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INVESTORPRESENTATION
JUNE 2020
2
Disclaimer
Additional information about Vista Oil & Gas, 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 amounts and percentages: Certain amounts and percentages included in this presentation have been rounded for ease of presentation. Percentage figures included in this presentation have not in all cases been calculated on
the basis of such rounded figures, but on the basis of such amounts prior to rounding. For this reason, certain percentage amounts in this presentation may vary from those obtained by performing the same calculations using the figures in
the financial statements. In addition, certain other amounts that appear in this presentation may not sum due to rounding.
This presentation contains certain metrics that do not have standardized meanings or 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. 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 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. 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 Affiliates, members, directors, officers or employees or any other person 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 date of this presentation and are subject to verification, completion and change without notice.
This presentation includes “forward-looking statements” concerning the future. The words such as “believes,” “thinks,” “forecasts,” “expects,” “anticipates,” “intends,” “should,” “seeks,” “estimates,” “future” or similar expressions are included
with the intention of identifying statements about the future. For the avoidance of doubt, any projection, guidance or similar estimation about the future or future results, performance of achievements is a forward-looking statement.
Although the assumptions and estimates on which forward-looking statements are based are believed by our management to be reasonable and based on the best currently available information, such forward-looking statements are
based on assumptions that are inherently subject 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. 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. These expectations and
projections are subject to significant known and unknown risks and uncertainties which may cause our actual results, performance or achievements, or industry results, to be materially different from any expected or projected 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-looking statements, including, among other things: uncertainties relating to future government concessions and exploration permits; adverse outcomes in litigation that may arise in the future; general political, economic, social,
demographic and business conditions in Argentina, Mexico and in other countries in which we operate; uncertainties relating to future election results in Argentina and Mexico; changes in law, rules, regulations and interpretations and
enforcements thereto applicable to the Argentine and Mexican energy sectors, including changes to the regulatory 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 averages;
changes in the regulation of the energy and oil and gas sector in Argentina and Mexico, and throughout Latin America; our relationship with our employees and our ability to retain key members of our senior management and key technical
employees; the ability of our directors and officers to identify an adequate number of potential acquisition opportunities; our expectations with respect to the performance of our recently acquired businesses; our expectations for future
production, 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.
Forward-looking statements speak only as of the date on which they were made, and we undertake no obligation to release publicly any updates or revisions to any forward-looking statements contained herein because of new
information, future events or other factors. In light of these limitations, undue reliance should not be placed on forward-looking statements contained in this presentation. Further information concerning risks and uncertainties associated
with these forward-looking statements 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.vistaoilandgas.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.
1Q20 Production26.5
Mboe/d
2020 1P Reserves(4) 101.8
MMboe
1Q20 Lifting cost 9.9 $/boe
Vaca Muerta acreage~134,000
net acres
LTM Revenue(1) $396MM
LTM Adj. EBITDA(1)(2) $159MM
Net debt $276MM
Net leverage ratio(3) 1.7x
3
Company overview
(1) “LTM” means last twelve months(2) Adj. EBITDA = Net (loss) / profit for the period + Income tax (expense) / benefit + Financial results,
net + Depreciation + Restructuring expenses + Other adjustments
Concentrated in Argentina’s Premier BasinStrong operating and financial performance
◼ 400+ locations under development in Bajada del Palo Oeste project
◼ Productivity of shale wells among best-in-basin, proving quality of Vaca Muerta acreage
◼ Continuous improvement in drilling and completion efficiency
◼ Conventional assets with production base and infrastructure in place, with spare capacity to treat and evacuate incremental production
◼ Low operating cost, driven by solid cost-reduction track record
◼ Strong cash position and low debt maturities during 2020
Profitable operated asset base with growth potential
(3) Net leverage ratio calculated as total financial debt minus cash & equivalents divided by LTM Adj. EBITDA.
(4) Reserves as of December 31, 2019, as audited by DeGolyer & MacNaughton and NSI.
