Exhibit 1
Fourth and Full Quarter Year 2022 Earnings Webcast February 24, 2023
About projections and forward-looking statements Additional information about Vista Energy, S.A.B. de C.V., a sociedad anónima bursátil de capital variable organized under the laws of Mexico (the “Company” or “Vista”) can be found in the “Investors” section on the website at www.vistaoilandgas.com. This presentation does not constitute an offer to sell or the solicitation of any offer to buy any securities of the Company, in any jurisdiction. Securities may not be offered or sold in the United States absent registration with the U.S. Securities Exchange Commission (“SEC”), the Mexican National Securities Registry held by the Mexican National Banking and Securities Commission (“CNBV”) or an exemption from such registrations. This presentation does not contain all the Company’s financial information. As a result, investors should read this presentation in conjunction with the Company’s consolidated financial statements and other financial information available on the Company’s website. All the amounts contained herein are unaudited. Rounding rounded figures, amounts but and on percentages: the basis of such Certain amounts prior and topercentages rounding. For included this reason, in this certain presentation percentage haveamounts been rounded in thisfor presentation ease of presentation may vary.from Percentage those obtained figures included by performing in this presentation the same calculations have not in using all cases the figures been calculated in the financial on the statements basis of such . In This addition, presentation certain other contains amounts certain that metrics appear that in this do not presentation have standardized may not sum meanings due toor rounding standard . methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods. No reliance may be placed for any purpose whatsoever on the information contained in this document or on its completeness. Certain information contained in this presentation has been obtained from published sources, which may not have been independently verified or audited. No representation or warranty, express or implied, is given or will be given by or on behalf of the Company, or any of its affiliates (within the meaning of Rule 405 under the Act, “Affiliates”), members, directors, officers or employees or any other person (the “Related Parties”) as to the accuracy, completeness or fairness of the information or opinions contained in this presentation or any other material discussed verbally, and any reliance you place on them will be at your sole risk. Any opinions presented herein are based on general information gathered at the time of writing and are subject to change without notice. In addition, no responsibility, obligation or liability (whether direct or indirect, in contract, tort or otherwise) is or will be accepted by the Company or any of its Related Parties in relation to such information or opinions or any other matter in connection with this presentation or its contents or otherwise arising in connection therewith. This presentation also includes certain non-IFRS (International Financial Reporting Standards) financial measures which have not been subject to a financial audit for any period. The information and opinions contained in this presentation are provided as at the Thisdate presentation of this presentation includes “forward and are-subject lookingto statements” verification,concerning completionthe andfuture change . The without words notice such . as “believes,” “thinks,” “forecasts,” “expects,” “anticipates,” “intends,” “should,” “seeks,” “estimates,” “future” or similar expressions are included with the estimates intention of on identifying which forward statements -looking about statements the future are . For based theare avoidance believedof by doubt, our management any projection, to be guidance reasonable or similar and based estimation on the about best currently the future available or future information, results, performance such forward or achievements -looking statements is a forward are based -looking onstatement assumptions . Although that arethe inherently assumptions subject and to significant uncertainties and contingencies, many of which are beyond our control. There will be differences between actual and projected results, and actual results may be materially greater or materially less than those contained in the projections. Projections related to production results as well as costs estimations – including Vista’s anticipated performance and guidance for 2023 included in this presentation – are based on information as of the date of this presentation and reflect numerous assumptions including assumptions with respect to type curves for new well designs and certain frac spacing expectations, all of which are difficult to predict and many of which are beyond our control and remain subject to several risks and uncertainties. The inclusion of the projected financial information in this document should not be regarded as an indication that we or our management considered or consider the projections to be a reliable prediction of future events. As such, no representation can be made as to the attainability of projections, guidances or other estimations of future results, performance or achievements. We have not warranted the accuracy, reliability, appropriateness or completeness of the projections to anyone. Neither our