November 8, 2022 - 10-Q: Quarterly report pursuant to Section 13 or 15(d)

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 September 30, 2022

☐	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 incorporation or organization)	(I.R.S. Employer Identification No.)

9800 Richmond Avenue Suite 700 Houston, Texas	77042
(Address of principal executive offices)	(Zip code)

(713) 623-0801

(Registrant’s telephone number, including area code)

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

Title of each class	Trading symbol(s)	Name of each exchange on which registered
Common Stock	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 Exchange Act during the past 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

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

Large accelerated filer

☐

Accelerated filer

☐

Non‑accelerated filer

☒

Smaller reporting company

Emerging growth company

☒

☐

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

Indicate by check mark whether the registrant is a shell company (as defined in Exchange Act Rule 12b-2). Yes ☐ No ☒

As of November 6, 2022, there were outstanding 108,374,838 shares of common stock, $0.10 par value per share, of the registrant.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

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PART I. FINANCIAL INFORMATION
ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (unaudited)

Condensed Consolidated Balance Sheets September 30, 2022 and December 31, 2021	2
Condensed Consolidated Statements of Operations Three and Nine Months Ended September 30, 2022 and 2021	3
Condensed Consolidated Statements of Shareholders’ Equity Three and Nine Months Ended September 30, 2022 and 2021	4
Condensed Consolidated Statements of Cash Flows Nine Months Ended September 30, 2022 and 2021	5
Notes to Condensed Consolidated Financial Statements	7
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	39
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	54
ITEM 4. CONTROLS AND PROCEDURES	55
PART II. OTHER INFORMATION	56
ITEM 1. LEGAL PROCEEDINGS	56
ITEM 1A. RISK FACTORS	56
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	63
ITEM 6. EXHIBITS	64

EXPLANATORY NOTE

On October 13, 2022, VAALCO Energy, Inc. (“VAALCO”) and VAALCO Energy Canada ULC (“AcquireCo”), an indirect wholly-owned subsidiary of VAALCO, completed the previously announced business combination involving TransGlobe Energy Corporation (“TransGlobe”) whereby AcquireCo acquired all of the issued and outstanding TransGlobe common shares (the “Arrangement”) and TransGlobe became a direct wholly-owned subsidiary of AcquireCo and an indirect wholly-owned subsidiary of VAALCO, pursuant to an arrangement agreement entered into by VAALCO, AcquireCo and TransGlobe on July 13, 2022 (the “Arrangement Agreement”).

Although this Quarterly Report on Form 10-Q is filed after the completion of the Arrangement, unless otherwise specifically noted herein, information set forth herein only relates to the period as of and for the quarter and year-to-date periods ended September 30, 2022 and therefore does not include the information of TransGlobe for those periods. Accordingly, unless the context otherwise indicates, references to “VAALCO,” “the Company”, “we,” “our,” or “us” in this Quarterly Report on Form 10-Q are only references to VAALCO Energy, Inc., including its wholly owned subsidiaries prior to the Arrangement and do not include TransGlobe and its subsidiaries.

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PART I. FINANCIAL INFORMATION

ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

	*As of September 30, 2022*			*As of December 31, 2021*
ASSETS	*(in thousands)*
Current assets:
Cash and cash equivalents	$	69,289		$	48,675
Restricted cash		203			79
Receivables:
Trade, net		16,781			22,464
Accounts with joint venture owners, net of allowance of $0.0 million in both periods presented		7,931			345
Other, net		12,190			9,977
Crude oil inventory		4,254			1,593
Prepayments and other		12,616			5,156
Total current assets		123,264			88,289

Crude oil and natural gas properties, equipment and other - successful efforts method, net		194,711			94,324
Other noncurrent assets:
Restricted cash		1,755			1,752
Value added tax and other receivables, net of allowance of $6.7 million and $5.7 million, respectively		5,846			5,536
Right of use operating lease assets		1,705			10,227
Right of use finance lease assets		1,630			—
Deferred tax assets		41,495			39,978
Abandonment funding		18,838			21,808
Other long-term assets		5,529			1,176
Total assets	$	394,773		$	263,090
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
Accounts payable	$	30,276		$	18,797
Accounts with joint venture owners		—			3,233
Accrued liabilities and other		83,148			49,444
Operating lease liabilities - current portion		1,200			9,642
Finance lease liabilities - current portion		317			—
Foreign income taxes payable		28,056			3,128
Current liabilities - discontinued operations		14			13
Total current liabilities		143,011			84,257
Asset retirement obligations		35,247			33,949
Operating lease liabilities - net of current portion		521			587
Finance lease liabilities - net of current portion		1,251			—
Deferred tax liabilities		41,057			—
Total liabilities		221,087			118,793
Commitments and contingencies (Note 10)
Shareholders’ equity:
Preferred stock, $25 par value; 500,000 shares authorized, none issued		—			—
Common stock, $0.10 par value; 100,000,000 shares authorized, 70,125,626 and 69,562,774 shares issued, 59,068,105 and 58,623,451 shares outstanding, respectively		7,013			6,956
Additional paid-in capital		78,500			76,700
Less treasury stock, 11,057,521 and 10,939,323 shares, respectively, at cost		(44,635	)		(43,847	)
Retained earnings		132,808			104,488
Total shareholders' equity		173,686			144,297
Total liabilities and shareholders' equity	$	394,773		$	263,090

See notes to condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

	*Three Months Ended September 30,*						*Nine Months Ended September 30,*
	*2022*			*2021*			*2022*			*2021*
	*(in thousands, except per share amounts)*
Revenues:
Crude oil and natural gas sales	$	78,097		$	55,899		$	257,738		$	142,696
Operating costs and expenses:
Production expense		23,312			25,208			67,147			57,760
FPSO demobilization		8,867			—			8,867			—
Exploration expense		56			479			250			1,286
Depreciation, depletion and amortization		8,963			6,970			21,827			16,928
General and administrative expense		1,979			2,940			10,507			12,221
Bad debt expense and other		1,020			318			2,083			814
Total operating costs and expenses		44,197			35,915			110,681			89,009
Other operating (expense) income, net		—			46			(5	)		(440	)
Operating income		33,900			20,030			147,052			53,247
Other income (expense):
Derivative instruments gain (loss), net		3,778			(5,147	)		(37,522	)		(21,070	)
Interest (expense) income, net		(234	)		3			(355	)		9
Other (expense) income, net		(7,707	)		(328	)		(10,514	)		4,088
Total other expense, net		(4,163	)		(5,472	)		(48,391	)		(16,973	)
Income from continuing operations before income taxes		29,737			14,558			98,661			36,274
Income tax expense (benefit)		22,843			(17,183	)		64,467			(11,272	)
Income from continuing operations		6,894			31,741			34,194			47,546
Loss from discontinued operations, net of tax		(26	)		(20	)		(58	)		(72	)
Net income	$	6,868		$	31,721		$	34,136		$	47,474