Vista blocks with unconventional potential Vista conventional blocks
Coirón Amargo Sur
OesteCoirón Amargo Norte
25 de Mayo
Medanito
Águila Mora
Platform poised for growthContinued growth path in 2019
4
(1) All FY 2018 figures were calculated with the Q1 pro forma results from the acquired entities and assets plus Vista’s results for Q2, Q3 and Q4.
Important Note: Projections are forward-looking statements that are based on assumptions that are inherently subject to significant uncertainties and contingencies, many of which are beyond our control. There will bedifferences between actual and projected results, and actual results may be materially greater or materially less than those contained in the projections.
(2) Adj. EBITDA = Net (loss) / profit for the period + Income tax (expense) / benefit + Financial results, net + Depreciation + Restructuring expenses + Other adjustments
High-growth organic development plan, based on current premium asset base
2019Actuals
29,112 boe/d
171 $MM
41%
10.8 $/boe
224 $MM
Daily Production
Adj. EBITDA(2)
Adj. EBITDA Margin
Operating Expenses
Capex
2018Actuals(1)
24,470 boe/d
195 $MM
45%
13.9 $/boe
130 $MM
%
+19%
(12)%
(4) p.p.
(22)%
+72%
26,485
Q1 2020 2022 Target
Waiting for market conditions to restart growth
boe/d
Vista operational highlights
Shale production from 12 wells in Bajada del Palo Oeste reached 11,500 boe/d in Q1 2020
Reduced average operating cost y-o-y by 18% to 9.9 $/boe
Achieved 19% production growth y-o-y (oil 24%) in 2019
Increased proved reserves from 57.6 MMboe to 101.8 MMboe - implied RRR of 516%
Firm response to Covid-19Low operating cost and solid financial position allow us to cope with low demand environment and restart capex activity when the right conditions are in place
Cash
preservation
▪ With lower demand
forecasts for Q2, we shut-
in our shale oil wells on
March 20th to keep
producing our
conventional assets
▪ Secured floating storage
at very competitive rates
for our expected May
production volumes
▪ Actively working on
intended exports of light
crude oil in Q2
▪ Will evaluate to reopen
shale oil wells and
evaluate the drilling &
completion of 4 additional
ones, if the right demand
and price conditions are
in place during the
second half of 2020
▪ Capex and cost savings
will make our operation
leaner and fitter for the
future
▪ We continue to lower
the development cost of
our Vaca Muerta
acreage
▪ Reinforced our
teamwork and unique
culture to keep
producing outstanding
operational results even
during critical periods
▪ Capex reductions of
50% to 65%
▪ Total Opex and G&A
savings of ~20%, looking
to stabilize opex per
barrel around 10 $/boe
to 11 $/boe in a lower
production environment
▪ Our solid cash position
of +200 $MM leaves us
with enough liquidity to
either re-start drilling and
completion activity in the
short term or remain on