management nor any of our representatives has made or makes any representation to any person regarding our future performance compared to the information contained in the projections, and none of them intends to or undertakes any obligation to update or otherwise revise the projections to reflect circumstances existing after the date when made These or to reflect expectations the occurrence and projections of futureare events subject in the to event significant that any known or all and ofunknown the assumptions risks and underlying uncertainties the projections which mayare cause shown ourto actual be inresults, error. We performance may or may ornot achievements, refer back toor these industry projections results,in toour befuture materially periodic different reports from filed any under expected the Exchange or projected Act. results, performance or achievements expressed or implied by such forward-looking statements. Many important factors could cause our actual results, performance or achievements to differ materially from those expressed or implied in our forward-conditions looking statements, in Argentina, including, Mexico among and inother other things: countries uncertainties in which we relating operate; to future changes government in law, rules, concessions regulations andand exploration interpretations permits;and adverse enforcements outcomesthereto in litigation applicable that may to the arise Argentine in the future; and Mexican general political, energy sectors, economic, including social, demographic changes to the and regulatory business environment in which we operate and changes to programs established to promote investments in the energy industry; any unexpected increases in financing costs or an inability to obtain financing and/or additional capital pursuant to attractive terms; any changes in the capital markets in general that may affect the policies or attitude in Argentina and/or Mexico, and/or Argentine and Mexican companies with respect to financings extended to or investments made in Argentina and Mexico or Argentine and Mexican companies; fines or other penalties and claims by the authorities and/or customers; any future restrictions on the ability to exchange Mexican or Argentine Pesos into foreign currencies or to transfer funds abroad; the revocation or amendment of our respective concession agreements by the granting authority; our ability to implement our capital expenditures plans or business strategy, including our ability to obtain financing when necessary and on reasonable terms; government intervention, including measures that result in changes to the Argentine and Mexican, labor markets, exchange markets or tax systems; continued and/or higher rates of inflation and fluctuations in exchange rates, including the devaluation of the Mexican Peso or Argentine Peso; any force majeure events, or fluctuations or reductions in the value of Argentine public debt; changes to the demand for energy; uncertainties relating to the effects of the Covid-19 outbreak; environmental, health and safety regulations and industry standards that are becoming more stringent; energy markets, including the timing and extent of changes and volatility in commodity prices, and the impact of any protracted or material reduction in oil prices from historical employees; averages; changes the ability in the of our regulation directors ofand theofficers energy to and identify oil andan gas adequate sector in number Argentina of potential and Mexico, acquisition and throughout opportunities; Latinour America; expectations our relationship with respect with to our the employees performance and of our ourability recently to retain acquired key businesses; members of our our expectations senior management for futureand production, key technical costs and crude oil prices used in our projections; increased market competition in the energy sectors in Argentina and Mexico; and potential changes in regulation and free trade agreements as a result of U.S., Mexican or other Latin American political conditions. or Forward other—factors looking . In statements light of these speak limitations, only as of undue the date reliance on which should they notwere be placed made, on and forward we undertake -looking statements no obligation contained to release inpublicly this presentation any updates . Further or revisions information to anyconcerning forward-looking risks and statements uncertainties contained associated herein with because theseof forward new information, -looking statements future events and Vista’s business can be found in Vista’s public disclosures filed on EDGAR (www.sec.gov) or at the web page of the Mexican Stock Exchange (www.bmv.com.mx). You should not take any statement regarding past trends or activities as a representation that the trends or activities will continue in the future. Accordingly, you should not put undue reliance on these statements. This presentation is not intended to constitute and should not be construed as investment advice. Other Information. Vista routinely posts important information for investors in the Investor Relations support section on its website, www.vistaenergy.com. From time to time, Vista may use its website as a channel of distribution of material information. Accordingly, investors should monitor Vista’s Investor Relations website, in addition to following Vista’s press releases, SEC filings, public conference calls and webcasts.
