# EDGAR Filing Document

**Accession Number:** 0000894627
**File Stem:** 0000894627-25-000041
**Filing Date:** 2025-8
**Character Count:** 197632
**Document Hash:** 4f448ab240ae55b903451bd189c3c52c
**Contains OCR:** False
**Source Format:** 

## Filing Content

## Filing Summary
**0000894627-25-000041.hdr.sgml**: 20250811

**ACCESSION NUMBER**: 0000894627-25-000041

**CONFORMED SUBMISSION TYPE**: 10-Q

**PUBLIC DOCUMENT COUNT**: 72

**CONFORMED PERIOD OF REPORT**: 20250630

**FILED AS OF DATE**: 20250811

**DATE AS OF CHANGE**: 20250811

**FILER**: 

**COMPANY DATA:**
- **COMPANY CONFORMED NAME:** VAALCO ENERGY INC /DE/
- **CENTRAL INDEX KEY:** 0000894627
- **STANDARD INDUSTRIAL CLASSIFICATION:** CRUDE PETROLEUM & NATURAL GAS [1311]
- **ORGANIZATION NAME:** 01 Energy & Transportation
- **EIN:** 760274813
- **STATE OF INCORPORATION:** DE
- **FISCAL YEAR END:** 1231

**FILING VALUES:**
- **FORM TYPE:** 10-Q
- **SEC ACT:** 1934 Act
- **SEC FILE NUMBER:** 001-32167
- **FILM NUMBER:** 251201848

**BUSINESS ADDRESS:**
- **STREET 1:** 2500 CITYWEST BLVD.
- **STREET 2:** SUITE 400
- **CITY:** HOUSTON
- **STATE:** TX
- **ZIP:** 77042
- **BUSINESS PHONE:** 713-623-0801

**MAIL ADDRESS:**
- **STREET 1:** 2500 CITYWEST BLVD.
- **STREET 2:** SUITE 400
- **CITY:** HOUSTON
- **STATE:** TX
- **ZIP:** 77042

?xml version='1.0' encoding='ASCII'? egy-20250630

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**UNITED STATES**

**SECURITIES AND EXCHANGE COMMISSION**

**Washington, D.C. 20549**

______________________

**FORM 10-Q**

______________________

**(Mark One)**

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

**For the quarterly period ended June 30, 2025** 

**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 1-32167**

______________________

**VAALCO Energy, Inc.**

**(Exact name of registrant as specified in its charter)**

______________________

---

| | |
|:---|:---|
| **Delaware** | **76-0274813** |
| **(State or other jurisdiction of**<br>**incorporation or organization)** | **(I.R.S. Employer**<br>**Identification No.)** |
| **2500 CityWest Blvd.**<br>**Suite 400**<br>**Houston, Texas**  | **77042** |
| **(Address of principal executive offices)** | **(Zip code)** |

---

**(713) 623-0801**

**(Registrant**'**s telephone number, including area code)**

______________________

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

---

| | | |
|:---|:---|:---|
| **<u>Title of each class</u>** | **<u>Trading symbol(s)</u>** | **<u>Name of each exchange on which registered</u>** |
| Common Stock | EGY | New York Stock Exchange |
| Common Stock | EGY | London 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 (§232.405 of this chapter) 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, a 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.&nbsp;&nbsp;&nbsp;&nbsp; □

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).&nbsp;&nbsp;&nbsp;&nbsp; Yes □ No ⌧

As of August 5, 2025, there were outstanding 104,258,253 shares of common stock, $0.10 par value per share, of the registrant.

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**VAALCO ENERGY, INC. AND SUBSIDIARIES**

**Table of Contents**

---

| | |
|:---|:---|
| **<u>[PART I. FINANCIAL INFORMATION](#i401a0abcc5f14f008bad4072ca899a5a_10)</u>** | |
| <u>[ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (unaudited)](#i401a0abcc5f14f008bad4072ca899a5a_13)</u> |  |
| <u>[Condensed Consolidated Balance Sheets](#i401a0abcc5f14f008bad4072ca899a5a_16)[June 30](#i401a0abcc5f14f008bad4072ca899a5a_16)[, 2025 and December 31, 2024](#i401a0abcc5f14f008bad4072ca899a5a_16)</u> | <u>[2](#i401a0abcc5f14f008bad4072ca899a5a_16)</u> |
| <u>[Condensed Consolidated Statements of Operations and Comprehensive Income Three and Six Months Ended June 30, 2025 and 2024](#i401a0abcc5f14f008bad4072ca899a5a_19)</u> | <u>[3](#i401a0abcc5f14f008bad4072ca899a5a_19)</u> |
| <u>[Condensed Consolidated Statements of Shareholders' Equity Three and Six Months Ended June 30, 2025 and 2024](#i401a0abcc5f14f008bad4072ca899a5a_22)</u> | <u>[4](#i401a0abcc5f14f008bad4072ca899a5a_22)</u> |
| <u>[Condensed Consolidated Statements of Cash Flows](#i401a0abcc5f14f008bad4072ca899a5a_25)[Six Months Ended](#i401a0abcc5f14f008bad4072ca899a5a_25)[June](#i401a0abcc5f14f008bad4072ca899a5a_16)[30](#i401a0abcc5f14f008bad4072ca899a5a_19)[, 2025 and 2024](#i401a0abcc5f14f008bad4072ca899a5a_25)</u> | <u>[5](#i401a0abcc5f14f008bad4072ca899a5a_25)</u> |
| <u>[Notes to Condensed Consolidated Financial Statements (unaudited)](#i401a0abcc5f14f008bad4072ca899a5a_28)</u> | <u>[7](#i401a0abcc5f14f008bad4072ca899a5a_28)</u> |
| <u>[ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS](#i401a0abcc5f14f008bad4072ca899a5a_76)</u> | <u>[21](#i401a0abcc5f14f008bad4072ca899a5a_76)</u> |
| <u>[ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK](#i401a0abcc5f14f008bad4072ca899a5a_106)</u> | <u>[35](#i401a0abcc5f14f008bad4072ca899a5a_106)</u> |
| <u>[ITEM 4. CONTROLS AND PROCEDURES](#i401a0abcc5f14f008bad4072ca899a5a_109)</u> | <u>[37](#i401a0abcc5f14f008bad4072ca899a5a_109)</u> |
| **<u>[PART II. OTHER INFORMATION](#i401a0abcc5f14f008bad4072ca899a5a_112)</u>** | <u>[38](#i401a0abcc5f14f008bad4072ca899a5a_112)</u> |
| <u>[ITEM 1. LEGAL PROCEEDINGS](#i401a0abcc5f14f008bad4072ca899a5a_115)</u> | <u>[38](#i401a0abcc5f14f008bad4072ca899a5a_115)</u> |
| <u>[ITEM 1A. RISK FACTORS](#i401a0abcc5f14f008bad4072ca899a5a_118)</u> | <u>[39](#i401a0abcc5f14f008bad4072ca899a5a_118)</u> |
| <u>[ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS](#i401a0abcc5f14f008bad4072ca899a5a_121)</u> | <u>[39](#i401a0abcc5f14f008bad4072ca899a5a_121)</u> |
| <u>[ITEM 5. OTHER INFORMATION](#i401a0abcc5f14f008bad4072ca899a5a_124)</u> | <u>[39](#i401a0abcc5f14f008bad4072ca899a5a_124)</u> |
| <u>[ITEM 6. EXHIBITS](#i401a0abcc5f14f008bad4072ca899a5a_127)</u> | <u>[40](#i401a0abcc5f14f008bad4072ca899a5a_127)</u> |

---

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**PART I. FINANCIAL INFORMATION**

**ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)**

**VAALCO ENERGY, INC. AND SUBSIDIARIES** 

**CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)** 

---

| | | |
|:---|:---|:---|
| | **As of June 30, 2025** | **As of December 31, 2024** |
| | ***(in thousands)*** | ***(in thousands)*** |
| **ASSETS** | | |
| Current assets: |  |  |
| &nbsp;&nbsp;&nbsp;Cash and cash equivalents | $**67871** | $82650 |
| &nbsp;&nbsp;&nbsp;Restricted cash | **194** | 143 |
| &nbsp;&nbsp;&nbsp;Receivables: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Trade, net of allowances for credit loss and other of $0.2 million and $0.2 million, respectively | **132879** | 94778 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Accounts with joint venture owners, net of allowance for credit losses of $2.2 million and <br>&nbsp;&nbsp;&nbsp;&nbsp;$1.5 million, respectively | **351** | 179 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Egypt receivables and other | **3991** | 35763 |
| &nbsp;&nbsp;&nbsp;Crude oil inventory | **1261** | 9441 |
| &nbsp;&nbsp;&nbsp;Prepayments and other | **17182** | 14973 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current assets | **223729** | 237927 |
| Crude oil, natural gas and NGLs properties and equipment, net | **587263** | 538103 |
| Other noncurrent assets: |  |  |
| &nbsp;&nbsp;&nbsp;Restricted cash | **—** | 8665 |
| &nbsp;&nbsp;&nbsp;Value added tax and other receivables, net of allowances for credit loss and other of $0.2 million and <br>&nbsp;&nbsp;&nbsp;&nbsp; $0.8 million, respectively | **5177** | 10094 |
| &nbsp;&nbsp;&nbsp;Right of use operating lease assets | **15340** | 17254 |
| &nbsp;&nbsp;&nbsp;Right of use finance lease assets | **75447** | 79849 |
| &nbsp;&nbsp;&nbsp;Deferred tax assets | **43659** | 55581 |
| &nbsp;&nbsp;&nbsp;Abandonment funding | **6268** | 6268 |
| &nbsp;&nbsp;&nbsp;Other long-term assets | **8039** | 1209 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total assets | $**964922** | $954950 |
| **LIABILITIES AND SHAREHOLDERS' EQUITY** |  |  |
| Current liabilities: |  |  |
| &nbsp;&nbsp;&nbsp;Accounts payable | $**21972** | $11756 |
| &nbsp;&nbsp;&nbsp;Accounts with joint venture owners | **2** | 3324 |
| &nbsp;&nbsp;&nbsp;Accrued liabilities and other | **99893** | 107710 |
| &nbsp;&nbsp;&nbsp;Operating lease liabilities - current portion | **3901** | 3512 |
| &nbsp;&nbsp;&nbsp;Finance lease liabilities - current portion | **13171** | 13383 |
| &nbsp;&nbsp;&nbsp;Foreign income taxes payable | **21978** | 42043 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current liabilities | **160917** | 181728 |
| Asset retirement obligations | **82798** | 78592 |
| Operating lease liabilities - net of current portion | **11903** | 13903 |
| Finance lease liabilities - net of current portion | **63162** | 67377 |
| Deferred tax liabilities | **74583** | 93904 |
| Long-term debt | **60000** |  |
| Other long-term liabilities | **—** | 17863 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total liabilities | **453363** | 453367 |
| Commitments and contingencies (Note 10) |  |  |
| Shareholders' equity: |  |  |
| &nbsp;&nbsp;&nbsp;Preferred stock, $25 par value; 500,000 shares authorized, none issued | **—** |  |
| &nbsp;&nbsp;&nbsp;Common stock,$0.10 par value; 160,000,000 shares authorized, 123,017,656 and 122,304,124 shares issued, 104,258,253 and 103,743,163 shares outstanding, respectively | **12302** | 12230 |
| &nbsp;&nbsp;&nbsp;Additional paid-in capital | **365332** | 362578 |
| &nbsp;&nbsp;&nbsp;Accumulated other comprehensive loss | **(86)** | (4962) |
| &nbsp;&nbsp;&nbsp;Less treasury stock, 18,759,403 and 18,560,931 shares, respectively, at cost | **(78733)** | (78024) |
| &nbsp;&nbsp;&nbsp;Retained earnings | **212744** | 209761 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total shareholders' equity | **511559** | 501583 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total liabilities and shareholders' equity | $**964922** | $954950 |

---

*See notes to unaudited condensed consolidated financial statements.*

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**VAALCO ENERGY, INC. AND SUBSIDIARIES**

**CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (Unaudited)**

---

| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
|  | ***(in thousands, except per share amounts)***  | ***(in thousands, except per share amounts)***  | ***(in thousands, except per share amounts)***  | ***(in thousands, except per share amounts)***  |
| Revenues: |  |  |  |  |
| &nbsp;&nbsp;Crude oil, natural gas and natural gas liquids sales | $**96893** | $116778 | $**207222** | $216933 |
| Operating costs and expenses: |  |  |  |  |
| &nbsp;&nbsp;Production expense | **40393** | 52446 | **85198** | 84535 |
| &nbsp;&nbsp;Exploration expense | **2520** |  | **2520** | 48 |
| &nbsp;&nbsp;Depreciation, depletion and amortization | **28273** | 33132 | **58578** | 58956 |
| &nbsp;&nbsp;General and administrative expense | **8496** | 7591 | **17548** | 14301 |
| &nbsp;&nbsp;Credit losses and other | **29** | 3341 | **2** | 5153 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total operating costs and expenses | **79711** | 96510 | **163846** | 162993 |
| &nbsp;&nbsp;Other operating income (expense), net | **—** | 132 | **—** | (34) |
| Operating income | **17182** | 20400 | **43376** | 53906 |
| Other income (expense): |  |  |  |  |
| &nbsp;&nbsp;Derivative instruments gain (loss), net | **400** | 257 | **326** | (590) |
| &nbsp;&nbsp;Interest expense, net | **(2572)** | (1117) | **(3866)** | (2052) |
| &nbsp;&nbsp;Bargain purchase gain | **—** | 19898 | **—** | 19898 |
| &nbsp;&nbsp;Other income (expense), net | **353** | (1984) | **(659)** | (3784) |
| &nbsp;&nbsp;&nbsp;&nbsp;Total other income (expense), net | **(1819)** | 17054 | **(4199)** | 13472 |
| Income before income taxes | **15363** | 37454 | **39177** | 67378 |
| Income tax expense | **6983** | 9303 | **23066** | 31541 |
| Net income | $**8380** | $28151 | $**16111** | $35837 |
| Other comprehensive income (loss) |  |  |  |  |
| &nbsp;&nbsp;Currency translation adjustments | **4759** | (1068) | **4876** | (3522) |
| Comprehensive income | $**13139** | $27083 | $**20987** | $32315 |
| Basic net income per share: |  |  |  |  |
| &nbsp;&nbsp;Net income per share | $**0.08** | $0.27 | $**0.15** | $0.34 |
| Basic weighted average shares outstanding | **103936** | 103528 | **103848** | 103594 |
| Diluted net income per share: |  |  |  |  |
| &nbsp;&nbsp;Net income per share | $**0.08** | $0.27 | $**0.15** | $0.34 |
| Diluted weighted average shares outstanding | **103958** | 103676 | **103872** | 103677 |

---

*See notes to unaudited condensed consolidated financial statements.*

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**VAALCO ENERGY, INC. AND SUBSIDIARIES**

**CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS**' **EQUITY (Unaudited)** 

---

| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
| | **Common Shares<br>Issued** | **Treasury Shares** | **Common Stock** | **Additional Paid-In<br>Capital** | **Accumulated Other<br>Comprehensive Income (Loss)** | **Treasury Stock** | **Retained Earnings** | **Total** |
| | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Balance at January 1, 2025 | 122304 | (18561) | $12230 | $362578 | $(4962) | $(78024) | $209761 | $501583 |
| &nbsp;&nbsp;&nbsp;Shares issued - stock-based compensation | 116 |  | 12 | (12) |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Stock-based compensation expense |  |  |  | 1389 |  |  |  | 1389 |
| &nbsp;&nbsp;&nbsp;Treasury stock |  | (40) |  |  |  | (155) |  | (155) |
| &nbsp;&nbsp;&nbsp;Dividend distributions |  |  |  |  |  |  | (6570) | (6570) |
| &nbsp;&nbsp;&nbsp;Other comprehensive loss |  |  |  |  | 117 |  |  | 117 |
| &nbsp;&nbsp;&nbsp;Net income |  |  |  |  |  |  | 7730 | 7730 |
| Balance at March 31, 2025 | 122420 | (18601) | $12242 | $363955 | $(4845) | $(78179) | $210921 | $504094 |
| &nbsp;&nbsp;&nbsp;Shares issued - stock-based compensation | 598 |  | 60 | (60) |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Stock-based compensation expense |  |  |  | 1437 |  |  |  | 1437 |
| &nbsp;&nbsp;&nbsp;Treasury stock |  | (158) |  |  |  | (554) |  | (554) |
| &nbsp;&nbsp;&nbsp;Dividend distributions |  |  |  |  |  |  | (6557) | (6557) |
| &nbsp;&nbsp;&nbsp;Other comprehensive loss |  |  |  |  | 4759 |  |  | 4759 |
| &nbsp;&nbsp;&nbsp;Net income |  |  |  |  |  |  | 8380 | 8380 |
| Balance at June 30, 2025 | 123018 | (18759) | $12302 | $365332 | $(86) | $(78733) | $212744 | $511559 |

---

*See notes to unaudited condensed consolidated financial statements.* 

---

| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
| | **Common Shares<br>Issued** | **Treasury Shares** | **Common Stock** | **Additional Paid-In<br>Capital** | **Accumulated Other<br>Comprehensive Income (Loss)** | **Treasury Stock** | **Retained Earnings** | **Total** |
| | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Balance at January 1, 2024 | 121398 | (17051) | $12140 | $357498 | $2880 | $(71222) | $177486 | $478782 |
| &nbsp;&nbsp;&nbsp;Shares issued - stock-based compensation | 543 |  | 54 | 393 |  |  |  | 447 |
| &nbsp;&nbsp;&nbsp;Stock-based compensation expense |  |  |  | 936 |  |  |  | 936 |
| &nbsp;&nbsp;&nbsp;Treasury stock |  | (1434) |  |  |  | (6344) |  | (6344) |
| &nbsp;&nbsp;&nbsp;Dividend distributions |  |  |  |  |  |  | (6463) | (6463) |
| &nbsp;&nbsp;&nbsp;Other comprehensive loss |  |  |  |  | (2454) |  |  | (2454) |
| &nbsp;&nbsp;&nbsp;Net income |  |  |  |  |  |  | 7686 | 7686 |
| Balance at March 31, 2024 | 121941 | (18485) | $12194 | $358827 | $426 | $(77566) | $178709 | $472590 |
| &nbsp;&nbsp;&nbsp;Shares issued - stock-based compensation | 364 |  | 36 | (36) |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Stock-based compensation expense |  |  |  | 1012 |  |  |  | 1012 |
| &nbsp;&nbsp;&nbsp;Treasury stock |  | (76) |  |  |  | (458) |  | (458) |
| &nbsp;&nbsp;&nbsp;Dividend Distribution |  |  |  |  |  |  | (6579) | (6579) |
| &nbsp;&nbsp;&nbsp;Other comprehensive loss |  |  |  |  | (1068) |  |  | (1068) |
| &nbsp;&nbsp;&nbsp;Net income |  |  |  |  |  |  | 28151 | 28151 |
| Balance at June 30, 2024 | 122305 | (18561) | 12230 | $359803 | (642) | $(78024) | 200281 | $493648 |

---

*See notes to unaudited condensed consolidated financial statements.* 

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**VAALCO ENERGY, INC. AND SUBSIDIARIES**

**CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)** 

---

| | | |
|:---|:---|:---|
| | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** |
|  | ***(in thousands)*** | ***(in thousands)*** |
| CASH FLOWS FROM OPERATING ACTIVITIES: |  |  |
| Net income | $**16111** | $35837 |
| Adjustments to reconcile net income to net cash provided by operating activities: |  |  |
| &nbsp;&nbsp;Depreciation, depletion and amortization | **58578** | 58956 |
| &nbsp;&nbsp;Bargain purchase gain | **—** | (19898) |
| &nbsp;&nbsp;Amortization of deferred financing costs | **461** |  |
| &nbsp;&nbsp;Deferred tax benefit | **(7399)** | (7407) |
| &nbsp;&nbsp;Unrealized foreign exchange (gain) loss | **305** | (196) |
| &nbsp;&nbsp;Stock-based compensation expense | **2976** | 1883 |
| &nbsp;&nbsp;Cash settlements paid on exercised stock appreciation rights | **—** | (154) |
| &nbsp;&nbsp;Derivative instruments loss, net | **(326)** | 590 |
| &nbsp;&nbsp;Cash settlements paid on matured derivative contracts, net | **214** | (33) |
| &nbsp;&nbsp;Credit losses and other | **2** | 5508 |
| &nbsp;&nbsp;Equipment and other expensed in operations | **2448** | 1029 |
| &nbsp;&nbsp;Change in operating assets and liabilities: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Trade receivables, net | **(47137)** | (20046) |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts with joint venture owners, net | **(853)** | (4603) |
| &nbsp;&nbsp;&nbsp;&nbsp;Egypt receivables and other, net | **31200** | 32 |
| &nbsp;&nbsp;&nbsp;&nbsp;Crude oil inventory | **8180** | 9618 |
| &nbsp;&nbsp;&nbsp;&nbsp;Prepayments and other | **(1673)** | (3829) |
| &nbsp;&nbsp;&nbsp;&nbsp;Value added tax and other receivables | **6178** | (2007) |
| &nbsp;&nbsp;&nbsp;&nbsp;Other long-term assets | **—** | 699 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts payable | **11212** | (727) |
| &nbsp;&nbsp;&nbsp;&nbsp;Foreign income taxes payable | **(20118)** | (6563) |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued liabilities and other | **(9310)** | (27295) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash provided by operating activities | **51049** | 21394 |
| CASH FLOWS FROM INVESTING ACTIVITIES: |  |  |
| &nbsp;&nbsp;Property and equipment expenditures | **(104426)** | (49099) |
| &nbsp;&nbsp;Cash acquired in business combination, net of cash paid | **—** | 412 |
| &nbsp;&nbsp;Acquisition of oil and gas properties | **(3034)** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash used in investing activities | **(107460)** | (48687) |
| CASH FLOWS FROM FINANCING ACTIVITIES: |  |  |
| &nbsp;&nbsp;Proceeds from the issuances of common stock | **—** | 447 |
| &nbsp;&nbsp;Proceeds from borrowings | **60000** |  |
| &nbsp;&nbsp;Dividend distribution | **(13127)** | (13042) |
| &nbsp;&nbsp;Payments for treasury shares | **(709)** | (6802) |
| &nbsp;&nbsp;Deferred financing costs paid | **(6910)** | (1) |
| &nbsp;&nbsp;Payments of finance lease | **(6332)** | (4169) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash provided by (used in) in financing activities | **32922** | (23567) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Effects of exchange rate changes on cash | **96** | (233) |
| NET CHANGE IN CASH, CASH EQUIVALENTS AND RESTRICTED CASH | **(23393)** | (51093) |
| CASH, CASH EQUIVALENTS AND RESTRICTED CASH AT BEGINNING OF PERIOD | **97726** | 129178 |
| CASH, CASH EQUIVALENTS AND RESTRICTED CASH AT END OF PERIOD | $**74333** | $78085 |

---

*See notes to unaudited condensed consolidated financial statements.*

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**VAALCO ENERGY, INC. AND SUBSIDIARIES**

**CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS SUPPLEMENTAL DISCLOSURES (Unaudited)** 

---

| | | |
|:---|:---|:---|
| | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** |
|  | ***(in thousands)*** | ***(in thousands)*** |
| Supplemental disclosure of cash flow information: |  |  |
| &nbsp;&nbsp;Income taxes paid in-kind with crude oil | $**32263** | $— |
| &nbsp;&nbsp;Interest paid, net of amounts capitalized | $**3160** | $3848 |
| Supplemental disclosure of non-cash investing and financing activities: |  |  |
| &nbsp;&nbsp;Property and equipment additions incurred but not paid at end of period | $**9491** | $12351 |
| &nbsp;&nbsp;Recognition of right-of-use finance lease assets and liabilities | $**2372** | $— |
| &nbsp;&nbsp;Asset retirement obligation revisions | $**126** | $— |

---

*See notes to unaudited condensed consolidated financial statements.*

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

**VAALCO ENERGY, INC. AND SUBSIDIARIES**

**NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS**

**1. ORGANIZATION AND ACCOUNTING POLICIES** 

Vaalco Energy, Inc. (together with its consolidated subsidiaries "we", "us", "our", "Vaalco" or the "Company") is a Houston, Texas-based independent energy company engaged in the acquisition, exploration, development and production of crude oil, natural gas and natural gas liquids ("NGLs") properties. We have a diversified African-focused asset portfolio in Gabon, Egypt, Côte d'Ivoire, Nigeria and Equatorial Guinea, as well as producing properties in Canada.

These unaudited condensed consolidated financial statements ("Financial Statements") reflect the opinion of management and all adjustments necessary for a fair presentation of results for the interim periods presented. All adjustments are of a normal recurring nature unless disclosed otherwise. Interim period results are not necessarily indicative of results expected for the full year.

These Financial Statements have been prepared in accordance with rules of the Securities and Exchange Commission ("SEC") and do not include all the information and disclosures required by accounting principles generally accepted in the United States ("GAAP") for complete financial statements. They should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2024, which includes a summary of the significant accounting policies.

***Allowance for credit losses and other*** – The Company estimates the current expected credit losses based primarily using either an aging analysis or discounted cash flow methodology that incorporates consideration of current and future conditions that could impact its counterparties' credit quality and liquidity. Uncollectible receivables are written off when a settlement is reached for an amount that is less than the outstanding historical balance or when the Company has determined that the balance will not be collected.

The following table provides an analysis of the change of the aggregate credit loss allowance and other allowances.

---

| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
|  | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Balance at beginning of period | $**(2527)** | $(7829) | $**(2554)** | $(6029) |
| &nbsp;&nbsp;Credit losses and other | **(326)** | (3341) | **(637)** | (5153) |
| &nbsp;&nbsp;Credit recoveries and other | **297** |  | **635** |  |
| &nbsp;&nbsp;Foreign currency gain | **—** | (1434) | **—** | (1422) |
| Balance at end of period | $**(2556)** | $(12604) | $**(2556)** | $(12604) |

---

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

***<u>Fair value of financial instruments</u>***

---

| | | | | | |
|:---|:---|:---|:---|:---|:---|
| | | **As of June 30, 2025** | **As of June 30, 2025** | **As of June 30, 2025** | **As of June 30, 2025** |
| | **Balance Sheet Line** | **Level 1** | **Level 2** | **Level 3** | **Total** |
| | | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Assets |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Derivative asset | Prepayments and other | $— | $634 | $— | $634 |
|  |  | $— | $634 | $— | $634 |
| Liabilities |  |  |  |  |  |
| &nbsp;&nbsp;Derivative liability | Accrued liabilities and other | $— | $417 | $— | $417 |
|  |  | $— | $**417** | $— | $**417** |

---

---

| | | | | | |
|:---|:---|:---|:---|:---|:---|
| | | **As of December 31, 2024** | **As of December 31, 2024** | **As of December 31, 2024** | **As of December 31, 2024** |
| |<br>**Balance Sheet Line** | **Level 1** | **Level 2** | **Level 3** | **Total** |
| | | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Assets |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Derivative asset | Prepayments and other | $— | $119 | $— | $119 |
| &nbsp;&nbsp;&nbsp;Derivative asset, noncurrent | Other long term assets | $— | $1209 | $— | $1209 |
|  |  | $— | $1328 | $— | $1328 |
| Liabilities |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Derivative liability | Accrued liabilities and other | $— | $17 | $— | $17 |
|  |  | $— | $17 | $— | $17 |

---

**2*.* NEW ACCOUNTING STANDARDS**

***Not Yet Adopted***

In December 2023*,* FASB issued new guidance to improve income tax disclosures to provide information to assess how an entity's operations and related tax risks and tax planning and operational opportunities affect its tax rate and prospects for future cash flows. The rules became effective for annual periods beginning after December 15, 2024. The standard modifies required income tax disclosures. The Company continues to evaluate the impact of adopting this guidance on the consolidated financial statements and processes.

In November 2024, the FASB issued ASU 2024-03, Accounting Standards Update 2024-03, Income Statement-Reporting Comprehensive Income-Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses to improve financial reporting by requiring that public business entities disclose additional information about specific expense categories in the notes to financial statements at interim and annual reporting periods. This ASU is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. Early adoption is permitted. The Company is currently evaluating the impact of adopting this ASU to our notes to the consolidated financial statements and processes.

**3. ACQUISITIONS**

***Acquisition of Interest in CI-705 Block***

In March 2025, the Company farmed into the CI-705 block offshore Côte d'Ivoire. The Company is the operator of the CI-705 block with a 70% working interest and a 100% paying interest through a commercial carry arrangement and is partnering with two other parties. The CI-705 block is located in the Tano basin, west of the Company's CI-40 Block, where the Baobab and Kossipo oil fields are located. The total amount of acquisition costs for this transaction is approximately $3.0 million.

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

***FPSO Acquisition***

In February 2025, the Company, through the joint operating agreement operator, completed the acquisition of the Baobab floating, production, storage and offloading vessel (the "Baobab FPSO") in Côte d'Ivoire for a total purchase price of $20.0 million, or approximately $5.5 million net cost to the Company.

***Svenska Acquisition***

On April 30, 2024, the Company completed the acquisition of all of the issued shares in the capital of Svenska Petroleum Exploration Aktiebolag, a company incorporated in Sweden ("Svenska") for a net adjusted purchase price of $40.2 million (the "Svenska Acquisition"). The total purchase price consideration was $40.2 million and was funded with Vaalco's cash-on-hand. Cash acquired in the business combination included $31.8 million of cash and cash equivalents as well as restricted cash of $8.8 million which nets to $0.4 million cash received on the business combination within the purchase price allocation.

As a result of comparing the purchase price to the fair value of the assets acquired and liabilities assumed, an initial $19.9 million bargain purchase gain was recognized as of the close date. The purchase price allocation was finalized in the fourth quarter of 2024 and the Company made adjustments to the amounts assigned to the net assets acquired based on new information obtained about facts and circumstances that existed as of the Svenska Acquisition date. As a result, the bargain purchase gain was reduced by $6.4 million. The bargain purchase gain is primarily attributable to a stronger forward pricing curve for oil and gas reserves on the date of the closing of the acquisition than was used for the purposes of the negotiations of the purchase price paid for Svenska.

The Svenska Acquisition qualified as a business combination and was accounted for using the acquisition method of accounting. The following tables summarize the cash paid for the purchase price and the final purchase price allocation of the acquisition consideration.

---

| | | | |
|:---|:---|:---|:---|
| | **April 30, 2024** | **Measurement Period Adjustment** | **April 30, 2024<br>(As Adjusted)** |
| | (in thousands) | (in thousands) | (in thousands) |
| Assets acquired: |  |  |  |
| &nbsp;&nbsp;Cash and cash equivalents | $31789 | $466 | $32255 |
| &nbsp;&nbsp;Other receivables, net | 830 |  | 830 |
| &nbsp;&nbsp;Crude oil inventory | 14981 |  | 14981 |
| &nbsp;&nbsp;Prepayments and other | 409 |  | 409 |
| &nbsp;&nbsp;Crude oil, natural gas and NGLs properties and equipment, net | 100188 | 6901 | 107089 |
| &nbsp;&nbsp;Restricted cash | 8788 |  | 8788 |
| &nbsp;&nbsp;Other LT receivables | 33 |  | 33 |
| &nbsp;&nbsp;Deferred tax asset | 28153 | (12095) | 16058 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total assets acquired | 185171 | (4728) | 180443 |
| Liabilities assumed: |  |  |  |
| &nbsp;&nbsp;Accounts payable | (2506) |  | (2506) |
| &nbsp;&nbsp;State oil liability | (19447) |  | (19447) |
| &nbsp;&nbsp;Accrued tax settlement | (8788) |  | (8788) |
| &nbsp;&nbsp;Accrued accounts payable invoices | (21692) |  | (21692) |
| &nbsp;&nbsp;Accrued liabilities and other | (19083) | (301) | (19384) |
| &nbsp;&nbsp;Asset retirement obligations | (15694) | (11617) | (27311) |
| &nbsp;&nbsp;Deferred tax liability | (37897) | 10280 | (27617) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total liabilities acquired | (125107) | (1638) | (126745) |
| Bargain purchase gain | (19898) | 6366 | (13532) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total purchase price | $40166 | $— | $40166 |

---

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

The unaudited pro forma results presented below have been prepared to give effect to the Svenska Acquisition discussed above on the Company's results of operations for the three and six months ended June 30, 2024*,* as if the acquisition had been consummated on January 1, 2024. The unaudited pro forma results do not purport to represent what the Company's actual results of operations would have been if the Svenska Acquisition had been completed on such date or to project the Company's results of operations for any future date or period.

---

| | | | |
|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | | **Six Months Ended June 30,** |
| | **2024** | | **2024** |
| | (in thousands) | (in thousands) | (in thousands) |
| Pro forma (unaudited) |  |  |  |
| Crude oil, natural gas and natural gas liquids sales | $116778 |  | $248458 |
| Operating income | $(7336) |  | $38091 |
| Net income | $(5842) | (a) | $9316 |
| Basic net income per share: |  |  |  |
| &nbsp;&nbsp;Net income | $(5842) |  | $9316 |
| &nbsp;&nbsp;Net income per share | $(0.06) |  | $0.09 |
| &nbsp;&nbsp;Basic weighted average shares outstanding | 103528 |  | 103594 |
| Diluted net income per share: |  |  |  |
| &nbsp;&nbsp;Net income | $(5842) |  | $9316 |
| &nbsp;&nbsp;Net income per share | $(0.06) |  | $0.09 |
| &nbsp;&nbsp;Diluted weighted average shares outstanding | 103676 |  | 103677 |

---

(a) The unaudited pro forma net income for the three and six months ended June 30, 2024 excludes a nonrecurring pro forma adjustment directly attributable to the Svenska Acquisition, consisting of a bargain purchase gain of $19.9 million.

**4. SEGMENT INFORMATION**

The Company's operations are based in Gabon, Egypt, Côte d'Ivoire, Canada, Nigeria and Equatorial Guinea. Each of the reportable operating segments are organized and managed based upon geographic location. The Company's Chief Executive Officer, who is the chief operating decision maker ("CODM") evaluates segment performance based on the operation of each geographic segment separately primarily based on Operating income (loss) and allocates financial and capital resources for each segment predominantly in the annual budget and forecasting process. The CODM also considers budget-to-actual variances on a quarterly basis for the performance measure when making decisions about allocating capital and personnel to the segments.

The operations of all segments include exploration for and production of hydrocarbons where commercial reserves have been found and developed. Revenues are based on the location of hydrocarbon production. Corporate and other is primarily corporate and operations support costs that are not allocated to the reportable operating segments and are shown in the tables to reconcile the business segments to consolidated totals. No transactions occurred between operating segments. "Other operating income (expense)" below are those items that are included in Net income (loss) but are not regularly provided to the CODM, or are reported to the CODM but are not considered to be significant segment expenses.

Segment activity of continuing operations for the three and six months ended June 30, 2025 and 2024, as well as long-lived assets and segment assets at June 30, 2025 and December 31, 2024 are as follows:

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

---

| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30, 2025** | **Three Months Ended June 30, 2025** | **Three Months Ended June 30, 2025** | **Three Months Ended June 30, 2025** | **Three Months Ended June 30, 2025** | **Three Months Ended June 30, 2025** | **Three Months Ended June 30, 2025** |
| ***(in thousands)*** | **Gabon** | **Egypt** | **Canada** | **Equatorial Guinea** | **Côte d'Ivoire** | **Corporate and Other** | **Total** |
| Revenues: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Crude oil, natural gas and natural gas liquids sales | $**58568** | $**33257** | $**4715** | $**—** | $**353** | $**—** | $**96893** |
| Operating costs and expenses: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Production expense | **23332** | **13130** | **2488** | **386** | **1056** | **1** | **40393** |
| &nbsp;&nbsp;&nbsp;Exploration expense | **—** | **—** | **—** | **—** | **2520** | **—** | **2520** |
| &nbsp;&nbsp;&nbsp;Depreciation, depletion and amortization | **14673** | **9220** | **3160** | **—** | **968** | **252** | **28273** |
| &nbsp;&nbsp;&nbsp;General and administrative expense | **202** | **62** | **39** | **86** | **237** | **7870** | **8496** |
| &nbsp;&nbsp;&nbsp;Credit (recovery) losses and other | **(297)** | **—** | **—** | **326** | **—** | **—** | **29** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating costs and expenses | **37910** | **22412** | **5687** | **798** | **4781** | **8123** | **79711** |
| &nbsp;&nbsp;&nbsp;Other operating income (expense), net | **—** | **—** | **—** | **—** | **—** | **—** | **—** |
| Operating income (loss) | **20658** | **10845** | **(972)** | **(798)** | **(4428)** | **(8123)** | **17182** |
| Other income (expense): |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Derivative instruments gain (loss), net | **—** | **—** | **—** | **—** | **—** | **400** | **400** |
| &nbsp;&nbsp;&nbsp;Interest (expense) income, net | **(835)** | **(180)** | **—** | **—** | **(1396)** | **(161)** | **(2572)** |
| &nbsp;&nbsp;&nbsp;Other income (expense), net | **(132)** | **57** | **430** | **(1)** | **116** | **(117)** | **353** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total other income (expense), net | **(967)** | **(123)** | **430** | **(1)** | **(1280)** | **122** | **(1819)** |
| Income (loss) before income taxes | **19691** | **10722** | **(542)** | **(799)** | **(5708)** | **(8001)** | **15363** |
| Income tax (benefit) expense | **5356** | **3343** | **—** | **—** | **(6139)** | **4423** | **6983** |
| Net income (loss) | **14335** | **7379** | **(542)** | **(799)** | **431** | **(12424)** | **8380** |
| Consolidated capital expenditures | $**9199** | $**7593** | $**210** | $**306** | $**23521** | $**37** | $**40866** |

