of our open derivative financial instruments by applying the income approach, using models with inputs that are classified within Level 2 of the valuation hierarchy.  The inputs used for the fair value measurement of our derivative financial instruments are the exercise price, the expiration date, the settlement date, notional quantities, the implied volatility, the discount curve with spreads, credit risk and published commodity futures prices.  The fair value of the 1.5 Lien Term Loan was estimated using the carrying value of the principal as no market has initially developed and the loan was recently consummated.  The fair values of our Second Lien Term Loan, Second Lien PIK Toggle Notes, Third Lien PIK Toggle Notes and Unsecured Senior Notes were based on quoted prices, although the market is not an active market; therefore, the fair value is classified within Level 2.  

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

The following table presents the fair value of our open derivatives and long-term debt, all of which are classified as Level 2 within the valuation hierarchy (in thousands):

7.  Share-Based Compensation and Cash-Based Incentive Compensation

Awards to Employees.  In 2010, the W&T Offshore, Inc. Amended and Restated Incentive Compensation Plan (the “Plan”) was approved by our shareholders, and amendments to the Plan were approved by our shareholders in May 2013 and in May 2016.  The May 2016 amendment increased the number of shares available in the Plan by 3,300,000 shares.  As allowed by the Plan, during 2016, 2015 and 2014, the Company granted restricted stock units (“RSUs”) to certain of its employees.  RSUs are a long-term compensation component of the Plan, which are granted to only certain employees, and are subject to adjustments at the end of the applicable performance period based on the results of certain predetermined criteria.  In addition to share-based compensation, the Company may grant to its employees cash-based incentive awards, which are a short-term component of the Plan and are typically based on the Company and the employee achieving certain pre-defined performance criteria.

As of September 30, 2016, there were 7,532,938 shares of common stock available for issuance in satisfaction of awards under the Plan.   The shares available for issuance are reduced when RSUs are settled in shares of common stock, net of withholding tax.  Although the Company has the option at vesting to settle RSUs in stock or cash, or a combination of stock and cash, only common stock has been used to settle vested RSUs to date.

RSUs currently outstanding have been adjusted for performance achieved against predetermined criteria for the applicable performance year.  The RSUs outstanding continue to be subject to employment-based criteria and vesting occurs in December of the second year after the grant.  See the second table below for potential vesting by year.

We recognize compensation cost for share-based payments to employees over the period during which the recipient is required to provide service in exchange for the award.  Compensation cost is based on the fair value of the equity instrument on the date of grant.  The fair values for the RSUs granted during 2016, 2015 and 2014 were determined using the Company’s closing price on the grant date.  We are also required to estimate forfeitures, resulting in the recognition of compensation cost only for those awards that are expected to actually vest.

All RSUs awarded are subject to forfeiture until vested and cannot be sold, transferred or otherwise disposed of during the restricted period.  

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

A summary of activity in 2016 related to RSUs is as follows:

For the outstanding RSUs issued to the eligible employees as of September 30, 2016, vesting is expected to occur as follows:  

Restricted Stock Units fair value at grant date and vested date:  The fair value of Restricted Stock Units granted during the nine months ended September 30, 2016 was $9.3 million based on the Company’s closing price on the date of grant.  The fair value of Restricted Stock Units that vested during the nine months ended September 30, 2016 was minimal and was based on the Company’s closing price on the date of vesting.

Awards to Non-Employee Directors.  Under the Director Compensation Plan, shares of restricted stock (“Restricted Shares”) have been granted to the Company’s non-employee directors.  Grants to non-employee directors were made during 2016, 2015 and 2014.  As of September 30, 2016, there were 317,896 shares of common stock available for issuance in satisfaction of awards under the Director Compensation Plan.  The shares available are reduced when Restricted Shares are granted.  

We recognize compensation cost for share-based payments to non-employee directors over the period during which the recipient is required to provide service in exchange for the award.  Compensation cost is based on the fair value of the equity instrument on the date of grant.  The fair values for the Restricted Shares granted were determined using the Company’s closing price on the grant date.   No forfeitures were estimated for the non-employee directors’ awards.

The Restricted Shares are subject to service conditions and vesting occurs at the end of specified service periods unless approved by the Board.  Restricted Shares cannot be sold, transferred or disposed of during the restricted period.  The holders of Restricted Shares generally have the same rights as a shareholder of the Company with respect to such Restricted Shares, including the right to vote and receive dividends or other distributions paid with respect to the Restricted Shares.  