Basic net income per share:
Income from continuing operations	$	0.12		$	0.53		$	0.57		$	0.81
Loss from discontinued operations, net of tax		0.00			0.00			0.00			0.00
Net income per share	$	0.12		$	0.53		$	0.57		$	0.81
Basic weighted average shares outstanding		59,068			58,586			58,900			58,102
Diluted net income per share:
Income from continuing operations	$	0.11		$	0.53		$	0.57		$	0.80
Loss from discontinued operations, net of tax		0.00			0.00			0.00			0.00
Net income per share	$	0.11		$	0.53		$	0.57		$	0.80
Diluted weighted average shares outstanding		59,450			58,916			59,335			58,654

See notes to condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY (Unaudited)

	*Common Shares Issued*		*Treasury Shares*			*Common Stock*		*Additional Paid-In Capital*		*Treasury Stock*			*Retained Earnings*			*Total*
	*(in thousands)*
Balance at January 1, 2022		69,562		(10,939	)	$	6,956	$	76,700	$	(43,847	)	$	104,488		$	144,297
Shares issued - stock-based compensation		300		(64	)		30		168		—			—			198
Stock-based compensation expense		—		—			—		404		—			—			404
Treasury stock		—		—			—		—		(387	)		—			(387	)
Dividend Distribution		—		—			—		—		—			(1,929	)		(1,929	)
Net income		—		—			—		—		—			12,164			12,164
Balance at March 31, 2022		69,862		(11,003	)	$	6,986	$	77,272	$	(44,234	)	$	114,723		$	154,747
Shares issued - stock-based compensation		263		(54	)		27		31		—			—			58
Stock-based compensation expense		—		—			—		616		—			—			616
Treasury stock		—		—			—		—		(401	)		—			(401	)
Dividend Distribution		—		—			—		—		—			(1,943	)		(1,943	)
Net income		—		—			—		—		—			15,104			15,104
Balance at June 30, 2022		70,125		(11,057	)	$	7,013	$	77,919	$	(44,635	)	$	127,884		$	168,181
Shares issued - stock-based compensation		—		—			—		—		—			—			—
Stock-based compensation expense		—		—			—		581		—			—			581
Treasury stock		—		—			—		—		—			—			—
Dividend Distribution		—		—			—		—		—			(1,944	)		(1,944	)
Net income		—		—			—		—		—			6,868			6,868
Balance at September 30, 2022		70,125		(11,057	)	$	7,013	$	78,500	$	(44,635	)	$	132,808		$	173,686

	*Common Shares Issued*		*Treasury Shares*			*Common Stock*		*Additional Paid-In Capital*		*Treasury Stock*			*Retained Earnings*		*Total*
	*(in thousands)*
Balance at January 1, 2021		67,897		(10,366	)	$	6,790	$	74,437	$	(42,421	)	$	22,652	$	61,458
Shares issued - stock-based compensation		431		(155	)		43		304		—			—		347
Stock-based compensation expense		—		—			—		323		—			—		323
Treasury stock		—		—			—		—		(403	)		—		(403	)
Net income		—		—			—		—		—			9,869		9,869
Balance at March 31, 2021		68,328		(10,521	)	$	6,833	$	75,064	$	(42,824	)	$	32,521	$	71,594
Shares issued - stock-based compensation		1,092		(314	)		109		597		—			—		706
Stock-based compensation expense		—		—			—		117		—			—		117
Treasury stock		—		—			—		—		(765	)		—		(765	)
Net income		—		—			—		—		—			5,884		5,884
Balance at June 30, 2021		69,420		(10,835	)	$	6,942	$	75,778	$	(43,589	)	$	38,405	$	77,536
Shares issued - stock-based compensation		108		(104	)		11		241		—			—		252
Stock-based compensation expense		—		—			—		327		—			—		327
Treasury stock		—		—			—		—		(258	)		—		(258	)
Net income		—		—			—		—		—			31,721		31,721
Balance at September 30, 2021		69,528		(10,939	)	$	6,953	$	76,346	$	(43,847	)	$	70,126	$	109,578

See notes to condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	*Nine Months Ended September 30,*
	*2022*			*2021*
	*(in thousands)*
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	34,136		$	47,474
Adjustments to reconcile net income to net cash provided by operating activities:
Loss from discontinued operations, net of tax		58			72
Depreciation, depletion and amortization		21,827			16,928
Bargain purchase gain		—			(7,651	)
Deferred taxes		39,540			(24,211	)
Unrealized foreign exchange loss (gain)		914			(342	)
Stock-based compensation		2,300			2,098
Cash settlements paid on exercised stock appreciation rights		(805	)		(3,051	)
Derivative instruments loss, net		37,522			21,070
Cash settlements paid on matured derivative contracts, net		(42,683	)		(10,189	)
Bad debt expense and other		2,083			814
Other operating expense, net		5			440
Operational expenses associated with equipment and other		953			835
Change in operating assets and liabilities:
Trade receivables		5,683			11,156
Accounts with joint venture owners		(11,118	)		(19	)
Other receivables		(2,904	)		94
Crude oil inventory		(2,661	)		4,059
Prepayments and other		(1,120	)		1,081
Value added tax and other receivables		(5,371	)		(1,339	)
Other noncurrent assets		(2,842	)		(1,176	)
Accounts payable		4,129			(9,686	)
Foreign income taxes receivable/payable		24,928			(2,916	)
Accrued liabilities and other		25,182			1,252
Net cash provided by continuing operating activities		129,756			46,793
Net cash used in discontinued operating activities		(57	)		(72	)
Net cash provided by operating activities		129,699			46,721
CASH FLOWS FROM INVESTING ACTIVITIES:
Property and equipment expenditures		(103,853	)		(8,459	)
Acquisition of crude oil and natural gas properties		—			(22,505	)
Net cash used in continuing investing activities		(103,853	)		(30,964	)
Net cash used in discontinued investing activities		—			—
Net cash used in investing activities		(103,853	)		(30,964	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from the issuances of common stock		257			1,305
Dividend distribution		(5,816	)		—
Treasury shares		(788	)		(1,426	)
Deferred financing costs		(1,535	)		—
Payments of finance lease		(193	)		—
Net cash used in continuing financing activities		(8,075	)		(121	)
Net cash used in discontinued financing activities		—			—
Net cash used in financing activities		(8,075	)		(121	)
NET CHANGE IN CASH, CASH EQUIVALENTS AND RESTRICTED CASH		17,771			15,636

CASH, CASH EQUIVALENTS AND RESTRICTED CASH AT BEGINNING OF PERIOD		72,314			61,317
CASH, CASH EQUIVALENTS AND RESTRICTED CASH AT END OF PERIOD	$	90,085		$	76,953

See notes to condensed consolidated financial statements.

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VAALCO ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS SUPPLEMENTAL DISCLOSURES (Unaudited)

	*Nine Months Ended September 30,*
	*2022*		*2021*
	*(in thousands)*
Supplemental disclosure of cash flow information:
Income taxes paid in-kind with crude oil	$	—	$	20,103
Interest paid, net of amounts capitalized	$	401	$	—
Supplemental disclosure of non-cash investing and financing activities:
Property and equipment additions incurred but not paid at end of period	$	39,105	$	4,607
Recognition of right-of-use finance lease assets and liabilities	$	1,851	$	—
Asset Retirement Obligations	$	—	$	14,564

See notes to condensed consolidated financial statements.