---

---

| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| | **Six Months Ended June 30, 2025** | **Six Months Ended June 30, 2025** | **Six Months Ended June 30, 2025** | **Six Months Ended June 30, 2025** | **Six Months Ended June 30, 2025** | **Six Months Ended June 30, 2025** | **Six Months Ended June 30, 2025** |
| ***(in thousands)*** | **Gabon** | **Egypt** | **Canada** | **Equatorial Guinea** | **Côte d'Ivoire** | **Corporate and Other** | **Total** |
| Revenues: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Crude oil, natural gas and natural gas liquids sales | $**110754** | $**67177** | $**10895** | $**—** | $**18396** | $**—** | $**207222** |
| Operating costs and expenses: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Production expense | **47655** | **25131** | **4611** | **686** | **7114** | **1** | **85198** |
| &nbsp;&nbsp;&nbsp;Exploration expense | **—** | **—** | **—** | **—** | **2520** | **—** | **2520** |
| &nbsp;&nbsp;&nbsp;Depreciation, depletion and amortization | **26094** | **17271** | **6550** | **—** | **8388** | **275** | **58578** |
| &nbsp;&nbsp;&nbsp;General and administrative expense | **446** | **103** | **31** | **150** | **863** | **15955** | **17548** |
| &nbsp;&nbsp;&nbsp;Credit (recovery) losses and other | **(635)** | **—** | **—** | **637** | **—** | **—** | **2** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating costs and expenses | **73560** | **42505** | **11192** | **1473** | **18885** | **16231** | **163846** |
| Operating income (loss) | **37194** | **24672** | **(297)** | **(1473)** | **(489)** | **(16231)** | **43376** |
| Other income (expense): |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Derivative instruments gain (loss), net | **—** | **—** | **—** | **—** | **—** | **326** | **326** |
| &nbsp;&nbsp;&nbsp;Interest (expense) income, net | **(1871)** | **(423)** | **—** | **—** | **(1287)** | **(285)** | **(3866)** |
| &nbsp;&nbsp;&nbsp;Other income (expense), net | **(764)** | **61** | **398** | **(5)** | **(61)** | **(288)** | **(659)** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total other income (expense), net | **(2635)** | **(362)** | **398** | **(5)** | **(1348)** | **(247)** | **(4199)** |
| Income (loss) before income taxes | **34559** | **24310** | **101** | **(1478)** | **(1837)** | **(16478)** | **39177** |
| Income tax (benefit) expense | **14244** | **8530** | **—** | **—** | **(10234)** | **10526** | **23066** |
| Net income (loss) | $**20315** | $**15780** | $**101** | $**(1478)** | $**8397** | $**(27004)** | $**16111** |
| Consolidated capital expenditures | $**16305** | $**13840** | $**1517** | $**559** | $**59941** | $**19** | $**92181** |

---

------

<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

---

| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30, 2024** | **Three Months Ended June 30, 2024** | **Three Months Ended June 30, 2024** | **Three Months Ended June 30, 2024** | **Three Months Ended June 30, 2024** | **Three Months Ended June 30, 2024** | **Three Months Ended June 30, 2024** |
| ***(in thousands)*** | **Gabon** | **Egypt** | **Canada** | **Equatorial Guinea** | **Cote d'Ivoire** | **Corporate and Other** | **Total** |
| Revenues: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;Crude oil, natural gas and natural gas liquids sales | $53674 | $35481 | $10383 | $— | $17240 | $— | $116778 |
| Operating costs and expenses: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;Production expense | 18486 | 13424 | 3359 | 272 | 16905 |  | 52446 |
| &nbsp;&nbsp;Depreciation, depletion and amortization | 13344 | 8416 | 5294 |  | 6049 | 29 | 33132 |
| &nbsp;&nbsp;General and administrative expense | 319 | 207 | (127) | 93 | 124 | 6975 | 7591 |
| &nbsp;&nbsp;Credit losses and other |  | 3178 |  | 163 |  |  | 3341 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating costs and expenses | 32149 | 25225 | 8526 | 528 | 23078 | 7004 | 96510 |
| &nbsp;&nbsp;Other operating income, net | 132 |  |  |  |  |  | 132 |
| Operating income (loss) | 21657 | 10256 | 1857 | (528) | (5838) | (7004) | 20400 |
| Other income (expense): |  |  |  |  |  |  |  |
| &nbsp;&nbsp;Derivative instruments gain, net |  |  |  |  |  | 257 | 257 |
| &nbsp;&nbsp;Interest (expense) income, net | (1158) | (350) | 14 |  | (1540) | 1917 | (1117) |
| &nbsp;&nbsp;Bargain Purchase Gain |  |  |  |  |  | 19898 | 19898 |
| &nbsp;&nbsp;Other income (expense), net | (137) |  | 5 | 3 | (301) | (1554) | (1984) |
| &nbsp;&nbsp;&nbsp;&nbsp;Total other income (expense), net | (1295) | (350) | 19 | 3 | (1841) | 20519 | 17054 |
| Income (loss) before income taxes | 20362 | 9906 | 1876 | (525) | (7679) | 13515 | 37454 |
| Income tax (benefit) expense | 9731 | 8749 |  |  | (3050) | (6127) | 9303 |
| Net income (loss) | $10631 | $1157 | $1876 | $(525) | $(4630) | $19642 | $28151 |
| Consolidated capital expenditures | $5102 | $1868 | $7155 | $— | $7152 | $1153 | $22431 |

---

---

| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| | **Six Months Ended June 30, 2024** | **Six Months Ended June 30, 2024** | **Six Months Ended June 30, 2024** | **Six Months Ended June 30, 2024** | **Six Months Ended June 30, 2024** | **Six Months Ended June 30, 2024** | **Six Months Ended June 30, 2024** |
| ***(in thousands)*** | **Gabon** | **Egypt** | **Canada** | **Equatorial Guinea** | **Côte d'Ivoire** | **Corporate and Other** | **Total** |
| Revenues: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Crude oil, natural gas and natural gas liquids sales | $111178 | $72442 | $16073 | $— | $17240 | $— | $216933 |
| Operating costs and expenses: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Production expense | 35199 | 26175 | 5738 | 517 | 16905 | 1 | 84535 |
| &nbsp;&nbsp;&nbsp;Exploration expense |  | 48 |  |  |  |  | 48 |
| &nbsp;&nbsp;&nbsp;Depreciation, depletion and amortization | 26795 | 16752 | 9191 |  | 6049 | 169 | 58956 |
| &nbsp;&nbsp;&nbsp;General and administrative expense | 953 | 376 | (115) | 171 | 124 | 12792 | 14301 |
| &nbsp;&nbsp;&nbsp;Credit (recovery) losses and other | 20 | 4812 |  | 321 |  |  | 5153 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating costs and expenses | 62967 | 48163 | 14814 | 1009 | 23078 | 12962 | 162993 |
| &nbsp;&nbsp;&nbsp;Other operating income (expense), net | (34) |  |  |  |  |  | (34) |
| Operating income (loss) | 48177 | 24279 | 1259 | (1009) | (5838) | (12962) | 53906 |
| Other income (expense): |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Derivative instruments loss, net |  |  |  |  |  | (590) | (590) |
| &nbsp;&nbsp;&nbsp;Interest (expense) income, net | (2475) | (760) | 38 |  | (1540) | 2685 | (2052) |
| &nbsp;&nbsp;&nbsp;Bargain Purchase Gain |  |  |  |  |  | 19898 | 19898 |
| &nbsp;&nbsp;&nbsp;Other income (expense), net | (231) |  | 5 | 2 | (301) | (3259) | (3784) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total other income (expense), net | (2706) | (760) | 43 | 2 | (1841) | 18734 | 13472 |
| Income (loss) before income taxes | 45471 | 23519 | 1302 | (1007) | (7679) | 5772 | 67378 |
| Income tax (benefit) expense | 26024 | 15782 |  |  | (3050) | (7215) | 31541 |
| Net income (loss) | $19447 | $7737 | $1302 | $(1007) | $(4630) | $12988 | $35837 |
| Consolidated capital expenditures | $11389 | $6196 | $19714 | $— | $7152 | $2001 | $46453 |

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| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| ***(in thousands)*** | **Gabon** | **Egypt** | **Canada** | **Equatorial Guinea** | **Côte d'Ivoire** | **Corporate and Other** | **Total** |
| Long-lived assets: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;As of June 30, 2025 | $**148979** | $**145698** | $**105467** | $**11200** | $**171062** | $**4857** | $**587263** |
| &nbsp;&nbsp;As of December 31, 2024 | $153576 | $149129 | $104891 | $10641 | $114756 | $5110 | $538103 |

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| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| ***(in thousands)*** | **Gabon** | **Egypt** | **Canada** | **Equatorial Guinea** | **Côte d'Ivoire** | **Corporate and Other** | **Total** |
| Total assets: |  |  |  |  |  |  |  |
| &nbsp;&nbsp;As of June 30, 2025 | $**294795** | $**268867** | $**110430** | $**13288** | $**223593** | $**53949** | $**964922** |
| &nbsp;&nbsp;As of December 31, 2024 | $300568 | $269905 | $113310 | $12331 | $187264 | $71572 | $954950 |

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**5*.* EARNINGS PER SHARE** 

Basic earnings per share ("EPS") is calculated using the average number of shares of common stock outstanding during each period. For the calculation of diluted shares, the Company assumes that restricted stock is outstanding on the date of vesting, and the Company assumes the issuance of shares from the exercise of stock options using the treasury stock method.

A reconciliation of reported net income to net income used in calculating EPS as well as a reconciliation from basic to diluted shares follows:

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| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
|  | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Net income (numerator): |  |  |  |  |
| &nbsp;&nbsp;&nbsp;Net income | $**8380** | $28151 | $**16111** | $35837 |
| &nbsp;&nbsp;&nbsp;Income attributable to unvested shares | **(100)** | (307) | **(197)** | (368) |
| Numerator for basic | **8280** | 27844 | **15914** | 35469 |
| &nbsp;&nbsp;&nbsp;Loss attributable to unvested shares | **—** |  | **—** |  |
| Numerator for dilutive | $**8280** | $27844 | $**15914** | $35469 |
| Weighted average shares (denominator): |  |  |  |  |
| Basic weighted average shares outstanding | **103936** | 103528 | **103848** | 103594 |
| Effect of dilutive securities | **22** | 148 | **24** | 83 |
| &nbsp;&nbsp;&nbsp;&nbsp;Diluted weighted average shares outstanding | **103958** | 103676 | **103872** | 103677 |
| Stock options and unvested restricted stock grants excluded from dilutive calculation because they would be antidilutive | **1312** | 281 | **1321** | 506 |

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**6. REVENUE**

***Production Sharing Contracts***

Exploration and production activities of our assets in Gabon, Egypt, Côte d'Ivoire, and Equatorial Guinea are generally governed by PSCs.

Our oil entitlement under the PSCs is generally the sum of cost oil, profit oil and excess cost oil, if applicable. Under the terms of the PSCs, the Company is typically the contractor partner ("Contractor") and bears the risk and cost of exploration, development, and production activities. In return, if exploration is successful, the Contractor receives entitlement to variable physical volumes of hydrocarbons, representing recovery of the costs incurred ("Cost Oil") and a stipulated share of production after cost recovery ("Profit Oil").

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The Contractor may be obligated to make royalty payments to the host government of each country using a variable percentage based on gross daily production levels. The remaining oil production, after deducting the gross royalty, if any, is split between Cost Oil and Profit Oil. Cost Oil is up to a maximum percentage and is allocated to recover approved operating and capital costs spent on specific projects. Excess Cost Oil, which is Cost Oil less the actual cost recovery, is further shared between the host government and the Contractor. Except as otherwise disclosed, all crude oil sales are priced at current market rates at the time of sale.

Our share of royalties are paid out of the government's share of production. Additionally, the income tax to which the Contractor is subject to ("Profit Oil Tax"), is deemed to have been paid to the host government as part of the payment of Profit Oil or is captured in the entitled share of Profit Oil production paid in-kind to the host government, and therefore no additional tax burden is due. Under this arrangement taxation is based on a set percentage of average daily production volume.

***<u>Gabon</u>***

The following table presents revenues from contracts with customers as well as revenues associated with the obligations under the Etame PSC.

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| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
| Revenues from customer contracts: | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| &nbsp;&nbsp;Sales under the COSPA or COSMA<sup>(1)</sup> | $**65984** | $62327 | $**97434** | $127115 |
| Other items reported in revenue not associated with customer contracts: |  |  |  |  |
| &nbsp;&nbsp;Gabonese government share of Profit Oil taken in-kind | **1980** |  | **30394** |  |
| &nbsp;&nbsp;Carried interest recoupment | **65** |  | **65** | 1174 |
| &nbsp;&nbsp;Royalties | **(9462)** | (8653) | **(17139)** | (17111) |
| &nbsp;&nbsp;&nbsp;&nbsp;Net revenues | $**58567** | $53674 | $**110754** | $111178 |

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<sup>(1)</sup> Crude oil sales and purchase agreements ("COSPAs") or crude oil sales and marketing agreements ("COSMA or COSMAs").

With respect to the government's share of Profit Oil, the Etame PSC provides that corporate income tax is satisfied through the payment of Profit Oil. In the unaudited condensed consolidated statements of operations and comprehensive income, the government's share of revenues from Profit Oil is reported in revenues with a corresponding amount reflected in the current provision for income tax expense. Payments of the income tax expense are reported in the period that the government takes its Profit Oil in-kind, which is the period in which it lifts the crude oil. As of June 30, 2025 and December 31, 2024, the Company had $21.9 million and $37.5 million, of foreign income tax payable, respectively.

***<u>Egypt</u>***

The following table presents revenues in Egypt from contracts with customers:

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| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
| Revenues from customer contracts: | *(in thousands)* | *(in thousands)* | *(in thousands)* | *(in thousands)* |
| &nbsp;&nbsp;Gross sales | $**55188** | $65314 | $**112844** | $128506 |
| &nbsp;&nbsp;Royalties | **(21752)** | (29716) | **(45339)** | (55836) |
| &nbsp;&nbsp;Selling costs | **(179)** | (117) | **(328)** | (228) |
| &nbsp;&nbsp;&nbsp;&nbsp;Net revenues | $**33257** | $35481 | $**67177** | $72442 |

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***<u>Canada</u>***

The following table presents revenues in Canada from contracts with customers:

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| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
| Revenues from customer contracts: | *(in thousands)* | *(in thousands)* | *(in thousands)* | *(in thousands)* |
| &nbsp;&nbsp;Oil revenue | $**3751** | $9547 | $**9076** | $13700 |
| &nbsp;&nbsp;Gas revenue | **572** | 384 | **1208** | 1205 |
| &nbsp;&nbsp;NGL revenue | **1259** | 1896 | **3019** | 3850 |
| &nbsp;&nbsp;Other revenue | **39** | 26 | **87** | 47 |
| &nbsp;&nbsp;Royalties | **(666)** | (1151) | **(2022)** | (2268) |
| &nbsp;&nbsp;Selling costs | **(240)** | (318) | **(473)** | (461) |
| &nbsp;&nbsp;&nbsp;&nbsp;Net revenues | $**4715** | $10384 | $**10895** | $16073 |

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***Côte d'Ivoire***

Revenues from contracts with customers are generated from sales in Côte d'Ivoire pursuant to crude oil sales and purchase agreements and revenues are recognized when a lifting is completed.

The following table presents revenues in Cote d'Ivoire from contracts with customers:

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| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
| Revenues from customer contracts: | *(in thousands)* | *(in thousands)* | *(in thousands)* | *(in thousands)* |
| &nbsp;&nbsp;Sales under the sales and purchase agreements | $**353** | $17240 | $**16527** | $17240 |
| Other item reported in revenue not associated with customer contracts: |  |  |  |  |
| &nbsp;&nbsp;Cote d'Ivoire government share of Profit Oil taken in-kind | **—** |  | **1869** |  |
| &nbsp;&nbsp;Net revenues | $**353** | $17240 | $**18396** | $17240 |

---

Similar to Gabon, the government's share of Profit Oil attributable to the Company's equity interest is reported in revenues with a corresponding amount reflected in the current provision for income tax expense. In addition, under the terms of the Côte d'Ivoire PSC, the tax payments to the Ivorian Government are deemed satisfied by its share of the Profit Oil. Payments of the income tax expense are reported in the period that the government takes its Profit Oil in-kind, which is the period in which it lifts the crude oil. As of June 30, 2025 and December 31, 2024, the Company had $0.4 million and $1.7 million of foreign income tax payable, respectively.

***Information about the Company's most significant customers***

For the three and six months ended June 30, 2025 and 2024, our revenue concentration by major customers are shown on the table below.

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| | | | | |
|:---|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** | **2025** | **2024** |
| Gabon | 100% | 100% | 100% | 100% |
| Egypt | 100% | 100% | 100% | 100% |
| Côte d'Ivoire | 100% | 100% | 100% | 100% |
| Canada | 59%, 17% and 11% | 45%, 24% and 20% | 55%, 20% and 15% | 35%, 30% and 24% |

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**7. CRUDE OIL, NATURAL GAS AND NGLs PROPERTIES AND EQUIPMENT, NET** 

The Company's crude oil, natural gas and NGLs properties and equipment is comprised of the following:

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| | | |
|:---|:---|:---|
| | **As of June 30, 2025** | **As of December 31, 2024** |
| | ***(in thousands)*** | ***(in thousands)*** |
| Crude oil, natural gas and NGLs properties and equipment, net |  |  |
| &nbsp;&nbsp;&nbsp;Wells, platforms and other production facilities | $**1617365** | $1593243 |
| &nbsp;&nbsp;&nbsp;Work-in-progress | **105131** | 44517 |
| &nbsp;&nbsp;&nbsp;Unproved properties | **66576** | 60761 |
| &nbsp;&nbsp;&nbsp;Capitalized equipment, spare parts and other | **90165** | 75581 |
|  | **1879237** | 1774102 |
| &nbsp;&nbsp;&nbsp;Accumulated depreciation, depletion, amortization and impairment | **(1291974)** | (1235999) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Crude oil, natural gas and NGLs properties and equipment, net | $**587263** | $538103 |

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**8. DERIVATIVES AND FAIR VALUE**

We have entered into derivative contracts primarily with counterparties that are also lenders under the 2025 RBL Facility (defined below) to hedge price risk associated with a portion of our oil, natural gas and NGLs production. Pricing for these derivative contracts are based on certain market indexes and prices at our primary sales points. See table below for the list of outstanding contracts as of June 30, 2025:

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| | | | | | |
|:---|:---|:---|:---|:---|:---|
| | | **Settlement Period** | **Settlement Period** | **Settlement Period** | **Settlement Period** |
|<br>**Instrument** |<br>**Index** | **July 2025 to September 2025** | **October 2025 to December 2025** | **January 2026 to March 2026** | **April 2026 to June 2026** |
| **Crude oil:** | | | | | |
| *Swaps* | Dated Brent |  |  |  |  |
| &nbsp;&nbsp;Total volumes (Bbls) |  | 100000 |  |  |  |
| &nbsp;&nbsp;**Weighted average fixed price ($/Bbl)** |  | $65.45 | $— | $— | $— |
| *Collars* | Dated Brent |  |  |  |  |
| &nbsp;&nbsp;Total volumes (Bbls) |  | 405000 | 480000 | 400000 | 360000 |
| &nbsp;&nbsp;Weighted average floor price ($/Bbl) |  | $63.02 | $60.83 | $62.29 | $61.88 |
| &nbsp;&nbsp;Weighted average ceiling price ($/Bbl) |  | $74.36 | $67.81 | $68.63 | $67.95 |
| **Natural Gas:** |  |  |  |  |  |
| *Swaps* | AECO 7A |  |  |  |  |
| &nbsp;&nbsp;Total volumes (GJs)<sup>(a)</sup> |  | 342000 | 114000 |  |  |
| &nbsp;&nbsp;Weighted average fixed price (CAD/GJ) |  | $2.15 | $2.15 | $— | $— |

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(a) One gigajoule (GJ) equals one billion joules (J). A gigajoule of natural gas is approximately 25.5 cubic meters standard conditions.

