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W&T OFFSHORE INC - Quarter Report: 2023 September (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 September 30, 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 October 31, 2023, there were 146,574,193 shares outstanding of the registrant’s common stock, par value $0.00001.

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 September 30, 2023 and December 31, 2022

1

 

Condensed Consolidated Statements of Operations for the Nine Months Ended September 30, 2023 and 2022

2

 

Condensed Consolidated Statements of Changes in Shareholders’ Equity (Deficit) for the Nine Months Ended September 30, 2023 and 2022

3

 

Condensed Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2023 and 2022

5

 

Notes to Condensed Consolidated Financial Statements

6

Item 2.

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

25

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

41

Item 4.

Controls and Procedures

41

 

 

PART II – OTHER INFORMATION

42

Item 1.

Legal Proceedings

42

Item 1A.

Risk Factors

42

Item 2.

Unregistered Sales of Equity Securities, Use of Proceed and Issuer Purchases of Equity Securities

42

Item 3.

Defaults Upon Senior Securities

42

Item 4.

Mine Safety Disclosures

42

Item 5.

Other Information

42

Item 6.

Exhibits

42

 

 

SIGNATURE

44

Table of Contents

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

(Unaudited)

September 30, 

December 31, 

    

2023

    

2022

Assets

 

  

 

  

Current assets:

 

  

 

  

Cash and cash equivalents

$

148,993

$

461,357

Restricted cash

4,417

4,417

Accounts receivable:

 

 

Oil and natural gas sales

 

48,522

 

66,146

Joint interest, net

 

16,049

 

14,000

Income taxes

 

275

 

Total receivables

64,846

80,146

Prepaid expenses and other current assets (Note 1)

 

30,476

 

24,343

Total current assets

 

248,732

 

570,263

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

 

771,454

 

735,215

Restricted deposits for asset retirement obligations

 

22,168

 

21,483

Deferred income taxes

 

42,633

 

57,280

Other assets (Note 1)

 

40,386

 

47,549

Total assets

$

1,125,373

$

1,431,790

Liabilities and Shareholders’ Equity

 

  

 

  

Current liabilities:

 

  

 

  

Accounts payable

$

80,412

$

65,158

Undistributed oil and natural gas proceeds

 

34,649

 

41,934

Advances from joint interest partners

 

3,106

 

3,181

Current portion of asset retirement obligation (Note 8)

 

33,169

 

25,359

Accrued liabilities (Note 1)

 

34,264

 

74,041

Current portion of long-term debt, net (Note 2)

30,015

582,249

Income taxes

 

53

 

412

Total current liabilities

 

215,668

 

792,334

Long-term debt, net (Note 2)

 

367,144

 

111,188

Asset retirement obligations (Note 8)

 

465,245

 

441,071

Other liabilities (Note 1)

 

29,448

 

59,134

Deferred income taxes

 

72

 

72

Commitments and contingencies (Note 12)

 

17,809

 

20,357

Shareholders’ equity:

 

  

 

  

Preferred stock, $0.00001 par value; 20,000 shares authorized; none issued at September 30, 2023 and December 31, 2022

 

 

Common stock, $0.00001 par value; 200,000 shares authorized; 149,443 issued and 146,574 outstanding at September 30, 2023; 149,002 issued and 146,133 outstanding at December 31, 2022

 

1

 

1

Additional paid-in capital

 

582,900

 

576,588

Retained deficit

 

(528,747)

 

(544,788)

Treasury stock, at cost; 2,869 shares at September 30, 2023 and December 31, 2022

 

(24,167)

 

(24,167)

Total shareholders’ equity

 

29,987

 

7,634

Total liabilities and shareholders’ equity

$

1,125,373

$

1,431,790

See Notes to Condensed Consolidated Financial Statements.

1

Table of Contents

W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per share data)

(Unaudited)

Three Months Ended September 30, 

Nine Months Ended September 30, 

    

2023

    

2022

    

2023

    

2022

    

Revenues:

 

  

 

  

 

  

 

  

 

Oil

$

100,331

$

130,560

$

287,313

$

412,526

NGLs

 

7,415

 

16,875

 

25,595

 

47,430

Natural gas

 

32,515

 

113,673

 

80,757

 

257,452

Other

 

2,150

 

5,377

 

6,651

 

13,889

Total revenues

 

142,411

 

266,485

 

400,316

 

731,297

Operating expenses:

 

  

 

  

 

  

 

  

Lease operating expenses

 

61,826

 

59,010

 

193,033

 

155,397

Gathering, transportation and production taxes

6,692

12,199

19,630

26,647

Depreciation, depletion, and amortization

 

30,218

 

27,493

 

81,019

 

79,848

Asset retirement obligations accretion

6,414

6,620

21,641

19,536

General and administrative expenses

 

19,978

 

23,047

 

57,290

 

51,790

Total operating expenses

 

125,128

 

128,369

 

372,613

 

333,218

Operating income

 

17,283

 

138,116

 

27,703

 

398,079

Interest expense, net

 

9,925

 

16,849

 

34,960

 

54,915

Derivative (gain) loss, net

 

(1,491)

 

38,749

 

(41,560)

 

109,892

Other expense (income), net

 

1,927

 

(600)

 

1,849

 

(1,229)

Income before income taxes

 

6,922

 

83,118

 

32,454

 

234,501

Income tax expense

 

4,777

 

16,397

 

16,413

 

46,801

Net income

$

2,145

$

66,721

$

16,041

$

187,700

Net income per common share:

Basic

$

0.01

$

0.46

$

0.11

$

1.30

Diluted

$

0.01

$

0.46

$

0.11

$

1.30

Weighted average common shares outstanding:

Basic

146,483

143,116

146,451

143,026

Diluted

151,459

145,882

149,856

144,696

See Notes to Condensed Consolidated Financial Statements.

2

Table of Contents

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 June 30, 2023

 

146,481

 

$

1

 

$

579,849

 

$

(530,892)

 

2,869

 

$

(24,167)

 

$

24,791

Share-based compensation

 

 

 

 

 

3,250

 

 

 

 

 

 

 

3,250

Stock issued

 

94

 

 

 

 

 

 

 

 

 

 

 

Shares withheld related to net settlement of equity awards

 

 

 

 

 

(199)

 

 

 

 

 

 

 

(199)

Net income

 

 

 

 

 

 

 

2,145

 

 

 

 

 

2,145

Balances at September 30, 2023

 

146,575

 

$

1

 

$

582,900

 

$

(528,747)

 

2,869

 

$

(24,167)

 

$

29,987

    

Common Stock

    

Additional

    

    

    

    

    

Total

Outstanding

Paid-In

Retained

Treasury Stock

Shareholders’

    

Shares

    

Value

    

Capital

    

Deficit

    

Shares

    

Value

    

Deficit

Balances at June 30, 2022

 

143,155

 

$

1

 

$

554,755

 

$

(654,958)

 

2,869

 

$

(24,167)

 

$

(124,369)

Share-based compensation

 

 

 

 

 

2,645

 

 

 

 

 

 

 

2,645

Stock issued

 

7

 

 

 

 

 

 

 

 

 

 

 

Shares withheld related to net settlement of equity awards

 

 

 

 

 

(14)

 

 

 

 

 

 

 

(14)

Net income

 

 

 

 

 

 

 

66,721

 

 

 

 

 

66,721

Balances at September 30, 2022

 

143,162

 

$

1

 

$

557,386

 

$

(588,237)

 

2,869

 

$

(24,167)

 

$

(55,017)

3

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W&T OFFSHORE, INC. AND SUBSIDIARIES

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

(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

 

 

 

 

 

7,259

 

 

 

 

 

 

 

7,259

Stock issued

442

 

 

 

 

 

 

 

 

 

 

 

Shares withheld related to net settlement of equity awards

 

 

 

 

 

(947)

 

 

 

 

 

 

 

(947)

Net income

 

 

 

 

16,041

 

 

 

16,041

Balances at September 30, 2023

 

146,575

$

1

$

582,900

$

(528,747)

 

2,869

$

(24,167)

$

29,987

    

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

 

 

 

 

 

5,179

 

 

 

 

 

 

 

5,179

Stock issued

299

 

 

 

 

 

 

 

 

 

 

 

Shares withheld related to net settlement of equity awards

 

 

 

 

 

(716)

 

 

 

 

 

 

 

(716)

Net income

 

 

 

 

187,700

 

 

 

187,700

Balances at September 30, 2022

 

143,162

$

1

$

557,386

$

(588,237)

 

2,869

$

(24,167)

$

(55,017)

See Notes to Condensed Consolidated Financial Statements.