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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. As operator, the Company has production operations and conducts exploration and development activities in Gabon, West Africa. The Company also has opportunities to participate in development and exploration activities in Equatorial Guinea, West Africa. As discussed further in Note 3 below, VAALCO has discontinued operations associated with activities in Angola, West Africa.

On October 13, 2022, the Company and VAALCO Energy Canada ULC (“AcquireCo”), an indirect wholly-owned subsidiary of the Company, completed the previously announced business combination involving TransGlobe Energy Corporation (“TransGlobe”), whereby AcquireCo acquired all of the issued and outstanding TransGlobe common shares (the “Arrangement”) and TransGlobe became a direct wholly-owned subsidiary of AcquireCo and an indirect wholly-owned subsidiary of VAALCO, pursuant to an arrangement agreement entered into by VAALCO, AcquireCo and TransGlobe on July 13, 2022 (the “Arrangement Agreement”). Prior to the Arrangement, TransGlobe was a cash flow-focused oil and gas exploration and development company whose activities were concentrated in the Arab Republic of Egypt and Canada. The post-Arrangement company (the “Combined Company”) is a leading African-focused operator with a strong production and reserve base and a diverse portfolio of assets in Gabon, Egypt, Equatorial Guinea and Canada. See Note 3 for further discussion regarding the Arrangement.

As of September 30, 2022 and prior to the completion of the Arrangement, the Company’s consolidated subsidiaries were VAALCO Gabon (Etame), Inc., VAALCO Production (Gabon), Inc., VAALCO Gabon S.A., VAALCO Angola (Kwanza), Inc., VAALCO Energy (EG), Inc., VAALCO Energy Mauritius (EG) Limited, VAALCO Energy, Inc. (UK Branch), VAALCO Energy (USA), Inc, VAALCO Energy (International), LLC, VAALCO Energy (Holdings), LLC and VAALCO Energy Canada ULC, an unlimited liability company incorporated under the laws of the Province of Alberta and a wholly owned subsidiary of the Company.

These condensed consolidated financial statements are unaudited, but in the opinion of management, reflect 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 condensed consolidated 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 consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021, which includes a summary of the significant accounting policies.

With respect to the novel strain of coronavirus (“COVID-19”), during 2021, and continuing in 2022, crude oil prices have experienced significant improvement and oil demand has stabilized over multiple quarters removing much of the uncertainty and instability in the industry. However, during the second quarter of 2022 the BA.5 strain of the Omicron variant caused surges in infections worldwide. While COVID-19 related travel restrictions have gradually eased as governments and people continue to have increasing access to vaccines that help reduce the spread of COVID-19, new surges in infections and hospitalizations could alter the current environment. The significant decline in oil prices experienced in 2020 was, in part, due to disruptions in the worldwide economy due to the COVID-19 pandemic which quarantined people and restricted travel. To date the Company's operations have not been materially impacted by COVID-19, and worldwide we are seeing improving economic activity while managing the risk of a resurgence, but there can be no guarantees that COVID-19 will not have an impact on the Company or its operations.

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In July 2021, the Organization of the Petroleum Exporting Countries, Russia and other allied producing countries (collectively, "OPEC+") agreed to increase production beginning in August 2021 and to gradually phase out prior production cuts by September 2022. However, as a result of the recent decline in oil prices, on October 5, 2022, OPEC+ announced plans to reduce overall oil production by 2 MMBbls per day starting November 2022. The Company has not received any mandate to reduce its current oil production from the Etame Marin block as a result of the OPEC+ initiative.

The average Brent crude oil price for the three months ended December 31, 2021, March 31, 2022, June 30, 2022 and September 30, 2022 was, $79 per barrel, $100 per barrel, $113 per barrel and $100 per barrel respectively.

During the nine months ended September 30, 2022, the Company noticed that the lead times associated with obtaining materials to support its operations and drilling activities has lengthened and, in some cases, prices for materials have increased. Management believes the ongoing war between Russia and Ukraine and its related impact on the global economy are causing supply chain issues and energy concerns in parts of the global economy. In addition, increased inflation, higher interest rates and current turmoil in certain governments are impacting the global supply chain market.

While the current commodity price environment is still favorable and the Company has not experienced material disruptions to its operations as a result of COVID-19 or as result of other forces, including the Russia/Ukraine conflict, affecting the global market, any emergence of a new variant or further deteriorations of the global supply chain market may have a material adverse impact on financial results and business operations of the Company, including the timing and ability of the Company to complete future drilling campaigns and other efforts required to advance the development of its crude oil and natural gas properties.

Principles of consolidation – The accompanying condensed consolidated financial statements (“Financial Statements”) include the accounts of VAALCO and its wholly owned subsidiaries. Investments in unincorporated joint ventures and undivided interests in certain operating assets are consolidated on a pro rata basis. All intercompany transactions within the consolidated group have been eliminated in consolidation.

Use of estimates – The preparation of the Financial Statements in conformity with GAAP requires estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the Financial Statements and the reported amounts of revenues and expenses during the respective reporting periods. The Financial Statements include amounts that are based on management’s best estimates and judgments. Actual results could differ from those estimates.

Cash and cash equivalents – Cash and cash equivalents includes deposits and funds invested in highly liquid instruments with original maturities of three months or less at the date of purchase.

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Restricted cash and abandonment funding – Restricted cash includes cash that is contractually restricted. Restricted cash is classified as a current or non-current asset based on its designated purpose and time duration. Current amounts in restricted cash at September 30, 2022 and 2021 each include an escrow amount for the floating, production, storage and offloading vessel (“FPSO”), representing bank guarantees for customs clearance in Gabon. Long-term amounts at September 30, 2022 and 2021 include a charter payment escrow for the FPSO offshore Gabon as discussed in Note 10 and amounts set aside for the future abandonment of the Etame Marin block. The Company invests restricted and excess cash in readily redeemable money market funds. The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed consolidated balance sheets to the amounts shown in the condensed consolidated statements of cash flows.

	*As of September 30,*
	*2022*		*2021*
	*(in thousands)*
Cash and cash equivalents	$	69,289	$	52,839
Restricted cash - current		203		81
Restricted cash - non-current		1,755		1,752
Abandonment funding		18,838		22,281
Total cash, cash equivalents and restricted cash	$	90,085	$	76,953

The Company conducts regular abandonment studies to update the estimated costs to abandon the offshore wells, platforms and facilities on the Etame Marin block. This cash funding is reflected under “Other noncurrent assets” as “Abandonment funding” on the 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. See Note 10 for further discussion.

