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W&T OFFSHORE INC - Quarter Report: 2023 March (Form 10-Q)

Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2023

or

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _______________ to ________________

Commission File Number 1-32414

Graphic

W&T OFFSHORE, INC.

(Exact name of registrant as specified in its charter)

Texas

    

72-1121985

(State or other jurisdiction of incorporation or organization)

(I.R.S. Employer Identification Number)

 

 

5718 Westheimer Road, Suite 700, Houston, Texas

77057-5745

(Address of principal executive offices)

(Zip Code)

Registrant’s telephone number, including area code: (713) 626-8525

Securities registered pursuant to section 12(b) of the Act:

Title of each class

    

Trading Symbol(s)

    

Name of each exchange on which registered

Common Stock, par value $0.00001

 

WTI

 

New York Stock Exchange

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 every interactive data file required to be submitted 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 such files).   Yes      No  

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

Large accelerated filer

    

Accelerated filer

Non-accelerated filer

 

Smaller reporting company

 

 

Emerging growth company

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

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

As of April 30, 2023 there were 146,460,902 shares outstanding of the registrant’s common stock, par value $0.00001, outstanding.

Table of Contents

W&T OFFSHORE, INC. AND SUBSIDIARIES

TABLE OF CONTENTS

 

 

Page

PART I – FINANCIAL INFORMATION

1

 

 

 

Item 1.

Financial Statements

1

 

Condensed Consolidated Balance Sheets as of March 31, 2023 and December 31, 2022

1

 

Condensed Consolidated Statements of Operations for the Three Months Ended March 31, 2023 and 2022

2

 

Condensed Consolidated Statements of Changes in Shareholders’ Deficit for the Three Months Ended March 31, 2023 and 2022

3

 

Condensed Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2023 and 2022

4

 

Notes to Condensed Consolidated Financial Statements

5

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

21

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

34

Item 4.

Controls and Procedures

34

 

 

PART II – OTHER INFORMATION

35

Item 1.

Legal Proceedings

35

Item 1A.

Risk Factors

35

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

35

Item 3.

Defaults Upon Senior Securities

35

Item 4.

Mine Safety Disclosures

35

Item 5.

Other Information

35

Item 6.

Exhibits

35

 

 

SIGNATURE

37

Table of Contents

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

(Unaudited)

March 31, 

December 31, 

    

2023

    

2022

Assets

 

  

 

  

Current assets:

 

  

 

  

Cash and cash equivalents

$

177,389

$

461,357

Restricted cash

4,417

4,417

Receivables:

 

 

Oil and natural gas sales

 

45,525

 

66,146

Joint interest, net

 

17,116

 

14,000

Total receivables

 

62,641

 

80,146

Prepaid expenses and other assets (Note 1)

 

22,483

 

24,343

Total current assets

 

266,930

 

570,263

Oil and natural gas properties and other, net (Note 1)

 

724,025

 

735,215

Restricted deposits for asset retirement obligations

 

21,565

 

21,483

Deferred income taxes

 

52,884

 

57,280

Other assets (Note 1)

 

44,897

 

47,549

Total assets

$

1,110,301

$

1,431,790

Liabilities and Shareholders’ Equity

 

  

 

  

Current liabilities:

 

  

 

  

Accounts payable

$

75,979

$

65,158

Undistributed oil and natural gas proceeds

 

31,678

 

41,934

Advances from joint interest partners

 

3,160

 

3,181

Asset retirement obligations

 

9,859

 

25,359

Accrued liabilities (Note 1)

 

26,215

 

74,041

Current portion of long-term debt, net

30,801

582,249

Income tax payable

 

4,655

 

412

Total current liabilities

 

182,347

 

792,334

Long-term debt (Note 2)

 

  

 

  

Principal

 

381,027

 

114,158

Unamortized debt issuance costs

 

(8,554)

 

(2,970)

Long-term debt, net (Note 2)

 

372,473

 

111,188

Asset retirement obligations, less current portion

 

459,347

 

441,071

Other liabilities (Note 1)

 

41,998

 

59,134

Deferred income taxes

 

72

 

72

Commitments and contingencies (Note 11)

 

19,226

 

20,357

Shareholders’ equity:

 

  

 

  

Preferred stock, $0.00001 par value; 20,000 shares authorized; none issued at March 31, 2023 and December 31, 2022

 

 

Common stock, $0.00001 par value; 200,000 shares authorized; 149,330 issued and 146,461 outstanding at March 31, 2023; 149,002 issued and 146,133 outstanding at December 31, 2022

 

1

 

1

Additional paid-in capital

 

577,787

 

576,588

Retained deficit

 

(518,783)

 

(544,788)

Treasury stock, at cost; 2,869 shares at March 31, 2023 and December 31, 2022

 

(24,167)

 

(24,167)

Total shareholders’ equity

 

34,838

 

7,634

Total liabilities and shareholders’ equity

$

1,110,301

$

1,431,790

See Notes to Condensed Consolidated Financial Statements.

1

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)

Three Months Ended March 31, 

    

2023

    

2022

Revenues:

 

  

 

  

Oil

$

97,000

$

122,702

NGLs

 

7,795

 

13,820

Natural gas

 

24,804

 

51,366

Other

 

2,126

 

3,116

Total revenues

 

131,725

 

191,004

Operating expenses:

 

  

 

  

Lease operating expenses

 

65,186

 

43,411

Gathering, transportation and production taxes

6,136

5,267

Depreciation, depletion, and amortization

 

22,624

 

24,675

Asset retirement obligations accretion

7,510

6,236

General and administrative expenses

 

19,919

 

13,776

Total operating expenses

 

121,375

 

93,365

Operating income

 

10,350

 

97,639

Interest expense, net

 

14,713

 

19,883

Derivative (gain) loss

 

(39,240)

 

79,997

Other expense, net

 

233

 

905

Income (loss) before income taxes

 

34,644

 

(3,146)

Income tax expense (benefit)

 

8,639

 

(689)

Net income (loss)

$

26,005

$

(2,457)

Net income (loss) per common share:

Basic

$

0.18

$

(0.02)

Diluted

$

0.17

$

(0.02)

Weighted average common shares outstanding:

Basic

146,418

142,942

Diluted

148,726

142,942

See Notes to Condensed Consolidated Financial Statements.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY (DEFICIT)

(In thousands)

(Unaudited)

    

Common Stock

    

Additional

    

    

    

    

    

Total

Outstanding

Paid-In

Retained

Treasury Stock

Shareholders’

    

Shares

    

Value

    

Capital

    

Deficit

    

Shares

    

Value

    

Equity

Balances at December 31, 2022

 

146,133

$

1

$

576,588

$

(544,788)

 

2,869

$

(24,167)

$

7,634

Share-based compensation

 

 

 

1,922

 

 

 

 

1,922

Stock Issued

328

RSUs surrendered for payroll taxes

 

 

 

 

 

(723)

 

 

 

 

 

 

 

(723)

Net income

 

 

 

 

26,005

 

 

 

26,005

Balances at March 31, 2023

 

146,461

$

1

$

577,787

$

(518,783)

 

2,869

$

(24,167)

$

34,838

    

Common Stock

    

Additional

    

    

    

    

    

Total

Outstanding

Paid-In

Retained

Treasury Stock

Shareholders’

    

Shares

    

Value

    

Capital

    

Deficit

    

Shares

    

Value

    

Deficit

Balances at December 31, 2021

 

142,863

$

1

$

552,923

$

(775,937)

 

2,869

$

(24,167)

$

(247,180)

Share-based compensation

 

 

 

520

 

 

 

 

520

Stock Issued

149

RSUs surrendered for payroll taxes

 

 

 

 

 

(268)

 

 

 

 

 

 

 

(268)

Net loss

 

 

 

 

(2,457)

 

 

 

(2,457)

Balances at March 31, 2022

 

143,012

$

1

$

553,175

$

(778,394)

 

2,869

$

(24,167)

$

(249,385)

See Notes to Condensed Consolidated Financial Statements.

3

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W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

Three Months Ended March 31, 

    

2023

    

2022

Operating activities:

 

  

 

  

Net income (loss)

$

26,005

$

(2,457)

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

 

  

 

  

Depreciation, depletion, amortization and accretion

 

30,134

 

30,911

Amortization and write off of debt issuance costs

 

3,249

 

2,594

Share-based compensation

 

1,922

 

520

Derivative (gain) loss

 

(39,240)

 

79,997

Derivative cash (payments) receipts, net

 

(5,328)

 

(30,515)

Deferred income taxes

 

4,396

 

(733)

Changes in operating assets and liabilities:

 

  

 

  

Oil and natural gas receivables

 

20,621

 

(37,774)

Joint interest receivables

 

(3,116)

 

(4,476)

Prepaid expenses and other assets

 

31,489

 

(12,183)

Income tax

 

4,243

 

44

Asset retirement obligation settlements

 

(8,642)

 

(5,492)

Cash advances from JV partners

 

(21)

 

(8,550)

Accounts payable, accrued liabilities and other

 

(42,277)

 

15,651

Net cash provided by operating activities

 

23,435

 

27,537

Investing activities:

 

  

 

  

Investment in oil and natural gas properties and equipment

 

(7,367)

 

(17,439)

Changes in operating assets and liabilities associated with investing activities

 

(5,791)

 

2,630

Acquisition of property interests

 

 

(30,153)

Purchases of furniture, fixtures and other

 

(156)

 

Net cash used in investing activities

 

(13,314)

 

(44,962)

Financing activities:

 

  

 

  

Issuance of 11.75% Senior Second Lien Notes

275,000

Repayments on 9.75% Second Senior Lien Notes

(552,460)

Repayments on Term Loan

 

(9,552)

 

(12,630)

Debt issuance costs

 

(6,354)

 

Other

 

(723)

 

(269)

Net cash used in financing activities

 

(294,089)

 

(12,899)

Decrease in cash and cash equivalents

 

(283,968)

 

(30,324)

Cash and cash equivalents and restricted cash, beginning of period

 

465,774

 

250,216

Cash and cash equivalents and restricted cash, end of period

$

181,806

$

219,892

See Notes to Condensed Consolidated Financial Statements.

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NOTE 1BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Nature of Operations

W&T Offshore, Inc. (with subsidiaries referred to herein as “W&T” or the “Company”) is an independent oil and natural gas producer with substantially all of its operations offshore in the Gulf of Mexico. The Company is active in the exploration, development and acquisition of oil and natural gas properties. Interests in fields, leases, structures and equipment are primarily owned by the Company and its 100% owned subsidiaries, W & T Energy VI, LLC, Aquasition LLC (“A-I, LLC”), and Aquasition II, LLC (“A-II LLC”), and through a proportionately consolidated interest in Monza Energy LLC (“Monza”), as described in more detail in Note 6 – Joint Venture Drilling Program.

Basis of Presentation

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 2022 Annual Report on Form 10-K (the “2022 Annual Report”).

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, the reported amounts of revenues and expenses during the reporting periods and the reported amounts of proved oil and natural gas reserves. Actual results could differ from those estimates.