A summary of activity in 2016 related to Restricted Shares is as follows:

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Restricted Shares fair value at grant date and vested date:  The fair value of Restricted Shares granted during the nine months ended September 30, 2016 was $0.3 million based on the Company’s closing price on the date of grant.  The fair value of Restricted Shares that vested during the nine months ended September 30, 2016 was $0.1 million based on the Company’s closing price on the date of vesting.  

For the outstanding Restricted Shares issued to the non-employee directors as of September 30, 2016, vesting is expected to occur as follows:

  Share-Based Compensation.  Share-based compensation expense is recorded in the line General and administrative expenses in the Condensed Statements of Operations.  A summary of incentive compensation expense under share-based payment arrangements and the related tax benefit is as follows (in thousands):

Unrecognized Share-Based Compensation.  As of September 30, 2016, unrecognized share-based compensation expense related to our awards of RSUs and Restricted Shares was $7.5 million and $0.4 million, respectively.  Unrecognized share-based compensation expense will be recognized through November 2018 for RSUs and April 2019 for Restricted Shares.

Cash-Based Incentive Compensation. As defined by the Plan, annual incentive awards may be granted to eligible employees and are typically payable in cash.  These awards are performance-based awards consisting of one or more business or individual performance criteria and a targeted level or levels of performance with respect to each such criterion.  Generally, the performance period is the calendar year and determination and payment is made in cash in the first quarter of the following year.  

During 2016 and 2015, the Company issued cash-based incentive awards for both years that, in addition to being performance-based awards related to respective 2016 and 2015 criteria, the payment of such awards is contingent on the Company achieving the following financial condition on or before December 31, 2018 and December 31, 2017, respectively:  Adjusted EBITDA less Interest Expense, as reported by the Company in its announced Earnings Release with respect to the end of any fiscal quarter plus three preceding quarters, exceeds $300.0 million.  As the Company did not achieve this financial condition up through September 30, 2016, no amounts have been recognized to date related to the 2016 and 2015 cash-based incentive awards.         

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

8.  Income Taxes

Our income tax benefit for the three and nine months ended September 30, 2016 was $3.8 million and $44.4 million, respectively.  Our effective tax rate for the three months ended September 30, 2016 was not meaningful primarily due to adjustments related to the book gain associated with the Exchange Transaction.  The annualized effective tax rate for the nine months ended September 30, 2016 was 14.3%.  Our income tax benefit for the three and nine months ended September 30, 2015 was $18.5 million and $166.2 million, respectively.  The annualized effective tax rate for the three and nine months ended September 30, 2015 was 3.7% and 14.3%, respectively.  Our annualized effective tax rates differs from the federal statutory rate of 35.0% for all periods presented primarily due to the valuation allowance recorded for our deferred tax assets.         

 During the three months and nine ended September 30, 2016, we recorded a reduction in the valuation allowance of $19.1 million and an increase in the valuation allowance of $63.1 million, respectively, related to federal and state deferred tax assets.  During the three and nine months ended September 30, 2015, we recorded a valuation allowance of $156.2 million and $241.6 million, respectively.  Deferred tax assets are recorded related to net operating losses and temporary differences between the book and tax basis of assets and liabilities expected to produce tax deductions in future periods.  The realization of these assets depends on recognition of sufficient future taxable income in specific tax jurisdictions in which those temporary differences or net operating losses are deductible.  In addition, the realization depends on the ability to carryback certain items to prior years for refunds of taxes previously paid.  In assessing the need for a valuation allowance on our deferred tax assets, we consider whether it is more likely than not that some portion or all of them will not be realized.  As of September 30, 2016 and December 31, 2015, we had a valuation allowance related to Federal, Louisiana and Alabama net operating losses and other deferred taxes.  The tax years 2012 through 2015 remain open to examination by the tax jurisdictions to which we are subject.   

In connection with the Exchange Transaction, we realized a tax gain due to the concession extended by the noteholders who elected to exchange their Unsecured Senior Notes.  This tax gain will be offset by a reduction in our net operating losses and other deferred tax asset attributes. The reduction in our deferred tax assets will be fully offset by a corresponding reduction in our valuation allowance. 