On February 28, 2019, the Gabonese branch of the international commercial bank holding the abandonment funds in a U.S. dollar denominated account advised that the bank regulator required transfer of the funds to the Central Bank (“Central Bank”) for African Economic and Monetary Community (“CEMAC”), of which Gabon is one of the six member states, for conversion to local currency with a credit back to the Gabonese branch in local currency. The Company’s production sharing contract related to the Etame Marin block located offshore Gabon (“Etame PSC”) provides these payments must be denominated in U.S. dollars and the CEMAC regulations provide for the establishment of a U.S. dollar account with the Central Bank. Although the Company requested establishment of such account, the Central Bank did not comply with its requests until February 2021. As a result, the Company was not able to make the annual abandonment funding payments in 2019, 2020 or 2021 totaling $4.3 million, net to VAALCO based on the 2018 abandonment study. In February of 2021, the Bank of Central African State (“BEAC”) authorized the Company to apply for a U.S. dollar denominated escrow account for the abandonment fund at Citibank Gabon (“Citibank”). Working with Citibank, on March 12, 2021 the Company filed the application to open the account and is currently awaiting the approval of the account from the Central Bank. Accordingly, the Company was not able to make its funding payment in 2021. In December 2021, as part of the new FX regulations issued by BEAC, BEAC allowed for the opening of U.S. dollars escrow accounts for the abandonment funds at BEAC. The Company is currently working with the extractive industry to formulate the agreements, which are expected to be finalized in 2022, that regulate these accounts. Accordingly, pursuant to Amendment No. 5 of the Etame PSC that required these funds to be in U.S. dollars, once the account for the U.S. dollars abandonment fund is open at BEAC the Company will resume its funding of the abandonment fund in compliance with the Etame PSC.

Accounts with joint venture owners – Accounts with joint venture owners represent the excess of charges billed over cash calls paid by the joint venture owners for exploration, development and production expenditures made by the Company as an operator.

Accounts Receivable and Allowance for Doubtful Accounts – The Company’s accounts receivable results from sales of crude oil production, joint interest billings to its joint interest owners for their share of expenses on joint venture projects for which the Company is the operator, and receivables from the government of Gabon for reimbursable Value-Added Tax (“VAT”). Collection efforts, including remedies provided for in the contracts, are pursued to collect overdue amounts owed to the Company. Portions of the Company’s costs in Gabon (including the Company’s VAT receivable) are denominated in the local currency of Gabon, the Central African CFA Franc (“XAF”). Most of these receivables have payment terms of 30 days or less. Joint owner receivables are secured through cash calls and other mechanisms for collection under the terms of the joint operating agreements.

The Company routinely assesses the recoverability of all material receivables to determine their collectability. The Company accrues a reserve on a receivable when, based on management’s judgment, it is probable that a receivable will not be collected and the amount of such reserve may be reasonably estimated. When collectability is in doubt, the Company records an allowance against the accounts receivable and a corresponding income charge for bad debts, which appears in the “Bad debt expense and other” line item of the condensed consolidated statements of operations.

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As of September 30, 2022, the outstanding VAT receivable balance, excluding the allowance for bad debt, was approximately $19.2 million ($11.2 million, net to VAALCO). As of September 30, 2022, the exchange rate was XAF 669.4 = $1.00. As of December 31, 2021, the outstanding VAT receivable balance, excluding the allowance for bad debt, was approximately $14.5 million ($9.6 million, net to VAALCO). As of December 31, 2021, the exchange rate was XAF 578.2 = $1.00. The receivable amount, net of allowances, is reported as a non-current asset in the “Value added tax and other receivables” line item in the condensed consolidated balance sheets. Because both the VAT receivable and the related allowances are denominated in XAF, the exchange rate revaluation of these balances into U.S. dollars at the end of each reporting period also has an impact on the Company’s results of operations. Such foreign currency gains (losses) are reported separately in the “Other (expense) income, net” line item of the condensed consolidated statements of operations.

The following table provides a roll forward of the aggregate allowance for bad debt:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2022			2021			2022			2021
	(in thousands)
Allowance for bad debt
Balance at beginning of period	$	(6,389	)	$	(5,575	)	$	(5,741	)	$	(2,273	)
Bad debt charge, net of receipts		(1,020	)		(318	)		(2,083	)		(814	)
Adjustment associated with Sasol Acquisition		—			—			—			(2,879	)
Foreign currency gain (loss)		355			117			770			190
Balance at end of period	$	(7,054	)	$	(5,776	)	$	(7,054	)	$	(5,776	)

Other receivables, net – Under the terms of the Etame PSC, the Company can be required to contribute to meeting domestic market needs of the Republic of Gabon by delivering to it, or another entity designated by the Republic of Gabon, an amount of crude oil proportional to the Company’s share of production to the total production in Gabon over the year. In 2021, the Company was notified by the Republic of Gabon to deliver to a refinery its proportionate share of crude oil to meet the domestic market need as per the terms of the Etame PSC. The Company is entitled, per the Etame PSC, to a fixed selling price for the oil delivered. Since the crude-oil produced by the Company was not compatible with the crude-oil requirements of the refinery, the Company entered into two contracts to fulfill its domestic market needs obligation under the Etame PSC. One contract was to purchase oil from another producer that produced the compatible oil the refinery needs and another contract with the refinery itself to deliver the crude oil to. Under the contract with the provider of the crude oil, the third-party provider is entitled to a selling price consistent with the price the Company receives under the terms of the Etame PSC for the delivery of the crude oil to the refinery. As a result of these contracts and timing differences between when the oil is procured and when it is delivered to and paid for by the refinery, included in the Company’s September 30, 2022 condensed consolidated balance sheet are current receivables in the "other, net" line item of approximately $12.1 million for amounts due to the Company from the refinery for 130 MBbls delivered in August and September of 2022, a $6.7 million current liability included in the "Account payable" line item for amounts due to the oil supplier for 65 MBbls purchased of crude oil from the supplier in August and a $6.1 million current liability included in the "Accrued liabilities and other" line item for amounts due to the oil supplier for 65 MBbls of crude oil purchased in September 2022.

Crude oil inventory – Crude oil inventories are carried at the lower of cost or net realizable value and represent the share of crude oil produced and stored on the FPSO, but unsold at the end of the period and crude oil purchased in order to comply with the domestic market needs of the Republic of Gabon.

Prepayments and Other – Included in “Prepayments and other” line item of the condensed consolidated balance sheet for the nine months ended September 30, 2022 are $7.9 million of prepayments related to fixed assets.

Materials and supplies – Materials and supplies, which are included in the “Prepayments and other” line item of the condensed consolidated balance sheet, are primarily used for production related activities. These assets are valued at the lower of cost, determined by the weighted-average method, or net realizable value.

Crude Oil and natural gas properties, equipment and other – The Company uses the successful efforts method of accounting for crude oil and natural gas producing activities. Management believes that this method is preferable, as the Company has focused on exploration activities wherein there is risk associated with future success and as such earnings are best represented by drilling results.