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Summary of Significant Accounting Policies

Revenue and Accounts ReceivableThe Company records revenues from the sale of oil, natural gas liquids (“NGLs”) and natural gas based on quantities of production sold to purchasers under short-term contracts (less than twelve months) at market prices when delivery to the customer has occurred, title has transferred, prices are fixed and determinable and collection is reasonably assured. Revenue from the sale of crude oil, NGLs and natural gas is recognized when performance obligations under the terms of the respective contracts are satisfied; this generally occurs with the delivery of oil, NGLs and natural gas to the customer. Each unit of product represents a separate performance obligation, therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.

The Company also has receivables related to joint interest arrangements primarily with mid-size oil and gas companies with a substantial majority of the net receivable balance concentrated in less than ten companies. A loss methodology is used to develop the allowance for credit losses on material receivables to estimate the net amount to be collected. The loss methodology uses historical data, current market conditions and forecasts of future economic conditions. The Company’s maximum exposure at any time would be the receivable balance. Joint interest receivables on the Condensed Consolidated Balance Sheets are presented net of allowance for credit losses of $11.9 million and $12.1 million as of March 31, 2023 and December 31, 2022, respectively.

Employee Retention Credit – Under the Consolidated Appropriations Act of 2021, the Company recognized a $2.2 million employee retention credit during the three months ended March 31, 2023, which is included as a credit to General and administrative expenses in the Condensed Consolidated Statement of Operations.

Prepaid Expenses and Other Assets – The amounts recorded are expected to be realized within one year and the major categories are presented in the following table (in thousands):

March 31, 2023

    

December 31, 2022

Derivatives(1) (Note 4)

$

3,482

$

4,954

Unamortized insurance/bond premiums

 

7,168

 

6,046

Prepaid deposits related to royalties

 

7,622

 

9,139

Prepayments to vendors

 

1,837

 

1,767

Prepayments to joint interest partners

1,708

1,717

Debt issue costs

640

687

Other

 

26

 

33

Prepaid expenses and other assets

$

22,483

$

24,343

(1)

Includes closed contracts which have not yet settled.

Oil and Natural Gas Properties and Other, Net – Oil and natural gas properties and equipment are recorded at cost using the full cost method. There were no amounts excluded from amortization as of the dates presented in the following table (in thousands):

March 31, 2023

    

December 31, 2022

Oil and natural gas properties and equipment

$

8,824,682

$

8,813,404

Furniture, fixtures and other

 

21,071

 

20,915

Total property and equipment

 

8,845,753

 

8,834,319

Less: Accumulated depreciation, depletion, amortization and impairment

 

(8,121,728)

 

(8,099,104)

Oil and natural gas properties and other, net

$

724,025

$

735,215

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Other Assets (long-term) – The major categories are presented in the following table (in thousands):

March 31, 2023

    

December 31, 2022

Right-of-Use assets

$

10,279

$

10,364

Investment in White Cap, LLC

 

2,565

 

2,453

Proportional consolidation of Monza (Note 6)

 

11,233

 

9,321

Derivatives(1) (Note 4)

 

19,433

 

23,236

Other

 

1,387

 

2,175

Total other assets (long-term)

$

44,897

$

47,549

(1)

Includes open contracts.

Accrued Liabilities – The major categories are presented in the following table (in thousands):

March 31, 2023

    

December 31, 2022

Accrued interest

$

5,750

$

8,967

Accrued salaries/payroll taxes/benefits

 

3,421

 

15,097

Litigation accruals

 

105

 

396

Lease liability

 

1,636

 

1,628

Derivatives(1) (Note 4)

 

14,250

 

46,595

Other

 

1,053

 

1,358

Total accrued liabilities

$

26,215

$

74,041

(1)

Includes closed contracts which have not yet settled.

Other Liabilities (long-term) – The major categories are presented in the following table (in thousands):

March 31, 2023

    

December 31, 2022

Dispute related to royalty deductions

$

5,250

$

4,937

Derivatives (Note 4)

 

25,563

 

43,061

Lease liability

 

10,553

 

10,527

Other

 

632

 

609

Total other liabilities (long-term)

$

41,998

$

59,134

At-the-Market Equity Offering – On March 18, 2022, the Company filed a prospectus supplement related to the issuance and sale of up to $100,000,000 of shares of common stock under the Company’s “at-the-market” equity offering program (the “ATM Program”). The designated sales agents will be entitled to a placement fee of up to 3.0% of the gross sales price per share sold. During the three months ended March 31, 2023, the Company did not sell any shares in connection with the ATM Program. During the year ended December 31, 2022, the Company sold an aggregate of 2,971,413 shares for an average price of $5.72 per share in connection with the ATM Program and received proceeds, net of commissions and expenses, of $16.5 million.

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NOTE 2 DEBT

The components comprising the Company’s debt are presented in the following table (in thousands):

March 31, 2023

December 31, 2022

Term Loan:

Principal

$

138,348

$

147,899

Unamortized debt issuance costs

(4,145)

(4,592)

Total Term Loan

 

134,203

 

143,307

Credit Agreement borrowings:

11.75% Senior Second Lien Notes due 2026:

 

 

  

Principal

 

275,000

 

Unamortized debt issuance costs

 

(5,929)

 

Total 11.75% Senior Second Lien Notes due 2026

 

269,071

 

9.75% Senior Second Lien Notes due 2023:

 

 

  

Principal

 

 

552,460

Unamortized debt issuance costs

 

 

(2,330)

Total 9.75% Senior Second Lien Notes due 2023

 

 

550,130

Less current portion, net

(30,801)

(582,249)

Total long-term debt, net

$

372,473

$

111,188

Current Portion of Long-Term Debt, Net

As of March 31, 2023, the current portion of long-term debt of $30.8 million represented principal payments due within one year on the Term Loan (defined below), net of current unamortized debt issuance costs.

Term Loan (Subsidiary Credit Agreement)

On May 19, 2021, A-I LLC and A-II LLC (collectively, the “Subsidiary Borrowers”), both Delaware limited liability companies and indirect, wholly-owned subsidiaries of the Company, entered into a credit agreement (the “Subsidiary Credit Agreement”) providing for a term loan (the “Term Loan”) in an aggregate principal amount equal to $215.0 million. The Term Loan requires quarterly amortization payments which commenced on September 30, 2021. The Term Loan bears interest at a fixed rate of 7.0% per annum and will mature on May 19, 2028.

At that time, in exchange for the net cash proceeds received by the Subsidiary Borrowers from the Term Loan, the Company assigned to (a) A-I LLC all of its interests in certain oil and gas leasehold interests and associated wells and units located in State of Alabama waters and U.S. federal waters in the offshore Gulf of Mexico, Mobile Bay region (such assets, the “Mobile Bay Properties”) and (b) A-II LLC its interest in certain gathering and processing assets located (i) in State of Alabama waters and U.S. federal waters in the offshore Gulf of Mexico, Mobile Bay region and (ii) onshore near Mobile, Alabama, including offshore gathering pipelines, an onshore crude oil treating and sweetening facility, an onshore gathering pipeline, and associated assets (such assets, the “Midstream Assets”).

The Term Loan is non-recourse to the Company and any subsidiaries other than the Subsidiary Borrowers and the subsidiary that owns the equity in the Subsidiary Borrowers, and is secured by the first lien security interests in the equity of the Subsidiary Borrowers and a first lien mortgage security interest and mortgages on certain assets of the Subsidiary Borrowers (the Mobile Bay Properties, defined below). See Note 5 – Subsidiary Borrowers for additional information.

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During the three months ended March 31, 2023, the Company repaid $9.6 million of principal outstanding. As of March 31, 2023, the Company had $138.3 million in principal amount of the Term Loan outstanding.

Credit Agreement

The Company has entered into a Credit Agreement with Calculus Lending, LLC (“Calculus”), a company affiliated with and controlled by W&T’s Chairman, Chief Executive Officer and President, Tracy W. Krohn, as sole lender under the Credit Agreement (as amended from time to time, the “Credit Agreement”). The Credit Agreement currently has a maturity date of January 3, 2024. Alter Domus (US) LLC serves as the administrative agent under the Credit Agreement. The primary terms and covenants associated with the Credit Agreement as of March 31, 2023, are as follows:

$100 million first priority lien secured revolving credit facility, with borrowings limited to a borrowing base of $50.0 million;
Outstanding borrowings accrue interest at SOFR plus 6.0% per annum;
The Company’s ratio of First Lien Debt (as such term is defined in the Credit Agreement) outstanding under the Credit Agreement on the last day of the most recent quarter to EBITDAX (as such term is defined in the Credit Agreement) for the trailing four quarters must not be greater than 2.50 to 1.00 on the last day of any fiscal quarter commencing with the fiscal quarter ended March 31, 2022;
The Company’s ratio of Total Proved PV-10 to First Lien Debt (as such terms are defined in the Credit Agreement) as of the last day of any fiscal quarter commencing with the fiscal quarter ended March 31, 2022, must be equal to or greater than 2.00 to 1.00;
The ratio of the Company and its restricted subsidiaries’ consolidated current assets to consolidated current liabilities (subject in each case to certain exceptions and adjustments as set forth in the Credit Agreement) at the last day of any fiscal quarter must be greater than or equal to 1.00 to 1.00;
As of the last day of any fiscal quarter commencing with the fiscal quarter ended March 31, 2022, the Company and its restricted subsidiaries on a consolidated basis must pass a “Stress Test” to determine whether certain future net revenues from the Company’s and its restricted subsidiaries’ oil and gas properties included in the collateral are sufficient to satisfy the aggregate first lien indebtedness under the Credit Agreement assuming it is 100% funded or fully utilized; and
Certain related party transactions are required to meet certain arm’s length criteria; except in each case as specifically permitted or excluded from the covenant under the Credit Agreement.

Availability under the Credit Agreement is subject to redetermination of the borrowing base that may be requested at the discretion of either the lender or the Company in accordance with the Credit Agreement. Any redetermination by the lender to change the borrowing base will result in a similar change in the availability under the Credit Agreement. The Credit Agreement is secured by a first priority lien on substantially all of the Company’s and its guarantor subsidiaries’ assets, excluding those assets of the Subsidiary Borrowers, which liens were released in the Mobile Bay Transaction (as described in Note 5 – Subsidiary Borrowers).

As of March 31, 2023, there were no borrowings outstanding under the Credit Agreement and no borrowings had been incurred under the Credit Agreement during the three months ended March 31, 2023. As of March 31, 2023 and December 31, 2022, the Company had $4.4 million outstanding in letters of credit which have been cash collateralized.

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11.75% Senior Second Lien Notes due 2026

On January 27, 2023, the Company issued and sold $275 million in aggregate principal amount of its 11.75% Senior Second Lien Notes at par with an interest rate of 11.75% per annum that matures on February 1, 2026 (the “11.75% Senior Second Lien Notes”), which are governed under the terms of an indenture (the “Indenture”). Interest on the 11.75% Senior Second Lien Notes is payable in arrears on February 1 and August 1, commencing August 1, 2023. The 11.75% Senior Second Lien Notes will be recorded at their carrying value consisting of principal and unamortized debt issuance costs. The 11.75% Senior Second Lien Notes are secured by second-priority liens on the same collateral that is secured under the Credit Agreement, which does not include the Mobile Bay Properties and the related Midstream Assets. The estimated annual effective interest rate on the 11.75% Senior Second Lien Notes is 12.4%, which includes amortization of deferred interest costs.

