• VAALCO Energy, Inc. Announces Second Quarter 2024 Results

    Источник: Nasdaq GlobeNewswire / 06 авг 2024 19:45:18   America/Chicago

    HOUSTON, Aug. 06, 2024 (GLOBE NEWSWIRE) -- VAALCO Energy, Inc. (NYSE: EGY, LSE: EGY) ("VAALCO" or the "Company") today reported operational and financial results for the second quarter of 2024. 

    Second Quarter 2024 Highlights and Recent Key Items:

    • Closed the accretive all cash acquisition of Svenska Petroleum Exploration AB (“Svenska”) for a net purchase price of $40.2 million;
      • Updated third-party reserve engineer's calculation of proved reserves as of December 31, 2023 for Svenska that shows significant increase of SEC proved reserves to 16.9 million barrels of oil equivalent (“MMBOE”) (93% oil);
      • Realized a $19.9 million bargain purchase gain on the transaction;
    • Reported strong Q2 2024 net income of $28.2 million ($0.27 per diluted share) and, Adjusted Net Income(1) of $22.6 million ($0.22 per diluted share);
    • Increased Adjusted EBITDAX(1) by 17% to $72.5 million compared to Q1 2024, driven by sales increase associated with Côte d’Ivoire lifting in May following the closing of the Svenska acquisition;
    • Achieved production of 20,588 net revenue interest (“NRI”)(2) barrels of oil equivalent per day (“BOEPD”) and working interest (“WI”)(3) production of 25,411 BOEPD; second quarter 2024 included new production of 3,329 NRI BOEPD (3,329 WI BOEPD) from Côte d’Ivoire;
    • Delivered better than expected results from the Canadian drilling program with three wells averaging 30 day initial production (“IP”)1 rates of 464 barrels of oil per day (“BOPD”), significantly increasing the liquid ratio in Canada;
    • Reported NRI sales of 1,764,000 barrels of oil equivalent (“BOE”), or 19,386 BOEPD, above the midpoint of guidance; and 18% above the first quarter of 2024 due to the Côte d’Ivoire lifting;
    • Posted unrestricted cash of $62.9 million which is after $40.2 million paid for the Svenska acquisition, $6.5 million paid for quarterly dividend and $32.5 million in cash capital spending for the quarter;
      • Received $8 million payment post quarter-end of back dated accounts receivables (“AR”) in Egypt from EGPC. And, in July, written confirmation that the invoice was recognized in their June Accounts Payable as owed to us for our Merged Concession effective date adjustment; 
    • Settled $30.2 million in foreign income taxes for Gabon through the government taking its oil in-kind during a Q2 2024 lifting; and
    • Announced quarterly cash dividend of $0.0625 per share of common stock to be paid on September 20, 2024.
     (1) Adjusted EBITDAX, Adjusted Net Income, Adjusted Working Capital and Free Cash Flow2 are Non-GAAP financial measures and are described and reconciled to the closest GAAP measure in the attached table under “Non-GAAP Financial Measures.”
     (2) All NRI production rates are VAALCO's working interest volumes less royalty volumes, where applicable.
     (3) All WI production rates and volumes are VAALCO's working interest volumes, where applicable.
        

    George Maxwell, VAALCO’s Chief Executive Officer commented, “We had another strong quarter operationally and financially, closed on a highly accretive acquisition and continue to focus on profitably generating cash flow to fund future projects, while maintaining our commitment to meaningful shareholder returns through our quarterly dividend policy. We are very pleased with the solid results from our Canadian drilling program, which improved our liquid mix considerably in the second quarter as we had three of the four wells come in with higher-than-expected IP30 rates. We closed the Côte d‘Ivoire transaction on April 30, had a lifting there in May and collected payment in June.”

    “Looking at our highly accretive Côte d’Ivoire acquisition, we recognized a $19.9 million non-cash bargain purchase gain, which benefited our second quarter earnings, but it’s the strategic opportunities that provide VAALCO another strong asset to support future growth that we are most excited about. We are very pleased with the results of our third-party reserve engineer’s calculation of proved reserves as of December 31, 2023 that shows even greater reserves than we initially disclosed, up approximately 30% from our initial disclosure. This strategic and highly cost-effective acquisition strategically expands our West African focus area with a sizeable producing asset that has significant upside potential and considerable future development opportunities in Côte d’Ivoire, a well-established and investment-friendly country.”

    “The focus for the second half of 2024 will be the preparation for major projects expected to deliver a step-change in organic growth across the portfolio in 2025. We expect to see an increase in capex investment through the second half of the year associated with these numerous projects including the drilling campaign in Gabon and the FPSO upgrade in Cote d’Ivoire. We are excited about the future and plan to continue to generate strong operational cash flow to fund our impressive organic opportunities moving forward, while continuing to return capital to our shareholders through the quarterly dividend.”

    Operational Update 

    Egypt

    VAALCO focused on enhancing production in the first half of 2024 through a series of planned workovers, as well as through interventions using the OGS-10 rig. VAALCO finalized the K-81 recompletion at the start of the first quarter which was a carry-over from its 2023 drilling activity. The EA-55 well, drilled in October 2023, was fracked and put online in January 2024. Three additional workover recompletions were completed in the second quarter with one more in progress. With the low cost of workovers, the well economics are strongly positive.

    A summary of the Egyptian workover campaign's impact in the first half of 2024 is presented below:

    VAALCO Egypt 2024 Workover Wells 
    WellWorkover dateTypeCompletion Zone Perforation Interval (ft)  IP-30 Rate (BOPD) 
    K-811-Jan-24RecompletionAsl-D  13.1   154 
    EA-5510-Jan-24Frac & CompleteRedbed Hydraulic Frac   143 
    H-227-Feb-24RecompletionYusr-A  9.8   82 
    K-65_ST114-Feb-24RecompletionAsl-D  13.1   43* 
    K-8516-Mar-24RecompletionAsl-D  13.1   420 
    K-8427-Mar-24RecompletionAsl-G  16.4   58* 
    K-743-Apr-24Water Shut-off RecompletionAsl-A  8.2   108 
    K-777-Apr-24RecompletionAsl-A  26.2   100 
    K-8413-Jun-24RecompletionAsl-D  19.7   430 
    K-8019-Jun-24RecompletionAsl-D  13.1   188 

     *Production as of June 30, 2024 – Sand production – Possible Sand Screen Required

    Canada

    The 2024 drilling campaign commenced in January 2024 with the drilling of 9-12-30-4W5, which was spud on January 17, 2024. The first well was drilled to a total depth of 22,732 feet. The second well of the program, 10-12-30-4W5, was spud on February 9, 2024, and drilled to a total depth of 21,736 feet. The third well on the program, 11-12-30-4W5 was spud on February 23, 2024, and drilled to a total depth of 21,624 feet. The fourth well on the program 1-18-30-3W5 was spud on March 9, 2024, and drilled to a total depth of 20,669 feet. The drilling rig was released on March 24, 2024.