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Capitalization – Costs of successful wells, development dry holes and leases containing productive reserves are capitalized and amortized on a unit-of-production basis over the life of the related reserves. Other exploration costs, including dry exploration well costs, geological and geophysical expenses applicable to undeveloped leaseholds, leasehold expiration costs and delay rentals, are expensed as incurred. The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. At the completion of drilling activities, the costs of exploratory wells remain capitalized if a determination is made that proved reserves have been found. If no proved reserves have been found, the costs of exploratory wells are charged to expense. In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells. Cost incurred for exploratory wells that find reserves that cannot yet be classified as proved are capitalized if (a) the well has found a sufficient quantity of reserves to justify its completion as a producing well and (b) sufficient progress in assessing the reserves and the economic and operating viability of the project has been made. The status of suspended well costs is monitored continuously and reviewed quarterly. Due to the capital-intensive nature and the geographical characteristics of certain projects, it may take an extended period of time to evaluate the future potential of an exploration project and the economics associated with making a determination of its commercial viability. Geological and geophysical costs are expensed as incurred. Costs of seismic studies that are utilized in development drilling within an area of proved reserves are capitalized as development costs. Amounts of seismic costs capitalized are based on only those blocks of data used in determining development well locations. To the extent that a seismic project covers areas of both developmental and exploratory drilling, those seismic costs are proportionately allocated between development costs and exploration expense.

Depreciation, depletion and amortization – Depletion of wells, platforms, and other production facilities are calculated on a block basis under the unit-of-production method based upon estimates of proved developed reserves. Depletion of developed leasehold acquisition costs are provided on a block basis under the unit-of-production method based upon estimates of proved reserves. Support equipment (other than equipment inventory) and leasehold improvements related to crude oil and natural gas producing activities, as well as property, plant and equipment unrelated to crude oil and natural gas producing activities, are recorded at cost and depreciated on a straight-line basis over the estimated useful lives of the assets, which are typically three to five years for office and miscellaneous equipment and five to seven years for leasehold improvements.

Impairment – The Company reviews the crude oil and natural gas producing properties for impairment on a block basis whenever events or changes in circumstances indicate that the carrying amount of such properties may not be recoverable. If the sum of the expected undiscounted future cash flows from the use of the asset and its eventual disposition is less than the carrying amount of the asset, an impairment charge is recorded based on the fair value of the asset. This may occur if the block contains lower than anticipated reserves or if commodity prices fall below a level that significantly effects anticipated future cash flows. The fair value measurement used in the impairment test is generally calculated with a discounted cash flow model using several Level 3 (as defined in the policy "Fair value" below) inputs that are based upon estimates the most significant of which is the estimate of net proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of development expenditures, including many factors beyond the Company’s control. Reserve engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact manner, and the accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. The quantities of crude oil and natural gas that are ultimately recovered, production and operating costs, the amount and timing of future development expenditures and future crude oil and natural gas sales prices may all differ from those assumed in these estimates. Capitalized equipment inventory is reviewed regularly for obsolescence. When undeveloped crude oil and natural gas leases are deemed to be impaired, exploration expense is charged. Unproved property costs consist of acquisition costs related to undeveloped acreage in the Etame Marin block in Gabon and in Block P in Equatorial Guinea. See Note 7 for further discussion.

Purchase Accounting – On February 25, 2021, VAALCO Gabon S.A., a wholly owned subsidiary of the Company, completed the acquisition of Sasol Gabon S.A.’s (“Sasol’s”) 27.8% working interest in the Etame Marin block offshore Gabon pursuant to the sale and purchase agreement (“SPA”) dated November 17, 2020 (the “Sasol Acquisition”). The Company made various assumptions in determining the fair values of acquired assets and liabilities assumed. In order to allocate the purchase price, the Company developed fair value models with the assistance of outside consultants. These fair value models were used to determine the fair value associated with the reserves and applied discounted cash flows to expected future operating results, considering expected growth rates, development opportunities, and future pricing assumptions. The fair value of working capital assets acquired, and liabilities assumed were transferred at book value, which approximates fair value due to the short-term nature of the assets and liabilities. The fair value of the fixed assets acquired was based on estimates of replacement costs and the fair value of liabilities assumed was based on their expected future cash outflows. See Note 3 for further discussion.

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Lease commitments – At inception, contracts are reviewed to determine whether an agreement contains a lease as defined under Accounting Standards Codification (“ASC”) 842, Leases. Further, if a lease is identified within the contract, a determination is made whether the lease qualifies as an operating or financing lease. Regardless of the type of lease, the initial measurement of the lease results in recording a right of use (“ROU”) asset and a lease liability at the present value of the future lease payments. ROU assets for operating leases are recorded under “Right of use operating lease assets” and the current portion and long-term portion of the lease liabilities for operating leases are reflected in “Operating lease liabilities – current portion” and “Operating lease liabilities – net of current portion” within the condensed consolidated balance sheets. ROU assets for financing leases are recorded within “Right of use finance lease assets” and the current portion and long-term portion of the lease liabilities for financing leases are reflected in “Finance lease liabilities – current portion” and “Finance lease liabilities – net of current portion” within the condensed consolidated balance sheets.

Asset retirement obligations (“ARO”) – The Company has significant obligations to remove tangible equipment and restore land or seabed at the end of crude oil and natural gas production operations. The removal and restoration obligations are primarily associated with plugging and abandoning wells, removing and disposing of all or a portion of offshore crude oil and natural gas platforms, and capping pipelines. Estimating the future restoration and removal costs is difficult and requires management to make estimates and judgments. Asset removal technologies and costs are constantly changing, as are regulatory, political, environmental, safety, and public relations considerations.

A liability for ARO is recognized in the period in which the legal obligations are incurred if a reasonable estimate of fair value can be made. The ARO liability reflects the estimated present value of the amount of dismantlement, removal, site reclamation, and similar activities associated with crude oil and natural gas properties. The Company uses current retirement costs to estimate the expected cash outflows for retirement obligations. Inherent in the present value calculation are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit-adjusted discount rates, timing of settlement, and changes in the legal, regulatory, environmental, and political environments. Initial recording of the ARO liability is offset by the corresponding capitalization of asset retirement cost recorded to crude oil and natural gas properties. To the extent these or other assumptions change after initial recognition of the liability, the fair value estimate is revised and the recognized liability adjusted, with a corresponding adjustment made to the related asset balance or income statement, as appropriate. Depreciation of capitalized asset retirement costs and accretion of asset retirement obligations are recorded over time. Depreciation is generally determined on a units-of-production basis for crude oil and natural gas production facilities, while accretion escalates over the lives of the assets to reach the expected settlement value. Where there is a downward revision to the ARO that exceeds the net book value of the related asset, the corresponding adjustment is limited to the amount of the net book value of the asset and the remaining amount is recognized as a gain. See Note 13 for further discussion.

Revenue recognition – Revenues from contracts with customers are generated from sales in Gabon pursuant to crude oil sales and purchase agreements. There is a single performance obligation (delivering crude oil to the delivery point, i.e., the connection to the customer’s crude oil tanker) that gives rise to revenue recognition at the point in time when the performance obligation event takes place. In addition to revenues from customer contracts, the Company has other revenues related to contractual provisions under the Etame PSC. The Etame PSC is not a customer contract. The terms of the Etame PSC includes provisions for payments to the government of Gabon for: royalties based on 13% of production at the published price and a shared portion of “Profit Oil” determined based on daily production rates, as well as a gross carried working interest of 7.5% (increasing to 10% beginning June 20, 2026) for all costs. For both royalties and Profit Oil, the Etame PSC provides that the government of Gabon may settle these obligations in-kind, i.e., taking crude oil barrels, rather than with cash payments. See Note 6 for further discussion.