Prior to August 1, 2024, the Company may redeem all or any portion of the 11.75% Senior Second Lien Notes at a redemption price equal to 100% of the principal amount of the outstanding plus accrued and unpaid interest, if any, to the redemption date, plus the “Applicable Premium” (as defined in the Indenture). In addition, prior to August 1, 2024, the Company may, at its option, on one or more occasions redeem up to 35% of the aggregate original principal amount of the 11.75% Senior Second Lien Notes in an amount not greater than the net cash proceeds from certain equity offerings at a redemption price of 111.750% of the principal amount of the outstanding plus accrued and unpaid interest, if any, to the redemption date.

On and after August 1, 2024, the Company may redeem the 11.75% Senior Second Lien Notes, in whole or in part, at redemption prices (expressed as percentages of the principal amount thereof) equal to 105.875% for the 12-month period beginning August 1, 2024, and 100.000% on August 1, 2025 and thereafter, plus accrued and unpaid interest, if any, to the redemption date. The 11.75% Senior Second Lien Notes are guaranteed by the Guarantors.

The 11.75% Senior Second Lien Notes contain covenants that limit or prohibit the Company’s ability and the ability of certain of its subsidiaries to: (i) make investments; (ii) incur additional indebtedness or issue certain types of preferred stock; (iii) create certain liens; (iv) sell assets; (v) enter into agreements that restrict dividends or other payments from the Company’s subsidiaries to the Company; (vi) consolidate, merge or transfer all or substantially all of the assets of the Company; (vii) engage in transactions with affiliates; (viii) pay dividends or make other distributions on capital stock or subordinated indebtedness; and (ix) create subsidiaries that would not be restricted by the covenants of the Indenture. These covenants are subject to important exceptions and qualifications set forth in the Indenture. In addition, most of the above-described covenants will terminate if both S&P Global Ratings, a division of S&P Global Inc., and Moody’s Investors Service, Inc. assign the 11.75% Senior Second Lien Notes an investment grade rating and no default exists with respect to the 11.75% Senior Second Lien Notes.

Redemption of 9.75% Senior Second Lien Notes due 2023

On October 18, 2018, the Company issued $625.0 million of 9.75% Senior Second Lien Notes due 2023 (the “9.75% Senior Second Lien Notes”), which were issued at par with an interest rate of 9.75% per annum that matures on November 1, 2023.

On February 8, 2023, the Company redeemed all of the $552.5 million of aggregate principle outstanding of the 9.75% Senior Second Lien Notes at a redemption price of 100.0%, plus accrued and unpaid interest to the redemption date. The Company used the net proceeds of $270.8 million from the issuance of the 11.75% Senior Second Lien Notes and cash on hand of $296.1 million to fund the redemption.

Covenants

As of March 31, 2023 and for all prior measurement periods presented, the Company was in compliance with all applicable covenants of the Credit Agreement and the Indenture.

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NOTE 3 – FAIR VALUE MEASUREMENTS

Derivative Financial Instruments

Derivative financial instruments are reported in the Condensed Consolidated Balance Sheets using fair value. See Note 4 – Derivative Financial Instruments for additional information on derivative financial instruments. The Company measures the fair value of derivative financial instruments by applying the income approach, using models with inputs that are classified within Level 2 of the valuation hierarchy. The income approach converts expected future cash flows to a present value amount based on market expectations. The inputs used for the fair value measurement of derivative financial instruments are the exercise price, the expiration date, the settlement date, notional quantities, the implied volatility, the discount curve with spreads and published commodity future prices.

The following table presents the fair value of the Company’s derivative financial instruments (in thousands):

March 31, 2023

    

December 31, 2022

Assets:

 

  

 

  

Derivative instruments - current

$

3,482

$

4,954

Derivative instruments - long-term

 

19,433

 

23,236

Liabilities:

 

  

 

  

Derivative instruments - current

 

14,250

 

46,595

Derivative instruments - long-term

 

25,563

 

43,061

Debt Instruments

The following table presents the net value and fair value of the Company’s debt (in thousands):

    

March 31, 2023

    

December 31, 2022

Net Value

    

Fair Value

    

Net Value

    

Fair Value

Liabilities:

 

  

 

  

 

  

 

  

Term Loan

$

134,203

$

131,376

$

143,307

$

139,056

11.75% Senior Second Lien Notes due 2026

269,071

 

270,603

 

 

9.75% Senior Second Lien Notes due 2023

 

 

 

550,130

 

544,902

Total

$

403,274

$

401,979

$

693,437

$

683,958

The fair value of the Term Loan was measured using a discounted cash flows model and current market rates. The fair value of the 11.75% Senior Second Lien Notes and 9.75% Senior Second Lien Notes was measured using quoted prices, although the market is not a highly liquid market. The fair value of debt was classified as Level 2 within the valuation hierarchy.

NOTE 4 — DERIVATIVE FINANCIAL INSTRUMENTS

W&T’s market risk exposure relates primarily to commodity prices. The Company attempts to mitigate a portion of its commodity price risk and stabilize cash flows associated with sales of oil and natural gas production through the use of oil and natural gas swaps, costless collars, sold calls and purchased puts. The Company is exposed to credit loss in the event of nonperformance by the derivative counterparties; however, the Company currently anticipates that the derivative counterparties will be able to fulfill their contractual obligations. The Company is not required to provide additional collateral to the derivative counterparties and does not require collateral from the derivative counterparties.

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W&T has elected not to designate commodity derivative contracts for hedge accounting. Accordingly, commodity derivatives are recorded on the Condensed Consolidated Balance Sheets at fair value with settlements of such contracts, and changes in the unrealized fair value, recorded as Derivative (gain) loss on the Condensed Consolidated Statements of Operations in each period presented. The cash flows of all commodity derivative contracts are included in Net cash provided by operating activities on the Condensed Consolidated Statements of Cash Flows.

The natural gas contracts are based off the Henry Hub prices, which is quoted off the New York Mercantile Exchange (“NYMEX”).

The following table reflects the contracted volumes and weighted average prices under the terms of the Company’s open derivative contracts as of March 31, 2023:

Average

Instrument

Daily

Total

Weighted

Weighted

Weighted

Period

    

Type

    

Volumes

    

Volumes

    

Strike Price

    

Put Price

    

Call Price

Natural Gas - Henry Hub (NYMEX)

(MMbtu)(1)

(MMbtu)(1)

($/MMbtu)(1)

($/MMbtu)(1)

($/MMbtu)(1)

Apr 2023 - Dec 2023

calls

52,740

19,250,000

$

$

$

7.50

Jan 2024 - Dec 2024

calls

65,000

23,790,000

$

$

$

6.13

Jan 2025 - Mar 2025

calls

62,000

5,580,000

$

$

$

5.50

Apr 2023 - Dec 2023(2)

swaps

54,247

19,800,000

$

2.38

$

$

Jan 2024 - Dec 2024(2)

swaps

65,574

24,000,000

$

2.46

$

$

Jan 2025 - Mar 2025(2)

swaps

63,333

5,700,000

$

2.72

$

$

Apr 2025 - Dec 2025(2)

puts

62,182

17,100,000

$

$

2.27

$

Jan 2026 - Dec 2026(2)

puts

55,890

20,400,000

$

$

2.35

$

Jan 2027 - Dec 2027(2)

puts

52,603

19,200,000

$

$

2.37

$

Jan 2028 - Apr 2028(2)

puts

49,587

6,000,000

$

$

2.50

$

(1)

MMbtu – Million British Thermal Units

(2)

These contracts were entered into by the Company’s wholly owned subsidiary, A-I LLC, in conjunction with the Term Loan (see Note 5 – Subsidiary Borrowers).

Financial Statement Presentation

The following fair value of derivative financial instruments amounts were recorded in the Condensed Consolidated Balance Sheets (in thousands):

    

March 31, 2023

    

December 31, 2022

Prepaid expenses and other current assets

$

3,482

$

4,954

Other assets (long-term)

 

19,433

 

23,236

Accrued liabilities

 

14,250

 

46,595

Other liabilities (long-term)

25,563

43,061

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Although the Company has master netting arrangements with its counterparties, the amounts recorded on the Condensed Consolidated Balance Sheets are on a gross basis.

Changes in the fair value and settlements of contracts are recorded on the Condensed Consolidated Statements of Operations as Derivative (gain) loss. The impact of commodity derivative contracts on the Condensed Consolidated Statements of Operations were as follows (in thousands):

Three Months Ended March 31, 

    

2023

    

2022

Realized loss

$

230

$

43,694

Unrealized (gain) loss

(39,470)

36,303

Derivative (gain) loss

$

(39,240)

$

79,997

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

Three Months Ended March 31, 

    

2023

    

2022

Derivative (gain) loss

$

(39,240)

$

79,997

Derivative cash payments, net

(5,328)

(30,515)

NOTE 5 — SUBSIDIARY BORROWERS

On May 19, 2021, the Subsidiary Borrowers, entered into the Subsidiary Credit Agreement providing for the Term Loan in an aggregate principal amount equal to $215.0 million. Proceeds of the Term Loan were used by the Subsidiary Borrowers to (i) fund the acquisition of the Mobile Bay Properties and the Midstream Assets from the Company and (ii) pay fees, commissions and expenses in connection with the transactions contemplated by the Subsidiary Credit Agreement and the other related loan documents, including to enter into certain swap and put derivative contracts described in more detail under Note 4 – Derivative Financial Instruments, of this Quarterly Report on Form 10-Q.

The Subsidiary Borrowers are wholly-owned subsidiaries of the Company; however, the assets of the Subsidiary Borrowers are not available to satisfy the debt or contractual obligations of any other entities, including debt securities or other contractual obligations of the Company, and the Subsidiary Borrowers do not bear any liability for the indebtedness or other contractual obligations of any other entities, and vice versa.

During the year ended December 31, 2022, the Subsidiary Borrowers paid cash distributions to W&T of $30.2 million. During the three months ended March 31, 2023, no distributions were paid.