4

Table of Contents

W&T OFFSHORE, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

Nine Months Ended September 30, 

    

2023

    

2022

    

Operating activities:

 

  

 

  

 

Net income

$

16,041

$

187,700

Adjustments to reconcile net income to net cash provided by operating activities:

 

  

 

  

Depreciation, depletion, amortization and accretion

 

102,660

 

99,384

Share-based compensation

 

7,259

 

5,179

Amortization and write off of debt issuance costs

 

5,714

 

6,114

Derivative (gain) loss

 

(41,560)

 

109,892

Derivative cash payments, net

 

(6,123)

 

(1,022)

Derivative cash premium payments

(46,111)

Deferred income taxes

 

14,647

 

40,171

Changes in operating assets and liabilities:

 

  

 

  

Oil and natural gas receivables

 

17,624

 

(34,276)

Joint interest receivables

(2,049)

(7,070)

Prepaid expenses and other current assets

 

25,550

 

(26,816)

Accounts payable, accrued liabilities and other

(34,475)

65,566

Asset retirement obligation settlements

 

(24,918)

 

(61,285)

Cash advances from JV partners

 

(74)

 

(12,055)

Income taxes payable

 

(634)

 

1,480

Net cash provided by operating activities

 

79,662

 

326,851

Investing activities:

 

  

 

  

Investment in oil and natural gas properties and equipment

 

(30,959)

 

(29,966)

Changes in operating assets and liabilities associated with investing activities

1,285

(8,237)

Acquisition of property interests

 

(28,863)

 

(51,474)

Deposit related to acqusition of property interests

(8,850)

Purchase of corporate aircraft (Note 13)

(8,983)

Purchases of furniture, fixtures and other

(3,081)

Net cash used in investing activities

 

(79,451)

 

(89,677)

Financing activities:

 

  

 

  

Repayment of 9.75% Senior Second Lien Notes due 2023

(552,460)

Repayment of Term Loan

(26,329)

(33,837)

Repayment of TVPX Loan

(458)

Proceeds from issuance of 11.75% Senior Second Lien Notes due 2026

275,000

Debt issuance costs

 

(7,380)

 

(1,290)

Other

 

(948)

 

(716)

Net cash used in financing activities

 

(312,575)

 

(35,843)

Change in cash, cash equivalents and restricted cash

 

(312,364)

 

201,331

Cash and cash equivalents and restricted cash, beginning of period

 

465,774

 

250,216

Cash and cash equivalents and restricted cash, end of period

$

153,410

$

451,547

See Notes to Condensed Consolidated Financial Statements.

5

Table of Contents

W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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. The Company operates in one reportable segment.

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries and an interest in Monza Energy LLC (“Monza”), which is accounted for under the proportional consolidation method. All intercompany accounts and transactions have been eliminated in consolidation. These condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Accordingly, certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted. 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 Item 8 “Financial Statements and Supplementary Data” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2022 (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.

Allowance for Credit Losses

The Company has receivables related to joint interest arrangements primarily with mid-size oil and natural 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 $11.2 million and $12.1 million as of September 30, 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 nine months ended September 30, 2023, which is included as a credit to General and administrative expenses in the Condensed Consolidated Statement of Operations.

6

Table of Contents

W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Prepaid Expenses and Other Current Assets

Prepaid expenses and other current assets consist of the following (in thousands):

September 30, 

    

December 31, 

2023

2022

Derivatives (1)

$

1,294

$

4,954

Insurance/bond premiums

 

8,955

 

6,046

Deposit related to acquisition (Note 14)

8,850

Prepaid deposits related to royalties

 

7,322

 

9,139

Prepayments to vendors

 

1,520

 

1,767

Prepayments to joint interest partners

2,242

1,717

Current portion of debt issuance costs

213

687

Other

 

80

 

33

Prepaid expenses and other current assets

$

30,476

$

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 other, net consist of the following (in thousands):

September 30, 

    

December 31, 

2023

2022

Oil and natural gas properties and equipment

$

8,908,490

$

8,813,404

Furniture, fixtures and other

 

43,087

 

20,915

Total property and equipment

 

8,951,577

 

8,834,319

Less: Accumulated depreciation, depletion, amortization and impairment

 

(8,180,123)

 

(8,099,104)

Oil and natural gas properties and other, net

$

771,454

$

735,215

Other Assets

Other assets consist of the following (in thousands):

September 30, 

    

December 31, 

2023

2022

Operating lease right-of-use assets

$

10,623

$

10,364

Investment in White Cap, LLC

 

2,924

 

2,453

Proportional consolidation of Monza

 

10,805

 

9,321

Derivatives (1)

 

14,372

 

23,236

Other

 

1,662

 

2,175

Total other assets

$

40,386

$

47,549

(1)

Includes open contracts.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Accrued Liabilities

Accrued liabilities consist of the following (in thousands):

September 30, 

    

December 31, 

2023

2022

Accrued interest

$

5,430

$

8,967

Accrued salaries/payroll taxes/benefits

 

9,065

 

15,097

Litigation accruals

 

56

 

396

Operating lease liabilities

 

871

 

1,628

Derivatives (1)

 

17,659

 

46,595

Other

 

1,183

 

1,358

Total accrued liabilities

$

34,264

$

74,041

(1)

Includes closed contracts which have not yet settled.

Other Liabilities

Other liabilities consist of the following (in thousands):

September 30, 

    

December 31, 

2023

2022

Dispute related to royalty deductions

$

5,250

$

4,937

Derivatives

 

11,790

 

43,061

Operating lease liabilities

 

11,700

 

10,527

Other

 

708

 

609

Total other liabilities

$

29,448

$

59,134

8

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W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 2 DEBT

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

September 30, 

    

December 31, 

2023

2022

TVPX Loan:

Principal

$

11,300

$

Unamortized discount

(1,434)

Unamortized debt issuance costs

 

(246)

Total

 

9,620

Term Loan:

Principal

121,571

147,899

Unamortized debt issuance costs

(3,337)

(4,592)

Total

 

118,234

 

143,307

Credit Agreement

11.75% Senior Second Lien Notes due 2026:

 

 

  

Principal

 

275,000

 

Unamortized debt issuance costs

 

(5,695)

 

Total

 

269,305

 

9.75% Senior Second Lien Notes due 2023:

 

 

  

Principal

 

 

552,460

Unamortized debt issuance costs

 

 

(2,330)

Total

 

 

550,130

Total debt, net

397,159

693,437

Less current portion, net

(30,015)

(582,249)

Long-term debt, net

$

367,144

$

111,188

Current Portion of Long-Term Debt, Net

As of September 30, 2023, the current portion of long-term debt of $30.0 million represented principal payments due within one year on the TVPX Loan and Term Loan (defined below), net of current unamortized debt issuance costs.

TVPX Loan

On May 15, 2023, the Company acquired a corporate aircraft from a company affiliated with and controlled by W&T’s Chairman, Chief Executive Officer (“CEO”) and President, Tracy W. Krohn. The terms of the transactions were reviewed and approved by the Audit Committee of the Company’s Board of Directors. See Note 13Related Party Transactions.

The purchase price of the aircraft was $19.1 million, which was paid using $9.0 million of the Company’s cash on hand and through the assumption of an approximately $11.8 million amortizing loan by TVPX Aircraft Solutions Inc. (the “TVPX Loan”), not in its individual capacity but as owner trustee of the trust which holds title to the aircraft, a wholly owned indirect subsidiary of the Company, as the borrower.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The TVPX Loan bears a fixed interest rate of 2.49% per annum for a term of 41 months and requires monthly amortization payments of $91.7 thousand plus accrued interest, and a balloon payment of $8.0 million at the end of the loan term. The TVPX Loan is guaranteed by the Company on an unsecured basis. At the date of assumption, the Company determined that the fair market value of the TVPX Loan was $10.1 million using current market rates.

The aircraft was purchased as part of a series of transactions pursuant to which the Company restructured the compensation for its Named Executive Officers. Prior to the Company’s purchase of the aircraft, the Company used the aircraft for business purposes, and the CEO also used the aircraft for personal purposes. Both the Company’s use for business purposes and the CEO’s unlimited use for personal purposes were paid for by the Company pursuant to the CEO’s prior employment agreement. In connection with the Company’s efforts to significantly reduce overall executive compensation, including perquisite compensation Mr. Krohn was receiving for personal use of the aircraft, on April 20, 2023, the Company entered into an amendment to the employment agreement with the CEO which requires that the Company be reimbursed for personal use of the aircraft in accordance with the Company’s aircraft use policy.

Term Loan

On May 19, 2021, Aquasition LLC and Aquasition-II LLC (collectively, the “Subsidiary Borrowers”), both indirect wholly owned subsidiaries of the Company, entered into a credit agreement (the “Subsidiary Credit Agreement”) providing for a $215.0 million term loan (the “Term Loan”). The Term Loan matures on May 19, 2028.

The Term Loan requires quarterly amortization payments and bears interest at a fixed rate of 7.0% per annum. The Subsidiary Credit Agreement required the Company to enter into certain natural gas swaps and put derivative contracts (see Note 4 – Derivative Financial Instruments).

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 (the “Subsidiary Parent”) 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 (see Note 6 Subsidiary Borrowers for additional information).

Credit Agreement

The Company entered into a Credit Agreement with Calculus Lending, LLC (“Calculus”), a company affiliated with and controlled by the Company’s CEO, 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. As of September 30, 2023, the primary terms and covenants associated with the Credit Agreement 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;
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 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;

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of the last day of any fiscal quarter, 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’ and certain joint ventures’ oil and gas properties included in the collateral are sufficient to satisfy the aggregate first lien indebtedness under the Credit Agreement assuming the Borrowing Base 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 borrowing base was reconfirmed at $50.0 million on October 2023. 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 (as described in Note 6 – Subsidiary Borrowers).

As of September 30, 2023, there were no borrowings outstanding under the Credit Agreement and no borrowings had been incurred under the Credit Agreement during the nine months ended September 30, 2023. As of September 30, 2023 and December 31, 2022, the Company had $4.4 million outstanding in letters of credit which have been cash collateralized.

11.75% Senior Second Lien Notes due 2026

On January 27, 2023, the Company issued at par $275 million in aggregate principal amount of its 11.75% Senior Second Lien Notes (the “11.75% Notes”) under an indenture dated January 27, 2023 (the “Indenture”). The 11.75% Notes mature on February 1, 2026, and interest is payable in arrears on February 1 and August 1.

The 11.75% Notes are secured by second-priority liens on the same collateral that is secured under the Credit Agreement, which does not include the assets of the Subsidiary Borrowers (as described in Note 6 – Subsidiary Borrowers). The estimated annual effective interest rate on the 11.75% Notes is 12.7%, which includes amortization of deferred interest costs.