Consistently delivering strong operational and financial performance Q4 2022—HIGHLIGHTS Production (1) Oil Production Revenues Lifting Cost (2) CAPEX (3) 54.7 Mboe/d 45.7 Mbbl/d 308 $MM 7.2 $/boe 145 $MM +33% y-o-y +41% y-o-y +57% y-o-y (11)% y-o-y +49% y-o-y Adj. EBITDA (4) Free Cash Flow (5) Net Leverage Ratio Adj. Net Income (6) Adj. EPS (7) 202 $MM 57 $MM 0.4 x 171 $MM 2.0 $/sh +73% y-o-y (9)% y-o-y (49)% y-o-y +383% y-o-y ~5x y-o-y (1) Includes natural gas liquids (NGL) and excludes flared gas, injected gas and gas consumed in operations + Impairment of long-lived assets + Other adjustments (2) Lifting cost includes production, transportation, treatment and field support services; excludes crude (5) Free cash flow = Operating activities cash flow + Investing activities cash flow stock fluctuations, depreciation, royalties, direct taxes, commercial, exploration and G&A costs (6) Adjusted net income/loss = Net profit/loss + Deferred Income Tax + Changes in the fair value of (3) Property, Adj. EBITDA plant = Net and profit equipment for the additions period + Income tax expense + Financial warrants + Impairment of long-lived assets (4) income (Expense), net + (7) Adj. EPS = Adj. Net Income divided by weighted average number of ordinary shares Depreciation, depletion and amortization + Restructuring and Reorganization expenses
Production growth driven by solid performance in Vaca Muerta Production growth driven by the tie-in of 4-well pad AF-3 in Aguada Federal and 4-well pad BPO-14 in Bajada del Palo Oeste Total shale oil production was 36.2 Mbbl/d, representing 79% of total oil production (1) LPG production in Q4 2022 totaled 460 boe/d, compared to 462 boe/d in Q3 2022 and 524 boe/d in Q4 2021
Vaca Muerta development update BAJADA DEL PALO OESTE—Core development Solid performance to date, with 60 wells tied-in and producing on average 3% above BPO type curve for the first 360 days (1) Completed and tied-in 5-well pad BPO-15 in Dec-22 (3 wells landed in La Cocina, 2 in Orgánico) Started drilling 4-well pad BPO-16 AGUADA FEDERAL—Core development extension Q4-22 production of 5.8 Mboe/d driven by the tie-in of 6 wells in pads AF-2 and AF-3 (tied-in during Oct-22) Finished drilling 4-well pad AF-4 in early Feb-23. Landed 2 wells in La Cocina, 1 in Orgánico and 1 in Middle Carbonate. Planning to complete and tie-in before the end of Q1-23 BAJADA DEL PALO ESTE—Ongoing pilot Drilled 1 well in BPE-3. Completed and tied-in in Feb-23 Drilling 2 wells in pad BPE-2. Planning to tie-in in Apr-23 All wells landed in La Cocina Will have fulfilled capex commitments with this activity AGUILA MORA—Ongoing pilot Completed first 2-well pad in Jan-23. Landed 1 well in La Cocina and 1 well in Middle Carbonate Planning to tie-in in Apr-23 upon completion of temporary production facilities construction
Strong y-o-y revenue growth REVENUES AVERAGE CRUDE OIL PRICE AVERAGE NATURAL GAS PRICE $MM $/bbl $/MMBtu +65% +57% +14% 333.6 4.4 4.5 308.1 76.6 60.6 68.9 196.0 2.7 53% 55% 36% Q4-21 Q3-22 Q4-22 Q4-21 Q3-22 Q4-22 Q4-21 Q3-22 Q4-22 Total Revenues % of export in total revenues Strong increase y-o-y, driven by Realized oil prices of 67.2 $/bbl (1) Interannual increase driven by 41% boost in oil production and 14% in the domestic market and 74.1 sales to industrial customers at improvement in realized oil prices $/bbl (2) in the export market 3.0 $/MMBtu, and exports to Oil revenues reflect inventory build- Exported 2.2 MMbbl (23.4 Mbbl/d) Chile at 8.8 $/MMBtu up of 238 Mbbl (2.6 Mbbl/d) during of crude oil, representing 52% of Q4-22 total oil sales volumes and 56% of Second straight quarter with total oil revenues exports above 50% of revenues (1) Does not include trucking transportation cost from sales point to refinery, total realized oil price net of this cost is 63.3 $/bbl (2) Net of export tax. Export price before export tax was 80.0 $/bbl in Q4-22