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The following table sets forth the gain (loss) on derivative instruments on the Company's unaudited condensed consolidated statements of operations and comprehensive income:

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| | | | | | |
|:---|:---|:---|:---|:---|:---|
| | | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| **Derivative Item** | **Statements of Operations Line** | **2025** | **2024** | **2025** | **2024** |
|  |  | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Commodity derivatives | Cash settlements received (paid) on matured derivative contracts, net | $**91** | $(9) | $**214** | $(33) |
|  | Unrealized gain (loss) | **309** | 266 | **112** | (557) |
|  | Derivative instruments gain (loss), net | $**400** | $257 | $**326** | $(590) |

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**9. CURRENT ACCRUED LIABILITIES AND OTHER**

Accrued liabilities and other balances were comprised of the following:

---

| | | |
|:---|:---|:---|
| | **As of June 30, 2025** | **As of December 31, 2024** |
| | ***(in thousands)*** | ***(in thousands)*** |
| Accrued accounts payable invoices | $**33429** | $48913 |
| State oil liability | **18244** | 19616 |
| Accrued capital expenditures | **14763** | 8923 |
| Egypt modernization payable | **9555** | 9933 |
| Gabon contractual obligations | **7611** | 6977 |
| Accrued wages and other compensation | **4496** | 4956 |
| Seismic data | **4975** | 2455 |
| Asset retirement obligation, current portion | **183** | 1174 |
| Other | **6637** | 4763 |
| &nbsp;&nbsp;&nbsp;Total accrued liabilities and other | $**99893** | $107710 |

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**10*.* COMMITMENTS AND CONTINGENCIES**

***Abandonment funding***

Under the terms of the Etame PSC, the Company has a cash funding arrangement for the eventual abandonment of all offshore wells, platforms and facilities on the Etame Marin block. At June 30, 2025, $10.7 million ($6.3 million, net to Vaalco) of the abandonment fund has been funded on an undiscounted basis. The annual payments will be adjusted based on revisions in the abandonment estimate. This cash funding is reflected under "Other noncurrent assets" in the "Abandonment funding" line item of the unaudited condensed consolidated balance sheets. Future changes to the anticipated abandonment cost estimate could change the asset retirement obligation and the amount of future abandonment funding payments.

***Share Buyback Program***

On November 1, 2022, the Company announced that the Company's board of directors formally ratified and approved a share buyback program. The board of directors also directed management to implement a Rule 10b5-1 trading plan (the "10b5-1 Plan") to facilitate share purchases through open market purchases, privately negotiated transactions, or otherwise in compliance with Rule 10b-18 under the Securities Exchange Act of 1934. The 10b5-1 Plan provided for an aggregate purchase of currently outstanding common stock up to $30 million over a maximum period of 20 months. Payment for shares repurchased under the share buyback program were funded using the Company's cash on hand and cash flow from operations. The share buyback program was completed on March 12, 2024. Under the share buyback program, we purchased a total of 6,797,711 shares at an average price of $4.41 per share.

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<u>[**Table of Contents**](#i401a0abcc5f14f008bad4072ca899a5a_7)</u>

***Merged Concession Agreement***

The Company is a party to the Merged Concession Agreement with the Egyptian General Petroleum Corporation ("EGPC"). In accordance with the Merged Concession Agreement, the Company is required to make a $10.0 million annual modernization payment to EGPC each year through February 1, 2026. The $10.0 million modernization payment due February 1, 2025 was fully offset against receivables owed to the Company from EGPC. On the unaudited condensed consolidated balance sheet as of June 30, 2025, the remaining modernization payment liability of $9.6 million was recorded in the line item "Accrued liabilities and other."

The Company also has minimum financial work commitments of $50 million per each five-year period of the primary development term, commencing on February 1, 2020 for a total of $150 million over the 15-year license contract term. Through June 30, 2025, the Company's financial work commitments have exceeded the five-year minimum $50 million threshold and any excess carries forward to offset against subsequent five-year commitments.

In addition, as of February 1, 2020 (the "Merged Concession Effective Date"), an effective date adjustment was owed to the Company for the difference in the historic commercial terms and the revised commercial terms applied against the production since the Merged Concession Effective Date (the "Effective Date Adjustment"). The Company recognized a receivable in connection with the Effective Date Adjustment of $67.5 million as of October 2022, based on historical realized prices (the "Backdated Receivable"). The Backdated Receivable was fully settled as of March 31, 2025.

**11*.* DEBT**

In April 2025, the Company drew down $60.0 million under the 2025 RBL Facility. The borrowing accrues interest at a rate of 10.8% per annum which is based on the Term SOFR plus the applicable margin of 6.5% per annum. In addition, the borrowing is due to be repaid within three months from the drawdown date with, subject to certain conditions, the option to rollover the debt upon maturity.

As of June 30, 2025, there were $60.0 million of outstanding borrowings under the 2025 RBL Facility. There were no outstanding borrowings as of December 31, 2024.

In addition, as of June 30, 2025 and December 31, 2024, we were in compliance with all of our debt covenants.

***2025 RBL Facility***

On March 4, 2025, the Company and certain of its subsidiaries (the "Vaalco Energy Group"), entered into a reserves based facility agreement (the "2025 Facility Agreement") providing for a senior secured reserve-based revolving credit facility (the "2025 RBL Facility") with The Standard Bank of South Africa Limited (acting through its Corporate and Investment Banking Division) as agent and security agent, The Standard Bank of South Africa Limited, Isle of Man Branch and the other financial institutions named in the 2025 Facility Agreement (the "Lenders"), providing for the 2025 RBL Facility.

The 2025 RBL Facility had aggregate commitments of $190.0 million (the "Initial Total Commitments") as of March 4, 2025, with an initial borrowing base of $182.0 million. In accordance with the conditions that were met subsequent to entering into the 2025 Facility Agreement, the initial borrowing base was increased to $184.0 million in April 2025. The Initial Total Commitments will reduce semi-annually by $19.0 million starting from September 30, 2026. The borrowing base amount is calculated pursuant to the 2025 Facility Agreement and redetermined on March 31 and September 30 of each year beginning June 30, 2025 and in certain circumstances, other interim triggers set out in the 2025 Facility Agreement. As of June 30, 2025, we had $190.0 million of aggregate commitments and $126.6 million of available borrowing capacity under the 2025 RBL Facility. The Company may, at any time prior to the date falling 30 months from the date of the 2025 Facility Agreement and subject to the conditions and process set out in the 2025 Facility Agreement give notice to the agent to increase the Initial Total Commitment up to a maximum amount of $300.0 million.

Each loan under the 2025 RBL Facility will bear interest at a rate equal to Term Secured Overnight Financing Rate ("SOFR") plus the applicable margin (the "Applicable Margin") of (i) 6.50%, from the date of the 2025 Facility Agreement until the date on which the renovation and repair of the floating production storage and offloading tanker facility named Baobab Ivorian MV10 FPSO for use in connection with the development of the Baobab field (the "Baobab FPSO Renovation") meets certain completion tests defined in the 2025 Facility Agreement and (ii) thereafter, 6.00% until the Final Maturity Date (defined below). We shall pay the accrued interest on the last day of each applicable interest period, which interest period may be, at our option, one, three or six months or such other period as agreed between us and the Lenders.

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The 2025 RBL Facility will mature on the earlier of (i) March 4, 2031, which is the sixth anniversary of the date of the 2025 Facility Agreement and (ii) the Reserve Tail Date (the "Final Maturity Date"). The Reserve Tail Date is the last day of the calculation period immediately preceding the first calculation period in which the aggregate remaining reserves for all of the borrowing base assets are projected in the then current banking case to be less than 25% of the initial approved reserves.

The 2025 RBL Facility is secured against certain assets of the Company and the other obligors under the 2025 Facility Agreement. The security package includes security over the shares in the obligors (other than in the Company), hedging agreements, intercompany loans, insurances, offtake agreements relating to the borrowing base assets and project accounts.

The 2025 Facility Agreement contains certain financial covenants, including that, beginning on June 30, 2025 and then as of each March 31 and September 30 until the Final Maturity Date, the ratio of Total Net Indebtedness to EBITDAX (each defined in the 2025 Facility Agreement) for the trailing 12 months shall not exceed 3.0x. Additionally, following the Baobab FPSO renovation completion date, the debt service cover ratio for the trailing 12 months commencing on the day immediately following each March 31 and September 30 (and any interim redetermination date) until the Final Maturity Date shall be at least 1.2:1. The Company also provides a liquidity forecast for the Vaalco Energy Group which shall demonstrate that the total corporate sources equal or exceed the total corporate uses. The liquidity forecast is delivered quarterly during the Baobab FPSO renovation period and otherwise on each redetermination of the banking case and any proposed distribution.

The Company is required to pay a quarterly commitment fee equal to (i) 35% per annum of the Applicable Margin on the daily amount of the difference (if any) by which the borrowing base amount exceeds the then outstanding amount of loans, plus (ii) 20% per annum of the Applicable Margin on the daily amount by which the then total commitments exceeds the higher of the total outstanding amount of loans and the borrowing base amount. The Company is also required to pay customary technical and modelling bank fees, agency fees and security agent fees. The 2025 Facility Agreement also contains customary information covenants as well as affirmative and negative covenants subject to customary threshold and materiality which include, among others, compliance with laws (including environmental laws, sanctions and anti-corruption laws), delivery of quarterly and annual financial statements and compliance certificates, no change of business, no merger and maintenance of corporate existence, field preservations and related contracts relating to the borrowing base assets, maintenance of insurance, entry into certain derivatives contracts which are regulated by the 2025 Facility Agreement and the hedging policy, restrictions on the incurrence of liens, indebtedness, asset dispositions, acquisitions, restricted payments, entry into offtake agreements and other customary covenants. If the aggregate borrowings exceeds 35% of the lower of (a) the available total commitments and (b) the applicable borrowing base amount, we are also required to enter into commodity price hedge positions covering certain volumes of anticipated future production set out in the banking case. There are other covenants that make the Company's ability to pay dividends and to enter into certain acquisitions and disposition transactions subject to certain conditions. These covenants are subject to a number of limitations and exceptions.

Additionally, the 2025 Facility Agreement contains customary events of default, including non-payment and borrowing base deficiency, funding shortfall subject to certain liquidity cure rights, breach of financial covenants, misrepresentation, insolvency, changes in ownership or business, litigation, cross default, expropriation of any borrowing base assets, political events, cessation of production and the occurrence of a material adverse effect. The 2025 Facility Agreement also contains events of default related to the failure to complete the Baobab FPSO Renovation by the Baobab FPSO renovation long stop date determined in the 2025 Facility Agreement and the failure to renew any field license on substantially the same terms three months before the expiration of such field license and if a change of operator occurs. The events of default contains thresholds and remedy periods customary for credit facilities of this nature. If the obligors do not comply with the financial and other covenants relating to non-payment, sanctions, anti-corruption, loans and guarantee or tax in the 2025 Facility Agreement, the Lenders may require immediate payment of all amounts outstanding under the 2025 Facility Agreement and any outstanding unfunded commitments may be terminated. In addition, if any principal amount payable is not paid upon due date, interest shall accrue on the overdue amount from the due date up to the date of the actual payment at an additional interest rate of 2% per annum, and such interest shall be immediately payable on demand.

***Fair Value Measurement***

The fair value of the 2025 RBL Facility approximates its respective carrying amount as its interest rate is variable and reflective of market rates. The fair value measurement for the 2025 RBL Facility represents Level 2 inputs.

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**12. INCOME TAXES** 

Vaalco and its domestic subsidiaries file a consolidated U.S. federal income tax return. Certain foreign subsidiaries also file tax returns in their respective local jurisdictions including Canada, Egypt, Equatorial Guinea, Gabon, Côte d'Ivoire and Nigeria.

The foreign taxes payable are attributable to Gabon and Côte d'Ivoire as of June 30, 2025 and 2024*.*

The Company's effective tax rate for the three months ended June 30, 2025, and 2024*,* excluding the impact of discrete items, was 52.91% and 43.78%, respectively. The Company's effective tax rate for the six months ended June 30, 2025 and 2024*,* excluding the impact of discrete items, was 58.36% and 54.58%, respectively. For the three and six months ended June 30, 2025 and 2024*,* the Company's overall effective tax rate was primarily impacted by tax rates in foreign jurisdictions higher than the US statutory rate and by non-deductible items associated with operations.

For the three months ended June 30, 2025, the income tax expense of $7.0 million includes a $3.1 million favorable oil price adjustment as a result of the change in value of the government of Gabon's allocation of Profit Oil between the time it was produced and the time it was taken in-kind. After excluding this impact, income taxes were $10.1 million for the period. For the six months ended June 30, 2025, the income tax expense of $23.1 million includes a $2.4 million favorable oil price adjustment as a result of the change in value of the government of Gabon's allocation of Profit Oil between the time it was produced and the time it was taken in-kind. After excluding this impact, income taxes were $25.4 million for the period.

As of June 30, 2025, the Company had no material uncertain tax positions. The Company's policy is to recognize potential interest and penalties related to unrecognized tax benefits as a component of income tax expense.

**13. OTHER COMPREHENSIVE INCOME** 

The Company's other comprehensive loss was $4.8 million and $4.9 million for the three and six months ended June 30, 2025, respectively. The functional currency of our Canadian segment is the Canadian Dollar. All of the Company's other comprehensive income arises from the currency translation of our Canadian segment to USD.

The components of accumulated other comprehensive income are as follows:

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| | |
|:---|:---|
| | **Currency Translation Adjustments** |
| | ***(in thousands)*** |
| Balance at December 31, 2024 | $(4962) |
| &nbsp;&nbsp;Amounts reclassified from accumulated other comprehensive income | 117 |
| Balance at March 31, 2025 | $(4845) |
| &nbsp;&nbsp;Amounts reclassified from accumulated other comprehensive income | 4759 |
| Balance at June 30, 2025 | $(86) |

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**14. SUBSEQUENT EVENT**

*Enactment of the One Big Beautiful Bill Act of 2025* 

On July 4, 2025, the budget reconciliation bill known as the One Big Beautiful Bill Act of 2025 ("OBBBA") was signed into law, which includes significant changes to federal tax law and other regulatory provisions that may impact the Company. Among other provisions, the OBBBA makes permanent key elements of the Tax Cuts and Jobs Act of 2017. We are currently evaluating the provisions of the OBBBA law and the potential effects on our financial position, results of operations, and cash flows, however we do not anticipate any material financial impact from the passage of the OBBBA.

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

**CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS**

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the impact of world health events, including any related impact on global demand for crude oil and crude oil prices, potential difficulties in obtaining additional liquidity, when and if needed, disruptions in global supply chains and disruptions to our workforce;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the impact of any future production quotas imposed by Gabon, as a member of the Organization of the Petroleum Exporting Countries ("OPEC"), as a result of agreements among OPEC, Russia and other allied producing countries (collectively, "OPEC+") with respect to crude oil production levels;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the impact of the wide-ranging policy changes and numerous executive actions issued by the current U.S. presidential administration on topics including international trade, imposition of trade tariffs, energy resources, corporate taxes, global climate change initiatives, employment practices, corporate compliance programs, environmental regulations, as well as other matters;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to remediate our material weaknesses;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• volatility of, and declines and weaknesses in crude oil, natural gas and natural gas liquids ("NGLs") prices, as well as our ability to offset volatility in prices through the use of hedging transactions;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the discovery, acquisition, development and replacement of crude oil, natural gas and NGLs reserves;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• impairments in the value of our crude oil, natural gas and NGLs assets;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• future capital requirements;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to maintain sufficient liquidity in order to fully implement our business plan;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to generate cash flows that, along with our cash on hand, will be sufficient to support our operations and cash requirements;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the ability of the BWE Consortium to successfully execute its business plan;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to attract capital or obtain debt financing arrangements;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to pay the expenditures required in order to develop certain of our properties;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• operating hazards inherent in the exploration for and production of crude oil, natural gas and NGLs;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• difficulties encountered during the exploration for and production of crude oil, natural gas and NGLs;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the impact of competition;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to identify and complete complementary opportunistic acquisitions;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to effectively integrate assets and properties that we acquire into our operations;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• weather conditions;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the uncertainty of estimates of crude oil, natural gas and NGLs reserves;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• currency exchange rates and regulations;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• unanticipated issues and liabilities arising from non-compliance with environmental regulations;

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&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our limited control over the assets we do not operate;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the impact and duration of scheduled maintenance of the floating, production, storage and offloading ("FPSO") vessel in Côte d'Ivoire;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the ultimate resolution of our abandonment funding obligations with the government of Gabon and the audit of our operations in Gabon that was conducted by the government of Gabon;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the availability and cost of seismic, drilling and other equipment;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• difficulties encountered in measuring, transporting and delivering crude oil, natural gas and NGLs to commercial markets;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• timing and amount of future production of crude oil, natural gas and NGLs;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• hedging decisions, including whether or not to enter into derivative financial instruments;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• general economic conditions, including any future economic downturn, the impact of inflation, and disruption in financial credit and other disruptions resulting from geo-political events such as the Russian invasion of Ukraine, the conflict in the Middle East, and trade tensions between the U.S. and China;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• our ability to enter into new customer contracts;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• changes in customer demand and producers' supply;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• actions by the governments and other significant actors with respect to events occurring in the countries in which we operate;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• actions by our joint venture owners;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• compliance with, or the effect of changes in, governmental regulations regarding our exploration, production, and well completion operations including those related to climate change;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the outcome of any governmental audit;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• the anticipated impact on our business and operations of the OBBBA; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;• actions of operators of our crude oil, natural gas and NGLs properties.

The information contained in this Quarterly Report and the information set forth under the heading "Item 1A. Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2024 ("2024 Form 10-K"), identifies additional factors that could cause our results or performance to differ materially from those we express in forward-looking statements. Although we believe that the assumptions underlying our forward-looking statements are reasonable, any of these assumptions and therefore also the forward-looking statements based on these assumptions, could themselves prove to be inaccurate. In light of the significant uncertainties inherent in the forward-looking statements that are included in this Quarterly Report, and the 2024 Form 10-K, our inclusion of this information is not a representation by us or any other person that our objectives and plans will be achieved. When you consider our forward-looking statements, you should keep in mind these risk factors and the other cautionary statements in this Quarterly Report.

Our forward-looking statements speak only as of the date the statements are made and reflect our best judgment about future events and trends based on the information currently available to us. Our results of operations can be affected by inaccurate assumptions we make or by risks and uncertainties known or unknown to us. Therefore, we cannot guarantee the accuracy of the forward-looking statements. Actual events and results of operations may vary materially from our current expectations and assumptions. Our forward-looking statements, express or implied, are expressly qualified in their entirety by this "Cautionary Statement Regarding Forward-Looking Statements," which constitute cautionary statements. These cautionary statements 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.

Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances occurring after the date of this Quarterly Report.

**INTRODUCTION**

Vaalco is a Houston, Texas-based, African-focused independent energy company with strong production and reserve portfolio of assets in Gabon, Egypt, Equatorial Guinea, Nigeria, Côte d'Ivoire, as well as Canada. We are currently engaged in the acquisition, exploration, development and production of crude oil, natural gas and NGLs.

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**RECENT DEVELOPMENTS** 

***Quarterly Cash Dividends*** 

The Company paid a quarterly cash dividend of $0.0625 per share of common stock for the second quarter of 2025 ($0.25 annualized) on June 27, 2025 to stockholders of record at the close of business on May 23, 2025. The Company also announced its next quarterly cash dividend of $0.0625 per share of common stock for the third quarter of 2025 ($0.25 annualized) to be paid on September 19, 2025 to stockholders of record at close of business on August 22, 2025. Payment of future dividends, if any, will be at the discretion of the board of directors after taking into account various factors, including current financial condition, the tax impact of repatriating cash, operating results and current and anticipated cash needs.

***Recent Operational Updates***

**Gabon** 

The Company secured a drilling rig in December 2024 in conjunction with its 2025/2026 drilling program, which is expected to begin near the end of the third quarter of 2025, as we wait for the drilling rig to complete its current commitments. The program includes drilling multiple development wells, and appraisal or exploration wells, and perform workovers, with options to drill additional wells. We plan to drill the wells at both the Etame platform and at our Seent platform, as well as a re-drill and several workovers in the Ebouri field to access production and reserves that were previously removed from proved reserves due to the presence of hydrogen sulfide.

In July 2025, the Company performed planned, staged shutdowns of the Gabon platforms to perform safety inspections and necessary maintenance to increase the integrity and reliability of the assets.