    Completion of the wells began in late March and was completed in April. By early May all wells were on production with strong initial rates as noted below:

    VAALCO Canada 2024 Wells
    WellSpud dateNet Pay (ft)Penetrated Pay ZonesCompletion Zone Perforation
    Interval (ft)    		 IP-30 Rate (BOEPD)
    09-12-30-4W51/17/20242.75-Mile Hz
    (4,400m,
    14,430ft)    		Upper Bioturbated CardiumCardium  115 Stg x 15T
    Hydraulic
    Fracture
    Treatment    		 479
    10-12-30-4W52/22/20242.75-Mile Hz
    (4,400m,
    14,430ft)    		Upper Bioturbated CardiumCardium  100 Stg x 15T
    Hydraulic
    Fracture
    Treatment    		 469
    11-12-30-4W52/23/20242.75-Mile Hz
    (4,400m,
    14,430ft)    		Upper Bioturbated CardiumCardium  108 Stg x 15T
    Hydraulic
    Fracture
    Treatment    		 444
    1-18-30-3W59/3/20242.75-Mile Hz
    (4,400m,
    14,430ft)    		Upper Bioturbated CardiumCardium  106 Stg x 15T
    Hydraulic
    Fracture
    Treatment    		 182
     

    Gabon

    VAALCO is currently finalizing locations and planning for the next drilling campaign at Etame that is expected to occur early in 2025. In October 2022, VAALCO successfully completed its transition to a Floating Storage and Offloading vessel (“FSO”) and related field reconfiguration processes. This project provides a low cost FSO solution that increases the storage capacity for the Etame block and improved operational performance. The Company continues to emphasize operational excellence, production uptime and enhancement in 2024 to minimize decline until the next drilling campaign.

    The focus is on the continued production optimization of the new flow line configurations through the Etame Facility, for final processing before being pumped to the FSO. This continued optimization and understanding of the post-reconfiguration process dynamics of the Etame platform, have resulted in a very high uptime of the Etame Facility.

    Côte d'Ivoire 

    Prior to closing of the acquisition, at the beginning of Q2 2024, production was shut in due to the planned field maintenance shutdown. The Baobab production shutdown took place successfully and as per plan between March 21, 2024 and April 13, 2024. All nine operational production wells were successfully restarted in mid-April with flush production rates of just over 21,000 BOEPD, which has since stabilized to around 18,000 BOEPD. 

    During the second quarter, one lifting took place in May of 655,715 gross barrels or 211,294 net barrels to VAALCO, achieving a price of $81.70 per barrel.

    Work with Modec, the operator of the Baobab Floating Production and Offloading Vessel (“FPSO”), on the drydocking project for the FPSO, projected to be offline in 2025, continued in the second quarter of 2024. The operator is currently preparing detailed project timetable and costings for the partners and regulator; however preliminary work including the execution of a letter of intent with Modec on April 4, 2024 which covers the key contracts to be executed, including vessel purchase, EPC, and O&M amendments, as well as selection of the disconnect and reconnect contractor, and support for the revised yard bid from Dubai dry docks among other activities. Additionally, in the second quarter of 2024, the outstanding tank inspections continued in preparation for the dry dock.

    Financial Update – Second Quarter of 2024

    VAALCO reported net income of $28.2 million ($0.27 per diluted share) for the second quarter of 2024 which was up significantly compared with net income of $7.7 million ($0.07 per diluted share) in the first quarter of 2024 and up compared to $6.8 million ($0.06 per diluted share) in the second quarter of 2023. The increase in earnings is driven by the non-cash bargain purchase gain on the acquisition, increased sales associated with Côte d’Ivoire and was partially offset by increased production expense. 

    Adjusted EBITDAX totaled $72.5 million in the second quarter of 2024, an increase from $61.7 million in the first quarter of 2024 and from $65.3 million generated in the same period in 2023. The increase was primarily due to additional sales volumes from Côte d'Ivoire.

    Quarterly Summary - Sales and Net Revenue                                        
    $ in thousands Three Months Ended June 30, 2024  Three Months Ended March 31, 2024 
      Gabon  Egypt  Canada  Côte d'Ivoire  Total  Gabon  Egypt  Canada  Côte d'Ivoire  Total 
    Oil Sales  62,327   65,314   9,547   17,240   154,428   64,788   63,192   4,153   —   132,133 
    NGL Sales  —   —   1,922   —   1,922   —   —   1,977   —   1,977 
    Gas Sales  —   —   384   -   384   -   -   820   —   820 
    Gross Sales  62,327   65,314   11,854   17,240   156,734   64,788   63,192   6,951   —   134,931 
                                             
    Selling Costs & carried interest  -   (117)  (318)  -   (435)  1,174   (111)  (143)  —   920 
    Royalties & taxes  (8,653)  (29,716)  (1,152)  -   (39,521)  (8,458)  (26,120)  (1,118)  —   (35,696)
                                             
                                             
    Net Revenue  53,674   35,481   10,384   17,240   116,778   57,504   36,961   5,690   —   100,155 
                                             
    Oil Sales MMB (working interest)  759   953   130   211   2,053   770   950   61   —   1,781 
    Average Oil Price Received $82.13  $68.52  $73.52  $81.70  $75.22  $84.19  $66.52  $67.83   —  $74.21 
    Change                  1%                    
    Average Brent Price  —   —   —      $84.65   —   —   —      $83.00 
    Change                  2%                    
                                             
    Gas Sales MMCF (working interest)  —   —   423       423   —   —   469       469 
    Average Gas Price Received  —   —  $0.91      $0.91   —   —  $1.75      $1.75 
    Change                  -48%                    
    Average Aeco Price ($USD)  —   —  $0.84      $0.84   —   —  $1.46      $1.46 
    Change                  -42%                    
                                             
    NGL Sales MMB (working interest)  —   —   76       76   —   —   76       76 
    Average Liquids Price Received  —   —  $25.16      $25.16   —   —  $25.98      $25.98 
    Change                  -3%                    


    Revenue and Sales Q2 2024  Q2 2023  % Change Q2 2024 vs. Q2 2023  Q1 2024  % Change Q2 2024 vs. Q1 2024 
    Production (NRI BOEPD)  20,588   19,676   5%  16,848   22%
    Sales (NRI BOE)  1,764,000   1,803,000   (2)%  1,490,000   18%
    Realized commodity price ($/BOE) $66.05  $59.37   11% $66.43   (1)%
    Commodity (Per BOE including realized commodity derivatives) $66.03  $59.34   11% $66.41   (1)%
    Total commodity sales ($MM) $116.5  $109.2   7% $100.2   16%
                         

    VAALCO had net revenues increase by $16.0 million or 16% as total NRI sales volumes of 1,764,000 BOE was higher than Q1 2024 and decreased 2% compared to 1,803,000 BOE for Q2 2023. Q2 2024 NRI sales were toward the upper end of VAALCO's guidance. The Company expects third quarter 2024 NRI sales to be between 21,700 and 24,000 BOEPD, reflecting the addition of the Côte d'Ivoire volume for an entire quarter.

    Q2 2024 realized pricing (net of royalties) was virtually flat compared to Q1 2024 and 11% higher compared to Q2 2023. 