Prior to August 1, 2024, the Company may redeem all or any portion of the 11.75% Notes at a redemption price equal to 100% of the principal amount of the notes 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% 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% 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% Notes are guaranteed by the Guarantors.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The 11.75% 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% Notes an investment grade rating and no default exists with respect to the 11.75% Notes.

Redemption of 9.75% Senior Second Lien Notes due 2023

On February 8, 2023, the Company redeemed all of the $552.5 million of aggregate principal outstanding of its 9.75% Senior Second Lien Notes (the 9.75% 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% Notes and cash on hand of $296.1 million to fund the redemption.

Covenants

As of September 30, 2023 and for all prior measurement periods presented, the Company was in compliance with all applicable covenants of the Credit Agreement and the Indenture.

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

September 30, 

    

December 31, 

2023

2022

Assets:

 

  

 

  

Derivative instruments - current

$

1,294

$

4,954

Derivative instruments - long-term

 

14,372

 

23,236

Liabilities:

 

  

 

  

Derivative instruments - current

 

17,659

 

46,595

Derivative instruments - long-term

 

11,790

 

43,061

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.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Debt Instruments

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

    

September 30, 2023

    

December 31, 2022

Net Value

    

Fair Value

    

Net Value

    

Fair Value

TVPX Loan

$

9,620

$

9,783

$

$

Term Loan

118,234

113,478

143,307

139,056

11.75% Notes

269,305

 

283,580

 

 

9.75% Notes

 

 

 

550,130

 

544,902

Total

$

397,159

$

406,841

$

693,437

$

683,958

The fair value of the TVPX Loan and the Term Loan were measured using a discounted cash flows model and current market rates. The fair value of the 11.75% Notes and 9.75% Notes were 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.

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, net on the Condensed Consolidated Statements of Operations in each period presented.

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 September 30, 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)

Oct 2023 - Dec 2023

calls

70,000

6,440,000

$

$

$

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

Oct 2023 - Dec 2023 (2)

swaps

71,739

6,600,000

$

2.50

$

$

Jan 2024 - Dec 2024 (2)

swaps

65,573

24,000,000

$

2.46

$

$

Jan 2025 - Mar 2025 (2)

swaps

63,333

5,700,000

$

2.72

$

$

Apr 2025 - Dec 2025 (2)

puts

62,183

17,100,000

$

$

2.27

$

Jan 2026 - Dec 2026 (2)

puts

55,895

20,400,000

$

$

2.35

$

Jan 2027 - Dec 2027 (2)

puts

52,607

19,200,000

$

$

2.37

$

Jan 2028 - Apr 2028 (2)

puts

49,725

6,000,000

$

$

2.42

$

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1)

MMbtu – Million British Thermal Units

(2)

These contracts were entered into by Aquasition LLC in conjunction with the Term Loan (see Note 6 – Subsidiary Borrowers).

Financial Statement Presentation

The fair value of the Company’s derivative financial instruments was recorded in the Condensed Consolidated Balance Sheets as follows (in thousands):

    

September 30, 

    

December 31, 

2023

2022

Prepaid expenses and other current assets

$

1,294

$

4,954

Other assets

 

14,372

 

23,236

Accrued liabilities

 

17,659

 

46,595

Other liabilities

11,790

43,061

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

The impact of commodity derivative contracts on the Condensed Consolidated Statements of Operations were as follows (in thousands):

Three Months Ended September 30, 

Nine Months Ended September 30, 

    

2023

    

2022

    

2023

    

2022

    

Realized loss (1)

$

1,971

$

132,289

$

2,501

$

96,315

Unrealized (gain) loss

(3,462)

(93,540)

(44,061)

13,577

Derivative (gain) loss, net

$

(1,491)

$

38,749

$

(41,560)

$

109,892

(1)The nine months ended September 30, 2022 includes the effect of the $138.0 million realized gain related to the monetization of certain natural gas call contracts through restructuring of strike prices.

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):

Nine Months Ended September 30, 

    

2023

    

2022

Derivative (gain) loss

$

(41,560)

$

109,892

Derivative cash payments, net (1)

(6,123)

(1,022)

Derivative cash premium payments, net

(46,111)

(1)The nine months ended September 30, 2022 includes $105.3 million of net cash receipts related to the monetization of certain natural gas call contracts through restructuring of strike prices.

NOTE 5 – ACQUISITION

On September 20, 2023, the Company entered into a purchase and sale agreement to acquire working interests in certain oil and natural gas producing properties in eight shallow water oil and natural gas producing assets in the central and eastern shelf region of Gulf of Mexico for $32.0 million. The transaction closed on September 20, 2023, and after normal and customary post-effective date adjustments (including net operating cash flow attributable to the properties from the effective date of June 1, 2023 to the close date), cash consideration of $28.9 million was paid to the sellers. The transaction was funded using cash on hand. The Company also assumed the related asset retirement obligations (“AROs”) associated with these assets.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The acquisition was accounted for as an asset acquisition, which requires that the total purchase price, including transaction costs, be allocated to the assets acquired and the liabilities assumed based on their relative fair values. The fair value measurements of the oil and natural gas properties acquired and ARO assumed were derived utilizing an income approach and based, in part, on significant inputs not observable in the market. These inputs represent Level 3 measurements in the fair value hierarchy and include, but are not limited to, estimates of reserves, future operating and development costs, future commodity prices, estimated future cash flows and appropriate discount rates. These inputs required significant judgments and estimates by the Company’s management at the time of the valuation.

The following table represents the Company’s preliminary allocation of total purchase consideration to the identifiable assets acquired and liabilities assumed based on the fair values on the date of acquisition (in thousands):

Oil and natural gas properties and other, net

$

45,215

Asset retirement obligations

 

(16,352)

Allocated purchase price

$

28,863

NOTE 6 — SUBSIDIARY BORROWERS

The Subsidiary Borrowers used the net proceeds from the Term Loan (see Note 2 – Debt) to acquire all of the Company’s 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 the Company’s interest in certain gathering and processing assets located offshore Gulf of Mexico, Mobile Bay region and 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 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 nine months ended September 30, 2023, no such distributions were paid.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Consolidation and Carrying Amounts

The following table presents the amounts recorded by the Company on the Condensed Consolidated Balance Sheets related to the consolidation of the Subsidiary Borrowers and the Subsidiary Parent (in thousands):

September 30, 

December 31, 

2023

2022

Assets:

 

  

 

  

Cash and cash equivalents

$

1,408

$

21,764

Receivables:

 

  

 

  

Oil and natural gas sales

 

22,988

 

37,344

Joint interest, net

 

(25,446)

 

(5,760)

Prepaid expenses and other assets

 

(55)

 

417

Oil and natural gas properties and other, net

 

290,686

 

280,649

Other assets

 

9,328

 

8,473

Liabilities:

 

  

 

  

Accounts payable

10,432

27,387

Undistributed oil and natural gas proceeds

 

4,480

 

7,930

Accrued liabilities

 

17,982

 

45,102

Current portion of long-term debt, net

29,451

32,119

Long-term debt, net

 

88,783

 

111,188

Asset retirement obligations

 

67,402

 

61,138

Other liabilities

 

16,531

 

47,398

The following table presents the amounts recorded by the Company in the Condensed Consolidated Statement of Operations related to the consolidation of the operations of the Subsidiary Borrowers and the Subsidiary Parent (in thousands):

Three Months Ended September 30, 

Nine Months Ended September 30, 

2023

2022

2023

2022

Total revenues

$

28,865

$

94,264

$

75,425

$

218,625

Total operating expenses

 

18,807

 

19,776

 

69,297

 

52,961

Interest expense, net

 

2,536

 

3,405

 

7,947

 

11,841

Derivative (gain) loss

 

(2,652)

 

55,850

 

(55,041)

 

187,896

NOTE 7 — JOINT VENTURE DRILLING PROGRAM

In March 2018, W&T and other members formed and 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. The 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.

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

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 September 30, 2023, ten wells have been completed since the inception of the Joint Venture Drilling Program, and W&T is the operator for eight of these wells.

Since inception through September 30, 2023, members of Monza have 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 $206.4 million. Since inception through September 30, 2023, W&T has made capital contributions, including the contributions of working interest in the drilling projects, to Monza totaling $68.2 million and received cash distributions totaling $44.5 million.

Consolidation and Carrying Amounts

W&T’s interest in Monza is considered to be a variable interest that is proportionally consolidated. Through September 30, 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):

September 30, 

December 31, 

2023

2022

Working capital

$

1,471

$

2,515

Oil and natural gas properties and other, net

 

33,104

 

37,260

Asset retirement obligations

572

467

Other assets

 

10,805

 

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. As of September 30, 2023 and December 31, 2022, the unused advances were $2.8 million and $2.9 million, respectively, which are included in Advances from joint interest partners in the Condensed Consolidated Balance Sheets.