hold until the conditions
to ramp up activity again
are in place
Value
protection
Key tactical
decisions
Vista is prepared
• Short capex cycle with flexible contracts
• Low investment commitments
• Low operating cost
• Low debt maturities in 2020
Investment highlights
6
Only “pure-play” Vaca Muerta public investment opportunity
Low-cost and stable operation
Prime Vaca Muerta locations already under development
with solid results
Strong cash flow generation with significant upside potential
Flat and agile organization led by experienced Oil & Gas
team
16.9
14.1
11.8 12.6 12.0 12.3
9.8 9.3 9.9
1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20
27.224.6 24.4 24.2 24.7 25.7
29.031.6
30.026.5
2017 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20
Conventional Shale
7
Low-cost and stable operationOperating milestones
24.1
Lifting cost
($/boe)
Increase in production due shale oil ramp-up
24.1
Total production
(Mboe/d)
Reduced operating expenses
Pro forma
Pro forma Actual
Actual
+8%
(41%)
Shut in shale production
on March 20th
8
2019 total proved reserves(1)
Strong Vaca Muerta productivity drives reserves and production boost
(1) 1 cubic meter of oil = 1,000 cubic meters of gas = 5,615 cubic feet of gas = 6.2898 barrels of oil equivalent(2) For the reserves replacement ratio, oil includes crude oil, condensate and NGL; NGLs represent less than 2% of total reserves(3) 101.5 MMboe in Argentina and 0.3 MMboe in Mexico
MMboe
2019 proved reserves reconciliation Reserve Replacement Ratio(2)
Total
516%
Gas
294%
Oil
633%
68.3%
1.5%
30.2%
Oil NGL Natural gas
%
Reserves breakdown
Oil Natural gas NGL
(3)
MMboe
Oil reserves evolution
34.2
71.0
2018 2019
+108%MMboe
Gas reserves evolution
23.430.8
2018 2019
+31%
52%48%
Shale Conventional
%
Breakdown by type
Block W.I. (%)
2019 1P Net
Reserves
(MMboe)
Net
Acreage
Q1 2020
production
(Mboe/d)
Concession
term Operator
Entre Lomas (EL) 100% 18.9 183,014 6.8 2026 Yes
Bajada del Palo Oeste
(BPO)100% 62.7 62,641 10.3 2053 Yes
Bajada del Palo Este
(BPE)100% 2.9 48,853 1.1 2053 Yes
Agua Amarga 100% 0.9 95,580 0.6 2034/2040 Yes
25 de Mayo Medanito 100% 6.7 32,247 2.9 2026 Yes
Jaguel de los Machos 100% 6.7 48,359 3.7 2025 Yes
Coirón Amargo Norte
(CAN)55% 0.4 14,629 0.3 2037 Yes
Aguila Mora 90% – 21,128 0.2 2054 Yes
Coirón Amargo Sur Oeste
(CASO)10% 1.6 1,644 0.1 2053 Yes
Sur Río Deseado Este 16.9% – 12,807 – 2021 No
No
roeste
Acambuco 1.5% 0.6 4,406 0.2 2036/2040 No
Su
reste
CS-01 50% 0.3 11,758 0.2 2047 Yes
A-10 50% – 42,915 0.2 2047 Yes
TM-01 50% – 8,944 0.0 2047 No
Total 101.8 588,925 26.5
Go
lfo
San
Jo
rge
Neu
qu
ina
Arg
en
tin
aM
ex
ico
Tam
pic
o -
Mis
an
tla
9
Low-cost and stable operation High-quality oil-weighted production cluster
(1) In 2Q19, Vista exported its first crude oil cargo(2) LTM as of Q1 2020.(3) Includes Entre Lomas Neuquén and Entre Lomas Río Negro.