During the third quarter, we received an income tax refund of $5.6 million primarily for a net operating loss (“NOL”) claim for 2015 carried back to 2005 filed on Form 1139, Corporation Application for Tentative Refund.  In addition, we have recorded $52.1 million as non-current income tax receivables related to our NOL claims for the years 2012, 2013 and 2014 that were carried back to the years 2003, 2004, 2007, 2010 and 2011 filed on Form 1120X, U.S. Corporation Income Tax Return.  These carryback claims are made pursuant to Internal Revenue Code (“IRC”) Section 172(f) which permits certain platform dismantlement, well abandonment and site clearance costs to be carried back 10 years.  The refund claims filed on Form 1120X will require a review by the Congressional Joint Committee on Taxation and are accordingly classified as non-current.

We recognize interest and penalties related to unrecognized tax benefits in income tax expense.  During the 2016 and 2015 periods reported, we recorded immaterial amounts of accrued interest expense related to our unrecognized tax benefit.

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

9.  Earnings/ (Loss) Per Share

The following table presents the calculation of basic and diluted loss per common share (in thousands, except per share amounts):

10.  Equity Structure and Transactions

During September 2016, a special meeting of shareholders of common stock was held and shareholders approved two proposals, which increased the number of authorized common shares to 200,000,000 and provided for the issuance of up to 76,590,000 common shares in conjunction with the Exchange Transaction.  Upon consummation of the Exchange Transaction, 60,435,544 common shares were issued to noteholders who elected to exchange their Unsecured Senior Notes.  

During the nine months ended September 30, 2016 and the full year of 2015, we did not pay any dividends and a suspension of dividends remains in effect.     

11.  Contingencies  

Supplemental Bonding Requirements by the BOEM.  The BOEM requires that lessees demonstrate financial strength and reliability according to its regulations or post surety bonds or other acceptable financial assurances that such decommissioning obligations will be satisfied.  Prior to 2015, we were partially exempt from providing such financial assurances.  The significant and sustained decline in crude oil and natural gas prices, however, has resulted in the Company no longer meeting the relevant financial strength and reliability criteria for such exemptions set forth in the regulations and then-current supplemental bonding procedures of the BOEM.  As a result, we were notified by the BOEM in 2015 that the Company was no longer eligible for any exemption from providing financial assurances to the BOEM under NTL #2008-N07.  In February and March 2016, we received several orders from the BOEM ordering the Company to secure financial assurances in the form of additional security in the aggregate of $260.8 million, with amounts specified with respect to certain designated leases, rights of use and easement (“RUEs”) and rights of way (“ROWs”).  We have filed appeals with the IBLA regarding four of the BOEM orders - specifically the February order requiring the Company to post a total of $159.8 million in additional security and three March orders requiring $101.0 million in additional security.  The IBLA, acknowledging that the BOEM and the Company were seeking to resolve the BOEM orders through settlement discussions, has agreed to stay the effectiveness of the orders.  This is the third stay that we have received from the IBLA, and their latest stay extends the effectiveness to January 31, 2017.  We submitted a proposal for a tailored plan of compliance in May 2016 and have had ongoing discussions with the BOEM and its sister agency, the Bureau of Safety and Environmental Enforcement (the “BSEE”), in an effort to seek an acceptable resolution of the orders.

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

In July 2016, effective September 12, 2016, the BOEM issued NTL #2016-N01, related to obligations for decommissioning activities on the OCS, to clarify the procedures and guidelines that BOEM Regional Directors use to determine if and when additional security may be required for OCS leases, ROW and RUE. This NTL supersedes and replaces NTL #2008-N07.  Among other things, the NTL eliminates the “waiver exemption” currently allowed by the BOEM, whereby lessees on the OCS meeting certain financial strength and reliability criteria are exempted from posting bonds or other acceptable financial assurances for such lessee’s decommissioning obligations.  Under the new NTL, qualifying operators may self-insure for an amount up to 10% of their tangible net worth.  In addition, the NTL implements a phase-in period for establishing compliance with additional security obligations for certain properties, whereby lessees may seek compliance with its additional security requirements under a “tailored plan” that is approved by the BOEM and would require securing phased in compliance in three approximately equal installments during a one-year period from the date of the BOEM approval of the tailored plan.  Additional security for sole liability properties (those leases, ROWs or RUEs where there are no co-lessees or other grant holders or prior interest holders who may be liable to the BOEM) may not be phased in.

In July 2016, the BOEM issued an implementation timeline with respect to NTL #2016-N01, setting forth a timeline for lessees to submit a self-insurance request, for the BOEM to send out proposal letters outlining required additional security, for the BOEM to send out the order letters, for lessees to submit a tailored plan and for lessees to provide additional security.  Implementation of this new NTL could result in us having to obtain additional bonds or other financial assurances and having to post collateral to obtain such additional bonds or other financial assurances.  