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):

Nine Months Ended September 30, 

2023

2022

Total revenues

$

9,635

$

23,681

Total operating expenses

 

7,046

 

10,805

Interest income

 

147

 

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 8 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):

Nine Months Ended September 30, 

    

2023

    

2022

Asset retirement obligations, beginning of period

$

466,429

$

424,495

Liabilities settled

 

(24,918)

 

(61,285)

Accretion expense

 

21,641

 

19,536

Liabilities acquired

 

16,352

 

33,202

Liabilities incurred

113

138

Revisions of estimated liabilities

 

18,797

 

37,524

Asset retirement obligations, end of period

498,414

453,610

Less: Current portion

 

(33,169)

 

(54,886)

Long-term

$

465,245

$

398,724

NOTE 9 SHARE-BASED AWARDS AND CASH-BASED INCENTIVE COMPENSATION

On June 16, 2023, the 2023 Incentive Compensation Plan (the “2023 Plan”) was approved by the Company’s shareholders. The 2023 Plan is effective June 16, 2023, and the Company will no longer grant awards pursuant to the W&T Offshore, Inc. Amended and Restated Incentive Compensation Plan, as amended from time to time, or the 2004 Directors Compensation Plan of W&T Offshore, Inc., as amended from time to time (collectively, the “Prior Plans”). Under the 2023 Plan, the Company may issue, subject to the approval of the Board of Directors, stock options, stock appreciation rights, restricted stock (“RSAs”), restricted stock units (“RSUs”), performance awards (“PSUs”), stock awards, dividend equivalents, other stock-based awards, performance units or shares, cash awards, substitute awards or any combination of the foregoing to eligible employees, non-employee directors, and consultants. Any awards granted prior to the effective date of the 2023 Plan are considered to have been granted under the applicable Prior Plan.

Share-Based Awards

Restricted Stock Units

During 2023, the Company granted RSUs to certain employees and non-employee directors under both the 2023 Plan and the Prior Plan. The RSUs granted to employees are a long-term compensation component, subject to service conditions, and generally vest in three equal annual installments. The fair value of the RSUs granted to employees on the date of grant was $6.6 million. The RSUs granted to non-employee directors generally vest one year from the date of the grant or on the date of W&T’s next annual shareholder meeting, subject to certain conditions. The fair value of the RSUs granted to non-employee directors on the date of grant was $0.6 million.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

A summary of activity related to RSUs during the nine months ended September 30, 2023 is as follows:

Weighted

    

    

Average

Grant Date

Restricted

Fair Value

Stock Units

per Unit

Nonvested, beginning of period

1,221,461

$

5.76

Granted

 

1,785,960

 

4.06

Vested

 

(486,134)

 

5.62

Forfeited

 

(111,717)

 

5.72

Nonvested, end of period

 

2,409,570

4.53

Performance Share Units

In June 2023, the Company granted PSUs to certain employees under both the 2023 Plan and the Prior Plan. These PSUs vest subject to continued employment and the Company’s total shareholder return (“TSR”) ranking against peer companies’ TSR over a three-year performance period, which ends on December 31, 2025. As these PSUs had both service and market conditions, the Company estimated the fair value of these PSUs using the Monte Carlo simulation model. The fair value of the PSUs on the date of grant was $6.3 million.

A summary of activity related to PSUs during the nine months ended September 30, 2023 is as follows:

Weighted

    

    

Average

Grant Date

Performance

Fair Value

Share Units

per Unit

Nonvested, beginning of period

1,502,239

$

9.78

Granted

 

1,289,720

 

4.85

Vested

 

(9,308)

 

8.13

Forfeited

 

(231,175)

 

9.69

Nonvested, end of period

 

2,551,476

7.30

The following table summarizes the assumptions used in the Monte Carlo simulation model to calculate the fair value of the PSUs granted:

Expected term for performance period (in years)

2.6

Expected volatility

76.1

%

Risk-free interest rate

4.2

%

Share-Based Awards to Non-Employee Directors

Under the Prior Plan, the Company issued RSAs to non-employee directors. These RSAs vested over a one-year period. There were no RSAs granted to non-employee directors during the nine months ended September 30, 2023. The non-employee directors were granted RSUs in July 2023 under the 2023 Plan.

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W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

A summary of activity related to restricted shares during the nine months ended September 30, 2023 is as follows:

Weighted

Average

Grant Date

    

Restricted

    

Fair Value

Shares

per Share

Nonvested, beginning of period

42,426

$

4.95

Granted

Vested

 

(42,426)

 

4.95

Nonvested, end of period

 

Share-Based Compensation Expense

The following table presents the compensation costs included in General and administrative expenses in the Condensed Consolidated Statements of Operations (in thousands):

Three Months Ended September 30, 

Nine Months Ended September 30, 

    

2023

    

2022

    

2023

    

2022

Restricted stock units

$

1,506

$

1,240

$

2,949

$

2,852

Performance share units

1,744

1,352

4,240

2,154

Restricted shares

 

 

53

 

70

 

173

Total

$

3,250

$

2,645

$

7,259

$

5,179

Cash-Based Incentive Compensation

In addition to share-based awards, the Company also grants short-term cash-based incentive awards to all eligible employees. These awards provide for an annual cash payment equal to an established target cash incentive amount multiplied by a target performance score for the Company (as determined by a set of pre-defined performance metrics) and multiplied by an individual performance multiplier for all eligible employees except Named Executive Officers.

The following table presents the cash-based incentive compensation costs in the Condensed Consolidated Statements of Operations (in thousands):

Three Months Ended September 30, 

Nine Months Ended September 30, 

    

2023

    

2022

    

2023

    

2022

Lease operating expenses

$

1,142

$

1,532

$

2,710

$

1,994

General and administrative expenses

 

2,609

 

3,559

 

9,478

 

6,164

Total

$

3,751

$

5,091

$

12,188

$

8,158

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W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 10 INCOME TAXES

Tax Expense and Effective Tax Rate

For the three months ended September 30, 2023 and 2022, the Company recognized income tax expense of $4.8 million and $16.4 million, respectively. The effective tax rate for the three months ended September 30, 2023 is not meaningful primarily as a result of changes in the valuation allowance on the Company’s deferred tax assets. For the three months ended September 30, 2022, the effective tax rate was 19.7%. For the nine months ended September 30, 2023 and 2022, the Company recognized income tax expense of $16.4 million and $46.8 million, respectively, for an effective tax rate of 50.6% and 20.0%, respectively. For both the three and nine months ended September 30, 2023, the Company’s effective tax rate differed from the statutory federal tax rate primarily due to the impact of state income taxes, nondeductible compensation, and adjustments to the valuation allowance. For both the three and nine months ended September 30, 2022, the Company’s effective tax rate differed from the statutory federal tax rate primarily due to 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 the Company’s deferred tax 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 September 30, 2023 and December 31, 2022, the valuation allowance was $21.7 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 September 30, 2023, the Company has a federal income tax receivable of $0.2 million and state income tax receivable of $0.1 million. As of December 31, 2022, the Company did not have any outstanding current income taxes receivable. During the nine months ended September 30, 2023, the Company did not receive any income tax refunds and made federal income tax payments of $2.2 million and state income tax payments of $0.3 million.

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

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W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 11 — 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 September 30, 

Nine Months Ended September 30, 

    

2023

    

2022

    

2023

    

2022

Net income

$

2,145

$

66,721

$

16,041

$

187,700

Weighted average common shares outstanding - basic

 

146,483

 

143,116

 

146,451

 

143,026

Dilutive effect of securities

4,976

2,766

3,405

1,670

Weighted average common shares outstanding - diluted

151,459

145,882

149,856

144,696

Earnings per common share:

Basic

$

0.01

$

0.46

$

0.11

$

1.30

Diluted

0.01

0.46

0.11

1.30

NOTE 12 CONTINGENCIES

Appeal with the Office of Natural Resources Revenue In 2009, W&T recognized allowable reductions of cash payments for royalties owed to the Office of Natural Resources Revenue (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 ONRR notified the Company that they had disallowed approximately $4.7 million of the reductions taken. The Company disagrees with the position taken by the ONRR and filed an appeal with the ONRR. The Company was required to post a surety bond in order to appeal the Interior Board of Land Appeals decision. As of September 30, 2023, the value of the surety bond posted is $8.9 million.

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.

ONRR Audit of Historical Refund Claims

On September 18, 2023, the Company received notification from the ONRR regarding results of an audit performed on W&T’s historical refund claims taken on various properties for alleged royalties owed to the ONRR. The Company’s review and the ONRR appeal process are ongoing and the Company does not believe any accrual is necessary at this time.

Civil Penalties

In January 2021, W&T entered into a Settlement Agreement with the Bureau of Safety and Environmental Enforcement (the “BSEE”) which resolved nine pending civil penalties issued by the BSEE. The civil penalties pertained to Incidents of Non-Compliance issued by the BSEE alleging regulatory non-compliance at separate offshore locations between July 2012 and January 2018. Under the Settlement Agreement, W&T agreed to pay a total of $0.7 million in three annual installments. The final installment was paid in February 2023

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W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 and 2022, 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 a total contingent loss accrual of $20.4 million related to anticipated decommissioning obligations, which was reflected in Other (income) expense, net on the Condensed Consolidated Statements of Operations in the period recorded. During the nine months ended September 30, 2023, the Company incurred $4.7 million in costs related to these decommissioning obligations and reassessed the existing decommissioning obligations, recording an additional $2.1 million. As of September 30, 2023, the remaining loss contingency recorded related to the anticipated decommissioning obligations was $17.8 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.

Other Claims

In the ordinary course of business, the Company is a party to various pending or threatened claims and complaints seeking damages or other remedies concerning commercial operations and other matters. 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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W&T OFFSHORE, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE 13 — RELATED PARTY TRANSACTIONS

On May 15, 2023, the Company acquired a corporate aircraft from a company affiliated with and controlled by the Company’s CEO. The purchase price of the aircraft was $19.1 million, which was paid using $9.0 million of cash on hand and through the assumption of the TVPX Loan (see Note 2 – Debt). The terms of this transaction were reviewed and approved by the Audit Committee of the Company’s Board of Directors.