    4

    Costs and Expenses Q2 2024  Q2 2023  % Change Q2 2024 vs. Q2 2023  Q1 2024  % Change Q2 2024 vs. Q1 2024 
    Production expense, excluding offshore workovers and stock comp ($MM) $52.4  $38.8   35% $32.1   63%
    Production expense, excluding offshore workovers ($/BOE) $29.70  $21.51   38% $21.58   38%
    Offshore workover expense ($MM) $0.1  $(0.2)  134% $(0.1)  —%
    Depreciation, depletion and amortization ($MM) $33.1  $38.0   (13)% $25.8   28%
    Depreciation, depletion and amortization ($/BOE) $18.78  $21.10   (11)% $17.33   8%
    General and administrative expense, excluding stock-based compensation ($MM) $6.6  $4.8   38% $5.9   14%
    General and administrative expense, excluding stock-based compensation ($/BOE) $3.8  $2.70   40% $3.9   (4)%
    Stock-based compensation expense ($MM) $0.9  $0.6   50% $0.9   -%
    Current income tax expense (benefit) ($MM) $13.3  $12.4   7% $25.7   (48)%
    Deferred income tax expense (benefit) ($MM) $(4.0) $(0.8)  405% $(3.4)  17%
                         

    Total production expense (excluding offshore workovers and stock compensation) of $52.4 million in Q2 2024 was an increase compared to Q1 2024 and an increase compared to the same period in 2023. The increase in Q2 2024 was primarily driven by a non-cash purchase price adjustment for the Svenska acquisition flowing through production expense and increased operating expenditure associated with the addition of Côte d'Ivoire in the quarter. VAALCO has seen withholding tax, inflationary and industry supply chain pressure on personnel and contractor costs.

    Q2 2024 had minimal offshore workover expense and was equal to workover expense in Q1 2024.

    Q2 2024 production expense per BOE, excluding offshore workover expense, increased to $29.70 per BOE which was higher than Q2 2023 and Q1 2024 primarily due to the increased costs associated with the non-cash purchase price adjustment for the Svenska acquisition.

    DD&A expense for Q2 2024 was $33.1 million which was higher than $25.8 million in Q1 2024 and lower than $38.0 million in Q2 2023. The increase in Q2 2024 DD&A expense compared to Q1 2024 is due primarily to increased depletion associated with the addition of Côte d'Ivoire. The decrease in Q2 2024 DD&A expense compared to Q2 2023 is due to lower depletable costs in Gabon, Egypt, and Canada partially offset by higher depletable costs in Côte d'Ivoire. 

    General and administrative (“G&A”) expense, excluding stock-based compensation, increased to $6.6 million in Q2 2024 from $5.9 million in Q1 2024 and $4.8 million in Q2 2023. The increase in general and administrative expenses compared to Q2 2023 and Q1 2024 is primarily due to higher professional service fees, salaries and wages, and accounting and legal fees due to growth due to the acquisition. Q2 2024 cash G&A was within the Company’s guidance and nearly flat compared to Q1 2024 on a per barrel basis.

    Non-cash stock-based compensation expense was $0.9 million for Q2 2024 compared to $0.6 million for Q2 2023. Non-cash stock-based compensation expense for Q1 2024 was $0.9 million.

    Other income (expense), net, was an expense of $2.0 million for Q2 2024, compared to an expense of $0.5 million during Q2 2023 and an expense of $1.8 million for Q1 2024. Other income (expense), net, normally consists of foreign currency losses. Also included in Q2 2024 amount are $1.8 million in transaction costs related to the Svenska acquisition.

    Foreign income taxes for Gabon are settled by the government taking oil in-kind. Q2 2024 income tax expense was an expense of $9.3 million and is comprised of current tax expense of $13.3 million and deferred tax benefit of $4.0 million. Current quarter tax was impacted by non-deductible items (such as the Svenska transaction costs) and the change in market value of tax barrels due to Gabon State mark-to-market at quarter end. Q1 2024 income tax expense was an expense of $22.2 million. This was comprised of $25.7 million of current tax expense and a deferred tax benefit of $3.4 million. Q2 2023 income tax expense was an expense of $11.6 million. This was comprised of $12.4 million of current tax expense and a deferred tax benefit of $0.8 million. For all periods, VAALCO’s overall effective tax rate was impacted by non-deductible items associated with tax rates in foreign jurisdictions higher than the US statutory rate and by non-deductible items associated with operations.

    Financial Update – First Six Months of 2024

    WI Sales for the first six months of 2024 increased to 4,134 MBOE compared to 3,438 MBOE in the first six months of 2023. The increase was driven primarily by the Côte d'Ivoire acquisition. Crude oil sales are a function of the number and size of crude oil liftings in each quarter and do not always coincide with volumes produced in any given period.

    The average realized crude oil price for the first six months of 2024 was $74.75 per barrel, representing an increase of 8.0% from $69.28 realized in the first six months of 2023. This increase in crude oil price reflects the increase in commodity pricing over the past year.

    The Company reported net income for the six months ended June 30, 2024 of $35.8 million, which compares to $10.2 million for the same period of 2023. The increase in net income for the six months ended June 30, 2024 compared to the same period in 2023 was primarily due to the bargain purchase gain related to the Svenska acquisition in April, as well as higher sales and realized pricing.

    Year to Date Summary - Sales and Net Revenue                                        
    $ in thousands Six Months Ended June 30, 2024  Six Months Ended June 30, 2023 
      Gabon  Egypt  Canada  Côte d'Ivoire  Total  Gabon  Egypt  Canada  Côte d'Ivoire  Total 
    Oil Sales  127,115   128,506   13,700   17,240   286,561   130,079   104,822   14,979   —   249,880 
    NGL Sales  —   —   3,898       3,898   —   —   4,348       4,348 
    Gas Sales  —   —   1,205       1,205   —   —   1,661       1,661 
    Gross Sales  127,115   128,506   18,802   17,240   291,663   130,079   104,822   20,988   —   255,889 
                                             
    Selling Costs & carried interest  1,174   (228)  (461)      485   2,212   (498)  —       1,714 
    Royalties & taxes  (17,111)  (55,836)  (2,269)      (75,216)  (17,630)  (48,232)  (2,098)  —   (67,960)
                                             
                                             
    Net Revenue  111,178   72,442   16,073   17,240   216,933   114,661   56,092   18,890   —   189,643 
                                             
                                             
    Oil Sales MMB (working interest)  1,528   1,903   191   211   3,834   1,641   1,750   216   —   3,607 
    Average Oil Price Received $83.17  $67.52  $71.70  $81.70  $74.75  $79.29  $59.89  $69.27  $-  $69.28 
    Change                  8%                    
    Average Brent Price                 $83.83                  $79.47 
    Change                  5%                    
                                             
    Gas Sales MMCF (working interest)  —   —   892       892   —   —   857       857 
    Average Gas Price Received  —   —  $1.35      $1.35   —   —  $1.94      $1.94 
    Change                  -30%                    
    Average Aeco Price ($USD)         $1.15      $1.15          $1.96      $1.96 
    Change                  -41%                    
                                             
    NGL Sales MMB (working interest)  —   —   152       152   —   —   155       155 
    Average Liquids Price Received  —   —  $25.63      $25.63   —   —  $28.08      $28.08 
    Change                  -9%                    
     

    Capital Investments/Balance Sheet 

    For the second quarter of 2024, net capital expenditures totaled $32.5 million on a cash basis and $22.4 million on an accrual basis. These expenditures were primarily related to costs associated with the development drilling programs in Egypt and Canada. 