Total production (Q1 2020)
64% 33%
2%
Oil Gas NGL
26.5 Mboe/d
◼ Oil and gas production from well-understood reservoirs
◼ Primary and secondary recovery showing attractive returns
◼ Light crude oil production sold mainly to domestic off-takers(1)
◼ Gas production sold to industrial clients (55%), distributors & CNG (38%) and spot sales to power generation and traders (7%)(2)
◼ Treatment and evacuation infrastructure in place with spare capacity
Asset profile
(5)
(5)
(4)
(3)
(4) Includes Jarilla Quemada and Charco del Palenque.(5) Vista will operate the field once approved by the National Hydrocarbons Commission “CNH”. (6) Consolidates the reserves of CS-01, A-10 and TM-01
~1,100 active producing wells
Medanito type crude oil
production with API >30
+200 injector wells2019 Reserve Replacement
Ratio of 516%
(6)
0
50
100
150
200
250
300
2012 2013 2014 2015 2016 2017 2018 2019
Vaca Muerta history recapBuilding momentum
Aug-2012: YPFannounces its 100-Days Plan, with VM as the key driver for growth
Oct-2012: YPFannounces the Plan ExploratorioArgentino (PEA)
Dec-2012: YPF signs MOU with Chevron
Jul-2014: First walking rigs start operating in Argentina
Oct-2014: Congress sanctions New Hydrocarbons Law
Dec-2014: YPFsigns deal with Petronas
Jun-2015: YPF discoversunconventional gas in La Ribera
Mar-2017: Tecpetrolstarts field development in Fortin de Piedra
Apr-2017: YPF signs agreement with Schlumberger
May-2017: YPF signs agreement with Shell
Aug-2017: YPF signs agreement with Equinor
May-2013: First unconventional EPF in Loma La Lata Norte
Jun-2013: EIA report states Vaca Muerta is the 2nd largest shale gas and 4th largest shale oil resource worldwide
Jul-2013: New Loma Campana concession approved (35 years)
Aug-2013: YPF signs agreement with Chevron
Sep-2013: YPF signs agreement with Dow
(Mboe/d)
Mar-2014: YPF introduces walking rigs to Vaca Muerta
Apr-2014: YPF starts full fielddevelopment in Loma Campana
Apr-2018: Vista acquires assets from Pampa and Pluspetrol
Jul-2018: Vista starts full fielddevelopment in Bajada del Palo Oeste
Aug-2018: Vista and Shellannounce asset swap
Nov-2018: Vista obtains CENCH for Bajada del Palo Este and Oeste
Jun-2018: Exxon signsagreement with Qatar Petroleum
Dec-2018: YPF startsfull field developmentin La Amarga Chica
Dec-2018: YPF signs agreement with Petronas
Feb-2019: Vista ties-in first pad in Bajada del Palo Oeste
10
◼ Net acres: 21,128 (90% WI)
◼ License term: 2054
◼ Operator: Vista
◼ Commitment: capital expenditure of $32MM before
November 2021
Vaca Muerta acreageFour blocks in the epicenter of prominent developments
Águila Mora
Bajada del Palo Este
◼ Net acres: 48,853 net acres (100% WI)
◼ License term: 2053
◼ Operator: Vista
◼ Commitment: capital expenditure of $52MM before
December 2021
Bajada del Palo Oeste
◼ Net acres: 62,641 (100% WI)
◼ License term: 2053
◼ Operator: Vista
◼ Commitment: capital expenditure of $106MM before
June 2020 – already fulfilled
◼ Production reached 11,500 boe/d with in March 2020
Coirón Amargo Sur Oeste
◼ Net acres: 1,644 (10% WI)
◼ License term: 2053
◼ Operator: Shell
◼ Four wells currently in production
De-risked areas adjacent to developed fields from global O&G players including ExxonMobil, Chevron, Shell and YPF, among others
Producing areas Pilot / Delineation areas
Contour lines numbers denote API degrees
11
LaCocina
Organic
LowerCarbonate
MidCarbonate
UpperCarbonate
Vaca Muerta developmentBajada del Palo Oeste prime acreage
Stacked pay potential across multiple zones
Potential Best-in-Class Resource Properties(1)
Permian (Wolfcamp)
Eagle FordBajada del Palo Oeste
TOC (%) 3 3 - 54.2
Thickness (m) 200 - 300 30 - 100250
Pressure (psi/ft) 0.6 0.5 – 0.90.9
(1) Based on Company estimates, Ministerio de Hacienda, Secretaría de Energía and the EIA.