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Consolidation and Carrying Amounts

The following table presents the amounts recorded by W&T on the Condensed Consolidated Balance Sheets related to the consolidation of the Subsidiary Borrowers and the subsidiary that owns the equity of the Subsidiary Borrowers (in thousands):

March 31, 2023

December 31, 2022

Assets:

 

  

 

  

Cash and cash equivalents

$

17,958

$

21,764

Receivables:

 

  

 

  

Oil and natural gas sales

 

8,753

 

37,344

Joint interest, net

 

(16,790)

 

(5,760)

Prepaid expenses and other assets

 

745

 

417

Oil and natural gas properties and other, net

 

289,139

 

280,649

Other assets

 

9,755

 

8,473

Liabilities:

 

  

 

  

Accounts payable

9,734

27,387

Undistributed oil and natural gas proceeds

 

2,714

 

7,930

Accrued liabilities

 

14,768

 

45,102

Current portion of long-term debt

30,800

32,119

Long-term debt, net

 

103,402

 

111,188

Asset retirement obligations

 

62,845

 

61,138

Other liabilities

 

30,031

 

47,398

The following table presents the amounts recorded by W&T in the Condensed Consolidated Statement of Operations related to the consolidation of the operations of the Subsidiary Borrowers and the subsidiary that owns the equity of the Subsidiary Borrowers (in thousands):

Three Months Ended March 31,

2023

2022

Total revenues

$

21,123

$

47,515

Total operating expenses

 

20,047

 

14,800

Interest expense, net

 

2,812

 

4,778

Derivative (gain) loss

 

(46,377)

 

96,158

NOTE 6 — JOINT VENTURE DRILLING PROGRAM

In March 2018, W&T and two other initial members formed and initially funded Monza, which jointly participates with the Company in the exploration, drilling and development of certain drilling projects (the “Joint Venture Drilling Program”) in the Gulf of Mexico. Subsequent to the initial closing, additional investors joined as members of Monza during 2018 and total commitments by all members, including W&T’s commitment to fund its retained interest in Monza projects held outside of Monza, was $361.4 million. W&T contributed 88.94% of its working interest in certain identified undeveloped drilling projects to Monza and retained 11.06% of its working interest. The Joint Venture Drilling Program is structured so that W&T initially receives an aggregate of 30.0% of the revenues less expenses, through the direct ownership from the retained working interest in the Monza projects and the Company’s indirect interest through its interest in Monza, for contributing 20.0% of the estimated total well costs plus associated leases and providing access to available infrastructure at agreed-upon rates. Any exceptions to this structure are approved by the Monza board of directors.

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The members of Monza are third-party investors, W&T and an entity owned and controlled by Tracy W. Krohn, the Company’s Chief Executive Officer and President. The entity affiliated with the Company’s CEO invested as a minority investor on the same terms and conditions as the third-party investors, and its investment is limited to 4.5% of total invested capital within Monza, and made a capital commitment to Monza of $14.5 million.

Monza is an entity separate from any other entity with its own separate creditors who will be entitled, upon its liquidation, to be satisfied out of Monza’s assets prior to any value in Monza becoming available to holders of its equity. The assets of Monza are not available to pay creditors of the Company and its affiliates.

Through March 31, 2023, ten wells have been completed since the inception of the Joint Venture Drilling Program. W&T is the operator for eight of the ten wells completed through March 31, 2023.

Since inception through March 31, 2023, members of Monza made partner capital contributions, including W&T’s contributions of working interest in the drilling projects, to Monza totaling $302.4 million and received cash distributions totaling $185.7 million. Since inception through March 31, 2023, W&T made total capital contributions, including the contributions of working interest in the drilling projects, to Monza totaling $68.2 million and received cash distributions totaling $40.0 million.

Consolidation and Carrying Amounts

W&T’s interest in Monza is considered to be a variable interest that is proportionally consolidated. Through March 31, 2023, there have been no events or changes that would cause a redetermination of the variable interest status. W&T does not fully consolidate Monza because the Company is not considered the primary beneficiary of Monza.

The following table presents the amounts recorded by W&T on the Condensed Consolidated Balance Sheets related to the consolidation of the proportional interest in Monza’s operations (in thousands):

March 31, 2023

December 31, 2022

Working capital

$

818

$

2,515

Oil and natural gas properties and other, net

 

35,761

 

37,260

Asset retirement obligations

485

467

Other assets

 

11,233

 

11,571

As required, W&T may call on Monza to provide cash to fund its portion of certain Joint Venture Drilling Program projects in advance of capital expenditure spending, and the unused balances as of March 31, 2023 and December 31, 2022 were $2.9 million and $2.9 million, respectively, which are included in the Condensed Consolidated Balance Sheets in Advances from joint interest partners.

The following table presents the amounts recorded by W&T in the Condensed Consolidated Statement of Operations related to the consolidation of the proportional interest in Monza’s operations (in thousands):

Three Months Ended March 31, 

2023

2022

Total revenues

$

3,155

$

6,542

Total operating expenses

 

2,484

 

3,254

Interest income

 

59

 

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NOTE 7 ASSET RETIREMENT OBLIGATIONS

AROs represent the estimated present value of the amount incurred to plug, abandon and remediate the Company’s properties at the end of their productive lives. A summary of the changes to ARO is as follows (in thousands):

Three Months Ended March 31, 

    

2023

Asset retirement obligations, beginning of period

$

466,430

Liabilities settled

 

(8,642)

Accretion expense

 

7,510

Liabilities incurred

110

Revisions of estimated liabilities

 

3,798

Asset retirement obligations, end of period

469,206

Less: Current portion

 

(9,859)

Long-term

$

459,347

NOTE 8 SHARE-BASED AWARDS AND CASH BASED AWARDS

The W&T Offshore, Inc. Amended and Restated Incentive Compensation Plan (as amended from time to time, the “Plan”) was approved by the Company’s shareholders in 2010. Under the Plan, the Company may issue, subject to the approval of the Board of Directors, stock options, stock appreciation rights, restricted stock, restricted stock units, stock awards, dividend equivalents, other stock-based awards, performance units or shares, cash awards, substitute awards or any combination of the foregoing to employees and consultants.

Share-Based Awards to Employees

Restricted Stock Units (“RSUs”) –RSUs outstanding as of March 31, 2023 relate to the 2022 and 2021 grants.

A summary of activity related to RSUs during the three months ended March 31, 2023 is as follows:

Weighted

    

    

Average

Restricted

Grant Date Fair

Stock Units

Value Per Unit

Nonvested, beginning of period

1,221,461

$

5.76

Granted

 

66,290

 

6.06

Vested

 

(470,750)

 

5.07

Forfeited

 

(32,019)

 

5.95

Nonvested, end of period

 

784,982

6.19

Performance Share Units (“PSUs”) – PSUs are RSU awards subject to performance criteria. PSUs outstanding as of March 31, 2023 relate to the 2022 and 2021 grants. No PSUs were granted during the three months ended March 31, 2023.

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Share-Based Awards to Non-Employee Directors

The W&T Offshore, Inc. 2004 Directors Compensation Plan (as amended from time to time) (the “Director Plan”) was initially approved by the Company’s shareholders in 2004 and an amendment to the Director Plan was approved by the Company’s shareholders in 2020. Under the Director Plan, the Company may issue, subject to the approval of the Board of Directors, stock options and restricted shares. There was no activity related to the Restricted Shares granted pursuant to the Director Plan during the three months ended March 31, 2023. Restricted Shares outstanding as of March 31, 2023 relate to the 2022 grants to non-employee directors.

Share-Based Compensation Expense

Compensation costs for share-based payments are recognized over the requisite service period. A summary of compensation expense under share-based payment arrangements is as follows (in thousands):

Three Months Ended March 31, 

    

2023

    

2022

Restricted stock units

$

498

$

251

Performance share units

1,371

205

Restricted Shares

 

53

 

64

Total

$

1,922

$

520

Cash-Based Incentive Compensation

In addition to share-based compensation, short-term cash-based incentive awards were granted under the Plan to all eligible employees during 2022. The short-term cash-based incentive awards granted in 2022 were paid in March 2023. No cash-based incentive awards were granted during the three months ended March 31, 2023.

During June 2021, the Company granted long-term, cash-based awards (the “2021 Cash Awards”) subject to the same performance-based criteria as the 2021 PSU grants. The 2021 Cash Awards are eligible to vest based on continued employment through October 1, 2023.

Share-Based Awards and Cash-Based Awards Compensation Expense

A summary of compensation expense related to share-based awards and cash-based awards is as follows (in thousands):

Three Months Ended March 31, 

    

2023

    

2022

Share-based compensation included in:

  

  

General and administrative expenses

$

1,922

$

520

Cash-based incentive compensation included in:

 

  

 

  

Lease operating expense(1)

 

1,248

 

255

General and administrative expenses(1)

 

5,970

 

1,957

Total charged to operating income (loss)

$

9,140

$

2,732

(1)Includes adjustments of accruals to actual payments.

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NOTE 9 INCOME TAXES

Tax Expense (Benefit) and Tax Rate

For the three months ended March 31, 2023, the Company recognized income tax expense of $8.6 million for an effective tax rate of 25.0%. For the three months ended March 31, 2022 the Company recognized income tax benefit of $0.7 million for an effective tax rate of 21.9%.

For the three months ended March 31, 2023 and 2022, the Company’s effective tax rate differed from the statutory Federal tax rate primarily by the impact of state income taxes and adjustments to the valuation allowance.

Valuation Allowance

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 assessing the need for a valuation allowance on deferred tax assets, the Company considers whether it is more likely than not that some portion or all of them will not be realized.

As of March 31, 2023, and December 31, 2022, the valuation allowance was $17.9 million and $15.3 million, respectively, and relates primarily to state net operating losses and the disallowed interest expense limitation carryover.

Income Taxes Receivable, Refunds and Payments

As of March 31, 2023 and December 31, 2022, the Company did not have any outstanding current income taxes receivable. During the three months ended March 31, 2023 and March 31, 2022 the Company did not receive any income tax refunds or make any income tax payments of significance.

The tax years 2019 through 2022 remain open to examination by the tax jurisdictions to which the Company is subject.

NOTE 10 — EARNINGS PER SHARE

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

Three Months Ended March 31, 

    

2023

    

2022

Net income (loss)

$

26,005

$

(2,457)

Weighted average common shares outstanding - basic

 

146,418

 

142,942

Dilutive effect of securities

2,308

Weighted average common shares outstanding - diluted

148,726

142,942

Earnings per common share:

Basic

$

0.18

$

(0.02)

Diluted

0.17

(0.02)

Shares excluded due to being anti-dilutive (weighted average)

717

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NOTE 11 CONTINGENCIES

Appeal with the Office of Natural Resources Revenue (“ONRR”) – In 2009, W&T recognized allowable reductions of cash payments for royalties owed to the ONRR for transportation of their deepwater production through subsea pipeline systems owned by the Company. In 2010, the ONRR audited calculations and support related to this usage fee, and in 2010, ONRR notified the Company that they had disallowed approximately $4.7 million of the reductions taken. The Company recorded a reduction to other revenue in 2010 to reflect this disallowance with the offset to a liability reserve; however, the Company disagrees with the position taken by the ONRR. W&T filed an appeal with the ONRR, which ultimately led to the Company posting a bond in the amount of $7.2 million and cash collateral of $6.9 million with the surety in order to appeal the Interior Board of Land Appeals decision. The cash collateral held by the surety was subsequently returned to the Company during the first quarter of 2020. The Company has continued to pursue its legal rights and, at present, the case is in front of the U.S. District Court for the Eastern District of Louisiana where both parties have filed cross-motions for summary judgment and opposition briefs. W&T has filed a Reply in support of its Motion for Summary Judgment and the government has in turn filed its Reply brief. With briefing now completed, the Company is waiting for the district court’s ruling on the merits. In compliance with the ONRR’s request for W&T to periodically increase the surety posted in the appeal to cover pre- and post-judgement interest, the sum of the bond posted is $8.9 million as of March 31, 2023.