The aircraft was purchased as part of a series of transactions pursuant to which the Company restructured the compensation for its Named Executive Officers. Prior to the Company’s purchase of the aircraft, the Company used the aircraft for business purposes, and the CEO also used the aircraft for personal purposes. Both the Company’s use for business purposes and the CEO’s unlimited use for personal purposes were paid for by the Company pursuant to the CEO’s prior employment agreement. In connection with the Company’s efforts to significantly reduce overall executive compensation, including perquisite compensation the CEO was receiving for personal use of the aircraft, on April 20, 2023, the Company entered into an amendment to the employment agreement with the CEO which requires that the Company be reimbursed for personal use of the aircraft in accordance with the Company’s aircraft use policy.

NOTE 14 — SUBSEQUENT EVENT

On September 26, 2023, the Company entered into a purchase and sale agreement to acquire rights, titles and interests in and to certain leases, wells and personal property in the central shelf region of the Gulf of Mexico, among other assets, for a gross purchase price of $88.5 million, subject to customary purchase price adjustments. On October 20, 2023, the Company terminated the purchase and sale agreement pursuant to and in accordance with section 14.1(f) thereof, which provided that either the Company or the seller could terminate the agreement at any time following 5:00 p.m. Central Time on October 20, 2023. In conjunction with the termination of the purchase and sale agreement, the $8.9 million deposit was returned to the Company.

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Table of Contents

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) should be read in conjunction with the unaudited condensed consolidated financial statements and the related notes included in Part I, Item 1, Financial Statements, of this Quarterly Report, as well as our audited consolidated financial statements and the notes thereto in the 2022 Annual Report and the related MD&A included in Part II, Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, 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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Table of Contents

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 September 30, 2023, we hold working interests in 54 producing offshore fields in federal and state waters (which include 45 fields in federal waters and 9 in state waters). We currently have under lease approximately 602,100 gross acres (466,800 net acres) spanning across the outer continental shelf off the coasts of Louisiana, Texas, Mississippi and Alabama, with approximately 8,000 gross acres in Alabama state waters, 440,600 gross acres on the conventional shelf and approximately 153,500 gross acres in the deepwater. A majority of our daily production is derived from wells we operate.

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 oil, NGLs and natural gas production and the prices that we receive for such production. Our realized sales prices received for our 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. 

The U.S. Energy Information Administration (“EIA”) published its latest Short-Term Energy Outlook on October 11, 2023. Prices for West Texas Intermediate (“WTI”) oil averaged $89.43 per barrel in September and the EIA is forecasting WTI spot prices to average $86.67 for the fourth quarter of 2023. Prices for Henry Hub natural gas averaged $2.64 per Mcf in September and the EIA is forecasting that Henry Hub prices will average $3.03 in the fourth quarter of 2023.

The EIA is forecasting WTI spot prices will rise in the coming months, reflecting its expectation of tightening balances in the global oil markets after Saudi Arabia extended its voluntary oil production cuts through the end of the year and U.S. oil inventories fell to the lowest level since early 2022. Although the recent attacks on Israel have not yet affected physical oil markets, they raise the potential for oil supply disruptions and higher oil prices. In addition to this development, the current production targets for the Organization of the Petroleum Exporting Countries and Russia (collectively “OPEC+”) are set to expire at the end of 2024, and the EIA expects that continuing voluntary cuts and other factors will keep actual OPEC+ oil production well below targets as the group tries to limit increase in global oil inventories. These shifts in OPEC+ production levels as well as the Russia-Ukraine war and related sanctions, and overall indicators of slowing global economic growth, continue to contribute to a high level of uncertainty surrounding energy supply and demand, putting additional pressure on commodity prices.

Rising Interest Rates and Inflation of Cost of Goods, Services and Personnel

Due to the cyclical nature of the oil and natural 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 increases, 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 prices may also result in increases in the costs of our oilfield goods, services and personnel, which would in turn cause our capital expenditures and operating costs to rise.

The United States has experienced a rise in inflation since October 2021. Inflation peaked during mid-2022 at 9.1% but has been gradually declining since the second half of 2022 according to the Consumer Price Index (the “CPI”). The annual inflation rate for September 2023 was 3.7% which matched the annual inflation rate for August 2023. These inflationary pressures have caused the Federal Reserve to tighten monetary policy by approving a series of increases to the Federal Funds Rate. As of September 30, 2023, the Federal Reserve benchmark rate ranges from 5.25% to 5.50%. If inflation were to continue to rise, it is possible the Federal Reserve would continue to take action they deem necessary 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.

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Table of Contents

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.

Planned and Unplanned Downtime

We are subject to downtime events impacting production, transportation, gathering and processing of our production. Unplanned or planned downtime may be caused, for example, by certain regulatory requirements and inspections or third-party pipeline maintenance. During such downtime, our operating income is negatively impacted. During the first quarter of 2023, our production was temporarily impacted by planned maintenance at Mobile Bay and unplanned downtime at other non-operated fields. During the second quarter of 2023, our production was negatively impacted by unplanned downtime due to third-party pipeline maintenance and production downtime at non-operated fields. During the third quarter of 2023, our production was negatively impacted by well and maintenance issues, particularly at our Mobile Bay Properties.

Financial Assurance for Decommissioning Obligations

In order to cover the various decommissioning obligations of lessees on the outer continental shelf, the Bureau of Ocean Energy Management (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. The Department of Interior is reviewing many BOEM regulations and proposed a rule in June 2023 that would revise the BOEM’s criteria for determining whether lessees are required to provide supplemental financial insurance. Accordingly, 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 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 nine months ended September 30, 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 September 30, 2023 Compared to the Three Months Ended September 30, 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, NGL and natural gas revenues do not include the effects of derivatives, which are reported in Derivative (gain) loss, net in our Condensed Consolidated Statements of Operations.

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Table of Contents

The following table presents our sources of revenue as a percentage of total revenue:

Three Months Ended September 30, 

2023

    

2022

Oil

70.5

%

49.0

%

NGLs

5.2

%

6.3

%

Natural gas

22.8

%

42.7

%

Other

1.5

%

2.0

%

The information below provides a discussion and an analysis of significant variances in, our oil, NGL and natural gas revenues, production volumes and realized sales prices (which exclude the effect of hedging unless otherwise stated) for the three months ended September 30, 2023 and 2022 (in thousands, except sales price data):

Three Months Ended September 30, 

    

2023

    

2022

    

Change

Revenues:

Oil

$

100,331

$

130,560

$

(30,229)

NGLs

 

7,415

 

16,875

 

(9,460)

Natural gas

 

32,515

 

113,673

 

(81,158)

Other

 

2,150

 

5,377

 

(3,227)

Total revenues

 

142,411

 

266,485

 

(124,074)

Production Volumes:

 

  

 

  

 

  

Oil (MBbls) (1)

 

1,227

 

1,447

 

(220)

NGLs (MBbls) (1)

 

348

 

454

 

(106)

Natural gas (MMcf) (20

 

10,359

 

11,499

 

(1,140)

Total oil equivalent (MBoe) (3)

 

3,302

 

3,818

 

(516)

Average daily equivalent sales (Boe/day)

35,891

41,500

(5,609)

Average realized sales prices:

 

 

 

Oil ($/Bbl)

$

81.77

$

90.23

$

(8.46)

NGLs ($/Bbl)

 

21.31

 

37.17

 

(15.86)

Natural gas ($/Mcf) (4)

 

3.14

 

9.89

 

(6.75)

Oil equivalent ($/Boe)

42.48

68.39

(25.91)

Oil equivalent ($/Boe), including realized commodity derivatives (5)

 

41.88

 

50.86

 

(8.98)

(1)MBbls thousands of barrels of oil, condensate or NGLs
(2)MMcf — million cubic feet
(3)MBoe — thousand barrels of oil equivalent
(4)Mcf — thousand cubic feet
(5)Excludes the effects of premium amortization. 

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 September 30, 2023 and 2022 (in thousands):

Price

    

Volume

Total

Oil

$

(10,367)

$

(19,862)

$

(30,229)

NGLs

 

(5,526)

(3,934)

 

(9,460)

Natural gas

 

(69,892)

(11,266)

 

(81,158)

$

(85,785)

$

(35,062)

$

(120,847)

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Realized Prices on the Sale of Oil, NGLs and Natural Gas – Our average realized sales price for oil and natural gas differs from the WTI average price and the NYMEX Henry Hub average price, respectively, primarily due to premiums or discounts, quality adjustments, location adjustments and volume weighting (collectively referred to as differentials). Our average realized NGL sales price is mostly a function of the change in oil prices.

Oil, NGLs, and Natural Gas Volumes – Production volumes decreased by 516 Mboe to 3,302 Mboe during the three months ended September 30, 2023 compared to the same period in 2022, primarily due to well and maintenance issues, particularly at our Mobile Bay Properties.

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 (in thousands, except average data):

Three Months Ended September 30, 

    

2023

    

2022

    

Change

Operating expenses:

Lease operating expenses

$

61,826

$

59,010

$

2,816

Gathering, transportation and production taxes

6,692

12,199

(5,507)

Depreciation, depletion, amortization and accretion

 

36,632

34,113

 

2,519

General and administrative expenses

19,978

23,047

(3,069)

Total operating expenses

$

125,128

$

128,369

$

(3,241)

Average per Boe ($/Boe):

 

  

 

  

 

  

Lease operating expenses

$

18.72

$

15.46

$

3.26

Gathering, transportation and production taxes

 

2.03

3.20

 

(1.17)

Depreciation, depletion, amortization and accretion

 

11.09

8.93

 

2.16

General and administrative expenses

 

6.05

6.04

 

0.01

Total operating expenses

$

37.89

$

33.63

$

4.26

Lease operating expensesLease operating expenses, which include base lease operating expenses, workovers, and facilities maintenance expense, increased $2.8 million to $61.8 million for the three months ended September 30, 2023 compared to $59.0 million for the three months ended September 30, 2022. On a component basis, base lease operating expenses increased $1.3 million, workover expenses increased $0.4 million, and facilities maintenance expense increased $1.1 million.