    At the end of the second quarter of 2024, VAALCO had an unrestricted cash balance of $62.9 million. Working capital at June 30, 2024 was $31.2 million compared with $45.7 million at December 31, 2023, while Adjusted Working Capital(2) at June 30, 2024 totaled $43.5 million. 

    In Egypt, the Company received written confirmation from EGPC that $51.7 million was recognized in their June Accounts Payable as owed to Company for our Merged Concession effective date adjustment, from which they will offset $11.2 million to satisfy any obligation of VAALCO or its subsidiaries in connection with the TransGlobe combination. This allowance of $11.2 million is fully covered in the 30th June 2024 Balance Sheet. Having this confirmation from EGPC is an important step in the process of getting this paid.

    Quarterly Cash Dividend

    VAALCO paid a quarterly cash dividend of $0.0625 per share of common stock for the second quarter of 2024 on June 21, 2024. The Company also announced its next quarterly cash dividend of $0.0625 per share of common stock for the third quarter of 2024 ($0.25 annualized), to be paid on September 20, 2024 to stockholders of record at the close of business on August 23, 2024. Future declarations of quarterly dividends and the establishment of future record and payment dates are subject to approval by the VAALCO Board of Directors (the "Board").

    Svenska Acquisition

    VAALCO closed its acquisition of Svenska for the net purchase price of $40.2 million, on April 30, 2024 after certain regulatory and government approvals were received.

    Svenska’s primary license interest is a 27.39% non-operated working interest (30.43% paying interest) in the CI-40 license, which includes the producing Baobab field, located in deepwater offshore Côte d’Ivoire. The field is operated by CNR International, which holds a 57.61% working interest in the project, with the national oil company, Petroci Holding, owning the remaining 15% working interest (10% of which is carried by the other license partners). The CI-40 license has an initial term through mid-2028 with the contractual option to extend the license term by 10 years to 2038, subject to certain conditions. Production in the Baobab field was approximately 5,000 WI BOEPD, with cumulative gross production from the field has been approximately 150 MMBOE, a portion of the estimated over one billion barrels of oil equivalent volumes initially in place.

    At the time of the initial announcement of the acquisition, VAALCO disclosed that the transaction included estimated 1P WI CPR reserves, as of October 1, 2023, of 13.0 MMBOE (99% oil) and total 2P WI CPR reserves at October 1, 2023, of 21.7 million MMBOE (97% oil). VAALCO at that time did not have a calculation of SEC proved reserves as of December 31, 2023 but has since worked with its third-party reserves auditors to calculate its SEC proved reserves. VAALCO reported on July 16, 2024 that SEC net proved reserves as of December 31, 2023 totaled 16.9 MMBOE and that 2P WI CPR reserves for Svenska as of December 31, 2023 are estimated at 22.5 MMBOE. On a pro-forma basis, this results in VAALCO’s year-end 2023 pro-forma SEC net proved reserves totaling 45.6 MMBOE, a 59% increase from its reported yearend 2023 SEC net proved reserves of 28.6 MMBOE. Utilizing the net cash purchase price of $40.2 million, VAALCO paid approximately $2.37 per net proved barrel of reserves.

    CI-40 has a long history of production and significantly de-risked reservoirs. With almost 20 years of production to date, the FPSO is planned to come off station at the start of 2025 for planned maintenance and upgrade work to allow the FPSO to continue to produce through the end of the expected extended field license in 2038. The scope of work for the FPSO upgrade is currently being finalized. Production on Baobab is expected to re-start in 2026 following the FPSO work program. In addition, a fully appraised development drilling program is expected to start in 2026, targeting the significant incremental probable reserve base on the field. VAALCO sees reduced geological risk relating to this drilling program and the joint venture partners have already commenced the ordering of certain long-lead drilling items. Further future drilling phases have not yet been sanctioned, but there is significant incremental potential in both the Baobab field itself, as well as the nearby Kossipo development, which has also been appraised by two wells drilled in 2002 and 2019.

    In addition to the CI-40 license in Côte d’Ivoire, VAALCO currently owns a 21.05% working interest in the early stage Uge discovery in the OML 145 concession in Nigeria alongside partners ExxonMobil (21.05%), Chevron (21.05%), Oando (21.05%) and NPDC (15.80%). There are minimal commitments on this license interest and no drilling or development is currently planned.

    Hedging

    The Company continued to opportunistically hedge a portion of its expected future production to lock in strong cash flow generation to assist in funding its capital and shareholder returns programs. 

    The following includes hedges remaining in place as of the end of the second quarter of 2024:

    Settlement PeriodType of ContractIndex Average Monthly Volumes  Weighted Average Put Price  Weighted Average Call Price 
        (Bbls) a  (per Bbl)  (per Bbl) 
    July 2024 - September 2024CollarsDated Brent  80,000  $65.00  $92.00 
                   

     a) The premium for these options was $4.01 per barrel and was paid in October 2023.

    Settlement PeriodType of ContractIndex Average Monthly Volumes  Weighted Average Put Price 
        (Bbls)  (per Bbl) 
    July 2024 - December 2024Put OptionsDated Brent  125,000  $65.00 


    Settlement PeriodType of ContractIndex Average Monthly Volumes  Weighted Average SWAP Price in CAD 
        (GJ)b  (per GJ) 
    November 2024 - March 2025SwapAECO (7A)  67,000  $2.80 
               

     b) One gigajoule (GJ) equals one billion joules (J). A gigajoule of natural gas is about 25.5 cubic metres at standard conditions.

    2024 Guidance:

    The Company has provided third quarter 2024 guidance and updated its full year 2024 guidance. All of the quarterly and annual guidance is detailed in the tables below.

       FY 2024  Gabon  Egypt  Canada  Côte d'Ivoire 
    Production (BOEPD)WI  23600 - 26500   8300 - 9600   9800 - 10600   2700 - 3200   2800 - 3100 
    Production (BOEPD)NRI  18900 - 21400   7200 - 8300   6700 - 7400   2200 - 2600   2800 - 3100 
    Sales Volume (BOEPD)WI  24300 - 27200   8300 - 9500   9800 - 10600   2700 - 3200   3500 - 3900 
    Sales Volume (BOEPD)NRI  19600 - 22200   7200 - 8300   6700 - 7400   2200 - 2600   3500 - 3900 
    Production Expense (millions)WI & NRI $174.0 - $189.0 MM                 
    Production Expense per BOEWI $18.00 - $20.50                 
    Production Expense per BOENRI $22.00 - $26.00                 
    Offshore Workovers (millions)WI & NRI $1 - $10 MM                 
    Cash G&A (millions)WI & NRI $20.0 - $28.0 MM                 
    CAPEX excluding acquisitions (millions)WI & NRI $115 - $140 MM                 
    DD&A ($/BOE)NRI $16.00 - $20.00                 