Since the new NTL went into effect in September 2016, we have received from the BOEM “self-insurance” letters confirming that we do not qualify to self-insure a portion of any additional financial assurance, as well as “proposal” letters outlining what additional security the BOEM proposes to require from us and other parties liable for lease, ROW, and RUE decommissioning obligations.  We are reviewing these proposal letters for accuracy.  We have also submitted a revised proposed tailored plan of compliance to the BOEM that we believe to be consistent with a tailored arrangement under NTL #2016-N01.     

Surety Bond Collateral.  Some of the sureties under our existing supplemental surety bonds have requested collateral from us, and may request additional collateral from us, which could be significant and could impact our liquidity.  In addition, pursuant to the terms of our agreements with various sureties under our existing bonds or under any additional bonds we may obtain, we are required to post collateral at any time, on demand, at the surety’s discretion.

   Notification by ONRR of Fine for Non-compliance.  In December 2013 and January 2014, we were notified by the Office of Natural Resources Revenue (“ONRR”) of an underpayment of royalties on certain Federal offshore oil and gas leases that cumulatively approximated $30,000 over several years, which represents 0.0045% of royalty payments paid by us during the same period of the underpayment.  In March 2014, we received notice from the ONRR of a statutory fine of $2.3 million (subsequently reduced to approximately $1.1 million) relative to such underpayment.  We believe the fine is excessive considering the circumstances and in relation to the amount of underpayment.  On April 23, 2014, we filed a request for a hearing on the record and a general denial of the ONRR’s allegations contained in the notice.  We intend to contest the fine to the fullest extent possible.  A hearing on this matter was held with an Administrative Law Judge in August 2016.  A decision on this case has been deferred until January 2017 at the earliest.  The ultimate resolution may result in a waiver of the fine, a reduction of the fine, or payment of the full amount plus interest covering several years.  As no amount has been determined as more likely than any other within the range of possible resolutions, no amount has been accrued as of September 30, 2016 or December 31, 2015.        

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Apache Lawsuit.   On December 15, 2014, Apache Corporation (“Apache”) filed a lawsuit against W&T Offshore, Inc., alleging that W&T breached the joint operating agreement (“JOA” or “contract”) related to the abandonment of deepwater wells in the Mississippi Canyon area of the Gulf of Mexico.  That lawsuit, styled Apache Corporation v. W&T Offshore, Inc., is currently pending in the United States District Court for the Southern District of Texas.  Apache contends that W&T has failed to pay its proportional share of the costs associated with plugging and abandoning three wells that are subject to the JOA.  We contend that the costs incurred by Apache are excessive and unreasonable.  Apache seeks an award of actual damages, interest, court costs, and attorneys’ fees.  In February 2015, we made a payment to Apache for our net share of the amount that we believe was reasonable to plug and abandon the wells.  Our estimate of the potential exposure ranges from zero to $47.2 million (which is the amount claimed by Apache as of September 30, 2016).  Such amount excludes potential interest, court costs and attorneys’ fees.  See Note 12 for events subsequent to September 30, 2016.  

Insurance Claims.  During the fourth quarter of 2012, underwriters of W&T’s excess liability policies (“Excess Policies”) (Indemnity Insurance Company of North America, New York Marine & General Insurance Company, Navigators Insurance Company, XL Specialty Insurance Company, National Liability & Fire Insurance Company (“Starr Marine”) and Liberty Mutual Insurance Co.) filed declaratory judgment actions in the United States District Court for the Southern District of Texas (the “District Court”) seeking a determination that our Excess Policies do not cover removal-of-wreck and debris claims arising from Hurricane Ike except to the extent we have first exhausted the limits of our Energy Package (defined as certain insurance policies relating to our oil and gas properties which includes named windstorm coverage) with only removal-of-wreck and debris claims.  The court consolidated the various suits filed by the underwriters.  In January 2013, we filed a motion for summary judgment seeking the court’s determination that such Excess Policies do not require us to exhaust the limits of our Energy Package policies with only removal-of-wreck and debris claims.  In July 2013, the District Court ruled in favor of the underwriters, adopting their position that the Excess Policies cover removal-of-wreck and debris claims only to the extent the limits of our Energy Package policies have been exhausted with removal-of-wreck and debris claims.  We appealed the decision in the United States Court of Appeals for the Fifth Circuit (the “Fifth Circuit”) and, in June 2014, the Fifth Circuit reversed the District Court’s ruling and ruled in our favor.  The underwriters filed three separate briefs requesting a rehearing or a certification to the Texas Supreme Court, all of which the Court denied.  A brief was subsequently filed by one underwriter requesting a rehearing to the District Court of the Fifth Circuit’s decision, which the District Court denied.  Claims of approximately $43 million were filed, of which approximately $1 million was paid under the Energy Package and of which approximately $1 million was paid under our Comprehensive General Liability policy.  One of the underwriters, Liberty Mutual Insurance Co., paid its portion of the Excess Policies (approximately $5 million), in addition to a portion of interest owed.  The other underwriters have not paid, and we filed a lawsuit in September 2014 against these underwriters for amounts owed, interest, attorney fees and damages.  Subsequent to the filing of that lawsuit, Liberty Mutual Insurance Co. paid additional interest and Starr Marine has paid its portion ($5 million) of the first excess liability policy without interest.  The lawsuit includes interest not paid by Starr Marine. The revised estimate of potential reimbursement is approximately $31 million, plus interest, attorney fees and damages, if any.  Removal-of-wreck costs are recorded in Oil and natural gas properties and equipment on the Condensed Consolidated Balance Sheets and recoveries from claims made on these Excess Policies will be recorded as reductions in this line item, which will reduce our future depreciation, depletion, amortization and accretion (“DD&A”) rate.