Base lease operating expenses increased primarily due to higher repair, maintenance and labor costs at various fields, and increased insurance premiums. The increases in workover expenses and facilities maintenance expenses were due to an increase in projects undertaken. 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.

Gathering, transportation and production taxesGathering, transportation and production taxes decreased $5.5 million for the three months ended September 30, 2023 compared to the three months ended September 30, 2022 primarily due to lower production volumes and realized prices.

Depreciation, depletion, amortization and accretion (“DD&A”) – DD&A, which includes accretion for ARO, increased $2.5 million for the three months ended September 30, 2023 as compared to the three months ended September 30, 2022. The DD&A rate increased to $11.09 per Boe for the three months ended September 30, 2023 from $8.93 per Boe for the three months ended September 30, 2022. The change in DD&A expense was due to a higher DD&A rate per Boe driven by the increase in the depreciable base due to capital spending and future development costs and lower proved reserves as compared to the third quarter of 2022, partially offset by lower production volumes.

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General and administrative expenses (“G&A”)G&A decreased $3.1 million, to $20.0 million for the three months ended September 30, 2023 as compared to $23.0 million for the three months ended September 30, 2022. The decrease is primarily due to decreased legal expenses, partially offset by higher contract labor, professional fees and medical claims. Legal expenses decreased primarily due to non-recurring legal fees incurred during the third quarter of 2022 related to a review of processes and controls within our information technology department. Contract labor and professional fees increased due to placement fees, engineering services and IT-related projects.

Other Income and Expense Items

The following table presents the components of other income and expense items for the periods presented and corresponding changes (in thousands):

Three Months Ended September 30, 

    

2023

    

2022

    

Change

Derivative (gain) loss, net

$

(1,491)

$

38,749

$

(40,240)

Interest expense, net

 

9,925

16,849

 

(6,924)

Other expense (income), net

 

1,927

(600)

 

2,527

Income tax expense

 

4,777

16,397

 

(11,620)

Derivative (gain) loss, netDuring the three months ended September 30, 2023, the $1.5 million derivative gain recorded for our natural gas derivative contracts consists of $3.5 million of unrealized gain from the increase in the fair value of open contracts, partially offset by $2.0 million of realized losses. During the three months ended September 30, 2022, the $38.7 million derivative loss recorded for our oil and natural gas derivative contracts consisted of $132.3 million in realized losses and $93.5 million of unrealized gain from the increase in the fair value of our open oil and natural gas contracts.

The following table summarizes the effect of our derivative contracts on the Condensed Consolidated Statements of Operations:

    

Three Months Ended September 30, 

    

2023

2022

Oil ($/Bbl):

 

  

 

  

 

Average realized sales price, before the effects of derivative settlements

$

81.77

$

90.23

Effects of realized commodity derivatives

 

 

(9.97)

Average realized sales price, including realized commodity derivatives

$

81.77

$

80.26

Natural Gas ($/Mcf)

 

  

 

  

Average realized sales price, before the effects of derivative settlements

$

3.14

$

9.89

Effects of realized commodity derivatives

 

(0.19)

 

(4.56)

Average realized sales price, including realized commodity derivatives

$

2.95

$

5.33

Unrealized gains or losses on open derivative contracts relate to production for future periods; however, changes in the fair value 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 of this Quarterly Report for additional information.

Interest expense, netInterest expense, net, was $9.9 million and $16.8 million for the three months ended September 30, 2023 and 2022, respectively. The decrease of $6.9 million in 2023 is due to the redemption of the 9.75% Notes in February 2023, lower interest expense on the lower outstanding principal balance of the Term Loan, partially offset by interest expense incurred on the 11.75% Notes issued in late January 2023.

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Income tax expenseOur effective tax rate for the three months ended September 30, 2023 is not meaningful primarily as a result of changes in the valuation allowance on our deferred tax assets. Our effective tax rate for the three months ended September 30, 2022 was 19.7%. For the three months ended September 30, 2023, the effective tax rate differed from the statutory federal tax rate primarily due to the impact of state income taxes, nondeductible compensation, and adjustments to the valuation allowance. For the three months ended September 30, 2022, the effective tax rate differed from the statutory federal tax rate primarily due to the impact of state income taxes and adjustments to the valuation allowance.

Nine Months Ended September 30, 2023 Compared to the Nine Months Ended September 30, 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, NGL and natural gas revenues do not include the effects of derivatives, which are reported in Derivative (gain) loss, net in our Condensed Consolidated Statements of Operations. The following table presents our sources of revenue as a percentage of total revenue:

Nine Months Ended September 30, 

2023

    

2022

Oil

71.9

%

56.4

%

NGLs

6.4

%

6.5

%

Natural gas

20.2

%

35.2

%

Other

1.7

%

1.9

%

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The information below provides a discussion of, and an analysis of significant variance in, our oil, NGL and natural gas revenues, production volumes and realized sales prices (which exclude the effect of hedging unless otherwise stated) for the nine months ended September 30, 2023 and 2022 (in thousands, except sales price data):

Nine Months Ended September 30, 

2023

    

2022

    

Change

Revenues:

Oil

$

287,313

$

412,526

$

(125,213)

NGLs

 

25,595

 

47,430

 

(21,835)

Natural gas

 

80,757

 

257,452

 

(176,695)

Other

 

6,651

 

13,889

 

(7,238)

Total revenues

$

400,316

$

731,297

$

(330,981)

Production Volumes:

 

  

 

  

 

  

Oil (MBbls)

 

3,831

 

4,227

 

(396)

NGLs (MBbls)

 

1,086

 

1,187

 

(101)

Natural gas (MMcf)

 

28,058

 

33,965

 

(5,907)

Total oil equivalent (MBoe)

 

9,593

11,075

(1,482)

Average daily equivalent sales (Boe/day)

35,139

40,568

(5,429)

Average realized sales prices:

 

Oil ($/Bbl)

$

75.00

$

97.59

$

(22.59)

NGLs ($/Bbl)

 

23.57

 

39.96

 

(16.39)

Natural gas ($/Mcf)

 

2.88

 

7.58

 

(4.70)

Oil equivalent ($/Boe)

41.04

64.78

(23.74)

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

 

40.78

 

63.76

 

(22.98)

(1)Excludes the effects of premium amortization and write-offs. 

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 nine months ended September 30, 2023 and 2022 (in thousands):

Price

    

Volume

Total

Oil

$

(86,552)

$

(38,661)

$

(125,213)

NGLs

 

(17,950)

(3,885)

 

(21,835)

Natural gas

 

(131,925)

(44,770)

 

(176,695)

$

(236,427)

$

(87,316)

$

(323,743)

Realized Prices on the Sale of Oil, NGLs and Natural Gas – Our average realized sales price for oil and natural gas differs from the WTI average price and the NYMEX Henry Hub average price, respectively, primarily due to premiums or discounts, quality adjustments, location adjustments and volume weighting (collectively referred to as differentials). Our average realized NGL sales price is mostly a function of the change in oil prices.

Oil, NGLs, and Natural Gas Volumes – Production volumes decreased by 1,482 MBoe to 9,593 MBoe during the nine months ended September 30, 2023 compared to the same period in 2022 primarily due to unplanned field and well maintenance at Mobile Bay as well as third party deepwater pipeline maintenance and production downtime at non-operated fields.

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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 (in thousands, except average data):

Nine Months Ended September 30, 

    

2023

    

2022

    

Change

Operating expenses:

Lease operating expenses

$

193,033

$

155,397

$

37,636

Gathering, transportation and production taxes

19,630

26,647

(7,017)

Depreciation, depletion, amortization and accretion

 

102,660

99,384

 

3,276

General and administrative expenses

57,290

51,790

5,500

Total operating expenses

$

372,613

$

333,218

$

39,395

Average per Boe ($/Boe):

 

  

 

  

 

  

Lease operating expenses

$

20.12

$

14.03

$

6.09

Gathering, transportation and production taxes

 

2.05

 

2.41

 

(0.36)

Depreciation, depletion, amortization and accretion

 

10.70

 

8.97

 

1.73

General and administrative expenses

 

5.97

 

4.68

 

1.29

Total operating expenses

$

38.84

$

30.09

$

8.75

Lease operating expensesLease operating expenses, which include base lease operating expenses, workovers, and facilities maintenance expense, increased $37.6 million to $193.0 million for the nine months ended September 30, 2023 compared to $155.4 million for the nine months ended September 30, 2022. On a component basis, base lease operating expenses increased $17.2 million, workover expenses increased $9.0 million, facilities maintenance expense increased $11.8 million, and hurricane repairs decreased $0.4 million.

Base lease operating expenses increased due to increased expenses related to a full nine months of expenses at the fields acquired during February 2022 as well as higher repair, maintenance and labor costs at various fields, and increased insurance premiums. The increases in workover expenses and facilities maintenance expenses were due to an increase in projects undertaken. 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 expenses are not necessarily comparable from period to period.

Gathering, transportation and production taxesGathering, transportation and production taxes decreased $7.0 million in the nine months ended September 30, 2023 compared to the nine months ended September 30, 2022 primarily due to lower production volumes and realized prices partially offset by the transportation contract related to the properties acquired in February 2022.