       Q3 2024  Gabon  Egypt  Canada  Côte d'Ivoire 
    Production (BOEPD)WI  24900 - 27600   8300 - 9300   9700 - 10700   2700 - 3000   4200 - 4600 
    Production (BOEPD)NRI  20300 - 22800   7200 - 8200   6600 - 7500   2300 - 2500   4200 - 4600 
    Sales Volume (BOEPD)WI  26100 - 28700   7300 - 8000   9700 - 10700   2700 - 3000   6400 - 7000 
    Sales Volume (BOEPD)NRI  21700 - 24000   6400 - 7000   6600 - 7500   2300 - 2500   6400 - 7000 
    Production Expense (millions)WI & NRI $38.5 - $49.0 MM                 
    Production Expense per BOEWI $14.50 - $21.00                 
    Production Expense per BOENRI $17.50 - $25.00                 
    Offshore Workovers (millions)WI & NRI $0 - $0 MM                 
    Cash G&A (millions)WI & NRI $4.5 - $6.5 MM                 
    CAPEX excluding acquisitions (millions)WI & NRI $32 - $54 MM                 
    DD&A ($/BOE)NRI $16.00 - $20.00                 
                         

    Conference Call

    As previously announced, the Company will hold a conference call to discuss its second quarter 2024 financial and operating results tomorrow, Wednesday, August 7, 2024, at 10:00 a.m. Central Time (11:00 a.m. Eastern Time and 4:00 p.m. London Time). Interested parties may participate by dialing (833) 685-0907. Parties in the United Kingdom may participate toll-free by dialing 08082389064 and other international parties may dial (412) 317-5741. Participants should request to be joined to the “VAALCO Energy Second Quarter 2024 Conference Call.” This call will also be webcast on VAALCO’s website at www.vaalco.com. An archived audio replay will be available on VAALCO’s website.

    A “Q2 2024 Supplemental Information” investor deck will be posted to VAALCO’s web site prior to its conference call on August 7, 2024 that includes additional financial and operational information.

    About VAALCO

    VAALCO, founded in 1985 and incorporated under the laws of Delaware, is a Houston, Texas, USA based, independent energy company with a diverse portfolio of production, development and exploration assets across Gabon, Egypt, Côte d'Ivoire, Equatorial Guinea and Canada.

    For Further Information

    VAALCO Energy, Inc. (General and Investor Enquiries)+00 1 713 623 0801
    Website:www.vaalco.com
      
      
    Al Petrie Advisors (US Investor Relations)+00 1 713 543 3422
    Al Petrie / Chris Delange 
      
    Buchanan (UK Financial PR)+44 (0) 207 466 5000
    Ben Romney / Barry ArcherVAALCO@buchanan.uk.com
      

    Forward Looking Statements
    This press release includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”) and Section 21E of the Securities Exchange Act of 1934, as amended, which are intended to be covered by the safe harbors created by those laws and other applicable laws and “forward-looking information” within the meaning of applicable Canadian securities laws. Where a forward-looking statement expresses or implies an expectation or belief as to future events or results, such expectation or belief is expressed in good faith and believed to have a reasonable basis. All statements other than statements of historical fact may be forward-looking statements. The words “anticipate,” “believe,” “estimate,” “expect,” “intend,” “forecast,” “outlook,” “aim,” “target,” “will,” “could,” “should,” “may,” “likely,” “plan” and “probably” or similar words may identify forward-looking statements, but the absence of these words does not mean that a statement is not forward-looking. Forward-looking statements in this press release include, but are not limited to, statements relating to (i) estimates of future drilling, production, sales and costs of acquiring crude oil, natural gas and natural gas liquids; (ii) expectations regarding VAALCO's ability to effectively integrate assets and properties it has acquired as a result of the Svenska acquisition into its operations; (iii) expectations regarding future exploration and the development, growth and potential of VAALCO’s operations, project pipeline and investments, and schedule and anticipated benefits to be derived therefrom; (iv) expectations regarding future acquisitions, investments or divestitures; (v) expectations of future dividends; (vi) expectations of future balance sheet strength; and (vii) expectations of future equity and enterprise value.

    Such forward-looking statements are subject to risks, uncertainties and other factors, which could cause actual results to differ materially from future results expressed, projected or implied by the forward-looking statements. These risks and uncertainties include, but are not limited to: risks relating to any unforeseen liabilities of VAALCO; the ability to generate cash flows that, along with cash on hand, will be sufficient to support operations and cash requirements; risks relating to the timing and costs of completion for scheduled maintenance of the FPSO servicing the Baobab field; and the risks described under the caption “Risk Factors” in VAALCO’s 2023 Annual Report on Form 10-K filed with the SEC on March 15, 2024 and subsequent Quarterly Reports on Form 10-Q filed with the SEC. 

    Dividends beyond the third quarter of 2024 have not yet been approved or declared by the Board of Directors for VAALCO. The declaration and payment of future dividends remains at the discretion of the Board and will be determined based on VAALCO’s financial results, balance sheet strength, cash and liquidity requirements, future prospects, crude oil and natural gas prices, and other factors deemed relevant by the Board. The Board reserves all powers related to the declaration and payment of dividends. Consequently, in determining the dividend to be declared and paid on VAALCO common stock, the Board may revise or terminate the payment level at any time without prior notice. 

    WI CPR Reserves

    WI CPR reserves represent proved (1P) and proved plus probable (2P) estimates as reported by Petroleum Development Consultants Limited and prepared in accordance with the definitions and guidelines set forth in the 2018 Petroleum Resources Management Systems approved by the Society of Petroleum Engineers. The SEC definitions of proved and probable reserves are different from the definitions contained in the 2018 Petroleum Resources Management Systems approved by the Society of Petroleum Engineers. As a result, 1P and 2P WI CPR reserves may not be comparable to United States standards. The SEC requires United States oil and gas reporting companies, in their filings with the SEC, to disclose only proved reserves after the deduction of royalties and production due to others but permits the optional disclosure of probable and possible reserves in accordance with SEC definitions.

    1P and 2P WI CPR reserves, as disclosed herein, may differ from the SEC definitions of proved and probable reserves because:

    • Pricing for SEC is the average closing price on the first trading day of each month for the prior year which is then held flat in the future, while the 1P and 2P WI CPR pricing assumption was $79.79 per barrel of oil beginning in 2024, $69.79 in 2025, and inflating 2% thereafter;
    • Lease operating expenses are typically not escalated under the SEC’s rules, while for the WI CPR reserves estimates, they are escalated at 2% annually beginning in 2024.

     

    Management uses 1P and 2P WI CPR reserves as a measurement of operating performance because it assists management in strategic planning, budgeting and economic evaluations and in comparing the operating performance of Svenska to other companies. Management believes that the presentation of 1P and 2P WI CPR reserves is useful to its international investors, particularly those that invest in companies trading on the London Stock Exchange, in order to better compare reserve information to other London Stock Exchange-traded companies that report similar measures. However, 1P and 2P WI CPR reserves should not be used as a substitute for proved reserves calculated in accordance with the definitions prescribed by the SEC. In evaluating VAALCO’s business, investors should rely on VAALCO’s SEC proved reserves and consider 1P and 2P WI CPR reserves only supplementally.