Major maintenance activities – Costs for major maintenance are expensed in the period incurred and can include the costs of workovers of existing wells, contractor repair services, materials and supplies, equipment rentals and labor costs.

Stock-based compensation – The Company measures the cost of employee services received in exchange for an award of equity instruments based on the fair value of the award on the date of the grant. The grant date fair value for options or stock appreciation rights (“SARs”) is estimated using either the Black-Scholes or Monte Carlo method depending on the complexity of the terms of the awards granted. The SARs fair value is estimated at the grant date and remeasured at each subsequent reporting date until exercised, forfeited or cancelled.

Black-Scholes and Monte Carlo models employ assumptions, based on management’s best estimates at the time of grant, which impact the calculation of fair value and ultimately, the amount of expense that is recognized over the life of the stock options or SAR award. These models use the following inputs: (i) the quoted market price of the Company’s common stock on the valuation date, (ii) the maximum stock price appreciation that an employee may receive, (iii) the expected term that is based on the contractual term, (iv) the expected volatility that is based on the historical volatility of the Company’s stock for the length of time corresponding to the expected term of the option or SAR award, (v) the expected dividend yield that is based on the anticipated dividend payments and (vi) the risk-free interest rate that is based on the U.S. treasury yield curve in effect as of the reporting date for the length of time corresponding to the expected term of the option or SAR award.

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For restricted stock, the grant date fair value is determined using the market value of the common stock on the date of grant.

The stock-based compensation expense for equity awards is recognized over the requisite or derived service period, using the straight-line attribution method over the service period for each separately vesting portion of the award as if the award was, in-substance, multiple awards.

Unless the awards contain a market condition, previously recognized expense related to forfeited awards is reversed in the period in which the forfeiture occurs. For awards containing a market condition, previously recognized stock-based compensation expense is not reversed when the awards are forfeited. See Note 15 for further discussion.

Income taxes – The annual tax provision is based on expected taxable income, statutory rates and tax planning opportunities available to the Company in the various jurisdictions in which the Company operates. The determination and evaluation of the annual tax provision and tax positions involves the interpretation of the tax laws in the various jurisdictions in which the Company operates and requires significant judgment and the use of estimates and assumptions regarding significant future events such as the amount, timing and character of income, deductions and tax credits. Changes in tax laws, regulations, agreements and tax treaties or the level of operations or profitability in each jurisdiction would impact the tax liability in any given year. The Company also operates in foreign jurisdictions where the tax laws relating to the crude oil and natural gas industry are open to interpretation, which could potentially result in tax authorities asserting additional tax liabilities. While the income tax provision (benefit) is based on the best information available at the time, a number of years may elapse before the ultimate tax liabilities in the various jurisdictions are determined. We also record as income tax expense the increase or decrease in the value of the government’s allocation of Profit Oil which results due to changes in value from the time the allocation is originally produced to the time the allocation is actually lifted.

Judgment is required in determining whether deferred tax assets will be realized in full or in part. Management assesses the available positive and negative evidence to estimate if existing deferred tax assets will be utilized, and when it is estimated to be more-likely-than-not that all or some portion of specific deferred tax assets, such as net operating loss carry forwards or foreign tax credit carryovers, will not be realized, a valuation allowance must be established for the amount of the deferred tax assets that are estimated to not be realizable. Factors considered are earnings generated in previous periods, forecasted earnings and the expiration period of carryovers.

In certain jurisdictions, the Company may deem the likelihood of realizing deferred tax assets as remote where the Company expects that, due to the structure of operations and applicable law, the operations in such jurisdictions will not give rise to future tax consequences. For such jurisdictions, the Company has not recognized deferred tax assets. Should the expectations change regarding the expected future tax consequences, the Company may be required to record additional deferred taxes that could have a material effect on the condensed consolidated financial position and results of operations. See Note 16 for further discussion.

Derivative instruments and hedging activities – The Company enters into crude oil hedging arrangements from time to time in an effort to mitigate the effects of commodity price volatility and enhance the predictability of cash flows relating to the marketing of a portion of our crude oil production. While these instruments mitigate the cash flow risk of future decreases in commodity prices, they may also curtail benefits from future increases in commodity prices.

The Company records balances resulting from commodity risk management activities in the condensed consolidated balance sheets as either assets or liabilities measured at fair value. Gains and losses from the change in fair value of derivative instruments and cash settlements on commodity derivatives are presented in the “Derivative instruments loss, net” line item located within the “Other income (expense)” section of the condensed consolidated statements of operations. See Note 8 for further discussion.

Fair value – Fair value is defined as the price that would be received to sell an asset or the price paid to transfer a liability in an orderly transaction between market participants at the measurement date. Inputs used in determining fair value are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. The three input levels of the fair-value hierarchy are as follows:

Level 1 – Inputs represent quoted prices in active markets for identical assets or liabilities (for example, exchange-traded commodity derivatives).

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Level 2 – Inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly (for example, quoted market prices for similar assets or liabilities in active markets or quoted market prices for identical assets or liabilities in markets not considered to be active, inputs other than quoted prices that are observable for the asset or liability, or market-corroborated inputs).

Level 3 – Inputs that are not observable from objective sources, such as internally developed assumptions used in pricing an asset or liability (for example, an estimate of future cash flows used in the internally developed present value of future cash flows model that underlies the fair-value measurement).

Nonrecurring Fair Value Measurements – The Company applies fair value measurements to its nonfinancial assets and liabilities measured on a nonrecurring basis, which consist of measurements or remeasurements of impairment of crude oil and natural gas properties, asset retirement assets and liabilities and other long-lived assets and assets acquired and liabilities assumed in a business combination. Generally, a cash flow model is used in combination with inflation rates and credit-adjusted, risk-free discount rates or industry rates to determine the fair value of the assets and liabilities. Based upon our review of the fair value hierarchy, the inputs used in these fair value measurements are considered Level 3 inputs.

Fair value of financial instruments – The Company’s current assets and liabilities include financial instruments such as cash and cash equivalents, restricted cash, accounts receivable, derivative assets and liabilities, accounts payable, liabilities for SARs and guarantees. As discussed further in Note 8, derivative assets and liabilities are measured and reported at fair value each period with changes in fair value recognized in net income. The derivatives referenced below are reported in “Accrued liabilities and other” on the condensed consolidated balance sheet. SARs liabilities are measured and reported at fair value using Level 2 inputs each period with changes in fair value recognized in net income. The SARs liabilities is reported in “Accrued liabilities and other” on the condensed consolidated balance sheet. With respect to the other financial instruments included in current assets and liabilities, the carrying value of each financial instrument approximates fair value primarily due to the short-term maturity of these instruments.