Civil Penalties – In January 2021, W&T executed a Settlement Agreement with the Bureau of Safety and Environmental Enforcement (“BSEE”) which resolved nine pending civil penalties issued by BSEE. The civil penalties pertained to Incidents of Non-Compliance (“INC”) issued by BSEE alleging regulatory non-compliance at separate offshore locations on various dates between July 2012 and January 2018, with the proposed civil penalty amounts totaling $7.7 million. Under the Settlement Agreement, W&T agreed to pay a total of $720,000 in three annual installments. The first, second and final installments were paid in March 2021, March 2022 and February 2023, respectively

Contingent Decommissioning Obligations – The Company may be subject to retained liabilities with respect to certain divested property interests by operation of law. Certain counterparties in past divestiture transactions or third parties in existing leases that have filed for bankruptcy protection or undergone associated reorganizations may not be able to perform required abandonment obligations. Due to operation of law, W&T may be required to assume decommissioning obligations for those interests. The Company may be held jointly and severally liable for the decommissioning of various facilities and related wells. W&T no longer owns these assets nor are they related to current operations.

During 2021, as a result of the declaration of bankruptcy by a third party that is the indirect successor in title to certain offshore interests that were previously divested by the Company, W&T recorded an initial contingent loss accrual of $4.5 million related to the anticipated decommissioning obligations, which was reflected in Other expense (income), net on the Condensed Consolidated Statements of Operations in the period recorded. The Company reassessed the recorded contingent loss related to the anticipated decommissioning obligations throughout 2022, and as of December 31, 2022, the total loss contingency recorded was $20.4 million. The additional $15.9 million recorded in 2022 was reflected in Other expense (income), net on the Condensed Consolidated Statements of Operations in the period recorded. During the three months ended March 31, 2023, the Company incurred $1.2 million in costs related to these decommissioning obligations and reduced the liability accordingly. As of March 31, 2023, the remaining loss contingency recorded related to the anticipated decommissioning obligations was $19.2 million.

Although it is reasonably possible that the Company could receive additional state or federal decommissioning orders in the future or be notified of defaulting third parties in existing leases, the Company cannot predict with certainty, if, how or when such orders or notices will be resolved or estimate a possible loss or range of loss that may result from such orders. However, the Company could incur judgments, enter into settlements or revise the Company’s opinion regarding the outcome of certain notices or matters, and such developments could have a material adverse effect on the Company’s results of operations in the period in which the amounts are accrued and the Company’s cash flows in the period in which the amounts are paid. To the extent that the Company does incur costs associated with these properties in future periods, W&T intends to seek contribution from other parties that owned an interest in the facilities.

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Other Claims – W&T is a party to various pending or threatened claims and complaints seeking damages or other remedies concerning commercial operations and other matters in the ordinary course of its business. In addition, claims or contingencies may arise related to matters occurring prior to the Company’s acquisition of properties or related to matters occurring subsequent to the Company’s sale of properties. In certain cases, W&T has indemnified the sellers of properties acquired, and in other cases, W&T has indemnified the buyers of properties sold. The Company is 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 W&T can give no assurance about the outcome of pending legal and federal or state administrative proceedings and the effect such an outcome may have, the Company believes 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 the consolidated financial position, results of operations or liquidity of the Company.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read in conjunction with our unaudited Condensed Consolidated Financial Statements and the notes to those financial statements included in Part I, Item 1 of this Quarterly Report, as well as our audited Consolidated Financial Statements and the notes thereto in our Annual Report on Form 10-K for the year ended December 31, 2022 (the “2022 Annual Report”) and the related Management’s Discussion and Analysis of Financial Condition and the Results of Operations included in Part II, Item 7 of our 2022 Annual Report. Unless otherwise indicated or the context otherwise requires, references in this Quarterly Report to “us,” “we,” “our,” “W&T” or the “Company” are to W&T Offshore, Inc. and its wholly owned subsidiaries.

Cautionary Note Regarding Forward-Looking Statements

The information in this Quarterly Report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical fact included in this Quarterly Report, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. These forward-looking statements are based on certain assumptions and analyses made by us in light of our experience and perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate under the circumstances. Although we believe that these forward-looking statements are based upon reasonable assumptions, they are subject to several risks and uncertainties and are made in light of information currently available to us. If the risks or uncertainties materialize or the assumptions prove incorrect, our results may differ materially from those expressed or implied by such forward-looking statements and assumptions. When used in this Quarterly Report, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “forecast,” “may,” “objective,” “plan,” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We assume no obligation, nor do we intend, to update these forward-looking statements, unless required by law.

The information included in this Quarterly Report includes forward-looking statements that involve risks and uncertainties that could materially affect our expected results of operations, liquidity, cash flows and business prospects. Such statements specifically include our expectations as to our future financial position, liquidity, cash flows, results of operations and business strategy, potential acquisition opportunities, other plans and objectives for operations, capital for sustained production levels, expected production and operating costs, reserves, hedging activities, capital expenditures, return of capital, improvement of recovery factors and other guidance. Actual results may differ from anticipated results, sometimes materially, and reported results should not be considered an indication of future performance. For any such forward-looking statement that includes a statement of the assumptions or bases underlying such forward-looking statement, we caution that, while we believe such assumptions or bases to be reasonable and make them in good faith, assumed facts or bases almost always vary from actual results, sometimes materially. Known material risks that may affect our financial condition and results of operations are discussed in Part I, Item 1A, Risk Factors, and market risks are discussed in Part II, Item 7A, Quantitative and Qualitative Disclosures About Market Risk, of our 2022 Annual Report, and may be discussed or updated from time to time in subsequent reports filed with the SEC.

Reserve engineering is a process of estimating underground accumulations of crude oil, NGLs and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data, and the price and cost assumptions made by reservoir engineers. In addition, the results of drilling, testing, and production activities, or changes in commodity prices, may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of crude oil, NGLs and natural gas that are ultimately recovered.

All forward-looking statements, expressed or implied, included in this Quarterly Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue.

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Overview

We are an independent oil and natural gas producer, active in the exploration, development and acquisition of oil and natural gas properties in the Gulf of Mexico. As of March 31, 2023, we hold working interests in 47 offshore fields in federal and state waters (46 fields producing and 1 field capable of producing, which include 39 fields in federal waters and 8 in state waters). We currently have under lease approximately 625,000 gross acres (457,000 net acres) spanning across the outer continental shelf (“OCS”) off the coasts of Louisiana, Texas, Mississippi and Alabama, with approximately 8,000 gross acres in Alabama state waters, 457,500 gross acres on the conventional shelf and approximately 159,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. Our interests in fields, leases, structures and equipment are primarily owned by W&T Offshore, Inc. and our wholly-owned subsidiaries, Aquasition LLC, Aquasition II LLC and, W & T Energy VI, LLC, each of which are Delaware limited liability companies, and through our proportionately consolidated interest in Monza, as described in more detail in Financial Statements – Note 6 – Joint Venture Drilling Program under Part I, Item 1 in this Quarterly Report.

Known Trends and Uncertainties

Volatility in Oil, NGL and Natural Gas Prices – Our financial condition, cash flow and results of operations are significantly affected by the volume of our crude oil, NGLs and natural gas production and the prices that we receive for such production. Our realized sales prices received for our crude oil, NGLs and natural gas production are affected by many factors outside of our control, including changes in market supply and demand, which are impacted by weather conditions, pipeline capacity constraints, inventory storage levels, domestic production activities and political issues, and international geopolitical and economic events. 

A high level of uncertainty remains regarding the volatility of energy supply and demand. In early April 2023, the Organization of the Petroleum Exporting Countries (“OPEC”) and Russia (together with OPEC, collectively “OPEC Plus”) announced a production cut of approximately 1.2 million barrels per day. These production cuts were in addition to Russia’s production cut of 0.5 million barrels per day announced in March 2023. This brings the total volume of cuts by OPEC Plus to over 3.6 million barrels per day since October 2022. These shifts in OPEC Plus production levels as well as the Russia-Ukraine war and related sanctions, which began in the first quarter of 2022, and continuing impact of the COVID-19 global public health crisis, continue to contribute to a high level of uncertainty surrounding energy supply and demand, putting additional pressure on commodity prices. As a result, governmental authorities have implemented, and may continue to implement, measures to address rising crude oil prices, including releasing emergency oil reserves.

The U.S. Energy Information Administration (“EIA”) published its latest Short-Term Energy Outlook on April 12, 2023. WTI crude oil prices and NYMEX Henry Hub natural gas prices have decreased following the surge in prices during the first quarter of 2023, closing the first quarter at $75.68 per barrel and $2.10 per Mcf, respectively. Prior to the OPEC Plus announcement, crude oil prices were generally decreasing in response to the overall indications of slowing global economic growth. Oil spot prices increased in the immediate aftermath of OPEC Plus’s announcement, and the EIA expects the WTI spot price average to increase to $80.00 per barrel during the second quarter of 2023 as compared to the first quarter 2023 average of $75.93 per barrel. The EIA also expects the Henry Hub spot price to remain relatively flat as compared to the first quarter 2023 average of $2.64 per Mcf.

Rising Interest Rates and Inflation of Cost of Goods, Services and Personnel Due to the cyclical nature of the oil and gas industry, fluctuating demand for oilfield goods and services can put pressure on the pricing structure within our industry. As commodity prices rise, the cost of oilfield goods and services generally also increase, while during periods of commodity price declines, oilfield costs typically lag and do not adjust downward as fast as oil prices do. Continued inflationary pressures and increased commodity may also result in increases to the costs of our oilfield goods, services and personnel, which would in turn cause our capital expenditures and operating costs to rise.

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The United States has experienced a rise in inflation since October 2021. The annual rate of inflation in the United States was measured at 5.0% in March 2023 by the Consumer Price Index. This is down from the June 2022 peak of 9.1%. While currently on the decline, the annual inflation rate remains at its highest level since the early 1980s. In addition, the Federal Reserve has tightened monetary policy by approving a series of increases to the Federal Funds Rate. On May 3, 2023, the Federal Reserve increased the Federal Funds Rate by another 0.25 percentage points, its tenth hike in the last 14 months. This puts the Federal Reserve’s benchmark rate between 5% to 5.25%, up from near zero in March 2022. With this last rate hike, the Federal Reserve has signaled that the current tightening policy is coming to an end. However, if inflation were to continue to rise, they would likely continue to take necessary action to bring inflation down and to ensure price stability, including further rate increases, which could have the effects of raising the cost of capital and depressing economic growth, either or both of which could negatively impact our business.

As a result of these factors, we cannot accurately predict future commodity prices and, therefore, we cannot determine with any degree of certainty what effect increases or decreases in these prices will have on our drilling program, production volumes or revenues.

Bureau of Ocean Energy Management (“BOEM”) Matters – In order to cover the various decommissioning obligations of lessees on the OCS, the BOEM generally requires that lessees post some form of acceptable financial assurance that such obligations will be met, such as surety bonds. The cost of such bonds or other financial assurance can be substantial, and we can provide no assurance that we can continue to obtain bonds or other surety in all cases. As many BOEM regulations are being reviewed by the Department of the Interior, we may be subject to additional financial assurance requirements in the future. As of the filing date of this Quarterly Report, we are in compliance with our financial assurance obligations to the BOEM and have no outstanding BOEM orders related to supplemental financial assurance obligations. We and other offshore Gulf of Mexico producers may, in the ordinary course of business, receive requests or demands in the future for financial assurances from the BOEM.