Continued to achieve cost efficiencies LIFTING COST (1) LIFTING COST PER BOE (1) $MM $/boe +19% (11)% 8.0 34.8 36.1 7.5 30.3 7.2 54.7 50.7 41.1 Q4-21 Q3-22 Q4-22 Q4-21 Q3-22 Q4-22 Lifting cost per boe Total production (Mboe/d) Implemented tactical cost-saving initiatives to contain the impact of real appreciation of the Argentine Peso Continued diluting fixed costs through incremental production volumes (1) Lifting cost includes production, transportation, treatment and field support services; excludes crude stock fluctuations, depreciation, royalties, direct taxes, commercial, exploration and G&A costs
Robust y-o-y adjusted EBITDA growth ADJ. EBITDA (1) ADJ. EBITDA MARGIN NETBACK (2) $MM % $/boe 73% +6p.p. +30% 233.7 70% 50.1 201.7 65% 59% 40.1 30.8 116.5 76.6 68.9 60.6 Q4-21 Q3-22 Q4-22 Q4-21 Q3-22 Q4-22 Q4-21 Q3-22 Q4-22 Adj. EBITDA margin Realized crude oil price ($/bbl) Adj. EBITDA y-o-y increase driven by strong revenue growth and lower lifting cost Sequential decrease in Adj. EBITDA driven by lower oil prices and oil inventory build-up Netback increased 30% y-o-y, driven by higher realized prices and increase in oil mix (1) Adj. EBITDA = Net (loss) / profit for the period + Income tax (expense) / benefit + Financial results, net + Depreciation + Restructuring and Reorganization expenses + Impairment of long-lived assets + Other adjustments (2) Netback = Adj. EBITDA / Total production
Another positive free cash flow quarter 9 FREE CASH FLOW (1) DEBT MATURITIES SCHEDULE $MM $MM Cross border (3) Local 244 62.8 57.2 160 44.4 138 114 76 45 Q4-21 Q3-22 Q4-22 Cash as of (2)(4) 2023 2024 2025 2026 2027-31 YE 2022 (as of Jan 20) Recorded another positive free cash flow quarter, for a total of 57.2 $MM (1) GROSS DEBT Generated 215.4 $MM of operating activities cash flow, a 55% $MM increase y-o-y Cash flow used in investing activities was 158.2 $MM, with capex activity of 145.2 $MM Refinanced 108.5 $MM maturities due in 2023 (45.0 $MM now due in 2025, 63.5 $MM now due in 2026), and 40.5 $MM maturities due in 2024 (now due in 2025), extending average life from 2.4 years to 2.8 years, and reducing average debt cost from 6.0% to 4.4% Debt as of Debt as of Syndicated loan Debt as of Cash at YE-22 was 244.4 $MM, up from 182.8 $MM at Q3-22 (2) Q3-22 Q4-22 repayment on Jan 20, 2023 Jan 20, 2023 (1) Free cash flow = Operating activities cash flow + Investing activities cash flow (2) Cash is defined as Cash and cash equivalents (3) Cross border debt includes: Syndicated loan installment (22.5 $MM), bond series III (9.5 $MM), XIII (43.5 $MM), XIV (36.4 $MM) and XV (13.5 $MM) , and ConocoPhillips loan (25.0 $MM) (4) Includes 22.5 $MM used in Syndicated loan repayment on January 20, 2023
Delivered on our superior shareholder return proposition in 2022 Full year 2022—HIGHLIGHTS 495% +32% 25% +3x Reserves replacement ratio Oil production y GHG intensity y Stock performance Increased P1 reserves and well inventory Delivered solid operating performance Strong progress in sustainability Delivered robust total shareholder returns Increased P1 reserves to Increased total production Reduced GHG emissions Recorded 765 $MM Adjusted 251.6 MMboe, resulting in an 25% y-o-y to 48.6 Mboe/d intensity 25% from 24 to 18 EBITDA and 197 $MM 39% increase y-o-y kgCO2e/boe (2) positive free cash flow (3) Exported 44% of oil Increased inventory to 900 production volumes Kicked off 4 NBS projects, Recorded 40% ROACE and wells in Vaca Muerta through: managed by Aike, a Vista Adj. EPS of 4.2 $/sh (4)(5) Decreased lifting cost to 7.5 $/boe (1) subsidiary Reduced gross debt by 84 Completion of 100% WI $MM y-o-y (6) acquisition of Aguada Federal and Bandurria Repurchased 3.2 million Norte (up to 300 new well shares for a total