**Egypt**

The drilling campaign in Egypt, which commenced in December 2024, continued through the second quarter of 2025. During the second quarter of 2025, we completed six wells. Three of the wells drilled in the second quarter of 2025 will be hydraulically fractured in the third quarter of 2025. Based on detailed analysis completed in the first quarter of 2025 to evaluate the well inventory potential, a series of workover re-completions, re-activations and well optimizations have also been carried out resulting in an incremental production gain.

**Canada**

In 2024, Vaalco drilled and completed five horizontal wells in Canada, with all laterals being greater than two miles long. These wells continue to meet production expectations and the Company is monitoring their longer-term performance for future drilling opportunities. In 2025, the Company has decided to defer the drilling of additional wells in Canada based on a reassessment of capital allocation priorities across the portfolio, ensuring that investment is directed toward projects with the highest expected returns.

**Côte d'Ivoire**

As part of the planned dry dock refurbishment, the Baobab FPSO ceased hydrocarbon production on January 31, 2025 and the final lifting of crude oil from the FPSO took place in February 2025. The vessel departed from the field in late March 2025 and arrived at the shipyard in Dubai ahead of schedule in mid-May 2025. The FPSO refurbishment is now underway in the shipyard. A rig has been secured for significant development drilling which is expected to begin in 2026 after the FPSO returns to service bringing meaningful additions to production from the main Baobab field in CI-40. The Company is also evaluating the anticipated impact of the potential future development of the Kossipo field, which is also on the CI-40 license.

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**Equatorial Guinea**

We own a 60% working interest in an undeveloped portion of Block P offshore Equatorial Guinea where we are the designated operator. We have an existing plan of development of the Venus field discovery on Block P, which focuses on key areas of drilling evaluations, facilities design, market inquiries and metocean review. The Company is still reviewing a Front End Engineering and Design study and is currently targeting a Final Investment Decision by the end of 2025.

**CAPITAL RESOURCES AND LIQUIDITY**

***Cash Flows***

Our cash flows for the six months ended June 30, 2025 and 2024 are as follows:

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| | | | |
|:---|:---|:---|:---|
| | **Six Months Ended June 30,** | **Six Months Ended June 30,** | |
| | **2025** | **2024** | **Change in 2025 over 2024** |
|  | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Net cash provided by operating activities before changes in operating assets and liabilities | $**73370** | $76033 | $(2663) |
| Net change in operating assets and liabilities | **(22321)** | (54639) | 32318 |
| Net cash provided by operating activities | **51049** | 21394 | $**29655** |
| Net cash used in investing activities | **(107460)** | (48687) | (58773) |
| Net cash used in in financing activities | **32922** | (23567) | 56489 |
| Effects of exchange rate changes on cash | **96** | (233) | 329 |
| Net change in cash, cash equivalents and restricted cash | $**(23393)** | $(51093) | $27700 |

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The $29.7 million increase in net cash provided by operating activities during the six months ended June 30, 2025 compared to the six months ended June 30, 2024, was driven primarily by changes in operating assets and liabilities during the period. The net increase in changes provided by operating assets and liabilities of $32.3 million for the six months ended June 30, 2025 compared to the same period of 2024 was primarily related to the overall decrease in accrued liabilities and accounts payable, as well as the increase in collections from the Egypt receivables, value added tax and other receivables.

The $58.8 million change in net cash used in investing activities during the six months ended June 30, 2025 compared to the six months ended June 30, 2024, was due to costs associated with the development drilling programs in Egypt, as well as maintenance, project costs and long lead items for Gabon and Côte d'Ivoire. For the six months ended June 30, 2024, cash used in investing activities was due to capital spending costs associated with the development drilling programs in Egypt and Canada not exceeding prior year expenditures along with reduced current year expenditures for Gabon. In addition, Vaalco used $40.2 million in cash for the acquisition of Svenska which is offset by the cash received from Svenska in the amount of $40.6 million.

Net cash used in financing activities during the six months ended June 30, 2025 included $13.1 million for dividend distributions, $6.9 million of payments for deferred financing costs and $6.3 million of principal payments on our finance leases, offset by $60.0 million in proceeds from borrowings under the 2025 RBL Facility. For the six months ended June 30, 2024, cash used in financing activities included $13.0 million for dividend distributions, $6.8 million for treasury stock repurchases made under our stock repurchase plan or as a result of tax withholding on options exercised and on vested restricted stock, and $4.2 million of principal payments on our finance leases partially offset by $0.5 million in proceeds from options exercised.

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***Capital Expenditures***

For the six months ended June 30, 2025, we had accrual basis capital expenditures of $92.2 million compared to $46.5 million accrual basis capital expenditures for the same period in 2024. For the six months ended June 30, 2025, our cash spending primarily related to the new wells drilled as part of the drilling campaign in Egypt as well as expenditures associated with the preparation of the FPSO dry dock project in Côte d'Ivoire. During the same period in 2024, our cash spending primarily related to the Svenska acquisition as well as payments for the 2024 drilling campaigns in both Egypt and Canada.

See discussion below in "*Capital Resources, Liquidity and Cash Requirements*" for further information.

***Commodity Price Hedging***

The price we receive for our crude oil significantly influences our revenue, profitability, liquidity, access to capital and prospects for future growth. Crude oil and natural gas commodities, and therefore their prices, can be subject to wide fluctuations in response to relatively minor changes in supply and demand. We believe these prices will likely continue to be volatile in the future.

Due to the inherent volatility in crude oil prices, we use commodity derivative instruments such as swaps, costless collars and put options to hedge price risk associated with a portion of our anticipated crude oil and gas production. These instruments allow us to reduce, but not eliminate, the potential effects of variability in cash flow from operations due to fluctuations in commodity prices. The instruments provide only partial protection against declines in crude oil and gas prices and may limit our potential gains from future increases in prices. None of these instruments are used for trading purposes. We do not speculate on commodity prices, but rather attempt to hedge physical production by individual hydrocarbon product in order to protect returns. The counterparty to our derivative swap transactions was a major oil company's trading subsidiary, and our costless collars are with Glencore. We have not designated any of our derivative contracts as fair value or cash flow hedges. The changes in fair value of the contracts are included in the unaudited condensed consolidated statements of operations and other comprehensive income. We record such derivative instruments as assets or liabilities in the unaudited condensed consolidated balance sheets. Our 2025 RBL Facility requires us to enter into commodity price hedge positions establishing certain minimum fixed prices for anticipated future production. See Part I, Item 1, Note 8. Derivatives and Fair Value to the unaudited condensed consolidated financial statements for further discussion.

***Cash on Hand***

At June 30, 2025, we had unrestricted cash of $67.9 million. We invest cash not required for immediate operational and capital expenditure needs in short-term money market instruments primarily with financial institutions where we determine our credit exposure is negligible. As operator of the Etame Marin block in Gabon, we enter into project-related activities on behalf of our working interest joint venture owners. We generally obtain advances from joint venture owners prior to significant funding commitments. Our cash on hand will be utilized, along with cash generated from operations, to fund our operations and capital expenditures.

***Capital Resources, Liquidity and Cash Requirements***

Our primary source of liquidity has been cash flows from operations and our primary use of cash has been to fund capital expenditures for development activities. We continually monitor the availability of capital resources, including equity and debt financings that could be utilized to meet our future financial obligations, planned capital expenditure activities and liquidity requirements including those to fund opportunistic acquisitions. Our future success in growing proved reserves, production and balancing the long-term development of our assets with a focus on generating attractive corporate-level returns will be highly dependent on the capital resources available to us.

Based on current expectations, we believe we have sufficient liquidity through our existing cash balances, cash flow from operations and our 2025 RBL Facility to support our current cash requirements during the next 12 months and beyond, including the FPSO refurbishment, drilling programs, as well as transaction expenses and capital and operational costs associated with our business segments' operations. However, our ability to generate sufficient cash flow from operations or fund any potential future acquisitions, consortiums, joint ventures or pay dividends for other similar transactions depends on operating and economic conditions, some of which are beyond our control. If additional capital is needed, we may not be able to obtain debt or equity financing on terms favorable to us, or at all. We are continuing to evaluate all uses of cash, including opportunistic acquisitions, and whether to pursue growth opportunities and whether such growth opportunities,

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additional sources of liquidity, including equity and/or debt financings, are appropriate to fund any such growth opportunities.

***Merged Concession Agreement***

For information on the Merged Concession Agreement, see Part I, Item 1, Note 10. Commitments and Contingencies to the unaudited condensed consolidated financial statements.

***2025 Facility Agreement and Available Credit***

For information on our 2025 Facility Agreement and available credit, see Part I, Item 1., Note 11. Debt, to the unaudited condensed consolidated financial statements.

***Cash Requirements***

Our material cash requirements generally consist of the FPSO refurbishment, finance and operating leases, capital projects, dividend payments, Merged Concession Agreement and abandonment funding, each of which is discussed in further detail below.

*Abandonment Funding* - Under the terms of the Etame PSC, we have a cash funding arrangement for the eventual abandonment of all offshore wells, platforms and facilities on the Etame Marin block. As a result of the extension of the Etame PSC, annual funding payments are spread over the periods from 2018 through 2028, under the applicable abandonment study. The amounts paid will be reimbursed through the Cost Account and are non-refundable. At June 30, 2025, the balance of the abandonment fund was $10.7 million ($6.3 million, net to Vaalco) on an undiscounted basis. The annual payments will be adjusted based on revisions in the abandonment estimate. This cash funding is reflected under "Other noncurrent assets" in the "Abandonment funding" line item of the unaudited condensed consolidated balance sheets. Future changes to the anticipated abandonment cost estimate could change the asset retirement obligation and the amount of future abandonment funding payments.

*Capital Projects* - In December 2024, Vaalco secured a rig for the 2025/26 drilling campaign at Etame and is currently finalizing locations and planning for the next drilling campaign, which is expected to begin near the end of the third quarter of 2025. In Egypt, additional drilling and completion activity is expected in the second half of 2025.

*Leases -* We are a party to several operating and financing lease arrangements, including operating leases for the corporate office, a drilling rig, rental of marine vessels and a helicopter, warehouse and storage facilities, equipment and financing lease agreements for the FSO, generators and turbines used in the operations of the Etame Marin block and for equipment, offices and vehicles used in the operations of Canada and Egypt. The annual costs of these leases are significant to us.

*Merged Concession Agreement* - On January 20, 2022, the Merged Concession Agreement was executed with EGPC that merged the three existing Eastern Desert concessions with a 15-year primary term and improved economics. As part of the agreement, the Company is required to make an annual modernization payment of $10.0 million per year to EGPC through February 2026. In accordance with the Merged Concession Agreement, we agreed to substitute the 2023, 2024 and 2025 payments and issue three $10.0 million credits against receivables owed from EGPC. We will make one further annual modernization payment of $10.0 million on February 1, 2026. For information on the Merged Concession Agreement, see Part I, Item 1, Note 10. Commitments and Contingencies to the unaudited condensed consolidated financial statements.

*Financial Work Commitments -* In Egypt, we also have financial work commitments of $50.0 million per each five-year period of the primary development term, commencing on February 1, 2020 for a total of $150 million over the 15 year license contract term. Through June 30, 2025, our financial work commitments have exceeded the five-year minimum $50 million threshold and any excess carries forward to offset against subsequent five-year commitments.

*FPSO Maintenance* – The Baobab FPSO arrived at the shipyard in Dubai ahead of schedule in mid-May for planned maintenance and upgrades. The FPSO refurbishment is now underway in the shipyard. The FPSO is expected to return to service in 2026.

**Trends and Uncertainties**

*Geopolitical Conflict and Other Market Forces* – The outbreak of armed conflict between Russia and Ukraine in February 2022 and the subsequent sanctions imposed on the Russian Federation has, and may continue to have, a destabilizing effect on the European continent and the global oil and natural gas markets. The ongoing conflict has caused, and could continue

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to intensify, volatility in oil and natural gas prices, and the extent and duration of the military action, sanctions and resulting market disruptions could be significant and could potentially have a substantial negative impact on the global economy and/or our business for an unknown period of time.

For example, shortly after the outbreak of the conflict through the year ended December 31, 2024 and ongoing into 2025, we noticed that the lead times associated with obtaining materials to support our operations and drilling activities have lengthened, leading to delays and, in most cases, prices for materials have increased. Management believes the ongoing war between Russia and Ukraine, the Houthis attacks on maritime vessels in the Red Sea region, conflicts in the Middle East and the related impact on the global economy are causing supply chain issues and energy concerns in parts of the global economy, as well as destabilizing impacts on the global oil and natural gas market. In addition, increased inflation, higher interest rates and current turmoil in certain governments are impacting the global supply chain market.

*U.S. Tariffs and Global Trade Policies* – In 2025, the U.S. administration enacted sweeping trade legislation, including significant tariff increases on industrial goods, energy-related equipment, and certain critical minerals, with a stated intent to prioritize domestic manufacturing and energy security. While there is significant uncertainty as to the duration of these and any further tariffs, and the impacts these tariffs and any corresponding retaliatory tariffs will have on the oil and gas industry and on commodity prices, these tariffs, along with anticipated retaliatory measures from affected trading partners, have introduced new volatility into the global supply chain for energy infrastructure. While we do not maintain U.S. based production assets, our operations in Canada and on the continent of Africa rely on equipment, services, and materials that are often sourced, engineered, or consolidated through the United States or through U.S. aligned trading routes. As a result, we may experience increased costs and longer lead times for the procurement and delivery of drilling and production equipment, particularly if suppliers adjust pricing in response to increased duties or if we are required to diversify sourcing channels. These impacts could affect the timing, cost structure and execution risk of certain development activities, especially in frontier offshore environments.

Additionally, the evolving global trade environment may increase compliance complexity and affect the cost efficiency of international operations. Enhanced documentation requirements and new rules of origin associated with U.S. trade actions could impact our ability to efficiently move materials through international logistics hubs, such as those in Houston, Texas and could necessitate additional internal resources to maintain compliance.

*Enactment of the One Big Beautiful Bill Act of 2025* – On July 4, 2025, the budget reconciliation bill known as the One Big Beautiful Bill Act of 2025 ("OBBBA") was signed into law, which includes significant changes to federal tax law and other regulatory provisions that may impact the Company. Among other provisions, the OBBBA makes permanent key elements of the Tax Cuts and Jobs Act of 2017. We are currently evaluating the provisions of the OBBBA law and the potential effects on our financial position, results of operations, and cash flows, however we do not anticipate any material financial impact from the passage of the OBBBA.

Moreover, to the extent U.S. policy shifts create uncertainty in bilateral relations or disrupt traditional trade partnerships, there could be indirect effects on our ability to manage risk and maintain favorable operating conditions in host countries. While we continue to monitor the evolving regulatory and trade landscape, we cannot predict the full impact of current or future tariffs, trade restrictions or retaliatory actions on our operations, financial condition or future capital deployment decisions.

*Commodity Prices* – Historically, the markets for oil, natural gas and NGLs have been volatile. Oil, natural gas and NGLs prices are subject to wide fluctuations in supply and demand. Our cash flows from operations may be adversely impacted by volatility in crude oil and natural gas prices, a decrease in demand for crude oil, natural gas or NGLs and future production cuts by OPEC. In addition, recent U.S. energy policy changes that prioritize domestic production and energy security, including through tax credits and development incentives, may influence global supply dynamics and capital flows, potentially altering the competitive landscape for international assets.

*ESG and Climate Change Effects* – Sustainability matters continue to attract public, political, regulatory and scientific attention.

While 2025 has seen a deceleration in the adoption of sustainability-oriented regulation, particularly in the U.S., and a noticeable shift by some financial institutions away from explicitly "ESG" or "Net Zero" branded initiatives due to perceived political or reputational sensitivities, we believe the underlying trend of focusing on sustainability remains consistent. Long-term structural pressures, including stakeholder expectations, evolving global market standards, and transition-related investment priorities, continue to support the integration of sustainability considerations into corporate strategy and capital markets.

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We expect continued required reporting attention on climate change issues and emissions of greenhouse gases ("GHG"), including methane (a primary component of natural gas) and carbon dioxide (a byproduct of crude oil and natural gas combustion) and freshwater use as and when the UK Government confirms that UK listed businesses shall be required to comply with IFRS S2 Climate-Related Disclosures. These requirements replace the Task Force on Climate-related Financial Disclosures ("TCFD") reporting requirements noted below.

The attention to climate change and environmental stewardship coupled with increasing government incentives around renewable energy sources may result in demand shifts away from crude oil and natural gas products, higher regulatory and compliance costs, additional governmental investigations and private litigation against the oil and gas industry, including Vaalco. For example, numerous proposals have been made and are likely to continue to be made at the international, national, regional and state levels of government to monitor and limit emissions of GHGs. These efforts have included consideration of cap-and-trade programs, carbon taxes, voluntary efforts to reduce routine flaring, GHG reporting and tracking programs and regulations that directly limit GHG emissions from certain sources. In addition, institutional investors, proxy advisory firms and other industry participants continue to focus on environmental, social and governance ("ESG") matters, including climate change. We expect that this heightened focus will continue to drive ESG efforts across our industry and influence investment and voting decisions, which for some investors may lead to less favorable sentiment towards carbon assets and diversion of investment to other industries.

*Climate-Related Disclosures* – On March 27, 2025, the SEC ended its defense of the final rules on climate-related disclosures, effectively withdrawing its support for the regulation. The rules, which were adopted in March 2024, require publicly traded companies to disclose climate-related risks and greenhouse gas emissions. The SEC's decision to end its defense was made after a change in administration and a shift in policy, with Acting Chairman Mark Uyeda expressing concerns about the rule's costs and intrusiveness. While the rules remain on hold pending legal challenges, the SEC's withdrawal of support signals a potential shift in direction for climate disclosure regulations. Despite this regulatory shift in the U.S., we remain committed to maintaining transparency and aligning with industry standards for similarly situated companies.

US activity notwithstanding, for the past three years, the Company has refined its reporting in line with the recommendations of the TCFD, which is recognized as the global standard in climate-related reporting and required by Vaalco to report against through its listing on the London Stock Exchange. The full TCFD report was included within the Company's 2024 Sustainability Report (rather than in the Annual Report on Form 10-K or in the annual report which was published in connection with the annual meeting), as the Sustainability Report details environmental, social and governance matters of which the TCFD report forms an important part. The 2024 Sustainability Report is available on the Company's website.

The Company considers itself aligned with both the TCFD's Governance and Strategy pillars and the recommendations therein. During 2025, the Company has made meaningful progress against certain of the underlying recommendations of the TCFD's Governance and Strategy pillars and provides statements of intent to address these recommendations, including communicating its short-, mid- and long-range goals for emission reductions, beginning with its operated assets.

**CRITICAL ACCOUNTING POLICIES AND ESTIMATES**

There have been no material changes to our critical accounting policies and estimates subsequent to December 31, 2024. For a discussion of the Company's critical accounting policies for the fiscal year ended December 31, 2024, please see our 2024 Form 10-K.

**NEW ACCOUNTING STANDARDS**

See Part I, Item 1, Note 2. New Accounting Standards to the unaudited condensed consolidated financial statements.

**RESULTS OF OPERATIONS** 

***Three Months Ended June 30, 2025 Compared to the Three Months Ended June 30, 2024***

Net income for the three months ended June 30, 2025 was $8.4 million compared to a net income of $28.2 million during the same period of 2024. See discussion below for changes in revenues and expenses.

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*Crude oil, natural gas and NGLs revenues* decreased $19.9 million, or approximately 17%, to $96.9 million during the three months ended June 30, 2025 from $116.8 million during the same period in 2024. The revenue decrease is primarily attributable to lower revenues in our Côte d'Ivoire and Canada segments.