12
Bajada del Palo Oeste shale production
Cube development scheduled to minimize parent-child effect
800 – 900ft / 250 – 300m lateral spacing
Base plan
Drilling inventory
+400 wells
PotentialIn base plan
~250m
▪ Consistent strong results across 12 wells in first 3 pads
▪ Completed and tied-in third 4-well pad with improved efficiency
Location of Vista’s first pads
Conceptual cube development
✓ Tested in BdPO
▪ To be tested
✓ Tested in BdPO
0.0
1.5
3.0
4.5
6.0
7.5
9.0
10.5
12.0
13.5
Mar-19 Apr-19 Jun-19 Jul-19 Sep-19 Nov-19 Dec-19 Feb-20
Oil GasShut in
production on
March 20th
Mboe/d
Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7
Vaca Muerta developmentBajada del Palo Oeste fast track to full-scale development in factory-mode
BAJADA DEL PALO OESTE
Fast track development
Fast track development plan supported by novel One-Team approach
Field Development in Factory ModeRamp-up
Field Development in Factory ModePilot Phase 1Delineation PhaseTypical development
Current stage
Location ready
Frac set completing 1st PAD
Spudder rig already drilled surface and
intermediate sections
Walking rig drilling horizontal sections in
2nd PAD
13Drilling Completions
13.812.6
11.7
Firstpad
Secondpad
Thirdpad
D&C cost per well(1)
$MM(15)%
Completion cost
$M/stage
220200
189
Firstpad
Secondpad
Thirdpad
(14%)
753 796
601
Firstpad
Secondpad
Thirdpad
Vaca Muerta developmentSignificant drilling and completion improvement between first and third pads
14
Drilling speed Cost per lateral foot
Third pad wells vs. previous pads
Improved efficiency in second and third pads
477
726741
Firstpad
Secondpad
Thirdpad
ft/day $/ft+55% (20)%
Drilling:
◼ Drilled surface and intermediate sections with spudder rig
◼ Rotary Steering System during the build-up section
Completion:
◼ Silobags to store proppant near the pad’s location
◼ Monoline frac-manifold system to connect all 4 wells
◼ Rig-lock wireline connection and frac valves remote greasing
◼ Flat-hose to source water, reducing cost and improving logistics
State-of-the-art technology
(1) Normalized to an average well of 2,500 meters lateral length and 34 frac stages
(2) Average of the 4 wells
Well nameFirst
pad(2)
Second
pad(2)
Third pad
2061 2062 2063 2064
Lateral length
(meters)2,550 2,117 2,723 2,624 3,025 1,427
Frac spacing
(meters)75 60 60 60 60 40
Total frac
stages34 36 46 44 51 36
0
30
60
90
120
150
180
210
240
270
300
330
0 40 80 120 160 200 240 280 320 360 400
Vaca Muerta developmentThird pad shows further improvement in production performance, lowering development cost
(1) Normalized to cumulative production per stage by dividing the total cumulative production of each day by the number of stages; the information shown for the first and second pads corresponds to the
average cumulative production per stage of the four wells15
0.0
0.4
0.8
1.2
1.6
2.0
2.4
2.8
0 40 80 120 160 200 240 280 320 360 400
0
100
200
300
400
500
600
700
800
0 5 10 15 20 25 30 35 40
Mboe/d
On average, production from
our first 8 wells is 26% above
type curve after 250 days
Cumulative boe/stage(1)
2063
2061
2062
2064
2063
206120622064
First pad
Second pad
Tested higher density fracs
Individual well performance against type curveBajada del Palo Oeste shale production
Mboe
Vaca MuertaType Curve(1)
Oil Gas Total
EUR 972 Mbbl 0.6 Bcf 1,079 Mboe
Peak IP-30 1,017 bbl/d 0.6 MMcf/d 1,119 boe/d
180-day cumulative 147 Mbbl 0.09 Bcf 163 Mboe
First pad Second pad First pad Second pad
Vaca Muerta developmentVista well productivity is top-decile in both Permian and Vaca Muerta
16
(1) Source: Enverus – Drilling Info; Oil lateral (between 1,900 to 3,000 meters) wells. Companies included: CPE, CXO, FANG, HK, LPI, MTDR, PE, PDCE, PXD, SM, WPX, XEC, EOG and CDEV; Only
includes wells drilled in the Delaweare, Central Platform and Midland Basins, focused on Wolfcamp formation