of 29.3 locations) $MM (7) Initial pilot results in Bajada del Palo Este (up to 50 new well locations) Delivered robust performance v vis our 2022 guidance (1) Lifting cost includes production, transportation, treatment and field support services; excludes crude (4) ROACE = (Adj. EBITDA—Depreciation) / (Average total debt + Average total shareholders’ equity). Total stock fluctuations, depreciation, royalties, direct taxes, commercial, exploration and G&A costs Debt = Current Borrowings + Non-current Borrowings + Current Lease liabilities + Non-current Le (2) Scope 1 & 2 GHG emissions liabilities (3) Wintershall Free Free cash payment flow = of Operating 90 $MM activities cash flow + Investing activities cash flow. Excludes (5) Adj. EPS = Adj. Net Income / weighted average number of ordinary shares (6) Includes 22.5 $MM syndicated loan repayment on Jan 20, 2023
Increased proved reserves by 39% Proved reserves as of December 31, 2022 (1) Key drivers MMboe Added 40 new well locations in Aguada Federal, 32 in Bajada del Palo Oeste, 4 in Bajada del Palo Este, resulting in a total of 210 booked well locations Proved reserves breakdown In MMboe Oil (3) Gas Total Bajada del Palo Oeste 155.9 30.6 186.4 Aguada Federal 31.5 5.9 37.4 Bajada del Palo Este 6.7 1.8 8.5 Coirón Amargo Norte 0.6 0.2 0.8 Acambuco 0.1 0.6 0.7 CS-01 2.9 1.1 4.0 Other Arg. Conventional 10.3 3.5 13.8 (2) Total 208.0 43.6 251.6 495% 515% 14.2 years Certified present value at 10% attributable to Vista interest in P1 Total RRR Oil RRR (3) Reserves life reserves of 3.2 $Bn (4) (1) Proved reserves were certified by DeGolyer & MacNaughton, under SEC methodology. 1 cubic meter of oil = 6.2898 barrels of oil; 1,000 cubic meters of gas = 6.2898 barrels of oil equivalent (2) (3) Net Includes additions crude are oil calculated and condensate, as the and difference NGL; NGLs between: represent (i) YE less 2022 than proved 1% of reserves total reserves and; (ii) the YE 2021 proved reserves minus the 2022 total production (4) Based on reserves certification reports performed by DeGolyer & McNaughton for Argentina and Mexico, under SEC guidelines. Realized oil price assumption of 72.3 $/bbl
Achieved significant operating milestones during 2022 TOTAL PRODUCTION Mboe/d Increased shale oil Aguada Federal Bajada del Palo Este ~2x wells on production Completed and tied-in 6 Completed and tied-in +25% 48.6 from 40 wells at YE-21 wells, incorporating it to 2 wells as part of to 68 wells at YE-22 core development area 5-well pilot, showing 38.8 (connected through oil robust productivity 83% pipeline to BPO) 26.6 78% 69% Started operating Vista local sand Upgraded treatment plant in our mine and washing plant, designed Bajada del Palo Cluster to process to fulfill 100% of Vista requirements up to 57 Mbbl/d of crude oil at full capacity (est. end Q2-23) 2020 2021 2022 Total production (Mboe/d) % of oil TOTAL SHALE PRODUCTION Secured evacuation capacity for Mboe/d production growth plan thru 2026: ~4x +49% 34.7 Awarded 31,500 bbl/d incremental Awarded 37,400 bbl/d of 23.2 transportation capacity in Oldelval throughput capacity in OTE port 28 expansion and committed upfront export facilities expansion, and payments of ~54 $MM in 2023 and committed upfront payments of ~65 $MM in 2024-25 (1) ~23 $MM in 2023 and ~6 $MM in 8.5 20 2024-25 (1) 12 Expected total oil evacuation capacity of 74,300 bbl/d (1) Upfront commitments might change subject to total project costs