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| | | | |
|:---|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** | **Increase/(Decrease)** |
| | **2025** | **2024** | **Increase/(Decrease)** |
|  | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Net crude oil, natural gas, and NGLs revenue | $**96893** | $116778 | $(19885) |
| Operating costs and expenses: |  |  |  |
| &nbsp;&nbsp;&nbsp;Production expense | **40393** | 52446 | (12053) |
| &nbsp;&nbsp;&nbsp;Exploration expense | **2520** |  | 2520 |
| &nbsp;&nbsp;&nbsp;Depreciation, depletion and amortization | **28273** | 33132 | (4859) |
| &nbsp;&nbsp;&nbsp;General and administrative expense | **8496** | 7591 | 905 |
| &nbsp;&nbsp;&nbsp;Credit losses and other | **29** | 3341 | (3312) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating costs and expenses | **79711** | 96510 | (16799) |
| &nbsp;&nbsp;&nbsp;Other operating income, net | **—** | 132 | (132) |
| Operating income | **17182** | 20400 | (3218) |
| Other expense, net | **(1819)** | 17054 | (18873) |
| Income before income taxes | **15363** | 37454 | (22091) |
| Income tax expense | **6983** | 9303 | (2320) |
| Net income | $**8380** | $28151 | $(19771) |

---

The revenue changes in the three months ended June 30, 2025 compared to the same period in 2024 identified as related to changes in price or volume, are shown in the table below:

---

| | |
|:---|:---|
| *(in thousands)* |  |
| Price | $(20036) |
| Volume | 50 |
| Other<sup>(1)</sup> | 101 |
|  | (19885) |

---

<sup>(1)</sup> Other in the table above includes revenues attributed to carried interests.

The table below shows net production, sales volumes and realized prices for both periods.

---

| | | |
|:---|:---|:---|
| | **Three Months Ended June 30,** | **Three Months Ended June 30,** |
| | **2025** | **2024** |
| Net crude oil, natural gas and NGLs production (MBoe) | **1543** | 1874 |
| Net crude oil, natural gas and NGLs sales (MBoe) | **1765** | 1764 |
| Average realized crude oil, natural gas and NGLs price ($/Boe) | $**54.87** | $66.22 |
| Average Dated Brent spot price\* ($/Bbl) | $**68.07** | $84.65 |

---

\*Average of daily Dated Brent spot prices posted on the U.S. Energy Information Administration website.

***Crude oil, natural gas and NGL revenues:***

*Gabon* 

Crude oil sales in Gabon are a function of the number and size of crude oil liftings in each year and thus crude oil sales do not always coincide with volumes produced in any given year. The Company's Gabon segment contributed $58.6 million of revenue to the Company's total revenue during the three months ended June 30, 2025, an increase of $4.9 million from

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the $53.7 million of revenue reported during the three months ended June 30, 2024. The increase in revenues is primarily due to a sales volume increase in Gabon from the 660 MBbls reported during the second quarter of 2024 to 900 MBbls for the three months ended June 30, 2025, offset by a lower average realized sales price received in Gabon of $65.02 per Bbl for three months ended June 30, 2025 compared to the $81.29 per Bbl average realized sales price received during the same period in 2024. Gabon's share of crude oil inventory, excluding royalty barrels, was approximately 54,776 barrels and 129,803 barrels at June 30, 2025 and 2024, respectively.

*Egypt*

Crude oil sales in Egypt are either sold to a third party via a cargo lifting or sold directly to the government, through EGPC. During the three months ended June 30, 2025, the oil sold in Egypt was through direct sales to EGPC. The Company's Egypt segment contributed $33.3 million of revenue to the Company's total revenue for the three months ended June 30, 2025, which is slightly lower than the $35.5 million of revenue reported during the three months ended June 30, 2024. The decrease in revenues was primarily due to a decrease in average realized sales price from $55.19 per Bbl during the three months ended June 30, 2024 to $48.01 per Bbl during the same period in 2025. Sales volumes in Egypt remained relatively consistent at 693 MBbls and 643 MBbls, during the three months ended June 30, 2025 and 2024, respectively.

*Canada*

Crude oil sales in Canada are normally sold through pipelines to a third party. The Company's Canadian segment contributed $4.7 million of revenue to the Company's total revenue for the three months ended June 30, 2025, or a decrease of $5.7 million compared to $10.4 million of revenue reported during the three months ended June 30, 2024. The decrease in revenues was primarily due to lower average realized sales price received of $27.35 per Boe during the three months ended June 30, 2025 compared to the $41.68 per Boe received during the same period in 2024. Sales volumes in Canada decreased during the three months ended June 30, 2025 to 172 MBoe in comparison to 249 MBoe in the same period in 2024.

*Côte d'Ivoire* 

Crude oil sales in Côte d'Ivoire are sold through a marketing contract with an international oil trading company which offers the cargo shipments to buyers, mainly refineries, around the world. The Company's Côte d'Ivoire segment contributed $0.4 million of revenue to the Company's total revenue during the three months ended June 30, 2025. As previously noted, the FPSO refurbishment is now underway in the shipyard. The FPSO is expected to return to service in 2026.

*Production expense*s decreased $12.1 million, or approximately 23%, for the three months ended June 30, 2025 to $40.4 million from $52.4 million for the same period in the prior year. The decrease was primarily driven by a reduction in production expenses in our Côte d'Ivoire segment. On a per barrel basis, production expense, excluding workover expense and stock compensation expense, for the three months ended June 30, 2025 decreased to $22.85 per barrel from $29.68 per barrel for the three months ended June 30, 2024.

*Exploration expense* for the three months ended June 30, 2025 of $2.5 million was attributable to the purchase of seismic data to be used in Block 705 in Cote d'Ivoire. There were no exploration costs incurred during the same period in 2024.

*Depreciation, depletion and amortization* costs decreased $4.9 million, or approximately 15%, for the three months ended June 30, 2025 to $28.3 million from $33.1 million during the same period in 2024. Since there was no production during the three months ended June 30, 2025 in Côte d'Ivoire, there was also no depletion expense recorded and therefore resulted in the decrease in the overall depletion expense for the period.

*General and administrative expenses* slightly increased $0.9 million, or 12%, for the three months ended June 30, 2025 to $8.5 million from $7.6 million during the same period in 2024. The increase in general and administrative expenses is primarily due to an increase in professional service fees, salaries and wages, and accounting and legal fees.

*Credit losses and other* decreased by approximately $3.3 million during the three months ended June 30, 2025 compared to the same period in 2024. The decrease in credit losses and other is primarily attributable to the higher allowance calculated during the second quarter of 2024 related to the Backdated Receivables, defined in Part I, Item 1, Note 10. Commitments and Contingencies to the unaudited condensed consolidated financial statements. The Backdated Receivables were settled as of March 31, 2025.

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*Derivative instruments gain (loss), net* is attributable to our swaps and collars as discussed in Part I, Item 1, Note 8. Derivatives and Fair Value to the unaudited condensed consolidated financial statements. Derivative gain increased by $0.1 million to a gain of $0.4 million for the three months ended June 30, 2025 from a gain of $0.3 million during the same period in 2024. Derivative gains for the three months ended June 30, 2025 are a result of the decrease in the price of Dated Brent crude oil over the initial strike price per barrel of the option over the three months ended June 30, 2025. Our derivative instruments currently cover a portion of our production through July 2026 for oil and through March 2026 for natural gas.

*Interest expense, net* was $2.6 million for the three months ended June 30, 2025 compared to an expense of $1.1 million during the same period in 2024. The increase in net interest expense for the three months ended June 30, 2025 primarily resulted from an increase in our amortization of debt issue costs, commitment fees incurred and interest incurred on our borrowing under the 2025 RBL Facility, partially offset by interest income.

*Other income (expense), net* decreased by $2.3 million to an income of $0.4 million for the three months ended June 30, 2025 from a $2.0 million expense during the same period in 2024. Other income (expense), net, normally consists primarily of foreign currency gains and losses. However, during the three months ended June 30, 2024, there was a $1.7 million expense related to transactions costs associated with the Svenska acquisition.

*Income tax expense (benefit)* for the three months ended June 30, 2025 was an expense of $7.0 million which includes a $3.1 million favorable oil price adjustment as a result of the change in value of the government of Gabon's allocation of Profit Oil between the time it was produced and the time it was taken in-kind. After excluding this impact, income taxes were $10.1 million for the period. Income tax expense for the three months ended June 30, 2024 was an expense of $9.3 million. This expense is comprised of current tax expense of $10.4 million including a $1.1 million favorable oil price adjustment as a result of the change in value of the government of Gabon's allocation of Profit Oil between the time it was produced and the time it was taken in-kind. After excluding this impact, current income taxes were $10.4 million for the period.

***Six Months Ended June 30, 2025 Compared to the Six Months Ended June 30, 2024***

Net income for the six months ended June 30, 2025 was $16.1 million compared to a net income of $35.8 million during the same period of 2024. See discussion below for changes in revenues and expenses.

*Crude oil, natural gas and NGLs revenues* decreased $9.7 million, or approximately 4%, to $207.2 million during the six months ended June 30, 2025 from $216.9 million during the same period in 2024. The revenue decrease is primarily due to lower revenues in Egypt and Canada.

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| | | | |
|:---|:---|:---|:---|
| | **Six Months Ended June 30,** | **Six Months Ended June 30,** | **Increase/(Decrease)** |
| | **2025** | **2024** | **Increase/(Decrease)** |
|  | ***(in thousands)*** | ***(in thousands)*** | ***(in thousands)*** |
| Net crude oil, natural gas, and NGLs revenue | $**207222** | $216933 | $(9711) |
| Operating costs and expenses: |  |  |  |
| &nbsp;&nbsp;&nbsp;Production expense | **85198** | 84535 | 663 |
| &nbsp;&nbsp;&nbsp;Exploration expense | **2520** | 48 | 2472 |
| &nbsp;&nbsp;&nbsp;Depreciation, depletion and amortization | **58578** | 58956 | (378) |
| &nbsp;&nbsp;&nbsp;General and administrative expense | **17548** | 14301 | 3247 |
| &nbsp;&nbsp;&nbsp;Credit losses and other | **2** | 5153 | (5151) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating costs and expenses | **163846** | 162993 | 853 |
| &nbsp;&nbsp;&nbsp;Other operating expense, net | **—** | (34) | 34 |
| Operating income | **43376** | 53906 | (10530) |
| Other income (expense), net | **(4199)** | 13472 | (17671) |
| Income before income taxes | **39177** | 67378 | (28201) |
| Income tax expense | **23066** | 31541 | (8475) |
| Net income | $**16111** | $35837 | $(19726) |

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The revenue changes in the six months ended June 30, 2025 compared to the same period in 2024 identified as related to changes in price or volume, are shown in the table below:

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| | |
|:---|:---|
| *(in thousands)* |  |
| Price | $(24948) |
| Volume | 15160 |
| Other<sup>(1)</sup> | 77 |
|  | $(9711) |

---

<sup>(1)</sup> Other in the table above includes revenues attributed to carried interests.

The table below shows net production, sales volumes and realized prices for both periods.

---

| | | |
|:---|:---|:---|
| | **Six Months Ended June 30,** | **Six Months Ended June 30,** |
| | **2025** | **2024** |
| Net crude oil, natural gas and NGLs production (MBoe) | **3142** | 3406 |
| Net crude oil, natural gas and NGLs sales (MBoe) | **3481** | 3254 |
| Average realized crude oil, natural gas and NGLs price ($/Boe) | $**59.50** | $66.67 |
| Average Dated Brent spot price\* ($/Bbl) | $**72.03** | $83.83 |

---

\*Average of daily Dated Brent spot prices posted on the U.S. Energy Information Administration website.

***Crude oil, natural gas and NGL revenues:***

*Gabon* 

Crude oil sales in Gabon are a function of the number and size of crude oil liftings in each year and thus crude oil sales do not always coincide with volumes produced in any given year. The Company's Gabon segment contributed $110.8 million of revenue to the Company's total revenue during the six months ended June 30, 2025, a slight decrease of $0.4 million from the $111.2 million of revenue reported during the six months ended June 30, 2024. The decrease in revenues is primarily due to the lower average realized sales price received in Gabon of $71.04 per Bbl for six months ended June 30, 2025 compared to $83.61 per Bbl average realized sales price received during the same period in 2024 offset by an increase in sales volume in Gabon to 1,558 MBbls for the six months ended June 30, 2025 from the 1,330 MBbls sales volume during the same period of 2024. Gabon's share of crude oil inventory, excluding royalty barrels, was approximately 54,776 barrels and 129,803 barrels at six months ended June 30, 2025 and 2024, respectively.

*Egypt*

Crude oil sales in Egypt are either sold to a third party via a cargo lifting or sold directly to the government, through EGPC. During the six months ended June 30, 2025, the oil sold in Egypt was through direct sales to EGPC. The Company's Egypt segment contributed $67.2 million of revenue to the Company's total revenue for the six months ended June 30, 2025, which is $5.2 million lower than the $72.4 million of revenue reported during the six months ended June 30, 2024. The decrease in revenues was primarily due to a decrease in average realized sales price from $56.43 per Bbl during the six months ended June 30, 2024 to $50.34 per Bbl during the same period in 2025. Sales volumes in Egypt remained relatively consistent at 1,334 MBbls and 1,284 MBbls during the six months ended June 30, 2025 and 2024, respectively.

*Canada*

Crude oil sales in Canada are normally sold through pipelines to a third party. The Company's Canadian segment contributed $10.9 million of revenue to the Company's total revenue for the six months ended June 30, 2025, or a decrease of $5.2 million, compared to $16.1 million of revenue reported during the six months ended June 30, 2024. The decrease in revenues was primarily due to lower average realized sales price received of $31.04 per Boe during the six months ended June 30, 2025 compared to $37.46 per Boe received during the same period in 2024. Sales volumes in Canada decreased during the six months ended June 30, 2025 to 351 MBoe in comparison to 429 MBoe in the same period in 2024.

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*Côte d'Ivoire* 

Crude oil sales in Côte d'Ivoire are sold through a marketing contract with an international oil trading company which offers the cargo shipments to buyers, mainly refineries, around the world. The Company's Côte d'Ivoire segment contributed $18.4 million of revenue to the Company's total revenue for the six months ended June 30, 2025, or an increase of $1.2 million, compared to $17.2 million of revenue reported during the six months ended June 30, 2024. The increase in revenues was primarily due to an increase in sales volumes from 211 MBbls during six months ended June 30, 2024 to 238 MBbls during the same period in 2025. The increase in sales volumes is offset by lower average realized sales price received of $77.36 per Boe during the six months ended June 30, 2025 compared to $81.59 per Boe received during the same period in 2024.

*Production expense*s increased $0.7 million for the six months ended June 30, 2025 to $85.2 million from $84.5 million for the same period in the prior year. The increase was primarily driven by higher expenses in Gabon which includes customs costs of approximately $4.7 million and increased maintenance costs to enhance well productivity partially offset by a decrease in expenses in the Cote d'Ivoire segment. On a per barrel basis, production expense, excluding workover expense and stock compensation expense, for the six months ended June 30, 2025 decreased to $24.43 per barrel from $25.96 per barrel for the six months ended June 30, 2024.

*Exploration expense* for the six months ended June 30, 2025 of $2.5 million was attributable to the purchase of seismic data to be used in Block 705 in Cote d'Ivoire. Exploration costs incurred during the same period in 2024 was minimal.

*Depreciation, depletion and amortization* costs decreased $0.4 million, or approximately 1%, for the six months ended June 30, 2025 to $58.6 million from $59.0 million during the same period in 2024. The decrease in depreciation, depletion and amortization expense is primarily related to the lower depletable costs in Gabon and Egypt.

*General and administrative expenses* slightly increased $3.2 million, or 23%, for the six months ended June 30, 2025 to $17.5 million from $14.3 million during the same period in 2024. The increase in general and administrative expenses is primarily due to an increase in professional service fees, salaries and wages, and accounting and legal fees.

*Credit losses and other* decreased by approximately $5.2 million during the six months ended June 30, 2025 compared to the same period in 2024. The decrease in credit losses and other for the six months ended June 30, 2025, is primarily attributable to the higher allowance calculated during the first six months of 2024 related to the Backdated Receivables, defined in Part I, Item 1, Note 10. Commitments and Contingencies to the unaudited condensed consolidated financial statements. The Backdated Receivables were settled as of March 31, 2025.

*Derivative instruments gain (loss), net* is attributable to our swaps and collars as discussed in Part I, Item 1, Note 8. Derivatives and Fair Value to the unaudited condensed consolidated financial statements. Derivative loss decreased by $0.9 million to a gain of $0.3 million for the six months ended June 30, 2025 from a loss of $0.6 million during the same period in 2024. Derivative gains for the six months ended June 30, 2025 are a result of the decrease in the price of Dated Brent crude oil over the initial strike price per barrel of the option over the six months ended June 30, 2025. Our derivative instruments currently cover a portion of our production through July 2026 for oil and through March 2026 for gas.

*Interest expense, net* was $3.9 million for the six months ended June 30, 2025 compared to an expense of $2.1 million during the same period in 2024. The increase in net interest expense for the six months ended June 30, 2025 primarily resulted from an increase in our amortization of debt issue costs, commitment fees incurred and interest incurred on our borrowings under the 2025 RBL Facility, partially offset by interest income.

*Other income (expense), net* decreased by $3.1 million compared to an expense of $0.7 million for the six months ended June 30, 2025 from a $3.8 million expense during the same period in 2024. The decrease in other income (expense) was substantially due to transactions costs associated with the Svenska acquisition of $3.1 million that were incurred during the six months ended June 30, 2024.

*Income tax expense (benefit)* for the six months ended June 30, 2025 was an expense of $23.1 million which includes a $2.4 million favorable oil price adjustment as a result of the change in value of the government of Gabon's allocation of Profit Oil between the time it was produced and the time it was taken in-kind. After excluding this impact, income taxes were $25.4 million for the period. Income tax expense for the six months ended June 30, 2024 was an expense of $31.5 million. This expense is comprised of current tax expense of $26.4 million including a $0.6 million adverse oil price

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adjustment as a result of the change in value of the government of Gabon's allocation of Profit Oil between the time it was produced and the time it was taken in-kind. After excluding this impact, current income taxes were $30.9 million for the period.

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**ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK**

**MARKET RISK**

We are exposed to market risk, including the effects of adverse changes in commodity prices, foreign exchange rates and interest rates as described below.

**FOREIGN EXCHANGE RISK** 

Our results of operations and financial condition are affected by currency exchange rates. While crude oil sales are denominated in U.S. dollars, portions of our costs in Gabon are denominated in the local currency (the "Central African CFA Franc" or "XAF"), and our VAT receivable as well as certain liabilities in Gabon are also denominated in XAF. A weakening U.S. dollar will have the effect of increasing costs while a strengthening U.S. dollar will have the effect of reducing costs. For our VAT receivable in Gabon, a strengthening U.S. dollar will have the effect of decreasing the value of this receivable resulting in foreign exchange losses, and vice versa. The Gabon local currency is tied to the Euro. The exchange rate between the Euro and the U.S. dollar has historically fluctuated in response to international political conditions, general economic conditions and other factors beyond our control. As of June 30, 2025, we had net monetary liabilities of $145.6 million (XAF $81.5 billion) denominated in XAF. Using month-end cash balances converted at month-end foreign exchange rates at June 30, 2025, we estimate that a 10% weakening of the CFA relative to the U.S. dollar would have a $13.2 million reduction in the value of these net liabilities. For the six months ended June 30, 2025, we had expenditures of approximately $48.1 million net to Vaalco), denominated in XAF.