Surety Bond Collateral – Some of the sureties that provide us surety bonds used for supplemental financial assurance purposes or bonds associated with our appeals of Department of the Interior’s orders or demands have on occasion requested and received collateral from us, and may request additional collateral from us in the future, which could be significant and materially 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. No additional demands were made to us by sureties during the three months ended March 31, 2023 and we do not have surety bond collateral outstanding as of the filing date of this Quarterly Report. The issuance of any additional surety bonds or other security to satisfy future BOEM orders, collateral requests from surety bond providers, and collateral requests from other third parties may require the posting of cash collateral, which may be significant, and may require the creation of escrow accounts.

Results of Operations

Three Months Ended March 31, 2023 Compared to the Three Months Ended March 31, 2022

Revenues

Our revenues are derived from the sale of our oil and natural gas production, as well as the sale of NGLs. Our oil, natural gas and NGL revenues do not include the effects of derivatives, which are reported in Derivative (gain) loss in our Condensed Consolidated Statements of Operations. The following table presents our sources of revenue as a percentage of total revenue:

Three Months Ended March 31, 

2023

    

2022

Oil

73.6

%

64.2

%

NGLs

5.9

%

7.2

%

Natural gas

18.8

%

26.9

%

Other

1.6

%

1.6

%

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The information below provides a discussion of, and an analysis of significant variances in, our oil, natural gas and NGL revenues, production volumes and realized sales prices (which exclude the effect of hedging unless otherwise stated) for the three months ended March 31, 2023 and 2022:

Three Months Ended March 31, 

    

2023

    

2022

    

Change

 

 (In thousands, except realized sales price data)

Revenues:

Oil

$

97,000

$

122,702

$

(25,702)

NGLs

 

7,795

 

13,820

 

(6,025)

Natural gas

 

24,804

 

51,366

 

(26,562)

Other

 

2,126

 

3,116

 

(990)

Total revenues

 

131,725

 

191,004

 

(59,279)

Production Volumes:

 

  

 

  

 

  

Oil (MBbls)

 

1,350

 

1,304

 

46

NGLs (MBbls)

 

294

 

349

 

(55)

Natural gas (MMcf)

 

7,677

 

10,471

 

(2,794)

Total oil equivalent (MBoe)

 

2,924

 

3,398

 

(474)

Average daily equivalent sales (Boe/day)

32,489

37,756

(5,267)

Average realized sales prices:

 

 

 

Oil ($/Bbl)

$

71.85

$

94.10

 

(22.25)

NGLs ($/Bbl)

 

26.51

 

39.60

 

(13.09)

Natural gas ($/Mcf)

 

3.23

 

4.91

 

(1.68)

Oil equivalent ($/Boe)

44.32

55.29

(10.97)

Oil equivalent ($/Boe), including realized commodity derivatives(1)

 

44.24

 

42.57

 

1.67

(1)Excludes the effects of premium amortization. 

Volume measurements not previously defined:

 

 

MBbls — thousand barrels for crude oil, condensate or NGLs

 

Mcf — thousand cubic feet

MBoe — thousand barrels of oil equivalent

MMcf – million cubic feet

Changes in average sales prices (which does not give effect to hedging) and sales volumes caused the following changes to our oil, NGL and natural gas revenues between the three months ended March 31, 2023 and 2022 (in thousands):

Price

    

Volume

Total

Oil

$

(29,972)

$

4,270

$

(25,702)

NGLs

 

(3,862)

(2,163)

 

(6,025)

Natural gas

 

(12,853)

(13,709)

 

(26,562)

$

(46,687)

$

(11,602)

$

(58,289)

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Realized Prices on the Sale of Oil, NGLs and Natural Gas – Our average realized crude oil sales price differs from the WTI benchmark average crude price due primarily to premiums or discounts, crude oil quality adjustments, and volume weighting (collectively referred to as differentials). Crude oil quality adjustments can vary significantly by field as a result of quality and location. All of our crude oil is produced offshore in the Gulf of Mexico and is primarily characterized as Poseidon, Light Louisiana Sweet (“LLS”), and Heavy Louisiana Sweet (“HLS”). Similar to crude oil prices, the differentials for our offshore crude oil have also been volatile in the past. The average differential of WTI versus LLS for the three months ended March 31, 2023 was favorable to the Company and increased on average by approximately $0.27 per barrel, compared to the same period in 2022. The average differential of WTI versus HLS for the three months ended March 31, 2023 was favorable to the Company and decreased on average by approximately $1.31 per barrel, compared to the same period in 2022. The average differential for WTI versus Poseidon was unfavorable to the Company and declined on average by approximately $2.84 per barrel compared to the same period in 2022.

Two major components of our NGLs, ethane and propane, typically make up over 70% of an average NGL barrel. For the three months ended March 31, 2023 compared to the three months ended March 31, 2022, average prices for domestic ethane decreased by 37.7% and average domestic propane prices decreased by 36.8% as measured using a price index for Mount Belvieu. The average prices for normal butane decreased by 30.2% while other domestic NGL components decreased between 26.5% and 27.7% for the three months ended March 31, 2023 compared to the same period in 2022. The change in prices for NGLs is mostly a function of the change in crude oil prices combined with changes in propane supply and demand.

The actual prices we realize from the sale of natural gas differ from the quoted NYMEX Henry Hub price as a result of quality and location differentials. The sales points of our gas production are generally within close proximity to the Henry Hub which creates a minimal differential in the prices we receive for our production versus average Henry Hub prices.

Oil, NGLs, and Natural Gas Volumes – Production volumes decreased by 474 MBoe to 2,924 MBoe in the three months ended March 31, 2023 compared to the same period in 2022, primarily due to shut-ins related to field and well maintenance, primarily at Mobile Bay, as well as production downtime at non-operated fields.

Operating Expenses

The following table presents information regarding costs and expenses and selected average costs and expenses per Boe sold for the periods presented and corresponding changes:

Three Months Ended March 31, 

    

2023

    

2022

    

Change

Operating expenses:

Lease operating expenses

$

65,186

$

43,411

$

21,775

Gathering, transportation and production taxes

6,136

5,267

869

Depreciation, depletion, amortization and accretion

 

30,134

30,911

 

(777)

General and administrative expenses

19,919

13,776

6,143

Total operating expenses

$

121,375

$

93,365

$

28,010

Average per Boe ($/Boe):

 

  

 

  

 

  

Lease operating expenses

$

22.29

$

12.78

$

9.51

Gathering, transportation and production taxes

 

2.10

1.55

 

0.55

DD&A

 

10.31

9.10

 

1.21

G&A expenses

 

6.81

4.05

 

2.76

Operating expenses

$

41.51

$

27.48

$

14.03

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Lease operating expensesLease operating expenses, which include base lease operating expenses, workovers, and facilities maintenance expense, increased $21.8 million to $65.2 million for the three months ended March 31, 2023 compared to $43.4 million for the three months ended March 31, 2022. On a component basis, base lease operating expenses increased $11.3 million, workover expenses increased $2.1 million, facilities maintenance expense increased $8.7 million, and hurricane repairs decreased $0.3 million.

Base lease operating expenses increased due to increased expenses related to the fields acquired during February 2022, increased contract labor, equipment rental, and transportation costs at various fields, and increased insurance expense. The increases in workover expenses and facilities maintenance expenses were due to an increase in projects undertaken, primarily at Mobile Bay. Workovers and facilities maintenance expenses consist of costs associated with major remedial operations on completed wells to restore, maintain or improve production. Since these remedial operations are not regularly scheduled, workover and maintenance expense are not necessarily comparable from period to period. Lastly, during the three months ended March 31, 2022 we incurred $0.3 million in expenses related to repairs associated with hurricanes that we did not incur during the three months ended March 31, 2023.

Gathering, transportation and production taxesGathering, transportation and production taxes increased $0.9 million during the three months ended March 31, 2023 compared to the three months ended March 31, 2022 primarily due to a new transportation contract related to the properties acquired in February 2022.

Depreciation, depletion, amortization and accretion (“DD&A”) – DD&A, which includes accretion for ARO, on a nominal basis decreased $0.8 million for the three months ended March 31, 2023 as compared to the three months ended March 31, 2022.The DD&A rate increased to $10.31 per Boe for the three months ended March 31, 2023 from $9.10 per Boe for the three months ended March 31, 2022. The decreased expense was primarily due to lower production volumes partially offset by the increase in the depreciable base resulting from the property acquisitions which occurred in February 2022 and April 2022 and the related increase in future development costs associated with the acquired properties.

General and administrative expenses (“G&A”)G&A increased $6.1 million, to $19.9 million for the three months ended March 31, 2023 as compared to $13.8 million for the three months ended March 31, 2022. The increase is primarily due to increased incentive compensation expense, payroll costs, and legal expenses. The increase was partially offset by a $2.2 million employee retention credit recorded during the three months ended March 31, 2023. We incurred increased incentive compensation costs related to the higher value of the short-term cash-based incentive compensation awards granted in 2022 as compared to the value of awards granted in 2021 and the higher grant date fair value of RSU and PSU awards granted during 2022 as compared to the value of awards granted in 2021.

Other Income and Expense

The following table presents the components of other income and expense for the periods presented and corresponding changes:

Three Months Ended March 31, 

    

2023

    

2022

    

Change

Other income and expenses:

Derivative (gain) loss

$

(39,240)

$

79,997

$

(119,237)

Interest expense, net

 

14,713

19,883

 

(5,170)

Other expense, net

 

233

905

 

(672)

Income tax expense (benefit)

 

8,639

(689)

 

9,328

Derivative (gain) lossDuring the three months ended March 31, 2023, the $39.2 million derivative gain recorded for crude oil and natural gas derivative contracts consists of $39.4 million of unrealized gain, net from the increase in the fair value of open contracts, partially offset by $0.2 million of realized losses. During the three months ended March 31, 2022, the $80.0 million derivative loss recorded for crude oil and natural gas derivative contracts consisted of $43.7 million in realized losses and $36.3 million of unrealized losses from the decrease in the fair value of open oil and natural gas contracts.

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Unrealized gains or losses on open derivative contracts relate to production for future periods; however, changes in the fair value of all of our open derivative contracts are recorded as a gain or loss on our Condensed Consolidated Statements of Operations at the end of each month. As a result of the derivative contracts we have on our anticipated production volumes through April 2028, we expect these activities to continue to impact net income (loss) based on fluctuations in market prices for natural gas. See Financial Statements – Note 4 – Derivative Financial Instruments under Part I, Item 1 of this Quarterly Report for additional information.

Interest expense, netInterest expense, net, was $14.7 million and $19.9 million for the three months ended March 31, 2023 and 2022, respectively. The decrease of $5.2 million in 2023 is due to the redemption of the 9.75% Senior Second Lien Notes which occurred in February 2023, and lower interest expense on the lower outstanding principal balance of the Term Loan and increased interest income.