As of September 30, 2022

Balance Sheet Line

Level 1

Level 2

Level 3

Total

(in thousands)

Assets

Derivative asset

Prepayments and other

—

348

—

348

—

348

—

348

Liabilities

SARs liability

Accrued liabilities and other

—

544

—

544

—

544

—

544

		*As of December 31, 2021*
	*Balance Sheet Line*	*Level 1*		*Level 2*		*Level 3*		*Total*
		*(in thousands)*
Liabilities
SARs liability	Accrued liabilities and other	$	—	$	609	$	—	$	609
Derivative liability	Accrued liabilities and other		—		4,806		—		4,806
		$	—	$	5,415	$	—	$	5,415

Earnings per Share – Basic earnings per common share is calculated by dividing earnings available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per common share is calculated by dividing earnings available to common stockholders by the weighted average number of diluted common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities consist of unvested restricted stock awards and stock options using the treasury method. Under the treasury method, the amount of unrecognized compensation expense related to unvested stock-based compensation grants or the proceeds that would be received if the stock options were exercised are assumed to be used to repurchase shares at the average market price. When a loss exists, all potentially dilutive securities are anti-dilutive and are therefore excluded from the computation of diluted earnings per share. See Note 5 for further discussion.

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2. NEW ACCOUNTING STANDARDS

Not Yet Adopted

In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Codification (“ASU”) No. 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (“ASU 2016-13”) related to the calculation of credit losses on financial instruments. All financial instruments not accounted for at fair value will be impacted, including the Company’s trade and joint venture owners’ receivables. Allowances are to be measured using a current expected credit loss (“CECL”) model as of the reporting date that is based on historical experience, current conditions and reasonable and supportable forecasts. This is significantly different from the current model that increases the allowance when losses are probable. Initially, ASU 2016-13 was effective for all public companies for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years and will be applied with a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The FASB subsequently issued ASU No. 2019-04 (“ASU 2019-04”): Codification Improvements to Topic 326, Financial Instruments-Credit Losses, Topic 815, Derivatives, and Topic 825, Financial Instruments and ASU No. 2019-05 (“ASU 2019-05”): Financial Instruments-Credit Losses (Topic 326) - Targeted Transition Relief. ASU 2019-04 and ASU 2019-05 provide certain codification improvements related to implementation of ASU 2016-13 and targeted transition relief consisting of an option to irrevocably elect the fair value option for eligible instruments. In November 2019, the FASB issued ASU No. 2019-10, Financial Instruments—Credit Losses (Topic 326), Derivatives and Hedging (Topic 815), and Leases (Topic 842): Effective Dates. This amendment deferred the effective date of ASU No. 2016-13 from January 1, 2020 to January 1, 2023 for calendar year end smaller reporting companies, which includes the Company. The Company plans to defer the implementation of ASU 2016-13, and related updates, until January 2023. The Company does not expect a material impact on adoption.

3. ACQUISITIONS AND DISPOSITIONS

TransGlobe Merger

On October 13, 2022, the Company and AcquireCo completed the previously announced business combination with TransGlobe whereby AcquireCo acquired all of the issued and outstanding common shares of TransGlobe and TransGlobe became a direct wholly owned subsidiary of AcquireCo and an indirect wholly owned subsidiary of the Company pursuant to an arrangement agreement entered into by the Company, AcquireCo and TransGlobe on July 13, 2022.

At the effective time of the Arrangement and pursuant to the Arrangement Agreement, each common share of TransGlobe issued and outstanding immediately prior to the effective time of the Arrangement (the “TransGlobe common shares”) was converted into the right to receive 0.6727 (the “exchange ratio”) of a share of common stock, par value $0.10 per share, of the Company (“VAALCO common stock,” and each share of VAALCO common stock, a “VAALCO share”). The total number of VAALCO shares issued to TransGlobe’s shareholders was approximately 49.3 million. The Arrangement resulted in VAALCO stockholders owning approximately 54.5%, and TransGlobe shareholders owning approximately 45.5% of the Combined Company, calculated based on vested outstanding shares of each company as of the date of the Arrangement Agreement. The Combined Company results of operations of VAALCO and TransGlobe for the fourth quarter of 2022 will be included in the Company’s consolidated results for the period ending December 31, 2022.

Prior to the Arrangement, TransGlobe was a cash flow-focused oil and gas exploration and development company whose activities were concentrated in the Arab Republic of Egypt and Canada. The Combined Company is a leading African-focused operator with a strong production and reserve base and a diverse portfolio of assets in Gabon, Egypt, Equatorial Guinea and Canada. The transaction qualifies as a business combination under ASC 805, Business Combinations and the Company is the accounting acquiror. The purchase accounting for the business combination has not been completed.

For the three and nine months ended September 30, 2022 included in the line item "Other (expense) income, net" is $6.4 million and $7.6 million of transactions costs, respectively, associated with the Arrangement with TransGlobe.

Acquisition of Sasol Gabon S.A.’s Interest in Etame

On February 25, 2021, VAALCO Gabon S.A. completed the acquisition of Sasol’s 27.8% working interest in the Etame Marin block offshore Gabon pursuant to the SPA. The effective date of the transaction was July 1, 2020. Prior to the Sasol Acquisition, the Company owned and operated a 31.1% working interest in Etame. The Sasol Acquisition increased the Company’s working interest to 58.8%. As a result of the Sasol Acquisition, the net portion of production and costs relating to the Company’s Etame operations increased from 31.1% to 58.8%. Reserves, production and financial results for the interests acquired in the Sasol Acquisition have been included in VAALCO’s results for periods after February 25, 2021.

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The following amounts represent the allocation of the purchase price to the assets acquired and liabilities assumed in the Sasol Acquisition.

	February 25, 2021
	*(in thousands)*
Purchase Consideration
Cash	$	33,959
Fair value of contingent consideration		4,647
Total purchase consideration	$	38,606

	February 25, 2021
	*(in thousands)*
Assets acquired:
Wells, platforms and other production facilities	$	37,176
Equipment and other		5,568
Value added tax and other receivables		1,234
Abandonment funding		11,781
Accounts receivable - trade		11,220
Other current assets		3,963
Liabilities assumed:
Asset retirement obligations		(14,564	)
Accrued liabilities and other		(10,121	)
Bargain purchase gain		(7,651	)
Total purchase price	$	38,606

All assets and liabilities associated with Sasol’s interest in Etame Marin block, including crude oil and natural gas properties, asset retirement obligations and working capital items, were recorded at their fair value. The Company used estimated future crude oil prices as of the closing date, February 25, 2021, to apply to the estimated reserve quantities acquired and market participant assumptions to the estimated future operating and development costs to arrive at the estimates of future net revenues. The future net revenues were discounted using the Company’s weighted average cost of capital to determine the fair value at closing. The valuations to derive the purchase price included the use of both proved and unproved categories of reserves, expectation for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates, and risk adjusted discount rates. Other significant estimates were used by the Company to determine the fair value of assets acquired and liabilities assumed. The Company had one year from the date of closing to record purchase price adjustments as a result of changes in such estimates. As a result of comparing the purchase price to the fair value of the assets acquired and liabilities assumed a $7.7 million bargain purchase gain was recognized. A bargain purchase gain of $5.5 million is included in “Other (expense) income, net" under "Other income (expense)" in the 2021 condensed consolidated statements of operations. An income tax benefit of $2.2 million, related to the bargain purchase gain, is also included in the 2021 condensed consolidated statements of operations.

The bargain purchase gain is primarily attributable to the increase in crude oil price forecasts from the date the SPA was signed, November 17, 2020, to the closing date, February 25, 2021, when the fair value of the reserves associated with the Sasol Acquisition were determined.