Depreciation, depletion, amortization and accretion – DD&A increased $3.3 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022. The DD&A rate increased to $10.70 per Boe for the nine months ended September 30, 2023 from $8.97 per Boe for the nine months ended September 30, 2022. The change in DD&A expense was due to a higher DD&A rate per Boe driven by the increase in the depreciable base due to capital spending and future development costs and lower proved reserves as compared to the nine months ended September 30, 2022, partially offset by lower production volumes.

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Table of Contents

General and administrative expenses G&A increased $5.5 million to $57.3 million for the nine months ended September 30, 2023 as compared to $51.8 million for the nine months ended September 30, 2022. The increase is primarily due to increased payroll costs, incentive compensation costs and professional fees, partially offset by a decrease in legal expenses and a $2.2 million employee retention credit recorded during the nine months ended September 30, 2023. Incentive compensation costs were higher due to the higher value of the short-term cash based incentive compensation awards granted in 2022 and paid in 2023 as compared to the awards paid for in the prior year, the higher grant date fair value of RSU and PSU awards granted during 2022 as compared to the awards granted in 2021 and the share-based compensation awards granted during the second quarter of 2023. Legal expenses decreased primarily due to non-recurring legal fees incurred during the nine months ended September 30, 2022 related to a review of processes and controls within our information technology department.

Other Income and Expense Items

The following table presents the components of other income and expense items for the periods presented and corresponding changes (in thousands):

Nine Months Ended September 30, 

    

2023

    

2022

    

Change

Derivative (gain) loss, net

$

(41,560)

$

109,892

$

(151,452)

Interest expense, net

 

34,960

54,915

 

(19,955)

Other expense (income), net

 

1,849

(1,229)

 

3,078

Income tax expense

 

16,413

46,801

 

(30,388)

Derivative (gain) loss, netDuring the nine months ended September 30, 2023, the $41.6 million derivative gain recorded for our natural gas derivative contracts consisted of $2.5 million of realized losses on settled contracts and $44.1 million of unrealized gains from the increase in the fair value of open contracts. During the nine months ended September 30, 2022, the $109.9 million derivative loss recorded for our oil and natural gas derivative contracts consisted of $96.3 million in realized losses on settled contracts and $13.6 million of unrealized losses from the decrease in the fair value of our open oil and natural gas contracts.

The following table summarizes the effect of our derivative contracts on the Condensed Consolidated Statements of Operations:

Nine Months Ended September 30, 

2023

2022

Oil ($/Bbl):

  

 

  

Average realized sales price, before the effects of derivative settlements

$

75.00

$

97.59

Effects of realized commodity derivatives(2)

 

 

(14.90)

Average realized sales price, including realized commodity derivatives

$

75.00

$

82.69

Natural Gas ($/Mcf)

 

  

 

  

Average realized sales price, before the effects of derivative settlements

$

2.88

$

7.58

Effects of realized commodity derivatives (1) (2)

 

(0.09)

 

1.52

Average realized sales price, including realized commodity derivatives

$

2.79

$

9.10

(1)The nine months ended September 30, 2022 includes the effect of the $138.0 million realized gain related to the monetization of certain natural gas call contracts through restructuring of strike prices.
(2)Excludes the effects of premium amortization and write-offs. 

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Table of Contents

In the second quarter of 2022, the Company monetized a portion of existing hedge positions through restructuring of certain outstanding purchased calls covering the second half of 2022 through the first quarter of 2025 by increasing the weighted-average strike prices. These transactions resulted in net cash proceeds of $105.3 million.

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 based on fluctuations in market prices for natural gas. See Financial Statements – Note 4 – Derivative Financial Instruments of this Quarterly Report for additional information.

Interest expense, netInterest expense, net was $35.0 million and $54.9 million for the nine months ended September 30, 2023 and 2022, respectively. The decrease of $20.0 million in 2023 is due to the redemption of the 9.75% Notes which occurred in February 2023, lower interest expense on the lower outstanding principal balance of the Term Loan, partially offset by interest expense incurred on the 11.75% Notes issued in late January 2023.

Income tax expenseThe effective tax rate for the nine months ended September 30, 2023 and 2022 was 50.6% and 20.0%, respectively. For the nine months ended September 30, 2023, the effective tax rate differed from the statutory federal tax rate primarily due to the impact of state income taxes, nondeductible compensation, and adjustments to the valuation allowance. For the nine months ended September 30, 2022, the effective tax rate differed from the statutory federal tax rate primarily due to the impact of state income taxes and adjustments to the valuation allowance.

THE SUBSIDIARY BORROWERS

On May 19, 2021, we formed Aquasition LLC (“AI LLC”) and Aquasition-II LLC (“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. See Financial Statements – Note 2 – Debt of 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% 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.

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Table of Contents

Below is consolidating balance sheet information reflecting the elimination of the accounts of our Unrestricted Subsidiaries from our Condensed Consolidated Balance Sheet as of September 30, 2023 (in thousands):

Consolidated

Elimination of Unrestricted Subsidiaries

Restricted Subsidiaries

Assets

 

  

 

  

 

  

Current assets:

 

  

 

  

 

  

Cash and cash equivalents

$

148,993

$

(1,408)

$

147,585

Restricted cash

4,417

4,417

Receivables:

 

  

 

  

 

  

Oil and natural gas sales

 

48,522

 

(22,988)

 

25,534

Joint interest, net

 

16,049

 

25,446

 

41,495

Income taxes

275

275

Prepaid expenses and other current assets

 

30,476

 

55

 

30,531

Total current assets

 

248,732

 

1,105

 

249,837

Oil and natural gas properties and other, net

 

771,454

 

(290,686)

 

480,768

Restricted deposits for asset retirement obligations

 

22,168

 

 

22,168

Deferred income taxes

 

42,633

 

 

42,633

Other assets

 

40,386

 

(9,328)

 

31,058

Total assets

$

1,125,373

$

(298,909)

$

826,464

Liabilities and Shareholders’ Equity (Deficit)

 

  

 

  

 

  

Current liabilities:

 

  

 

  

 

  

Accounts payable

$

83,518

$

(10,432)

$

73,086

Undistributed oil and natural gas proceeds

 

34,649

 

(4,480)

 

30,169

Asset retirement obligations

 

33,169

 

 

33,169

Accrued liabilities

 

34,264

 

(17,982)

 

16,282

Current portion of long-term debt

30,015

(29,451)

564

Income tax payable

 

53

 

 

53

Total current liabilities

 

215,668

 

(62,345)

 

153,323

Long-term debt, net

 

367,144

 

(88,783)

 

278,361

Asset retirement obligations, less current portion

 

465,245

 

(67,402)

 

397,843

Other liabilities

 

47,257

 

(16,531)

 

30,726

Deferred income taxes

 

72

 

 

72

Common stock

 

1

 

 

1

Shareholders' equity (deficit):

Additional paid-in capital

 

582,900

 

 

582,900

Retained deficit

 

(528,747)

 

(63,848)

 

(592,595)

Treasury stock, at cost

 

(24,167)

 

 

(24,167)

Total shareholders’ equity (deficit)

 

29,987

 

(63,848)

 

(33,861)

Total liabilities and shareholders’ equity (deficit)

$

1,125,373

$

(298,909)

$

826,464

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Table of Contents

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 nine months ended September 30, 2023 (in thousands):

Consolidated

Elimination of Unrestricted Subsidiaries

Restricted Subsidiaries

Revenues:

Oil

$

287,313

$

(485)

$

286,828

NGLs

 

25,595

 

(16,317)

 

9,278

Natural gas

 

80,757

 

(55,299)

 

25,458

Other

 

6,651

 

(3,324)

 

3,327

Total revenues

 

400,316

 

(75,425)

 

324,891

Operating expenses:

 

  

 

  

 

  

Lease operating expenses

 

193,033

 

(63,665)

 

129,368

Gathering, transportation and production taxes

19,630

(6,318)

13,312

Depreciation, depletion, amortization and accretion

 

102,660

 

1,648

 

104,308

General and administrative expenses

 

57,290

 

(962)

 

56,328

Total operating expenses

 

372,613

 

(69,297)

 

303,316

Operating income

 

27,703

 

(6,128)

 

21,575

Interest expense, net

 

34,960

 

(8,517)

 

26,443

Derivative (gain) loss, net

 

(41,560)

 

55,041

 

13,481

Other income, net

 

1,849

 

570

 

2,419

Income (loss) before income taxes

 

32,454

 

(53,222)

 

(20,768)

Income tax expense

 

16,413

 

 

16,413

Net (loss) income

$

16,041

$

(53,222)

$

(37,181)

Our produced oil, NGLs and natural gas volumes (net to our interests) from the Subsidiary Borrowers are as follows:

Nine Months Ended September 30, 

Production Volumes:

2023

2022

Oil (MBbls)

 

12

 

13

NGLs (MBbls)

 

699

 

729

Natural gas (MMcf)

 

18,565

 

22,919

Total oil equivalent (MBoe)

 

3,805

 

4,562

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Table of Contents

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.

We expect to support our business requirements primarily with cash generated from operations and, if necessary, through borrowings under our Credit Agreement. As of September 30, 2023, we had $149.0 million cash on hand and $50.0 million available under our Credit Agreement, based on a borrowing base of $50.0 million. We also have up to approximately $83.0 million of availability through our “at-the-market” equity offering program, pursuant to which we may offer and sell shares or our common stock from time to time. Based on our current financial condition and current expectations of future market conditions, we believe our cash on hand, cash flows from operating activities, availability under our Credit Agreement and access to the equity markets from our “at-the-market” equity offering program will provide us with additional liquidity to continue our growth to take advantage of the current commodity environment and will allow us to meet our cash requirements for at least the next 12 months.