    Other Oil and Gas Advisories

    Investors are cautioned when viewing BOEs in isolation. The Svenska reserves estimates as of October 1, 2023 were calculated using a BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 MCF: 1 Bbl). The Svenska reserves estimates as of December 31, 2023 were calculated using a BOE conversion ratio of five thousand eight hundred cubic feet of natural gas to one barrel of oil equivalent (5.8 MCF: 1 Bbl). BOE conversion ratio is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalencies described above, utilizing such equivalencies may be incomplete as an indication of value.

    Inside Information

    This announcement contains inside information as defined in Regulation (EU) No. 596/2014 on market abuse which is part of UK domestic law by virtue of the European Union (Withdrawal) Act 2018 (“MAR”) and is made in accordance with the Company’s obligations under article 17 of MAR. The person responsible for arranging the release of this announcement on behalf of VAALCO is Matthew Powers, Corporate Secretary of VAALCO.


    VAALCO ENERGY, INC AND SUBSIDIARIES
    Consolidated Balance Sheets (Unaudited)

      As of June 30, 2024  As of December 31, 2023 
    ASSETS (in thousands) 
    Current assets:        
    Cash and cash equivalents $62,890  $121,001 
    Restricted cash  139   114 
    Receivables:        
    Trade, net of allowances for credit loss and other of $0.2 and $0.5 million, respectively  64,934   44,888 
    Accounts with joint venture owners, net of allowance for credit losses of $0.8 and $0.8 million, respectively  721   1,814 
    Egypt receivables and other, net of allowances for credit loss and other of $11.2 and $4.6 million, respectively  40,628   45,942 
    Crude oil inventory  8,586   1,948 
    Prepayments and other  17,509   12,434 
    Total current assets  195,407   228,141 
             
    Crude oil, natural gas and NGLs properties and equipment, net  548,415   459,786 
    Other noncurrent assets:        
    Restricted cash  8,788   1,795 
    Value added tax and other receivables, net of allowances for credit loss and other of $0.0 and $0.0 million, respectively  6,109   4,214 
    Right of use operating lease assets  580   2,378 
    Right of use finance lease assets  86,342   89,962 
    Deferred tax assets  64,859   29,242 
    Abandonment funding  6,268   6,268 
    Other long-term assets  1,216   1,430 
    Total assets $917,984  $823,216 
    LIABILITIES AND SHAREHOLDERS' EQUITY        
    Current liabilities:        
    Accounts payable $22,605  $22,152 
    Accounts with joint venture owners  896   5,990 
    Accrued liabilities and other  116,006   67,597 
    Operating lease liabilities - current portion  574   2,396 
    Finance lease liabilities - current portion  11,751   10,079 
    Foreign income taxes payable  12,361   19,261 
    Total current liabilities  164,193   127,475 
    Asset retirement obligations  65,373   47,343 
    Operating lease liabilities - net of current portion  -   33 
    Finance lease liabilities - net of current portion  74,388   78,293 
    Deferred tax liabilities  111,535   73,581 
    Other long-term liabilities  8,847   17,709 
    Total liabilities  424,336   344,434 
    Commitments and contingencies        
    Shareholders’ equity:        
    Preferred stock, $25 par value; 500,000 shares authorized, none issued  —   — 
    Common stock, $0.10 par value; 160,000,000 shares authorized, 122,304,124 and 121,397,553 shares issued, 103,743,163 and 104,346,233 shares outstanding, respectively  12,230   12,140 
    Additional paid-in capital  359,803   357,498 
    Accumulated other comprehensive income  (642)  2,880 
    Less treasury stock, 18,560,961 and 17,051,320 shares, respectively, at cost  (78,024)  (71,222)
    Retained earnings  200,281   177,486 
    Total shareholders' equity  493,648   478,782 
    Total liabilities and shareholders' equity $917,984  $823,216 
     


    VAALCO ENERGY, INC AND SUBSIDIARIES
    Consolidated Statements of Operations (Unaudited)

      Three Months Ended  Six Months Ended 
      June 30, 2024  June 30, 2023  March 31, 2024  June 30, 2024  June 30, 2023 
      (in thousands except per share amounts) 
    Revenues:                    
    Crude oil, natural gas and natural gas liquids sales $116,778  $109,240  $100,155  $216,933  $189,643 
    Operating costs and expenses:                    
    Production expense  52,446   38,604   32,089   84,535   66,804 
    FPSO demobilization and other costs  —   5,647   —   -   5,647 
    Exploration expense  —   57   48   48   65 
    Depreciation, depletion and amortization  33,132   38,003   25,824   58,956   62,420 
    General and administrative expense  7,591   5,395   6,710   14,301   10,619 
    Credit losses and other  3,341   680   1,812   5,153   1,615 
    Total operating costs and expenses  96,510   88,386   66,483   162,993   147,170 
    Other operating income (expense), net  132   (303)  (166)  (34)  (303)
    Operating income  20,400   20,551   33,506   53,906   42,170 
    Other income (expense):                    
    Derivative instruments gain (loss), net  257   31   (847)  (590)  52 
    Interest expense, net  (1,117)  (1,703)  (935)  (2,052)  (3,949)
    Bargain purchase gain  19,898   —   —   19,898   — 
    Other income (expense), net  (1,984)  (539)  (1,800)  (3,784)  (1,692)
    Total other income (expense), net  17,054   (2,211)  (3,582)  13,472   (5,589)
    Income before income taxes  37,454   18,340   29,924   67,378   36,581 
    Income tax expense  9,303   11,588   22,238   31,541   26,359 
    Net income $28,151  $6,752  $7,686  $35,837  $10,222 
    Other comprehensive income (loss)                    
    Currency translation adjustments  (1,068)  2,006   (2,454)  (3,522)  1,881 
    Comprehensive income $27,083  $8,758  $5,232  $32,315  $12,103 
                         
    Basic net income (loss) per share:                    
    Net income (loss) per share $0.27  $0.06  $0.07  $0.34  $0.10 
    Basic weighted average shares outstanding  103,528   106,965   103,659   103,594   107,175 
    Diluted net income (loss) per share:                    
    Net income (loss) per share $0.27  $0.06  $0.07  $0.34  $0.09 
    Diluted weighted average shares outstanding  103,676   107,613   104,541   103,677   108,050 
                         


    VAALCO ENERGY, INC AND SUBSIDIARIES
    Consolidated Statements of Cash Flows (Unaudited)