The impact of the Sasol Acquisition was an increase to “Crude oil and natural gas sales” in the condensed consolidated statement of operations of $36.9 million and $121.6 million for the three and nine months ended September 30, 2022, respectively, and $3.3 million and $16.1 million increase to “Net income” in the condensed consolidated statements of operations for the three and nine months ended September 30, 2022, respectively.

The impact of the Sasol Acquisition was an increase to “Crude oil and natural gas sales” in the condensed consolidated statement of operations of $26.4 million and$58.0 million for the three and nine months ended September 30, 2021, respectively, and $10.2 million and $20.1 million increase to “Net income” in the condensed consolidated statements of operations for the three and nine months ended September 30, 2021, respectively.

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The unaudited pro forma results presented below have been prepared to give the effect to the Sasol Acquisition discussed above on the Company’s results of operations for the three and nine months ended September 30, 2021, respectively, as if the Sasol Acquisition had been consummated on January 1, 2020. The unaudited pro forma results do not purport to represent what the Company’s actual results operations would have been if the Sasol 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 September 30,*		*Nine Months Ended September 30,*
	*2021*		*2021*
	*(in thousands - unaudited)*
Pro forma (unaudited)
Crude oil and natural gas sales	$	55,899	$	160,469
Operating income		20,030		63,929
Net income		31,721		49,341	(a)

Basic net income loss per share:
Income from continuing operations	$	0.53	$	0.85
Net income per share	$	0.53	$	0.85
Basic weighted average shares outstanding		58,586		58,102
Diluted net income per share:
Income from continuing operations	$	0.53	$	0.84
Net income per share	$	0.53	$	0.84
Diluted weighted average shares outstanding		58,916		58,654

(a)

The pro forma net income for the nine months ended September 30, 2021 excludes nonrecurring pro forma adjustments directly attributable to the Sasol Acquisition, consisting of a bargain purchase gain of $7.7 million and transaction costs of $1.0 million.

Under the terms of the SPA, a contingent payment of $5.0 million was payable to Sasol should the average Dated Brent price over a consecutive 90-day period from July 1, 2020 to June 30, 2022 exceed $60.00 per barrel. Included in the purchase consideration was the fair value, at closing, of the contingent payment due to Sasol. The conditions related to the contingent payment were met and on April 29, 2021, the Company paid the $5.0 million contingent amount to Sasol in accordance with the terms of the SPA.

Discontinued Operations - Angola

In November 2006, the Company signed a production sharing contract for Block 5 offshore Angola (“Block 5 PSA”). The Company’s working interest was 40%, and the Company carried Sonangol P&P, for 10% of the work program. On September 30, 2016, the Company notified Sonangol P&P that it was withdrawing from the joint operating agreement effective October 31, 2016. On November 30, 2016, the Company notified the national concessionaire, Sonangol E.P., that it was withdrawing from the Block 5 PSA and reduced its activities in Angola. As a result of this strategic shift, the Company classified all the related assets and liabilities as those of discontinued operations in the condensed consolidated balance sheets. The operating results of the Angola segment have been classified as discontinued operations for all periods presented in the Company’s condensed consolidated statements of operations. The Company segregated the cash flows attributable to the Angola segment from the cash flows from continuing operations for all periods presented in the Company’s condensed consolidated statements of cash flows. During the three and nine months ended September 30, 2022 and 2021, the Angola segment did not have a material impact on the Company’s financial position, results of operations, cash flows and related disclosures.

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4. SEGMENT INFORMATION

The Company’s operations are based in Gabon and the Company has an undeveloped block in Equatorial Guinea. Each of the Company’s two reportable operating segments is organized and managed based upon geographic location. The Company’s Chief Executive Officer, who is the chief operating decision maker, and management review and evaluate the operation of each geographic segment separately, primarily based on operating income (loss). 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.

Segment activity of continuing operations for the three and nine months ended September 30, 2022 and 2021 as well as long-lived assets and segment assets at September 30, 2022 and December 31, 2021 are as follows:

	*Three Months Ended September 30, 2022*
*(in thousands)*	*Gabon*			*Equatorial Guinea*			*Corporate and Other*			*Total*
Revenues:
Crude oil and natural gas sales	$	78,097		$	—		$	—		$	78,097
Operating costs and expenses:
Production expense		22,828			484			—			23,312
FPSO demobilization		8,867			—			—			8,867
Exploration expense		56			—			—			56
Depreciation, depletion and amortization		8,940			—			23			8,963
General and administrative expense		915			120			944			1,979
Bad debt expense and other		681			339			—			1,020
Total operating costs and expenses		42,287			943			967			44,197
Other operating expense, net		—			—			—			—
Operating income		35,810			(943	)		(967	)		33,900
Other income (expense):
Derivative instruments loss, net		—			—			3,778			3,778
Interest (expense) income, net		(351	)		—			117			(234	)
Other (expense) income, net		(1,305	)		1			(6,403	)		(7,707	)
Total other expense, net		(1,656	)		1			(2,508	)		(4,163	)
Income from continuing operations before income taxes		34,154			(942	)		(3,475	)		29,737
Income tax (benefit) expense		25,415			—			(2,572	)		22,843
Income from continuing operations		8,739			(942	)		(903	)		6,894
Loss from discontinued operations, net of tax		—			—			(26	)		(26	)
Net income	$	8,739		$	(942	)	$	(929	)	$	6,868
Consolidated capital expenditures	$	51,610		$	—		$	53		$	51,663

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	*Nine Months Ended September 30, 2022*
*(in thousands)*	*Gabon*			*Equatorial Guinea*			*Corporate and Other*			*Total*
Revenues:
Crude oil and natural gas sales	$	257,738		$	—		$	—		$	257,738
Operating costs and expenses:
Production expense		66,269			878			—			67,147
FPSO demobilization		8,867			—			—			8,867
Exploration expense		250			—			—			250
Depreciation, depletion and amortization		21,766			—			61			21,827
General and administrative expense		2,073			329			8,105			10,507
Bad debt expense and other		1,744			339			—			2,083
Total operating costs and expenses		100,969			1,546			8,166			110,681
Other operating expense, net		(5	)		—			—			(5	)
Operating income		156,764			(1,546	)		(8,166	)		147,052
Other income (expense):
Derivative instruments loss, net		—			—			(37,522	)		(37,522	)
Interest (expense) income, net		(515	)		—			160			(355	)
Other (expense) income, net		(2,799	)		(1	)		(7,714	)		(10,514	)
Total other expense, net		(3,314	)		(1	)		(45,076	)		(48,391	)
Income from continuing operations before income taxes		153,450			(1,547	)		(53,242	)		98,661
Income tax (benefit) expense		74,671			1			(10,205	)		64,467
Income from continuing operations		78,779			(1,548	)		(43,037	)		34,194
Loss from discontinued operations, net of tax		—			—			(58	)		(58	)
Net income	$	78,779		$	(1,548	)	$	(43,095	)	$	34,136
Consolidated capital expenditures	$	121,492		$	—		$	120		$	<

Form: 10-Q

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