Related to our Canadian operations, our currency exchange risk relates primarily to certain cash and cash equivalents, accounts receivable, lease obligations and accounts payable and accrued liabilities denominated in Canadian dollars. Using month-end cash balances converted at month-end foreign exchange rates at June 30, 2025, we estimate that a 10% decrease in the value of the Canadian dollar against the US dollar would decrease the value of the net assets for the three months ended June 30, 2025 by approximately $0.6 million. Conversely, a 10% increase in the value of the Canadian dollar against the US dollar would increase the value of the net assets for the six months ended June 30, 2025 by approximately $0.8 million.

We are also exposed to foreign currency exchange risk on cash balances denominated in Egyptian pounds. Some collections of accounts receivable from the Egyptian Government are received in Egyptian pounds, and while we are generally able to use the Egyptian pounds received on accounts payable denominated in Egyptian pounds, there remains foreign currency exchange risk exposure on Egyptian pound cash balances. Using month-end cash balances converted at month-end foreign exchange rates at June 30, 2025, we estimate that a 10% increase in the value of the Egyptian pound against the US dollar would increase the cash value for the six months ended June 30, 2025 by $7.5 million. Conversely, a 10% decrease in the value of the Egyptian pound against the US dollar would decrease our US dollar cash value for the six months ended June 30, 2025 by $6.1 million.

In Côte d'Ivoire, our currency exchange risk also relates primarily to certain cash and cash equivalents, accounts receivable and accounts payable and accrued liabilities denominated in Swedish Krona. We estimate that a 10% increase in the value of the Swedish Krona against the US dollar would increase the value of the net liabilities for the six months ended June 30, 2025 by approximately $9.7 million. Conversely, a 10% decrease in the value of the Swedish Krona against the US dollar would decrease the value of the net liabilities for the six months ended June 30, 2025 by approximately $7.9 million.

We do not utilize derivative instruments to manage foreign exchange risk.

We maintain nominal balances of British Pounds Sterling to pay in-country costs incurred in operating our London office. Foreign exchange risk on these funds is not considered material.

**COUNTERPARTY RISK**

We are exposed to market risk on our open derivative instruments related to potential nonperformance by our counterparties. To mitigate this risk, we enter into such derivative contracts with creditworthy financial institutions deemed by management as competent and competitive market makers.

**COMMODITY PRICE RISK** 

Our major market risk exposure continues to be the prices received for our crude oil, natural gas and NGLs production. Sales prices are primarily driven by the prevailing market prices applicable to our production. Market prices for crude oil,

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natural gas and NGLs have been volatile and unpredictable in recent years, and this volatility may continue. Sustained low crude oil, natural gas and NGLs prices or a resumption of the decreases in crude oil, natural gas and NGLs prices could have a material adverse effect on our financial condition, the carrying value of our proved reserves, our undeveloped leasehold interests and our ability to borrow funds and to obtain additional capital on attractive terms.

At June 30, 2025, the Company had open commodity derivative contracts covering our anticipated future production as follows:

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| | | | | | |
|:---|:---|:---|:---|:---|:---|
| | | **Settlement Period** | **Settlement Period** | **Settlement Period** | **Settlement Period** |
|<br>**Instrument** |<br>**Index** | **July 2025 to September 2025** | **October 2025 to December 2025** | **January 2026 to March 2026** | **April 2026 to June 2026** |
| **Crude oil:** | | | | | |
| *Swaps* | Dated Brent |  |  |  |  |
| &nbsp;&nbsp;Total volumes (Bbls) |  | 100000 |  |  |  |
| &nbsp;&nbsp;Weighted average fixed price ($/Bbl) |  | $65.45 | $— | $— | $— |
| *Collars* | Dated Brent |  |  |  |  |
| &nbsp;&nbsp;Total volumes (Bbls) |  | 405000 | 480000 | 400000 | 360000 |
| &nbsp;&nbsp;Weighted average floor price ($/Bbl) |  | $63.02 | $60.83 | $62.29 | $61.88 |
| &nbsp;&nbsp;Weighted average ceiling price ($/Bbl) |  | $74.36 | $67.81 | $68.63 | $67.95 |
| **Natural Gas:** |  |  |  |  |  |
| *Swaps* | AECO 7A |  |  |  |  |
| &nbsp;&nbsp;Total volumes (GJs)<sup>(a)</sup> |  | 342000 | 114000 |  |  |
| &nbsp;&nbsp;Weighted average fixed price (CAD/GJ) |  | $2.15 | $2.15 | $— | $— |

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(a) One gigajoule (GJ) equals one billion joules (J). A gigajoule of natural gas is approximately 25.5 cubic meters standard conditions.

The table below presents commodity swaps entered into subsequent to June 30, 2025.

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| | | | | |
|:---|:---|:---|:---|:---|
| | | **Settlement Period** | **Settlement Period** | **Settlement Period** |
|<br>**Instrument** |<br>**Index** | **October 2025 to December 2025** | **January 2026 to March 2026** | **July 2026** |
| **Crude oil:** | | | | |
| *Collars* | Dated Brent |  |  |  |
| &nbsp;&nbsp;Total volumes (Bbls) |  |  |  | 75000 |
| &nbsp;&nbsp;Weighted average floor price ($/Bbl) |  | $— | $— | $65.00 |
| &nbsp;&nbsp;Weighted average ceiling price ($/Bbl) |  | $— | $— | $71.00 |
| **Natural Gas:** |  |  |  |  |
| *Swaps* | AECO 7A |  |  |  |
| &nbsp;&nbsp;Total volumes (GJs)<sup>(a)</sup> |  | 100000 | 150000 |  |
| &nbsp;&nbsp;Weighted average fixed price (CAD/GJ) |  | $2.86 | $2.86 | $— |

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&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;a) One gigajoule (GJ) equals one billion joules (J). A gigajoule of natural gas is approximately 25.5 cubic meters standard conditions.

Oil and gas properties are assessed for impairment annually as well as whenever events or changes in circumstances indicate that a property's carrying amount may not be recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company would estimate the fair value of its properties and record an impairment charge for any excess of the carrying amount of the properties over the estimated fair value of the properties. Factors used to estimate fair value may include estimates of proved reserves, estimated future commodity prices, future production estimates, and anticipated capital and operating expenditures, using a commensurate discount rate. Unfavorable changes in any of these assumptions could result in a reduction in undiscounted future cash flows and could indicate property impairment. Uncertainties related to the primary assumptions could affect the timing of an impairment. In most cases, the

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assumption that generates the most variability in undiscounted future net cash flows is future oil and gas prices. We observed volatility in commodity prices during the three months and six months ended June 30, 2025, however, no triggering events were identified and therefore no impairment was recorded at June 30, 2025. However, further decline in commodity prices will result in declined future cash flows which would lead to oil and gas properties to be at risk for future impairment.

It is also reasonably possible that prolonged low or further decline in commodity prices, negative reserve revisions, changes to the Company's drilling plans in response to lower prices or increases in drilling or operating costs would result in material future impairment charges.

If crude oil sales were to remain constant at the most recent annual sales volumes, a $5 per Bbl decrease in crude oil price would decrease our revenues and operating income or increase our operating loss for the six months ended June 30, 2025 as follows:

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| | | | |
|:---|:---|:---|:---|
| | **2025 Sales Volumes (Mbls)** | **Decrease in <br>Revenues<br>(In Millions)** | **Decrease in Operating Income (Increase in Operating Loss) <br>(In Millions)** |
| Gabon | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;1558 | $7.8 | $7.0 |
| Egypt | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;1334 | $6.7 | $4.0 |
| Côte d'Ivoire | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;238 | $1.2 | $0.6 |
| Canada | 351 | $1.8 | $1.4 |
| Consolidated | 3481 |  |  |

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With respect to our crude oil sales in Gabon, Egypt and Côte d'Ivoire the price received are based on Dated Brent prices plus or minus a differential. With respect to our crude oil and NGLs sales in Canada, the prices received are based on NYMEX WTI (West Texas Intermediate) prices plus or minus a differential. Natural gas sales are based on Canadian index price whose price is based, in part, on the NYMEX Henry Hub Natural Gas futures contracts. Egypt production is based on Dated Brent prices, less a quality differential and is shared with the Egyptian government. When the price of oil increases, it takes fewer barrels to recover costs (cost oil or cost recovery barrels) which are assigned 100% to the Company.

Exploration and production activities of our assets in Gabon, Egypt, Cote d'Ivoire, and Equatorial Guinea are generally governed by PSCs. The PSCs provide for cost recovery per quarter up to a maximum percentage of total production. Timing differences often exist between Vaalco's recognition of costs and their recovery as Vaalco accounts for costs on an accrual basis, whereas cost recovery is determined on a cash basis. If the eligible cost recovery is less than the maximum defined cost recovery, the difference is defined as "excess". Production sharing splits are set in each contract for the life of the contract. Typically, the government's share of Profit Oil increases when production exceeds pre-set production levels in the respective contracts. During times of high oil prices, the Company may receive less cost oil and may receive more profit-sharing oil. During times of lower oil prices, the Company receives more cost oil and may receive less Profit Oil.

**INTEREST RATE RISK**

As of June 30, 2025, our primary exposure to interest rate risk resulted from our $60.0 million of outstanding borrowings under our 2025 RBL Facility. The borrowing accrues interest at a rate of 10.8% per annum which is based on the Term SOFR plus the applicable margin of 6.5% per annum. We currently do not hedge our interest rate exposure. We estimate that a 10% increase in the applicable average interest rates during the time from the date the debt was drawn through June 30, 2025 would have resulted in an increase in interest expense of $0.06 million. There were no outstanding borrowings during the year ended December 31, 2024. Additionally, changes in market interest rates could impact interest costs associated with any future indebtedness.

**ITEM 4. CONTROLS AND PROCEDURES** 

**EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES** 

Our management, including our Principal Executive Officer and Principal Financial Officer, have evaluated the effectiveness of our disclosure controls and procedures pursuant to Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the "Exchange Act"), as of the end of the period covered by this report. Based on the evaluation of our disclosure controls and procedures, our Principal Executive Officer and Principal Financial Officer have concluded that, as a result of material weaknesses in our internal control over financial reporting identified in connection

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with the preparation and audit of our consolidated financial statements for the year ended December 31, 2024, our disclosure controls and procedures were not effective as of June 30, 2025.

**MATERIAL WEAKNESS IN INTERNAL CONTROL OVER FINANCIAL REPORTING**

As previously disclosed in Part II, Item 9A of our Annual Report on Form 10-K for the fiscal year ended December 31, 2024, Management previously identified the following material weaknesses in internal control over financial reporting.

• The Company had ineffective general information technology controls ("GITCs") that support the consistent operation of the Company's information technology ("IT") systems, specific to its procure-to-pay system. As a result, automated process-level controls and manual controls dependent upon the accuracy and completeness of information derived from that IT system were also ineffective because they could have been adversely impacted; and

• The Company did not effectively design, implement, or operate process-level control activities related to its financial reporting process, specific to its procure-to-pay process.

After giving full consideration to the material weakness, and the additional analyses and other procedures we performed to ensure that our unaudited condensed consolidated financial statements included in this Quarterly Report on Form 10-Q were prepared in accordance with GAAP, our management has concluded that our unaudited condensed consolidated financial statements present fairly, in all material respects, our financial position, results of operations and cash flows for the periods disclosed in conformity with GAAP. We have developed and are implementing a remediation plan for the material weakness, which is described below.

**MANAGEMENT'S PLAN FOR REMEDIATION OF THE MATERIAL WEAKNESS**

As previously described in Part II, Item 9A of our Annual Report on Form 10-K for the fiscal year ended December 31, 2024, we began implementing a remediation plan to address the material weaknesses mentioned above. The material weaknesses will not be considered remediated until the applicable controls operate for a sufficient period of time and management has concluded, through testing, that these controls are operating effectively.

Although we intend to complete the remediation process as promptly as possible, we cannot at this time estimate how long it will take to remediate the material weaknesses described above. We may discover additional material weaknesses that require additional time and resources to remediate, and we may decide to take additional measures to address the material weaknesses or modify the remediation steps described above.

In addition, while certain of the activities described above have continued to enhance our internal control over financial reporting, certain of these newly designed controls have not operated effectively for a sufficient period of time to be able to conclude on effectiveness. We remain committed to continue investing significant time and resources and taking actions to remediate the material weaknesses in our internal control over financial reporting as we work to further enhance our control environment. Until these material weaknesses are remediated, we plan to continue to perform additional analyses and other procedures to ensure that our consolidated financial statements are prepared in accordance with U.S. GAAP.

**CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING**

Except for the activities taken related to the remediation of the material weaknesses described above, there have been no changes in our internal control over financial reporting during the three months ended June 30, 2025 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

**PART II. OTHER INFORMATION** 

**ITEM 1. LEGAL PROCEEDINGS**

We are subject to litigation claims and governmental and regulatory proceedings arising in the ordinary course of business. While we cannot predict the occurrence or outcome of these proceedings with certainty, it is management's opinion that all claims and litigation we are currently involved in are not likely to have a material adverse effect on our unaudited condensed consolidated financial position, cash flows or results of operations.

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**ITEM 1A. RISK FACTORS**

Our business faces many risks. Any of the risks discussed elsewhere in this Quarterly Report and our other SEC filings could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also impair our business operations.

For a discussion of our potential risks and uncertainties, see the information in Item 1A. "Risk Factors" in our 2024 Form 10-K. Except as set forth below, there have been no material changes in our risk factors from those described in our 2024 Form 10-K.

***Provisions of our agreements could discourage an acquisition of us by a third-party.***

Certain provisions of our production sharing contracts, joint operating agreements and other agreements could make it more difficult or more expensive for a third-party to acquire us or our assets, or may even prevent a third-party from acquiring us or our assets. For example, some of these agreements contain restrictions on assignments of our assets, including requirements to obtain consent from applicable counterparties, preemption rights and requirements to make bonus payments. In some cases, these restrictions apply to "indirect assignments." By discouraging an acquisition of us or our assets by a third-party, these provisions could have the effect of deterring otherwise interested third-parties from proposing or consummating these acquisitions. This could deprive the holders of our common stock of an opportunity to sell their common stock at a premium over prevailing market prices.

**ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS**

***Unregistered Sale of Equity Securities***

There were no sales of unregistered securities during the three months ended June 30, 2025 that were not previously reported on a Current Report on Form 8-K.

**ITEM 5*.* OTHER INFORMATION**

During the three months ended June 30, 2025, none of the Company's directors or officers (as defined in Rule 16a-1(f) of the Exchange Act) adopted, terminated or modified a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (as such terms are defined in Item 408 of Regulation S-K of the Securities Act).

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**ITEM 6. EXHIBITS** 

(a) **Exhibits**

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| | |
|:---|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;3.1 | <u>[Restated Certificate of Incorporation as amended through May 7, 2014 (filed as Exhibit 3.1 to the Company's Quarterly Report on Form 10-Q filed on November 10, 2014 and incorporated herein by reference).](https://www.sec.gov/Archives/edgar/data/894627/000156459014005421/egy-ex31_20140930223.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;3.1.1 | <u>[Certificate of Amendment to Restated Certificate of Incorporation of VAALCO, dated October 13, 2022 (filed as Exhibit 3.1 to the Company's Current Report on Form 8-K filed on October 13, 2022 and incorporated herein by reference).](https://www.sec.gov/Archives/edgar/data/894627/000114036122037165/brhc10042848_ex3_1.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;3.2 | <u>[Third Amended and Restated Bylaws, dated July 30, 2020 (filed as Exhibit 3.1 to the Company's Current Report on Form 8-K filed on August 4, 2020 and incorporated herein by reference).](https://www.sec.gov/Archives/edgar/data/894627/000089462720000057/egy-20200804xex3_1.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;3.3 | <u>[Certificate of Elimination of Series A Junior Participating Preferred Stock of VAALCO Energy, Inc., dated as of December 22, 2015 (filed as Exhibit 3.2 to the Company's Current Report on Form 8-K filed on December 23, 2015, and incorporated herein by reference).](https://www.sec.gov/Archives/edgar/data/894627/000089462715000065/egy-20151223ex325fe6003.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;10.1(a)\* | <u>[Form of Restricted Stock Award Agreement under the VAALCO Energy, Inc. 2020 Long Term Incentive Plan](ex101aformofagreement-perf.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;31.1(a) | <u>[Sarbanes-Oxley Section 302 certification of Principal Executive Officer.](egy-20250630xex311.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;31.2(a) | <u>[Sarbanes-Oxley Section 302 certification of Principal Financial Officer.](egy-20250630xex312.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;32.1(b) | <u>[Sarbanes-Oxley Section 906 certification of Principal Executive Officer.](egy-20250630xex321.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;32.2(b) | <u>[Sarbanes-Oxley Section 906 certification of Principal Financial Officer.](egy-20250630xex322.htm)</u> |
| &nbsp;&nbsp;&nbsp;&nbsp;101.INS(a) | Inline XBRL Instance Document. |
| &nbsp;&nbsp;&nbsp;&nbsp;101.SCH(a) | Inline XBRL Taxonomy Schema Document. |
| &nbsp;&nbsp;&nbsp;&nbsp;101.CAL(a) | Inline XBRL Calculation Linkbase Document. |
| &nbsp;&nbsp;&nbsp;&nbsp;101.DEF(a) | Inline XBRL Definition Linkbase Document. |
| &nbsp;&nbsp;&nbsp;&nbsp;101.LAB(a) | Inline XBRL Label Linkbase Document. |
| &nbsp;&nbsp;&nbsp;&nbsp;101.PRE(a) | Inline XBRL Presentation Linkbase Document. |
| &nbsp;&nbsp;&nbsp;&nbsp;104 | Cover Page Interactive Data File (Formatted as Inline XBRL and contained in Exhibit 101). |

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___________________________________

(a)Filed herewith

(b)Furnished herewith

\* Management contract or compensatory plan or arrangement

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**SIGNATURE**

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

VAALCO ENERGY, INC.

(Registrant)

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| | |
|:---|:---|
| By: | /s/ Ronald Bain |
|  | **Ronald Bain**<br>**Chief Financial Officer**<br>(Duly authorized officer and Principal Financial Officer) |

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Dated: August 11, 2025

## Exhibit 10.1

**Exhibit 10.1**

***Performance Hurdles***

**VAALCO ENERGY, INC.RESTRICTED STOCK AWARD AGREEMENT**

**Participant:_________________________**

**THIS RESTRICTED STOCK AGREEMENT** (the **"Agreement"**) is

made and entered into by and between VAALCO Energy, Inc., a Delaware corporation (the **"Company"**) and , an individual and employee of the Company (the **"Participant"**), with respect to Awards approved by the Committee on the 5th day of June 2025 (the **"Date of Grant"**), subject to the VAALCO Energy, Inc. 2020 Long Term Incentive Plan (the **"Plan"**). This Agreement is subject to the terms and conditions of the Plan, which is incorporated herein in its entirety by reference. A copy of the Plan has been made available to the Participant. Capitalized terms not otherwise defined in this Agreement shall have the meaning given to such terms in the Plan.