Solid progress on all ESG fronts Environment Initiated NBS projects execution Recorded GHG emissions intensity of 18 kgCO2e/boe for the year, a 25% y-o-y reduction. Q4-22 GHG emissions intensity was 14 kgCO2e/boe (1) Set up Aike to design, manage and execute our carbon offset Signed renewable power purchase agreement, gradually increasing from projects, staffed with leading local experts ~20% of electricity needs in 2023 ✓ Purchased 3,322 ha in ✓ Signed sustainable Executing first Corrientes and started ARR (2) agriculture agreement with 4 NBS projects, managed by Aike, a Vista subsidiary landowner in Santa Fe, project. Planted 1,080 ha Social during 2022, planning to plant Córdoba, Buenos Aires and (3) Río Negro, for a total of ~1,200 ha in 2023 ~1,900 ha Recorded TRIR < 1 for the third consecutive year Progress in gender initiatives through hiring and development of female talent, issuance of new policies and workshops to increase employee ✓ Signed sustainable livestock ✓ Signed binding commitment farming with landowner in to purchase ~5,000 ha for a awareness Santa Fe covering ~1,900 ha (4) REDD+ project in Salta Set up Social Management System to support our social performance (externally audited and following IFC standards) Aike project in Corrientes Governance Implementing Human Rights polices in line with best practices Strengthened governance by issuing policies related to business ethics and increasing training hours to staff Implemented public grievance mechanism procedure and added community feedback link to our website Progressing towards our 2026 Net Zero ambition, presented in our 2021 Investor Day (1) (1) Scope 1 & 2 GHG emissions (2) ARR stands for Afforestation, Reforestation and Revegetation (3) 1 hectare is equivalent to 2.47 acres (4) REDD+ stands for Reducing Emissions from Deforestation and forest Degradation, as well as the role of conservation, sustainable management of forests and enhancement of forest carbon stocks
Delivered robust total shareholder returns FREE CASH FLOW (1) NET LEVERAGE RATIO Vista share price performance (4) $MM x Adj. EBITDA $/Share 197.1 3.5x 20 105.9 2022: +3x 0.8x 0.4x 15 (62.3) YE2020 YE2021 YE2022 2020 2021 2022 10 ROACE (2) ADJ. EPS (3) % $/share 40% 4.2 5 17% 0.9 0 (5)% Jan-22 Mar-22 Jun-22 Aug-22 Oct-22 Dec-22 (1.3) 2020 2021 2022 2020 2021 2022 (1) Free Free cash flow = Operating activities cash flow + Investing activities cash flow. Excludes (3) Adj. EPS = Adj. Net Income / weighted average number of ordinary shares Wintershall payment of 90 $MM (4) Source: Bloomberg (2) Total ROACE Debt = (Adj = Current . EBITDA Borrowings —Depreciation) + Non /—(Average current Borrowings total debt + + Average Current total Lease shareholders’ liabilities + Non equity) -current . Lease liabilities
Enhancing focus on shale operations to strengthen shareholder returns DEAL BASICS Vista entered into a two-phased agreement with Petrolera Aconcagua, which will become operator of certain conventional concessions as of March 1, 2023, and pay 100% of opex, capex, royalties and taxes Vista to remain concession title holder until Feb 28, 2027, when 100% ownership will be transferred to Aconcagua (subject to Provincial AF ELO approvals) and keep entitlement of 40% of hydrocarbons production (1) MED BPE JDM Vista will receive: BPO ✓ 26.5 $MM upfront payment (paid in 3 annual instalments) (2) CAN Oil treatment plant ✓ 4 MMbbl of oil and 300 MMm3 of gas, through rights over 40% of excluded from transaction hydrocarbon production from the concessions, until Feb 28, 2027 (3) ✓ Right to buy Aconcagua’s 60% WI of natural gas production at 1 JQ/CDP $/MMbtu, until Feb 28, 2027 Bajada del Palo cluster oil treatment plant (located in Entre Lomas) excluded from the transaction (net book value of 20 $MM) Concessions not included in the transaction Vista retains right to develop Vaca Muerta play in the concessions Conventional concessions included in the transaction: Entre Lomas Río Negro and Entre Lomas Neuquén (ELO), Jarilla Quemada / Charco del Palenque (JQ/CDP), 25 de Mayo Medanito SE (MED), Jagüel de los Machos (JDM) STRATEGIC RATIONALE EXPECTED AM KEY IMPACTS Transforms Vista into a