Income tax expense (benefit)Income tax expense for the three months ended March 31, 2023 was $8.6 million compared to an income tax benefit of $0.7 million during the three months ended March 31, 2022. For the three months ended March 31, 2023 and 2022, the Company’s income tax expense (benefit) differed from the statutory Federal tax rate primarily by the impact of state income taxes and adjustments to our valuation allowance. The company’s effective tax rate was 25.0% and 21.9% for the three months ended March 31, 2023 and 2022, respectively.

As of March 31, 2023, the valuation allowance on our deferred tax assets was $17.9 million. We continually evaluate the need to maintain a valuation allowance on our deferred tax assets. Any future reduction of a portion or all of the valuation allowance would result in a non-cash income tax benefit in the period the decision occurs. See Financial Statements – Note 9 –Income Taxes under Part I, Item 1 of this Quarterly Report for additional information.

Liquidity and Capital Resources

Liquidity Overview

Our primary liquidity needs are to fund capital and operating expenditures and strategic acquisitions to allow us to replace our oil and natural gas reserves, repay and service outstanding borrowings, operate our properties and satisfy our ARO obligations. We have funded such activities in the past with cash on hand, net cash provided by operating activities, sales of property, securities offerings and bank and other borrowings, and expect to continue to do so in the future.

The primary sources of our liquidity are cash from operating activities and borrowings under our Credit Agreement. As of March 31, 2023, we had $177.4 million cash on hand and $50.0 million available under our Credit Agreement, based on a borrowing base of $50.0 million. We believe our access to the equity markets from our “at-the-market” equity offering program, our reserve based lending currently available under our Credit Agreement, along with our cash position, will provide us with additional liquidity to continue our growth to take advantage of the current commodity environment.

Sources and Uses of Cash

Three Months Ended March 31, 

    

2023

2022

    

Change

(In thousands)

Operating activities

 

$

23,435

$

27,537

$

(4,102)

Investing activities

 

(13,314)

 

(44,962)

 

31,648

Financing activities

 

(294,089)

 

(12,899)

 

(281,190)

Operating activitiesNet cash provided by operating activities decreased $4.1 million for the three months ended March 31, 2023 compared to the corresponding period in 2022. This was primarily due to (i) the $59.3 million decrease in revenues, and (ii) the increase in ARO settlements, which decreased operating cash flows $8.6 million as compared to $5.5 million for the three months ended March 31, 2023 and 2022, respectively. The decrease in revenues was due to a decrease in realized prices for oil, NGLs and natural gas, and to a lesser extent the decrease in production volumes.

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These decreases in operating cash flow were partially offset by (i) a $25.2 million decrease in cash derivative settlement payments during the three months ended March 31, 2023 as compared to the same period in 2022, and (ii) changes in operating assets and liabilities (excluding ARO settlements) which increased operating cash flows by $10.9 million for the three months ended March 31, 2023 as compared to a decrease of $47.3 million for the three months ended March 31, 2022, primarily related to lower oil and natural gas receivables balances due to decreased realized prices.

Investing activitiesNet cash used in investing activities decreased $31.6 million for the three months ended March 31, 2023 compared to the corresponding period in 2022. The decrease was primarily due to the acquisition of properties for $30.2 million during the three months ended March 31, 2022.

Financing activities – During the three months ended March 31, 2023, cash used in financing activities increased by $281.1 million for the three months ended March 31, 2023 compared to the corresponding period in 2022. This was due to the redemption of the $552.5 million principal amount outstanding 9.75% Senior Second Lien Notes on February 8, 2023, which was partially offset by the net cash proceeds of $270.8 million received from the issuance of the 11.75% Senior Second Lien Notes. Additionally, the principal repayments on the Term Loan decreased by $3.1 million.

Derivative Financial InstrumentsFrom time to time, we use various derivative instruments to manage a portion of our exposure to commodity price risk from sales of oil and natural gas. See Financial Statements – Note 4 – Derivative Financial Instruments under Part I, Item 1 of this Quarterly Report for additional information about our derivative activities. The following table summarizes the historical results of our hedging activities:

Three Months Ended March 31, 

2023

2022

Crude Oil ($/Bbl):

  

 

  

Average realized sales price, before the effects of derivative settlements

$

71.85

$

94.10

Effects of realized commodity derivatives

 

 

(16.62)

Average realized sales price, including realized commodity derivatives

$

71.85

$

77.48

Natural Gas ($/Mcf)

 

  

 

  

Average realized sales price, before the effects of derivative settlements

$

3.23

$

4.91

Effects of realized commodity derivatives(1)

 

(0.03)

 

(2.06)

Average realized sales price, including realized commodity derivatives

$

3.20

$

2.85

(1)Excludes the effects of premium amortization.

Income TaxesFor 2023, the Company expects approximately 50% of our income tax expense to be cash taxes. The Company does not have any outstanding current income taxes receivable nor did we make income tax payments during the three months ended March 31, 2023. See Financial Statements – Note 9 –Income Taxes under Part I, Item 1 of this Quarterly Report for additional information.

Employee Retention CreditUnder the Consolidated Appropriations Act of 2021, the Company recognized a $2.2 million Employee Retention Credit during the three months ended March 31, 2023, which is included as a credit to General and administrative expenses in the Condensed Consolidated Statement of Operations.

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Capital Expenditures

The level of our investment in oil and natural gas properties changes from time to time depending on numerous factors, including the prices of crude oil, NGLs and natural gas, acquisition opportunities, available liquidity and the results of our exploration and development activities. The following table presents our capital expenditures for exploration, development and other leasehold costs:

Three Months Ended March 31, 

    

2023

    

2022

 

(In thousands)

Exploration(1)

$

755

$

9,183

Development(1)

 

6,674

 

3,736

Acquisitions of interests

 

 

30,152

Seismic and other

 

(62)

 

4,521

Investments in oil and gas property/equipment – accrual basis

$

7,367

$

47,592

(1)Reported geographically in the subsequent table.

The following table presents our exploration and development capital expenditures geographically in the Gulf of Mexico:

Three Months Ended March 31, 

    

2023

    

2022

 

(In thousands)

Conventional shelf (1)

$

4,868

$

4,296

Deepwater

 

2,561

 

8,623

Exploration and development capital expenditures – accrual basis

$

7,429

$

12,919

(1)Includes exploration and development capital expenditures in Alabama state waters. 

The capital expenditures are included within Oil and natural gas properties and other, net on the Condensed Consolidated Balance Sheets and recorded on an accrual basis. The capital expenditures reported within the Investing activities section of the Condensed Consolidated Statements of Cash Flows include adjustments to report cash payments related to capital expenditures. Our capital expenditures for the three months ended March 31, 2023 were financed by cash flow from operations and cash on hand.

Acquisitions – There were no acquisitions during the three months ended March 31, 2023. During the three months ended March 31, 2022, the Company acquired the working interest and operatorship of certain oil and natural gas producing properties in federal shallow waters in the Gulf of Mexico at Ship Shoal 230, South Marsh Island 27/Vermilion 191, and South Marsh Island 73 fields on February 1, 2022. After normal and customary post-effective date adjustments (including net operating cash flow attributable to the properties from the effective date to the respective close date), cash consideration of approximately $34.0 million was paid to the sellers. The transaction was funded using cash on hand.

Asset Retirement Obligations – Each quarter, we review and revise our ARO estimates. Our ARO estimates as of March 31, 2023 and December 31, 2022 were $469.2 million and $466.4 million, respectively. The decrease is primarily due to ARO liabilities settled. As our ARO estimates are for work to be performed in the future, and in the case of our non-current ARO, extend from one to many years in the future, actual expenditures could be substantially different than our estimates. See Risk Factors, under Part I, Item 1A of our 2022 Annual Report for additional information.

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Drilling Activity

We did not drill any wells in the three months ended March 31, 2023. During the three months ended March 31, 2022, we completed the East Cameron 349 B-1 well (Cota). The Cota well is in the Monza Joint Venture Drilling Program. See Financial Statements – Note 6 –Joint Venture Drilling Program under Part I, Item 1 of this Quarterly Report for additional information.

Debt

Term LoanAs of March 31, 2023, we had $138.3 million of Term Loan principal outstanding. The Term Loan requires quarterly amortization payments, bears interest at a fixed rate of 7% per annum and will mature on May 19, 2028. The Term Loan is non-recourse to the Company and its subsidiaries other than Subsidiary Borrowers and the subsidiary that owns the equity of the Subsidiary Borrowers, and is not secured by any assets other than first lien security interests in the equity in the Subsidiary Borrowers and a first lien mortgage security interest and mortgages on certain assets of Subsidiary Borrowers (the Mobile Bay Properties). See Financial Statements – Note 2 –Debt under Part I, Item 1 of this Quarterly Report for additional information.

Credit Agreement During the three months ended March 31, 2023, we had no borrowings incurred or outstanding under the Credit Agreement.

11.75% Senior Second Lien Notes due 2026On January 27, 2023, we issued and sold $275 million in aggregate principal amount of our 11.75% Senior Second Lien Notes at par with an interest rate of 11.75% per annum that matures on February 1, 2026. The Senior Second Lien Notes are secured by a second-priority lien on all of our assets that are secured under the Credit Agreement. As of March 31, 2023, we had outstanding $275.0 million principal of 11.75% Senior Second Lien Notes. See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

9.75% Senior Second Lien Notes due 2023 – On February 8, 2023, we redeemed all of the 9.75% Senior Second Lien Notes outstanding at a redemption price of 100.000%, plus accrued and unpaid interest to the redemption date. The Company used the net proceeds of $270.8 million from the issuance of the 11.75% Senior Second Lien Notes due 2026 and cash on hand of $296.1 million to fund the redemption. See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

Debt CovenantsThe Term Loan, Credit Agreement, and 11.75 % Senior Second Lien Notes contain financial covenants calculated as of the last day of each fiscal quarter, which include thresholds on financial ratios, as defined in the respective Subsidiary Credit Agreement, Credit Agreement and the Indenture. We were in compliance with all applicable covenants of the Term Loan, Credit Agreement and the Indenture as of and for the period ended March 31, 2023. See Financial Statements – Note 2 – Debt under Part I, Item 1 of this Quarterly Report for additional information.

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The Subsidiary Borrowers

On May 19, 2021, we formed A-I LLC and A-II LLC, both indirect, wholly-owned subsidiaries of W&T Offshore, Inc., through their parent, Aquasition Energy LLC (collectively, the “Aquasition Entities”). Concurrently, A-I LLC and A-II LLC, entered into a credit agreement providing for the Term Loan in an initial aggregate principal amount equal to $215.0 million. Proceeds of the Term Loan were used by A-I LLC and A-II LLC to fund the acquisition of the Mobile Bay Properties and the Midstream Assets, respectively, from the Company. The Term Loan is non-recourse to the Company and any subsidiaries other than the Aquasition Entities and is secured by the first lien security interests in the equity of the Aquasition Entities and a first lien mortgage security interest in the Mobile Bay Properties. See Financial Statements – Note 5 – Subsidiary Borrowers under Part I, Item 1 in this Quarterly Report for additional information.