**WHEREAS**, the Participant is an Employee of the Company, and in connection therewith, the Company desires to grant restricted shares of the Company's Common Stock (the "**Common Stock**") to the Participant, subject to the terms and conditions of this Agreement and the Plan, with a view to increasing the Participant's interest in the Company's success and growth; and

**WHEREAS**, the Participant desires to be the holder of shares of Common Stock subject to the terms and conditions of this Agreement;

**NOW, THEREFORE**, in consideration of the premises, mutual covenants and agreements contained herein, and such other good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the parties hereto, intending to be legally bound hereby, agree as follows:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**1.Grant of Common Stock**. Subject to the restrictions, vesting, forfeiture, and other terms and conditions set forth herein (a) the Company hereby grants to the Participant, shares of the Common Stock (the **"Restricted Shares"**), and (b) the Participant shall have all rights and privileges of ownership of the Restricted Shares subject to this Agreement and the terms of the Plan. The **"Price at Grant"** is [the closing price as of the Date of Grant]. The **"Term"** shall begin on the Date of Grant and end on the ten-year anniversary thereof.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**2.Transfer Restrictions.**

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)*<u>Generall</u>y*. The Participant shall not sell, assign, exchange, pledge, encumber, gift, devise, hypothecate or otherwise transfer (individually and collectively, **"Transfer"**) any Restricted Shares unless and until vested. The Transfer restrictions imposed by this <u>Section 2</u> shall lapse in accordance with the vesting schedule set out below (the "**Vesting Schedule**") when the Restricted Shares become vested, provided that the Participant then is, and continuously from the Date of Grant has been, an employee of the Company and there has not been Termination of Service (as defined in the Plan) before the applicable vesting date set out in the Vesting Schedule. The Restricted Shares as to which such restrictions have lapsed are referred to herein as **"Vested Shares."**

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&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)The Restricted Shares shall be registered in the Participant's name as of the Date of Grant through a book entry credit in the records of the Company's transfer agent, but shall be restricted as described herein from the Date of Grant and during the period prior to the vesting of such shares in accordance with <u>Section 2</u>(<u>d</u>) (the "**Restriction Period**"). During the Restriction Period, any certificates representing the Restricted Shares shall carry a legend evidencing the restrictions of this Agreement.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(c)If, from time to time during the Restriction Period, there is any stock dividend, stock split, reorganization, recapitalization, merger, or other event described in the Plan, any and all new, substituted, additional, or other securities to which the Participant is entitled by reason of his ownership of the Restricted Shares shall be considered "Restricted Shares" for purposes of this Agreement and shall be subject to the restrictions described in this Agreement during the Restriction Period.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(d)Subject to the restrictions set forth in this Agreement, the Participant shall have all the rights of a stockholder with respect to the Restricted Shares, including any applicable voting and dividend rights.

In the event of forfeiture of the Restricted Shares, the Participant shall have no further rights with respect to such Restricted Shares. The forfeiture of any Restricted Shares shall not create any obligation to repay cash dividends received as to such Restricted Shares, nor shall such forfeiture invalidate any votes given by the Participant with respect to such Restricted Shares prior to forfeiture. The Restricted Shares shall become vested during the employment period if the Participant remains in continuous employment in accordance with the following Vesting Schedule:

One-third of the awards vest on the first day during the Term that a stock price performance hurdle of 15% above the Price at Grant

has been achieved, provided that if such date is before the one-year anniversary of the Date of Grant, vesting shall occur on such one- year anniversary;

another one-third of the awards vest on the first day during the Term that a stock price performance hurdle of 32.5% above the Price at Grant has been achieved, provided that if such date is before the two-year anniversary of the Date of Grant, vesting shall occur on such two-year anniversary;

the remaining one-third of the awards vest on the first day during the Term that a stock price performance hurdle of 52.5% above the Price at Grant has been achieved, provided that if such date is before the three-year anniversary of the Date of Grant, vesting shall occur on such three-year anniversary.

Each hurdle is measured using a 30-day average stock price. Each stock price performance hurdle must be achieved during the Term to trigger vesting.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(e)If there is a Change in Control of the Company (as defined in the Plan), all the then-unvested Restricted Shares shall automatically become

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100% vested as of the date of the Change in Control.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(f)During the Restriction Period, the Participant shall not sell, transfer, pledge, assign, alienate, hypothecate, or otherwise encumber or dispose of the Restricted Shares other than by will or the laws of descent and distribution. Any attempt to do so contrary to the foregoing shall be null and void.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(g)Any Restricted Shares forfeited hereunder shall be cancelled and automatically revert to the Plan. Any certificate(s) representing Restricted Shares which include forfeited shares shall only represent the number of Restricted Shares not forfeited hereunder. Upon the Company's request, the Participant agrees to tender to the Company any certificate(s) representing Restricted Shares which include forfeited shares for a new certificate representing only the unforfeited number of Restricted Shares.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**3.Termination of Service.&nbsp;&nbsp;&nbsp;&nbsp;**Voluntary or involuntary Termination of Service shall affect the Participant's rights under the Agreement as follows:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)<u>Retirement</u>. In the event of the Participant's Retirement at or after attaining (i) age 65 and (ii) at least ten (10) years of employment service, all of the non-vested Restricted Stock shall become 100% vested as of the date of Termination of Service. Upon a Termination of Service due to the Participant's Retirement at or after attaining age 65 but without ten (10) years of employment service, subject to the Vesting Schedule, any non- vested portion of the Restricted Stock shall immediately terminate and no further vesting shall occur.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)<u>Death or Total and Permanent Disabili</u>ty. If the Participant's Termination of Service is due to death or Total and Permanent Disability (as defined in the Plan at the time of such termination), then (i) subject to the Vesting Schedule, any non-vested portion of the Restricted Stock shall become 100% vested on the Termination of Service date.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(c)<u>Other Involuntary Termination or Voluntary Termination</u>. If the Participant's incurs a Termination of Service for whatever reason, or the Participant resigns for any reason, either voluntarily or involuntarily, except for Retirement, death or Total and Permanent Disability as set out above, then subject to the Vesting Schedule, any non-vested portion of the Restricted Stock shall immediately expire on the date of such Termination of Service.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**4.Issuance of Certificate**.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)The Restricted Shares shall not be transferred until they become Vested Shares. Further, the Vested Shares may not be sold or otherwise disposed of in any manner that would constitute, in the opinion of counsel for the Company, a violation of any applicable federal or state securities or other laws or regulations, or any rules or regulations of any stock exchange on which the Common Stock is listed. The Company may cause to be issued a stock certificate, registered in the name of the Participant, evidencing the Restricted Shares upon receipt of a stock power duly endorsed in blank with respect to such shares. Each such stock certificate shall bear the following or a substantially similar legend:

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*The transferability of this certificate and the shares of stock represented hereby are subject to the restrictions, terms and conditions (including forfeiture and restrictions against transfer) contained in the VAALCO Energy, Inc. 2020 Long Term Incentive Plan and a Restricted Stock Agreement entered into between the registered owner of such shares and VAALCO Energy, Inc. Copies of the Plan and Restricted Stock Agreement are on file in the main corporate offices of VAALCO Energy, Inc.*

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)The certificate, together with the stock powers relating to the Restricted Shares evidenced by such certificate, shall be held by the Company. The Company shall issue to the Participant a receipt evidencing the certificates held by it which are registered in the name of the Participant.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(c)Upon the vesting of any Restricted Shares granted hereunder, the Company shall direct its transfer agent to record such shares as unrestricted or to deliver to the Participant certificates evidencing such shares. If certificates are delivered to the Participant, such certificates shall not bear the legend referenced in <u>Section 3</u>(<u>a</u>). Nothing herein shall obligate the Company to register the shares pursuant to any applicable securities law or to take any other affirmative action in order to cause the issuance or transfer of the shares to comply with any law or regulation of any governmental authority. The Participant will enter into such written representations and agreements as the Company may reasonably request to comply with any securities law or regulation.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**5.Participant's Representations.** The Participant acknowledges that the Participant has been provided a copy of the prospectus, dated June 25, 2020 relating to the issuance of the Restricted Shares. Notwithstanding any provision hereof to the contrary, the Participant hereby agrees and covenants that the Participant will not acquire any Restricted Shares, and that the Company will not be obligated to issue any Restricted Shares or unrestricted shares to the Participant hereunder or under the Plan, if the issuance of such shares would constitute a violation by the Participant or the Company of any applicable federal or state securities or other laws or regulations, or any rules or regulations of any stock exchange on which the Common Stock is listed, as determined by legal counsel for the Company. The rights and obligations of the Company and the Participant hereunder are subject to all applicable laws and regulations.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**6.Tax Withholding. The Participant is hereby advised to consult immediately with his or her own tax advisor regarding the tax consequences of this Agreement, the method and timing for filing an election to include this Agreement in income under Section 83(b) of the Code, and the tax consequences of such election.** By execution of this Agreement, the Participant agrees that if the Participant makes such an election, the Participant shall provide the Company with written notice of such election in accordance with the regulations promulgated under Section 83(b) of the Code. To the extent that the receipt or vesting of Restricted Shares results in compensation income to the Participant for any tax purposes, the Participant shall deliver to Company at such time the sum that the Company requires to meet its tax withholding obligations under applicable law or regulation, and, if the Participant fails to do so, the Company is authorized to (a) withhold from any cash or stock remuneration then or thereafter payable to the Participant any federal, state, local or foreign tax that Company determines is

------

required to be withheld, or (b) sell such number of Restricted Shares before their transfer to the Participant as is deemed appropriate to satisfy such tax withholding requirements, before transferring the resulting net number of shares to the Participant in full satisfaction of its obligations under this Agreement. The Company may, in its sole discretion, withhold any such taxes from any other cash remuneration otherwise paid by the Company to the Participant.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**7.Interpretation** The meaning assigned to each term defined herein shall be equally applicable to both the singular and the plural forms of such term and vice versa, and words denoting either gender shall include both genders as the context requires. Where a word or phrase is defined herein, each of its other grammatical forms shall have a corresponding meaning. The terms "hereof," "herein" and "herewith" and words of similar import shall, unless otherwise stated, be construed to refer to this Agreement as a whole and not to any particular provision of this Agreement. When a reference is made in this Agreement to a Section, such reference is to a Section of this Agreement unless otherwise specified. The terms "include", "includes", and "including" when used in this Agreement shall be deemed to be followed by the words "without limitation", unless otherwise specified. A reference to any party to this Agreement or any other agreement or document shall include such party's predecessors, successors, and permitted assigns. Reference to any law means such law as amended, modified, codified, replaced, or reenacted, and all rules and regulations promulgated thereunder. All captions contained in this Agreement are for convenience of reference only, do not form a part of this Agreement, and shall not affect in any way the meaning or interpretation of this Agreement. The parties have participated jointly in the negotiation and drafting of this Agreement; therefore any rule of construction or interpretation otherwise requiring this Agreement to be construed or interpreted against any party by virtue of the authorship of this Agreement shall not apply to the construction and interpretation hereof.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**8.Participant Acknowledgment**. The Participant acknowledges that

(a) he is knowledgeable and sophisticated as to business matters, including the subject matter of this Agreement, (b) he has read this Agreement and understands its terms and conditions, (c) he has had ample opportunity to discuss this Agreement with his legal counsel and tax advisors prior to execution, and (d) no strict rules of construction shall apply for or against the drafter or any other party. It is the desire of the parties hereto that this Agreement be enforced to the maximum extent permitted by law, and should any provision contained herein be held invalid or otherwise unenforceable by a court of competent jurisdiction, the parties hereby agree and confirm that such provision shall be reformed to create a valid and enforceable provision to the maximum extent permitted by law.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**9.Compliance with Code Section 409A.** The Restricted Shares awarded under this Agreement are not intended to be subject to Section 409A of the

U.S. Internal Revenue Code of 1986, as amended ("**Section 409A**"), including the authoritative guidance issued thereunder, and shall be interpreted and administered to be exempt from the application of Section 409A to the full extent possible under Section 409A.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**10.Miscellaneous.**

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;a.*<u>Certain Tran</u>s<u>fers Void</u>*. Any purported transfer of shares of Common Stock in breach of any provision of this Agreement shall be void and ineffective, and shall not operate to transfer any interest or title in the purported transferee.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;b.*<u>No Fractional Shares</u>*. All provisions of this Agreement

------

concern whole shares of Common Stock. If the application of any provision hereunder would yield a fractional share, such fractional share shall be rounded down to the next whole share if it is less than 0.5 and rounded up to the next whole share if it is 0.5 or more.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;c.*<u>Not an Employment Agreement</u>*. This Agreement is not an employment agreement, and no provision of this Agreement shall be construed or interpreted to create any employment relationship between the Participant and the Company for any guaranteed time period. The employment of the Participant shall be subject to termination to the same extent as if this Agreement had not been executed.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;d.*<u>Notices</u>*. Any notice, instruction, authorization, request or demand required hereunder shall be in writing, and shall be delivered either by personal in-hand delivery, by telecopy or similar facsimile means, by certified or registered mail, return receipt requested, or by courier or delivery service, addressed to the Company at its then current main corporate address, and to the Participant at his address indicated on the Company's records, or at such other address and number as a party has last previously designated by written notice given to the other party in the manner hereinabove set forth. Notices shall be deemed given when received, if sent by facsimile means (confirmation of such receipt by confirmed facsimile transmission being deemed receipt of communications sent by facsimile means); and when delivered and receipted for (or upon the date of attempted delivery where delivery is refused), if hand-delivered, sent by courier or delivery service, or sent by certified or registered mail, return receipt requested.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;e.*<u>Shares Reserved</u>*. The Company shall, at all times during the period that any Restricted Shares remain subject to this Agreement, reserve under the Plan such number of shares of Common Stock as shall be sufficient to satisfy the requirements of this Agreement.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;f.*<u>Amendment, Termination and Waiver</u>*. This Agreement may be amended, modified, terminated or superseded only by written instrument executed by or on behalf of the Company and the Participant. Any waiver of the terms or conditions hereof shall be made only by a written instrument executed and delivered by the party waiving compliance. Any waiver granted by the Company shall be effective only if executed and delivered by a duly authorized executive officer of the Company other than the Participant. The failure of any party at any time or times to require performance of any provisions hereof shall in no manner affect the right to enforce the same. No waiver by any party of any term or condition herein, or the breach thereof, in one or more instances shall be deemed to be, or construed as, a further or continuing waiver of any such condition or breach or a waiver of any other condition or the breach of any other term or condition.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;g.*<u>No Guarantee o</u>f <u>Tax Conse</u>q<u>uences</u>*. The Company makes no commitment or guarantee that any tax treatment will apply or be available to the Participant or any other person. The Participant has been advised, and provided with the opportunity, to obtain independent legal and tax advice regarding the grant, vesting, Transfer and the disposition of any Restricted Shares.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;h.*<u>Severabili</u>ty*. Any provision of this Agreement which is ruled to be invalid or unenforceable in any applicable jurisdiction shall be

------

ineffective to the extent of such invalidity or unenforceability without invalidating or rendering unenforceable the remaining provisions hereof, and any such invalidity or unenforceability in any jurisdiction shall not invalidate or render unenforceable such provision in any other jurisdiction.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;a.*<u>Supersedes Prior Agreements</u>*. This Agreement, together with the Plan, shall supersede and replace any and all prior agreements and understandings, oral or written, between the Company and the Participant regarding the grant of the Restricted Shares covered hereby. All prior negotiations and agreements between the parties with respect to the subject matter hereof are merged into this Agreement. Each party to this Agreement acknowledges that no representations, inducements, promises, or agreements, orally or otherwise, have been made by any party or by anyone acting on behalf of any party, which are not embodied in this Agreement or the Plan and that any agreement, statement, or promise that is not contained in this Agreement or the Plan shall not be valid or binding or of any force or effect.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;b.*<u>Recoupment</u>*. The Participant acknowledges, understands and agrees, with respect to any Restricted Shares delivered to the Participant (or registered in the Participant's name) pursuant to this Agreement, that such Shares shall be subject to recovery by the Company, and the Participant shall be required to repay such compensation or shares of Common Stock, in accordance with the Company's clawback policy, as in effect from time to time. The Participant further acknowledges, understands, and agrees that the Board retains the right to modify the Company's clawback policy at any time.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;c.*<u>Governing Law</u>*. The Agreement shall be construed in accordance with the laws of the State of Delaware, without regard to its conflict of law provisions, to the extent federal law does not supersede and preempt Delaware law.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;d.*<u>Successors and Ass</u>ig<u>ns</u>*. This Agreement shall bind, be enforceable by, and inure to the benefit of, the Company and the Participant and any permitted successors and assigns under the Plan.

11**Survival of Certain Provisions**. Wherever appropriate to the intention of the parties hereto, the respective rights and obligations of the parties hereunder shall survive any termination or expiration of this Agreement.

12**Signature in Counterparts**. This Agreement may be signed in counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument. The parties agree that the delivery of this Agreement may be effected by means of an exchange of facsimile or electronic signatures which shall be deemed original signatures thereof.

*[Signature page follows.]*

------

**IN WITNESS WHEREOF**, this Restricted Stock Agreement is made and entered into effective as of the Date of Grant first written above.

---

| | |
|:---|:---|
| **VAALCO Energy, Inc.** | **VAALCO Energy, Inc.** |
| By: | /s/George Maxwell |
| Name: | George Maxwell |
| Title: | CEO |
| Address for Notices: | Address for Notices: |
| VAALCO Energy, Inc. <br>2500 CityWest Blvd., Suite 400 <br>Houston, TX 77042 | VAALCO Energy, Inc. <br>2500 CityWest Blvd., Suite 400 <br>Houston, TX 77042 |
| Attn: Legal Department | Attn: Legal Department |
| Participant: | Participant: |
| Signed Electronically | Signed Electronically |
| Signature | Signature |
| Address for Notices: As on file with Human Resources | Address for Notices: As on file with Human Resources |

---

## Exhibit 31.1

**EXHIBIT 31.1** 

**CERTIFICATION OF PRINCIPAL FINANCIAL EXECUTIVE OFFICER**

**PURSUANT TO**

**EXCHANGE ACT RULES 13a-14(a) AND 15d-14(a), AS ADOPTED PURSUANT TO**

**SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002**

I, George W.M. Maxwell, certify that:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(1)I have reviewed this quarterly report on Form 10-Q of VAALCO Energy, Inc.;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(2)Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(3)Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(4)The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(5)The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 11, 2025

---

| |
|:---|
| /s/ George W.M. Maxwell |
| George W.M. Maxwell<br>Chief Executive Officer  |

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## Exhibit 31.2

**EXHIBIT 31.2** 

**CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER**

**PURSUANT TO**

**EXCHANGE ACT RULES 13a-14(a) AND 15d-14(a), AS ADOPTED PURSUANT TO**

**SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002**

I, Ronald Bain, certify that:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(1)I have reviewed this quarterly report on Form 10-Q of VAALCO Energy, Inc.;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(2)Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(3)Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(4)The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(5)The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 11, 2025

---

| |
|:---|
| /s/ Ronald Bain |
| Ronald Bain |
| Chief Financial Officer |

---

## Exhibit 32.1

**EXHIBIT 32.1**

**CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER**

**PURSUANT TO**

**18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO**

**SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002**

In connection with the Quarterly Report of VAALCO Energy, Inc. (the "Company") on Form 10-Q for the quarterly period ended June 30, 2025 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, George W.M. Maxwell, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: August 11, 2025

---

| | |
|:---|:---|
| /s/ George W.M. Maxwell | /s/ George W.M. Maxwell |
| George W.M. Maxwell, Chief Executive Officer | George W.M. Maxwell, Chief Executive Officer |

---

## Exhibit 32.2

**EXHIBIT 32.2**

**CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER**

**PURSUANT TO** 

**18 U.S.C. SECTION 1350,** 

**AS ADOPTED PURSUANT TO** 

**SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002** 

In connection with the Quarterly Report of VAALCO Energy, Inc. (the "Company") on Form 10-Q for the quarterly period ended June 30, 2025, as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Ronald Bain, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities and Exchange Act of 1934, as amended; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: August 11, 2025

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| |
|:---|
| /s/ Ronald Bain  |
| Ronald Bain, Chief Financial Officer |

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