(2) Source: Chapter IV – Argentine Secretariat of Energy; All oil lateral wells included
(3) Calculated as the average of the cumulative oil of the 8 wells
0
50
100
150
200
250
300
350
400
0
50
100
150
200
250
300
P25P75 P50 P10
Vista wells
Vaca Muerta wells - cumulative 180-day oil production(2)
Permian wells - cumulative 180-day oil production (vintage 2017, 2018 and 2019)(1)
Mboe/well - normalized to 2,500 meters lateral length
Mboe/well
Other companies wells
P75 P50 P25 P10
Vista average well(3)
Financial overviewSolid financial position
17
(1) A payment of 17.0 $MM corresponding to Proceeds from other financial liabilities, net was reclassified from financing activities to investing activities in the graph
(2) Calculated using Vista’s LTM Adj. EBITDA of 159.0 $MM
✓ Cash preservation strategy adopted
✓ Drilling and completion activity currently on stand-by
✓ Investing activities driven by drilling and completion until
March 20th
Q1 2020 cash flow
$MM
Financial debt 481.4 $MM
(-) Cash and cash equivalents (205.3) $MM
Net Debt 276.2 $MM
Net leverage ratio(2) 1.7x
Quarterly leverage ratios as of March 31, 2020(2)
(1) (1)
Susan L. Segal – Independent
Member of the Board of Americas Society / Council of the Americas, the Tinker Foundation, Scotiabank and MercadoLibre, as well as President of the Board of Scotiabank USA
▪ Sarah Lawrence University and MBA from Columbia University
Lean organization led by one of the most experienced O&G teams in the region
18(1) Schlumberger Production Management and Schlumberger Integrated Project Management, business segments of Schlumberger Ltd.
Juan Garoby – Chief Operating Officer
+20 years of E&P and oilfield services experience
▪ Former Interim VP E&P, Head of Drilling and Completions, Head Unconventionals at YPF and
former President for YPF Servicios Petroleros (YPF owned drilling contractor)
▪ Prior experience in Baker Hughes and Schlumberger
▪ Petroleum Engineer from Instituto Tecnológico de Buenos Aires
Alejandro Cherñacov – Strategic Planning & Investor Relations Officer
+13 years of LatAm E&P strategy, portfolio management and investor relations experience
▪ Former CFO of small-cap Canada-listed E&P company
▪ Prior experience as Investor Relations Officer at YPF
▪ Masters in Finance from Universidad Di Tella, Strategic Decision & Risk Management
Professional Certificate from Stanford, Economics degree from Universidad de Buenos Aires
Pablo Vera Pinto – Chief Financial Officer
+15 years of international business development, consulting and investment banking experience
▪ Former Business Development Director at YPF; board member at Profertil (Agrium-YPF),
Dock Sud (Enel-YPF) and Metrogas (YPF)
▪ Prior experience at McKinsey and Credit Suisse
▪ MBA INSEAD; Economics degree from Universidad Di Tella
Chairman and CEO
Miguel Galuccio▪ +25 years of energy experience across five continents (integrated oil and gas and oilfield services)
▪ Independent board member of Schlumberger
▪ Former Chairman and CEO of YPF and President of Schlumberger SPM/IPM(1)
▪ Petroleum Engineering degree from Instituto Tecnológico de Buenos Aires
Kenneth Ryan – Non-independent
Partner, Head of Corporate Development, Capital Strategies and Investor Relations at Riverstone in New York
▪ University of Dublin Law School, Trinity College
Mauricio Doehner Cobián – Independent
Executive Vice President of Corporate Affairs & Risk Management at Cemex since 2014
▪ Bachelor’s degree in Economics from Tecnológico de Monterrey, MBA from IESE/IPADE, and a Professional Certificate in Competitive Intelligence by the FULD Academy of Competitive Intelligence in Boston, Massachusetts