We continuously review our liquidity and capital resources. We have commenced discussions with potential lenders and institutions regarding potential replacement or augmentation of our current Credit Agreement which matures on January 3, 2024. The terms of such replacement could vary significantly from those under the current Credit Agreement. If market conditions were to change, for instance due to uncertainty created by geopolitical events, a pandemic or a significant decline in oil and natural gas prices, and our revenue was reduced significantly or operating costs were to increase significantly, our cash flows and liquidity could be negatively impacted.

Sources and Uses of Cash

Nine Months Ended September 30, 

2023

2022

Change

Operating activities

$

79,662

$

326,851

$

(247,189)

Investing activities

 

(79,451)

 

(89,677)

 

10,226

Financing activities

 

(312,575)

 

(35,843)

 

(276,732)

Operating ActivitiesNet cash provided by operating activities decreased $247.2 million for the nine months ended September 30, 2023 compared to the corresponding period in 2022. This was primarily due to (i) a $331.0 million decrease in revenues and (ii) a $42.6 million increase in operating expenses, partially offset by (iii) a $41.0 million decrease in derivative cash settlements and (iv) a $18.7 million decrease in cash interest expense. These decreases in operating cash flow were partially offset by the changes in operating assets and liabilities which increased operating cash flows by $46.6 million primarily related to (i) lower accounts receivable balance due to decreased realized prices, (ii) and lower accounts payable and accrued liabilities balances in the current period and (ii) a $36.4 million decrease in ARO settlements.

Investing ActivitiesNet cash used in investing activities decreased $10.2 million for the nine months ended September 30, 2023 compared to the corresponding period in 2022. This was primarily due to decreases of $22.6 million in acquisition of property interests and $8.5 million in investment in oil and natural gas properties, partially offset by increases of $8.9 million in deposits related to acquisition of property interests and $12.1 million in purchases of the corporate aircraft and furniture, fixtures and other.

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Table of Contents

Financing ActivitiesNet cash used in financing activities increased by $276.7 million for the nine months ended September 30, 2023 compared to the corresponding period in 2022. This was due to the redemption of the $552.5 million principal amount outstanding 9.75% Notes partially offset by the net cash proceeds of $275.0 million received from the issuance of the 11.75% Notes.

Income Taxes

We made income tax payments of $2.2 million for federal and $0.3 million for state purposes and have income taxes receivable of $0.2 million for federal and $0.1 million for state purposes for the nine months ended September 30, 2023. See Financial Statements – Note 10 –Income Taxes of this Quarterly Report for additional information.

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 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 (in thousands):

Nine Months Ended September 30, 

    

2023

    

2022

Exploration (1)

$

3,974

$

10,065

Development (1)

 

26,041

 

12,743

Acquisitions of interests

 

28,863

 

51,474

Seismic and other

 

944

 

7,158

Investments in oil and gas property/equipment – accrual basis

$

59,822

$

81,440

(1)Reported geographically in the subsequent table.

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

Nine Months Ended September 30, 

    

2023

    

2022

Conventional shelf (1)

$

10,461

$

10,473

Deepwater

 

19,554

 

12,335

Exploration and development capital expenditures – accrual basis

$

30,015

$

22,808

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

Acquisitions

We have grown the Company by making strategic acquisitions of producing properties in the Gulf of Mexico. We seek opportunities where we can exploit additional drilling projects and can reduce costs. In September 2023, we acquired eight shallow water oil and natural gas producing assets in the central and eastern shelf region of Gulf of Mexico for $28.9 million, after normal and customary post-effective date adjustments (including net operating cash flow attributable to the properties from the effective date to the respective closing date). The transaction was funded with cash on hand.

On September 26, 2023, we entered into a purchase and sale agreement to acquire rights, titles and interests in and to certain leases, wells and personal property in the central shelf region of the Gulf of Mexico, among other assets, for a gross purchase price of $88.5 million, subject to customary purchase price adjustments. In accordance with the purchase and sale agreement, the Company made an $8.9 million deposit. On October 20, 2023, the Company terminated the purchase and sale agreement pursuant to and in accordance with section 14.1(f) thereof, which provided that either the Company or the seller could terminate the agreement at any time following 5:00 p.m. Central Time on October 20, 2023.

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In conjunction with the termination of the purchase and sale agreement, the $8.9 million deposit was returned to the Company.

Any future acquisitions are subject to the completion of satisfactory due diligence, the negotiation and resolution of significant legal issues, the negotiation, documentation and completion of mutually satisfactory definitive agreements among the parties, the consent of our lenders, our ability to finance the acquisition and approval of our Board of Directors. We cannot guarantee that any such potential transaction would be completed on acceptable terms, if at all.

Asset Retirement Obligations

We have obligations to plug and abandon wells, remove platforms, pipelines, facilities and equipment and restore the land or seabed at the end of oil and natural gas production operations. Through the nine months ended September 30, 2023, we have paid $24.8 million related to these obligations, and we expect to incur $33.2 million of payments in the next twelve months. Our ARO estimates as of September 30, 2023 and December 31, 2022 were $498.4 million and $466.4 million, respectively. 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 Part I, Item 1A, Risk Factors, of our 2022 Annual Report for additional information.

Drilling Activity

We did not drill any wells during the nine months ended September 30, 2023. During September 30, 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 7 –Joint Venture Drilling Program of this Quarterly Report for additional information.

Debt

As of September 30, 2023, we have $407.9 million in aggregate principal amount of long-term debt outstanding, with $31.9 million in aggregate principal coming due over the next twelve months.

On May 15, 2023, we acquired a corporate aircraft from a company affiliated with and controlled by our CEO. The purchase price of the aircraft was $19.1 million, which was paid using $9.0 million of cash on hand and through the assumption of the TVPX Loan, which had a fair market value of $10.1 million on the date of assumption. A valuation prepared by an independent third-party appraiser was one of the components used in determining the purchase price value. Factors considered for purchasing the aircraft were the primary use in making business travel efficient as well as our intent to charter out the aircraft to defray a portion of the operating costs and certain tax considerations and benefits. The terms of this transaction were reviewed and approved by the Audit Committee of the Company’s Board of Directors. See Financial Statements – Note 2 – Debt and Note 13 – Related Party Transactions for additional information.

For additional information about our long-term debt, see Financial Statements – Note 2 – Debt of this Quarterly Report and Part II, Item 8, Financial Statements and Supplementary Data, in our 2022 Annual Report.

Contractual Obligations

During the nine months ended September 30, 2023, we entered into a contract for a drilling rig. The contract is to begin in February 2024 and terminate in October 2024. We expect the total obligation under the contract to be $16.8 million.

Except as disclosed herein, contractual obligations as of September 30, 2023 did not change materially from the disclosures in Part II, Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, of our 2022 Annual Report.

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Critical Accounting Policies and Estimates

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

Recent Accounting Pronouncements

No new accounting pronouncements issued or effective during the nine months ended September 30, 2023, have had or are expected to have a material impact on our condensed consolidated financial statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We do not utilize financial instruments for trading or other speculative purposes. Our exposure to other market risks has not changed materially from the disclosures in Part II, Item 7A, Quantitative and Qualitative Disclosures About Martket Risk, of 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 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 September 30, 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 September 30, 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 12 – Contingencies 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, USE OF PROCEEDS AND ISSUER PURCHASES OF EQUITY SECURITIES

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

None.

ITEM 5. OTHER INFORMATION

During the three months ended September 30, 2023, none of our directors or “officers” (as such term is defined in Rule 16(a)-1(f) under the Exchange Act) adopted or terminated a “Rule 10b5-1 trading agreement” or “non-Rule 10b5-1 trading arrangement (each as defined in Item 408(a) and (c) of Regulation S-K).

ITEM 6. EXHIBITS

Exhibit
Number

    

Description

 

 

 

3.1

 

Second Amended and Restated Articles of Incorporation of W&T Offshore, Inc. (Incorporated by reference to Exhibit 3.1 of the Company’s Quarterly Report on Form 10-Q, filed August 2, 2023 (File No. 001-32414))

 

 

 

3.2

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

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10.1†

Purchase and Sale Agreement, dated September 26, 2023, by and among W&T Offshore, Inc., as buyer, and Cox Oil Offshore, L.L.C., Energy XXI GOM, LLC, EPL Oil & Gas, LLC, MLCJR LLC, Cox Operating L.L.C., Energy XXI Gulf Coast, LLC and M21K, LLC, as sellers (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8 K, filed September 29, 2023 (File No. 001-32414))

10.2

First Amendment to Purchase and Sale Agreement, dated October 13, 2023, by and among W&T Offshore, Inc., as buyer, and Cox Oil Offshore, L.L.C., Energy XXI GOM, LLC, EPL Oil & Gas, LLC, MLCJR LLC, Cox Operating L.L.C., Energy XXI Gulf Coast, LLC and M21K, LLC, as sellers (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8 K, filed October 18, 2023 (File No. 001-32414))

10.3+*

Form of Restricted Stock Unit Grant Notice (Performance Vesting), pursuant to the W&T Offshore, Inc. 2023 Incentive Compensation Plan

10.4+*

Form of Restricted Stock Unit Grant Notice (Service-based Vesting), pursuant to the W&T Offshore, Inc. 2023 Incentive Compensation Plan

10.5+*

Form of Non-Employee Director Restricted Stock Unit Grant Notice, pursuant to the W&T Offshore, Inc. 2023 Incentive Compensation Plan

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.

+

Management contract or compensatory plan or arrangement.

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 to each some 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 November 8, 2023.

W&T OFFSHORE, INC.

 

By:

/s/ Sameer Parasnis

 

Sameer Parasnis

 

Executive Vice President and Chief Financial Officer

(Principal Financial Officer), duly authorized to sign on behalf of the registrant

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