fully-focused Vaca Muerta company, with lower lifting and development costs, and higher ROACE and EBITDA margin No impact +5 p.p. to 71% Improves delivery of 2026 targets through additional FCF 2023 Adj. EBITDA (5) 2023 Adj. EBITDA Margin Right timing to execute the transaction (1-2 years ahead of the renegotiation of concessions extension) -2 $/boe (-25%) +100 $MM (+9%) Vista assessment of the transaction value is estimated at ~400 $MM (4) 2023 Lifting Cost (6) 2023-26 Cash generation (7) (1) 40% of crude oil production, 40% of natural gas production and 100% of LPG and condensates production Aconcagua’s 60% share of natural gas (2) Installments as follows: 10.00 $MM on February 15, 2023, 10.74 $MM on March 1, 2024, and 5.74 $MM (5) Adj. EBITDA = Net profit for the period + Income tax expense + Financial income (Expense), net + on March 1, 2025. All amounts will be payable in Argentina and in Argentine pesos. Depreciation, depletion and amortization + Restructuring and Reorganization expenses (3) If such volumes are not produced by February 28, 2027, Aconcagua shall pay Vista in cash to (6) Lifting cost includes production, transportation, treatment and field support services; excludes crude compensate for the production gap (at the average realized prices of the Neuquina Basin for the last 12 stock fluctuations, depreciation, royalties, direct taxes, commercial, exploration and G&A costs months) plus a 10% penalty (7) 2023-2026 cash generation = cumulative free cash flow, calculated as Operating activities cash flow (4) Based natural on gas a nominal at 4.5 $/Mmbtu sum of (i) and upfront 37,000 payment; tons of LPG (ii) sale at 250 of 4 $ MMbbl /tn; and of (iii) oil 3 at .5 65 $/MMbtu $/bbl , 300 margin MMm3 over of plus Investing activities cash flow
2023 Guidance (1) TIE-INS PRODUCTION LIFTING COST (2) # wells +4% Mboe/d $/boe 29 +13% (27)% 28 55 7.5 48.6 5.5 2022A 2023F 2022A 2023F 2022A 2023F New well tie-ins: 16 in BPO, 8 in Aguada Forecasting solid y-o-y growth every Rebased cost structure driven by Federal and 3 in BPE and 2 in Aguila Mora quarter; exit rate ~60 Mboe/d conventional assets sale ADJ. EBITDA (3) CAPEX (4) GHG EMISSIONS (5) $MM $MM kgCO2e/boe +11-18% (44)% 850-900 +11% 765 600 18 540 <10 2022A 2023F 2022A 2023F 2022A 2023F Based on an average realized oil price of Driven by higher D&C activity and upfront Captures full year impact of 2022 65-68 $/bbl investments in facilities decarbonization initiatives and 2023 projects Well on track to deliver long term targets presented in De 2021, with room for ove delivery on production, efficiency metrics and free cash flow (1) See “About projections and forward-looking statements” on slide 2 (4) Does not include upfront capacity payments to Oldelval or OTE (2) Lifting cost includes production, transportation, treatment and field support services; excludes crude stock (5) Scope 1 & 2 GHG emissions (3) Adj fluctuations, . EBITDA = depreciation, Net (loss) / profit royalties, for the direct period taxes, + Income commercial, tax (expense) exploration / benefit and G&A + Financial costs results, net + Depreciation + Restructuring and Reorganization expenses + Impairment of long-lived assets + Other adj.
Closing remarks 2022 Results 2022 Returns 2023 Focus 2023 Guidance Completed a year Delivered on our Signed innovative Expecting a of robust superior total agreement to double-digit operational and shareholder return become a fully- growth in financial proposition by focused Vaca production and performance, reducing gross Muerta company, Adj. EBITDA delivering on debt, repurchasing with improved with higher guidance and shares, and operational and margins making good executing warrants financial metrics progress towards exchange, resulting our 2026 targets in a peer-leading stock performance
THANKS! Q&A