      Six Months Ended June 30, 
      2024  2023 
      (in thousands) 
    CASH FLOWS FROM OPERATING ACTIVITIES:        
    Net income $35,837  $10,222 
    Adjustments to reconcile net income to net cash provided by operating activities:        
    Depreciation, depletion and amortization  58,956   62,420 
    Bargain purchase gain  (19,898)  1,412 
    Deferred taxes  (7,407)  1,618 
    Unrealized foreign exchange loss  (196)  313 
    Stock-based compensation  1,883   1,254 
    Cash settlements paid on exercised stock appreciation rights  (154)  (233)
    Derivative instruments (gain) loss, net  590   (52)
    Cash settlements paid on matured derivative contracts, net  (33)  (63)
    Cash settlements paid on asset retirement obligations  (82)  (374)
    Credit losses and other  5,474   1,615 
    Other operating loss, net  34   62 
    Operational expenses associated with equipment and other  1,029   (1,196)
    Change in operating assets and liabilities:        
    Trade, net  (20,046)  (5,208)
    Accounts with joint venture owners, net  (4,603)  21,746 
    Egypt receivables and other, net  1,306   (1,868)
    Crude oil inventory  8,343   (7,465)
    Prepayments and other  (3,829)  (69)
    Value added tax and other receivables  (2,007)  (2,302)
    Other long-term assets  699   1,508 
    Accounts payable  (727)  (10,897)
    Foreign income taxes receivable/(payable)  (6,563)  15,344 
    Deferred tax liability  —   (3,081)
    Accrued liabilities and other  (27,211)  (7,137)
    Net cash provided by (used in) operating activities  21,395   77,569 
    CASH FLOWS FROM INVESTING ACTIVITIES:     
    Property and equipment expenditures  (49,099)  (54,832)
    Cash paid in business combination  (40,166)  - 
    Cash received in business combination  40,578   - 
    Net cash provided by (used in) investing activities  (48,687)  (54,832)
    CASH FLOWS FROM FINANCING ACTIVITIES:     
    Proceeds from the issuances of common stock  447   382 
    Dividend distribution  (13,042)  (13,452)
    Treasury shares  (6,802)  (11,403)
    Deferred financing costs  (1)  (30)
    Payments of finance lease  (4,169)  (3,379)
    Net cash provided by (used in) in financing activities  (23,567)  (27,882)
    Effects of exchange rate changes on cash  (234)  (285)
    NET CHANGE IN CASH, CASH EQUIVALENTS AND RESTRICTED CASH  (51,093)  (5,430)
    CASH, CASH EQUIVALENTS AND RESTRICTED CASH AT BEGINNING OF PERIOD  129,178   59,776 
    CASH, CASH EQUIVALENTS AND RESTRICTED CASH AT END OF PERIOD $78,085  $54,346 
     


    VAALCO ENERGY, INC AND SUBSIDIARIES
    Selected Financial and Operating Statistics
    (Unaudited)

      Three Months Ended  Six Months Ended 
      June 30, 2024  June 30, 2023  March 31, 2024  June 30, 2024  June 30, 2023 
    NRI SALES DATA                    
    Crude oil, natural gas and natural gas liquids sales (MBOE)  1,764   1,803   1,490   3,254   3,027 
    Average daily sales volumes (BOE)  19,386   19,813   16,374   17,881   16,724 
                         
    WI PRODUCTION DATA                    
    Etame Crude oil (MBbl)  780   934   819   1,599   1,876 
    Egypt Crude oil (MBbl)  953   1,054   950   1,903   1,957 
    Canada Crude Oil (MBbl)  130   123   61   191   216 
    Canada Natural Gas (Mcf)  423   442   469   892   857 
    Canada Natural Gas Liquid (MBOE)  76   78   76   152   155 
    Canada Crude oil, natural gas and natural gas liquids (MBOE)  277   275   215   492   514 
    Côte d'Ivoire Crude oil (MBbl)  303   —   —   303   — 
    Total Crude oil, natural gas and natural gas liquids production (MBOE)  2,313   2,263   1,984   4,297   4,347 
    Gabon Average daily production volumes (BOEPD)  8,566   10,262   9,001   8,784   10,364 
    Egypt Average daily production volumes (BOEPD)  10,474   11,579   10,440   10,457   10,810 
    Canada Average daily production volumes (BOEPD)  3,041   3,021   2,363   2,702   2,839 
    Côte d'Ivoire Average daily production volumes (BOEPD)  3,329   —   —   1,664   — 
    Average daily production volumes (BOEPD)  25,411   24,863   21,807   23,607   24,013 
                         
    NRI PRODUCTION DATA                    
    Etame Crude oil (MBbl)  678   812   713   1,391   1,632 
    Egypt Crude oil (MBbl)  643   726   641   1,284   1,342 
    Canada Crude Oil (MBbl)  117   113   51   169   195 
    Canada Natural Gas (Mcf)  381   406   392   787   773 
    Canada Natural Gas Liquid (MBOE)  69   72   63   134   140 
    Canada Crude oil, natural gas and natural gas liquids (MBOE)  250   253   179   429   464 
    Côte d'Ivoire Crude oil (MBbl)  303   —   —   303   — 
    Total Crude oil, natural gas and natural gas liquids production (MBOE)  1,873   1,791   1,533   3,406   3,438 
    Gabon Average daily production volumes (BOEPD)  7,451   8,923   7,835   7,642   9,017 
    Egypt Average daily production volumes (BOEPD)  7,066   7,978   7,044   7,053   7,414 
    Canada Average daily production volumes (BOEPD)  2,742   2,776   1,971   2,356   2,563 
    Côte d'Ivoire Average daily production volumes (BOEPD)  3,329   —   —   1,664   — 
    Average daily production volumes (BOEPD)  20,588   19,676   16,848   18,716   18,994 
                         
    AVERAGE SALES PRICES:                    
    Crude oil, natural gas and natural gas liquids sales (per BOE) - WI basis $70.92  $64.67  $69.62  $70.31  $65.41 
                         
    Crude oil, natural gas and natural gas liquids sales (per BOE) - NRI basis $66.05  $59.37  $66.43  $66.22  $61.92 
    Crude oil, natural gas and natural gas liquids sales (Per BOE including realized commodity derivatives) $66.03  $59.34  $66.41  $66.21  $61.90 
                         
                         
    COSTS AND EXPENSES (Per BOE of sales):                    
    Production expense $29.74  $21.41  $21.54  $25.98  $22.07 
    Production expense, excluding offshore workovers and stock compensation*  29.68   21.51   21.56   25.96   22.48 
    Depreciation, depletion and amortization  18.78   21.08   17.33   18.12   20.62 
    General and administrative expense**  4.30   2.99   4.50   4.39   3.51 
    Property and equipment expenditures, cash basis (in thousands) $32,481  $27,132  $16,618  $49,099  $54,832 
                         

    *Offshore workover costs excluded from the three months ended June 30, 2024 and 2023 and March 31, 2024 are $(0.1) million, $(0.2) million and $(0.1) million, respectively.
    *Stock compensation associated with production expense excluded from the three months ended June 30, 2024 and 2023 and March 31, 2024 are immaterial.
    **General and administrative expenses include $0.51, $0.33 and $0.60 per barrel of oil related to stock-based compensation expense in the three months ended June 30, 2024 and 2023 and March 31, 2024, respectively.

    NON-GAAP FINANCIAL MEASURES

    Management uses Adjusted Net Income to evaluate operating and financial performance and believes the measure is useful to investors because it eliminates the impact of certain non-cash and/or other items that management does not consider to be indicative of the Company’s performance from period to period. Management also believes this non-GAAP measure is useful to investors to evaluate and compare the Company’s operating and financial performance across periods, as well as facilitating comparisons to others in the Company’s industry. Adjusted Net Income is a non-GAAP financial measure and as used herein represents net income before discontinued operations, impairment of proved crude oil and natural gas properties, deferred income tax expense, unrealized commodity derivative loss, gain on the Sasol Acquisition and non-cash and other items.