We designated the Aquasition Entities as unrestricted subsidiaries under the Indenture (the “Unrestricted Subsidiaries”). Having been so designated, the Unrestricted Subsidiaries do not guarantee the 11.75% Senior Second Lien Notes and the liens on the assets sold to the Unrestricted Subsidiaries have been released under the Credit Agreement. The Unrestricted Subsidiaries are not bound by the covenants contained in the Credit Agreement or the Indenture. Under the Subsidiary Credit Agreement and related instruments, assets of the Aquasition Entities may not be available to mortgage or pledge as security to secure new indebtedness of the Company and its other subsidiaries. See Financial Statements – Note 2 – Debt under Part I, Item 1 in this Quarterly Report for additional information.

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Below is consolidating balance sheet information reflecting the elimination of the accounts of our Unrestricted Subsidiaries from our Condensed Consolidated Balance Sheet as of March 31, 2023 (in thousands):

Consolidated
Balance Sheet

Eliminations of Unrestricted Subsidiaries

Consolidated Balance Sheet of restricted subsidiaries

Assets

 

  

 

  

 

  

Current assets:

 

  

 

  

 

  

Cash and cash equivalents

$

177,389

$

(17,958)

$

159,431

Restricted cash

4,417

4,417

Receivables:

 

  

 

  

 

  

Oil and natural gas sales

 

45,525

 

(8,753)

 

36,772

Joint interest, net

 

17,116

 

16,790

 

33,906

Total receivables

 

62,641

 

8,037

 

70,678

Prepaid expenses and other assets

 

22,483

 

(745)

 

21,738

Total current assets

 

266,930

 

(10,666)

 

256,264

Oil and natural gas properties and other, net

 

724,025

 

(289,139)

 

434,886

Restricted deposits for asset retirement obligations

 

21,565

 

 

21,565

Deferred income taxes

 

52,884

 

 

52,884

Other assets

 

44,897

 

(9,755)

 

35,142

Total assets

$

1,110,301

$

(309,560)

$

800,741

Liabilities and Shareholders’ Equity (Deficit)

 

  

 

  

 

  

Current liabilities:

 

  

 

  

 

  

Accounts payable

$

79,139

$

(9,734)

$

69,405

Undistributed oil and natural gas proceeds

 

31,678

 

(2,714)

 

28,964

Asset retirement obligations

 

9,859

 

 

9,859

Accrued liabilities

 

26,215

 

(14,768)

 

11,447

Current portion of long-term debt

30,801

(30,800)

1

Income tax payable

 

4,655

 

 

4,655

Total current liabilities

 

182,347

 

(58,016)

 

124,331

Long-term debt

 

  

 

  

 

  

Principal

 

381,027

 

(106,027)

 

275,000

Unamortized debt issuance costs

 

(8,554)

 

2,625

 

(5,929)

Long-term debt, net

 

372,473

 

(103,402)

 

269,071

Asset retirement obligations, less current portion

 

459,347

 

(62,845)

 

396,502

Other liabilities

 

61,223

 

(30,031)

 

31,192

Deferred income taxes

 

72

 

 

72

Common stock

 

2

 

 

2

Shareholders' equity (deficit):

Additional paid-in capital

 

577,787

 

 

577,787

Retained deficit

 

(518,783)

 

(55,266)

 

(574,049)

Treasury stock, at cost

 

(24,167)

 

 

(24,167)

Total shareholders’ equity (deficit)

 

34,839

 

(55,266)

 

(20,427)

Total liabilities and shareholders’ equity (deficit)

$

1,110,301

$

(309,560)

$

800,741

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Below is Consolidating Statement of Operations information reflecting the elimination of the accounts of our Unrestricted Subsidiaries from our Condensed Consolidated Statement of Operations for the three months ended March 31, 2023 (in thousands):

Consolidated Statement of Operations

Eliminations of Unrestricted Subsidiaries

Consolidated Statement of Operations of restricted subsidiaries

Revenues:

Oil

$

97,000

$

(116)

$

96,884

NGLs

 

7,795

 

(3,834)

 

3,961

Natural gas

 

24,804

 

(16,016)

 

8,788

Other

 

2,126

 

(1,157)

 

969

Total revenues

 

131,725

 

(21,123)

 

110,602

Operating expenses:

 

  

 

  

 

  

Lease operating expenses

 

65,186

 

(23,727)

 

41,459

Gathering, transportation and production taxes

6,136

(1,551)

4,585

Depreciation, depletion, amortization and accretion

 

30,134

 

5,553

 

35,687

General and administrative expenses

 

19,919

 

(322)

 

19,597

Total operating expenses

 

121,375

 

(20,047)

 

101,328

Operating income

 

10,350

 

(1,076)

 

9,274

Interest expense, net

 

14,713

 

(2,812)

 

11,901

Derivative (gain) loss

 

(39,240)

 

46,377

 

7,137

Other income, net

 

233

 

 

233

Income (loss) before income taxes

 

34,644

 

(44,641)

 

(9,997)

Income tax expense

 

8,639

 

 

8,639

Net income (loss)

$

26,005

$

(44,641)

$

(18,636)

The following table presents our produced oil, NGLs and natural gas volumes (net to our interests) from the Subsidiary Borrowers for the periods indicated:

Three Months Ended March 31, 

Three Months Ended March 31, 

Production Volumes:

2023

2022

Oil (MBbls)

 

3

 

4

NGLs (MBbls)

 

150

 

226

Natural gas (MMcf)

 

4,655

 

7,330

Total oil equivalent (MBoe)

 

929

 

1,452

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Contractual Obligations

As of March 31, 2023, there were no long-term drilling rig commitments. Except as disclosed herein, contractual obligations as of March 31, 2023 did not change materially from the disclosures in Management’s Discussion and Analysis of Financial Condition and Results of Operations, under Part II, Item 7 of our 2022 Annual Report.

Critical Accounting Policies and Estimates

We consider accounting policies related to revenue recognition, full cost accounting, impairment of oil and natural gas properties, oil and natural gas reserve quantities, asset retirement obligations, and income taxes as critical accounting policies. These policies include significant estimates made by management using information available at the time the estimates are made. However, these estimates could change materially if different information or assumptions were used.

There have been no changes to our critical accounting policies which are summarized in Management’s Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7 of our 2022 Annual Report.

Recent Accounting Pronouncements

There were no recently issued accounting standards material to us.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Information about the types of market risks for the three months ended March 31, 2023 did not change materially from the disclosures in Quantitative and Qualitative Disclosures About Market Risk under Part II, Item 7A of our 2022 Annual Report. In addition, the information contained herein should be read in conjunction with the related disclosures in our 2022 Annual Report.

Item 4. Controls and Procedures

We have established disclosure controls and procedures designed to ensure that material information required to be disclosed in our reports filed under the Exchange Act is recorded, processed, summarized and reported within the time periods specified by the SEC and that any material information relating to us is accumulated and communicated to our management, including our Chief Executive Officer (“CEO “) and Chief Financial Officer (“CFO”), as appropriate to allow timely decisions regarding required disclosures. In designing and evaluating our disclosure controls and procedures, our management recognizes that controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving desired control objectives. In reaching a reasonable level of assurance, our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

As required by Exchange Act Rule 13a-15(b), our CEO and CFO performed an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of the end of the period covered by this Quarterly Report. Based on that evaluation, our CEO and CFO have each concluded that as of March 31, 2023, our disclosure controls and procedures are effective to ensure that information we are required to disclose in reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that our controls and procedures are designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

During the quarter ended March 31, 2023, there was no change in our internal control over financial reporting that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

Item 1. Legal Proceedings

See Financial Statements – Note 11 – Contingencies under Part I Item 1 of this Quarterly Report for information on various legal proceedings to which we are a party or our properties are subject.

Item 1A. Risk Factors

In addition to the information set forth in this Quarterly Report, investors should carefully consider the risk factors and other cautionary statements included under Part I, Item 1A, Risk Factors, in our 2022 Annual Report, together with all of the other information included in this Quarterly Report, and in our other public filings, which could materially affect our business, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

Notwithstanding the matters discussed herein, there have been no material changes in our risk factors as previously disclosed in Part I, Item 1A, Risk Factors, in our 2022 Annual Report.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

None.

Item 5. Other Information

None.

Item 6. Exhibits

Exhibit
Number

    

Description

 

 

 

3.1

 

Amended and Restated Articles of Incorporation of W&T Offshore, Inc. (Incorporated by reference to Exhibit 3.1 of the Company’s Current Report on Form 8-K, filed February 24, 2006 (File No. 001-32414))

 

 

 

3.2

 

Certificate of Amendment to the Amended and Restated Articles of Incorporation of W&T Offshore, Inc. (Incorporated by reference to Exhibit 3.3 of the Company’s Quarterly Report on Form 10-Q, filed July 31, 2012 (File No. 001-32414))

 

 

 

3.3

 

Certificate of Amendment to the Amended and Restated Articles of Incorporation of W&T Offshore, Inc., dated as of September 6, 2016. (Incorporated by reference to Exhibit 3.1 of the Company’s Current Report on Form 8-K, filed September 6, 2016 (File No. 001-32414))

 

 

 

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3.4

Fourth Amended and Restated Bylaws of W&T Offshore, Inc. (Incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K, filed April 26, 2023 (File No. 001-32414))

4.1†

Indenture, dated as of January 27, 2023, by and among W&T Offshore, Inc., the guarantors party thereto and Wilmington Trust, National Association, as trustee (Incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K, filed January 30, 2023 (File No. 001-32414))

4.2

Form of 11.750% Senior Second Lien Note due 2026 (Incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K, filed January 30, 2023 (File No. 001-32414))

10.1

Priority Confirmation Joinder, dated as of January 27, 2023, to the Intercreditor Agreement, by Wilmington Trust, National Association, as Second Lien Collateral Trustee (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K, filed January 30, 2023 (File No. 001-32414))

31.1*

 

Section 302 Certification of Chief Executive Officer

 

 

 

31.2*

 

Section 302 Certification of Chief Financial Officer

 

 

 

32.1**

 

Section 906 Certification of Chief Executive Officer and Chief Financial Officer

 

 

 

101.INS*

 

Inline XBRL Instance Document

 

 

 

101.SCH*

 

Inline XBRL Schema Document

 

 

 

101.CAL*

 

Inline XBRL Calculation Linkbase Document

 

 

 

101.DEF*

 

Inline XBRL Definition Linkbase Document

 

 

 

101.LAB*

 

Inline XBRL Label Linkbase Document

 

 

 

101.PRE*

 

Inline XBRL Presentation Linkbase Document

 

 

 

104*

 

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

*

Filed herewith.

**

Furnished herewith.

Certain schedules and similar attachments to this agreement have been omitted pursuant to Item 601(a)(5) of Regulation S-K. The Company hereby undertakes to furnish a supplemental copy of each such omitted schedule or similar attachment to the SEC upon request.

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SIGNATURE

Pursuant to the requirements of Section 13 or 15(d) of the Exchange Act, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on May 9, 2023.

W&T OFFSHORE, INC.

 

By:

/s/ Janet Yang

 

Janet Yang

 

Executive Vice President and Chief Financial Officer
(Principal Financial Officer), duly authorized to sign on behalf of the registrant

37