Royalties.  In 2009, the Company recognized allowable reductions of cash payments for royalties owed to the ONRR for transportation of their deepwater production through our subsea pipeline systems.  In 2010, the ONRR audited the calculations and support related to this usage fee, and in 2010, we were notified that the ONRR had disallowed approximately $4.7 million of the reductions taken.  We recorded a reduction to other revenue in 2010 to reflect this disallowance; however, we disagree with the position taken by the ONRR.  We filed an appeal with the ONRR, which was denied in May 2014.  On June 17, 2014, we filed an appeal with the IBLA.  W&T’s brief was filed in November 2014 and we expect the briefing before the IBLA to be completed in the second half of 2016.

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

The ONRR has publicly announced an “unbundling” initiative to review the methodology employed by producers in determining the appropriate allowances for transportation and processing costs that are permitted to be deducted in determining royalties under Federal oil and gas leases.  In the second quarter of 2015, pursuant to the initiative, the Company received requests from the ONRR for additional data regarding the Company’s transportation and processing allowances on natural gas production that is processed through a specific processing plant.  The Company also received a preliminary determination notice from the ONRR asserting its preliminary determination that the Company’s allocation of certain processing costs and plant fuel use at another processing plant were impermissibly allowed as deductions in the determination of royalties owed under Federal oil and gas leases.  The Company intends to submit a response to the preliminary determination asserting the reasonableness of its own allocation methodology of such costs.  These open ONRR unbundling reviews, and any further similar reviews, could ultimately result in an order for payment of additional royalties under the Company’s Federal oil and gas leases for current and prior periods.  The Company is not able to determine the likelihood or range of any additional royalties or, if and when assessed, whether such amounts would be material.

Notices of Proposed Civil Penalty Assessment.  The Company currently has five open Incidents of Noncompliance (“INCs”) issued by the BSEE, which have not been settled as of the filing of this Form 10-Q.  The INC’s were issued during 2015 and 2016 and relate to five separate offshore locations with occurrence dates ranging from July 2012 to September 2014.  The proposed civil penalties for these INCs total $8.3 million.  W&T has paid one penalty in the amount of $83,000 and the contractor responsible for the activity giving rise to the penalty has agreed to reimburse W&T.  The Company has accrued approximately $1.0 million, which is the Company’s best estimate of the final settlement once all appeals have been exhausted.  The Company’s position is that the proposed civil penalties are excessive given the specific facts and circumstances related to these INCs.      

Iberville School Board Lawsuit.  In August 2013, a citation was issued on behalf of plaintiffs, the State of Louisiana and the Iberville Parish School Board, in their suit against the Company (among others) in the 18^th Judicial District Court for the Parish of Iberville, State of Louisiana.  This case involves claims by the Iberville Parish School Board that this property has allegedly been contaminated or otherwise damaged by certain defendants’ oil and gas exploration and production activities.  The plaintiff’s claims include assessment costs, restoration costs, diminution of property value, punitive damages, and attorney fees and expenses, of which were not quantified in the claim.  The case was set for trial on August 15, 2016, but the trial date has been deferred until early 2017. We cannot currently estimate our potential exposure, if any, related to this lawsuit.  We are currently, and intend to continue vigorously defending this litigation.