    Adjusted EBITDAX is a supplemental non-GAAP financial measure used by VAALCO’s management and by external users of the Company’s financial statements, such as industry analysts, lenders, rating agencies, investors and others who follow the industry, as an indicator of the Company’s ability to internally fund exploration and development activities and to service or incur additional debt. Adjusted EBITDAX is a non-GAAP financial measure and as used herein represents net income before discontinued operations, interest income net, income tax expense, depletion, depreciation and amortization, exploration expense, impairment of proved crude oil and natural gas properties, non-cash and other items including stock compensation expense, gain on the Sasol Acquisition and unrealized commodity derivative loss.

    Management uses Adjusted Working Capital as a transition tool to assess the working capital position of the Company’s continuing operations excluding leasing obligations because it eliminates the impact of discontinued operations as well as the impact of lease liabilities. Under the lease accounting standards, lease liabilities related to assets used in joint operations include both the Company’s share of expenditures as well as the share of lease expenditures which its non-operator joint venture owners’ will be obligated to pay under joint operating agreements. Adjusted Working Capital is a non-GAAP financial measure and as used herein represents working capital excluding working capital attributable to discontinued operations and current liabilities associated with lease obligations.

    Management uses Free Cash Flow to evaluate financial performance and to determine the total amount of cash over a specified period available to be used in connection with returning cash to shareholders, and believes the measure is useful to investors because it provides the total amount of net cash available for returning cash to shareholders by adding cash generated from operating activities, subtracting amounts used in financing and investing activities, and adding back amounts used for dividend payments and stock repurchases. Free Cash Flow is a non-GAAP financial measure and as used herein represents net change in cash, cash equivalents and restricted cash and adds the amounts paid under dividend distributions and share repurchases over a specified period.

    Free Cash Flow has significant limitations, including that it does not represent residual cash flows available for discretionary purposes and should not be used as a substitute for cash flow measures prepared in accordance with GAAP. Free Cash Flow should not be considered as a substitute for cashflows from operating activities before discontinued operations or any other liquidity measure presented in accordance with GAAP. Free Cash Flow may vary among other companies. Therefore, the Company’s Free Cash Flow may not be comparable to similarly titled measures used by other companies.

    Adjusted EBITDAX and Adjusted Net Income have significant limitations, including that they do not reflect the Company’s cash requirements for capital expenditures, contractual commitments, working capital or debt service. Adjusted EBITDAX, Adjusted Net Income, Adjusted Working Capital and Free Cash Flow should not be considered as substitutes for net income (loss), operating income (loss), cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Adjusted EBITDAX and Adjusted Net Income exclude some, but not all, items that affect net income (loss) and operating income (loss) and these measures may vary among other companies. Therefore, the Company’s Adjusted EBITDAX, Adjusted Net Income, Adjusted Working Capital and Free Cash Flow may not be comparable to similarly titled measures used by other companies.

    The tables below reconcile the most directly comparable GAAP financial measures to Adjusted Net Income, Adjusted EBITDAX, Adjusted Working Capital and Free Cash Flow.

    VAALCO ENERGY, INC AND SUBSIDIARIES
    Reconciliations of Non-GAAP Financial Measures
    (Unaudited)
    (in thousands)

      Three Months Ended  Six Months Ended 
    Reconciliation of Net Income to Adjusted Net Income June 30, 2024  June 30, 2023  March 31, 2024  June 30, 2024  June 30, 2023 
    Net income $28,151  $6,752  $7,686  $35,837  $10,222 
    Adjustment for discrete items:                    
    Unrealized derivative instruments loss (gain)  (266)  (35)  823   557   (115)
    (Gain) /adjustment of acquisition price, net  (19,898)  1,412   —   (19,898)  1,412 
    FPSO demobilization  —   5,647   —   —   5,647 
    Deferred income tax expense (benefit)  (2,021)  (813)  (3,441)  (5,462)  1,658 
    Non-cash purchase price adjustment  14,981   —   —   14,981   — 
    Transaction costs related to acquisition  1,762   —   1,313   3,075   303 
    Other operating (income) expense, net  (132)  303   166   —   — 
    Adjusted Net Income $22,577  $13,266  $6,547  $29,090  $19,127 
                         
    Diluted Adjusted Net Income per Share $0.22  $0.12  $0.06  $0.28  $0.18 
    Diluted weighted average shares outstanding (1)  103,676   107,613   104,541   103,677   108,050 
                         

    (1) No adjustments to weighted average shares outstanding

      Three Months Ended  Six Months Ended 
    Reconciliation of Net Income to Adjusted EBITDAX June 30, 2024  June 30, 2023  March 31, 2024  June 30, 2024  June 30, 2023 
    Net income $28,151  $6,752  $7,686  $35,837  $10,222 
    Add back:                    
    Interest expense (income), net  1,117   1,703   935   2,052   3,949 
    Income tax expense (benefit)  9,303   11,588   22,238   31,541   26,359 
    Depreciation, depletion and amortization  33,132   38,003   25,824   58,956   62,420 
    Exploration expense  —   57   48   48   65 
    FPSO demobilization  —   5,647   —   —   5,647 
    Non-cash or unusual items:                    
    Stock-based compensation  984   605   899   1,883   1,254 
    Unrealized derivative instruments loss (gain)  (266)  (35)  823   557   (115)
    Bargain purchase gain  (19,898)  —   —   (19,898)  1,412 
    Other operating (income) expense, net  (132)  303   166   34   303 
    Non-cash purchase price adjustment  14,981   —   —   14,981   — 
    Transaction costs related to acquisition  1,762   —   1,313   3,075   — 
    Credit losses and other  3,341   680   1,812   5,153   1,615 
    Adjusted EBITDAX $72,475  $65,303  $61,744  $134,219  $113,131 
     


    VAALCO ENERGY, INC AND SUBSIDIARIES 
    Reconciliations of Non-GAAP Financial Measures
    (Unaudited)
    (in thousands)

    Reconciliation of Working Capital to Adjusted Working Capital As of June 30, 2024  As of December 31, 2023  Change 
    Current assets $195,407  $199,367  $(3,960)
    Current liabilities  (164,193)  (153,703)  (10,490)
    Working capital  31,214   45,664   (14,450)
    Add: lease liabilities - current portion  12,325   9,351   2,974 
    Add: current liabilities - discontinued operations  —   673   (673)
    Adjusted Working Capital $43,539  $55,688  $(11,476)


      Six Months Ended June 30, 2024 
    Reconciliation of Free Cash Flow    
    Net cash provided by Operating activities $21,395 
    Net cash used in Investing activities  (49,099)
    Net cash used in Financing activities  (23,567)
    Effects of exchange rate changes on cash  (234)
    Total net cash change  (51,505)
         
    Add back shareholder cash out:    
    Dividends paid  13,042 
    Stock buyback  5,502 
    Total cash returned to shareholders  18,544 
         
    Free Cash Flow $(32,961)
         

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