Other Claims.  We are a party to various pending or threatened claims and complaints seeking damages or other remedies concerning our commercial operations and other matters in the ordinary course of our business.  In addition, claims or contingencies may arise related to matters occurring prior to our acquisition of properties or related to matters occurring subsequent to our sale of properties.  In certain cases, we have indemnified the sellers of properties we have acquired, and in other cases, we have indemnified the buyers of properties we have sold.  In addition, the BOEM considers all owners of record title and/or operating rights interest in an OCS lease to be jointly and severally liable for the satisfaction of the supplemental bonding obligations and/or decommissioning obligations.  Accordingly, we may be required to satisfy supplemental bonding obligations or decommissioning obligations of a defaulting owner of record title and/or operating rights interest in an OCS lease in which we are (or in some cases were) an owner of record title and/or operating rights interest in the same OCS lease.  We are also subject to federal and state administrative proceedings conducted in the ordinary course of business including matters related to alleged royalty underpayments on certain federal-owned properties.  Although we can give no assurance about the outcome of pending legal and federal or state administrative proceedings and the effect such an outcome may have on us, we believe that any ultimate liability resulting from the outcome of such proceedings, to the extent not otherwise provided for or covered by insurance, will not have a material adverse effect on our consolidated financial position, results of operations or liquidity.

Contingent Liability Recorded.  There were no material expenses recognized related to accrued and settled claims, complaints and fines for the nine months ended September 30, 2016 and 2015.  As of September 30, 2016 and December 31, 2015, we had no material amounts recorded in liabilities for claims, complaints and fines.  

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

12.  Subsequent Events  

Apache Lawsuit. The case Apache Corporation v. W&T Offshore, Inc., described in Note 11, went to the jury on October 28, 2016.  On the same date, the jury made the following findings:

W&T intends to file a motion with the trial court requesting a judgment consistent with the jury’s finding that Apache acted in bad faith thereby causing W&T not to comply with the contract, which W&T asserts bars Apache from recovery for damages under applicable law, and if damages are not barred in their entirety, that any judgment for monetary damages is offset by $17.0 million as determined by the jury.

13.  Supplemental Guarantor Information

Our payment obligations under the Credit Agreement, the 1.5 Lien Term Loan, the Second Lien Term Loan, the Second Lien PIK Toggle Notes, the Third Lien PIK Toggle Notes and the Unsecured Senior Notes (see Note 5) are fully and unconditionally guaranteed by certain of our 100%-owned subsidiaries, including Energy VI and W & T Energy VII, LLC (together, the “Guarantor Subsidiaries”).  W & T Energy VII, LLC does not currently have any active operations or contain any assets.  Guarantees will be released under certain circumstances, including:  

(1) in connection with any sale or other disposition of all or substantially all of the assets of a Guarantor Subsidiary (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary, if the sale or other disposition does not violate the Asset Sales provisions (as such terms are define in certain debt documents);

(2) in connection with any sale or other disposition of the capital stock of such Guarantor Subsidiary to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary of the Company, if the sale or other disposition does not violate the Asset Sales provisions of the indenture and the Guarantor Subsidiary ceases to be a subsidiary of the Company as a result of such sales or disposition;

(3) if such Guarantor Subsidiary is a Restricted Subsidiary and the Company designates such Guarantor Subsidiary as an Unrestricted Subsidiary in accordance with the applicable provisions of certain debt documents;

(4) upon Legal Defeasance or Covenant Defeasance (as such terms are defined in certain debt documents) or upon satisfaction and discharge of the certain debt documents;

(5) upon the liquidation or dissolution of such Guarantor Subsidiary, provided no event of default has occurred and is continuing; or

(6) at such time as such Guarantor Subsidiary is no longer required to be a Guarantor Subsidiary as described in certain debt documents, provided no event of default has occurred and is continuing.

The following condensed consolidating financial information presents the financial condition, results of operations and cash flows of the Parent Company and the Guarantor Subsidiaries, together with consolidating adjustments necessary to present the Company’s results on a consolidated basis.  Transfers of property were made from the Parent Company to the Guarantor Subsidiaries.  As these transfers were transactions between entities under common control, the prior period financial information has been retrospectively adjusted for comparability purposes, as prescribed under authoritative guidance.  None of the adjustments had any effect on the consolidated results for the current or prior periods presented.  

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Condensed Consolidating Balance Sheet as of September 30, 2016

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W&T OFFSHORE, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)

Condensed Consolidating Balance Sheet as of December 31, 2015