Pierre-Jean Sivignon – IndependentAdvisor to the Chairman and CEO of Carrefour Group in Paris until December 2018, where he previously held the position of Deputy CEO, CFO and Member of the Executive Board
▪ French baccalaureate with honors in France and MBA from ESSEC (Ecole Superieure des Sciences Economiques et Commerciales)
Mark Bly – Independent
+30 years of experience in the O&G industry
▪ Occupied various executive positions internationally at BP
▪ Master’s degree in Structural Engineering from the University of California and a Bachelor’s degree in Civil Engineering from the University of California
Board of directors of world class professionalsTop performing executive team
Closing remarks
19
Only “pure-play” Vaca Muerta public investment opportunity
Low-cost and stable operation
Prime Vaca Muerta locations already under development
with solid results
Strong cash flow generation with significant upside potential
Flat and agile organization led by experienced Oil & Gas
team
CU
ST
OM
LA
YO
UT
Unsaved Document / 3/6/2019 / 23:41
Appendix
22 Km flat-hose water transfer to tanks
on location
• 100% guaranteed water availability during frac activities
• Reduced cost
• Minimal environmental impact
• 7,500 truck trips avoided
Vaca Muerta developmentBajada del Palo Oeste fast track to full-scale development in factory-mode
21
100% of completion using sand boxes
• Minimal exposure to sand dust
• Improved logistics and reduced trucking costs
• Improved productivity by increasing sand available on location
Vaca Muerta developmentBajada del Palo Oeste fast track to full-scale development in factory-mode
22
Funding: capital markets activityRaised $250 million through dual listing in NYSE, a two-tranche Argentine bond issuances and a subsequent 48-month Argentine bond
23
Vista Argentina raised $50 million in 24-month local bond
issuance and raised additional $50 million in 36-month
subsequent local bond issuance
• 7.88% and 8.50% annual interest rate for the 24-month and
36-month class, respectively
• Bullet at maturity on July 31, 2021 and August 7, 2022
• Quarterly interest payments
Vista closed and settled a global offering of 10,906,257
shares in NYSE and BMV and began trading on the NYSE
• Gross proceeds totaled approximately $ 101 million
• Following the closing of the transaction, Vista’s outstanding
shares reached 86,835,259
• Shares were issued at 9.25 $/share
• After the offering, shares are traded under the ticker VIST in
NYSE
Vista Argentina raised $50 million in 48-month local bond
issuance
• 3.5% annual interest rate
• Bullet at maturity on February 21, 2024
• Bi-annual interest payments
Revenues and pricingProduction growth offset by lower realized prices
24
56.748.1
43.0
Q1 2019 Q4 2019 Q1 2020
3.7
2.2 2.2
Q1 2019 Q4 2019 Q1 2020
93.7 96.4
73.3
Q1 2019 Q4 2019 Q1 2020
Crude oil average price$/bbl
Natural gas average price$/MMBtu$MM
Revenues
▪ Average sales price was 55.7
$/bbl for January, 48.2 $/bbl for
February and 26.5 $/bbl for March
▪ In March, most of our sales made
at international export parity
formula were affected by lower
Brent price
▪ Mainly driven by a decrease of
∼50% in industry segment prices
and ∼35% in the power
generation segment prices
(24)%(41)%
(22)%
OpexStable q-o-q opex per boe despite lower production
25
27.825.7
23.8
Q1 2019 Q4 2019 Q1 2020
Total Opex$MM
Opex per boe$/boe
12.0
9.3 9.9
Q1 2019 Q4 2019 Q1 2020
▪ Optimized field operations and absorbed fixed cost base with incremental shale production ramp-up
▪ Implemented cost-cutting measures by the end of Q1 2020
▪ Reduced pulling activities during March as crude oil prices softened
(14)%
(18)%
Adjusted EBITDALower margins driven by low realization price environment
26
(1) Adj. EBITDA = Net (loss) / profit for the period + Income tax (expense) / benefit + Financial results, net + Depreciation + Restructuring expenses + Other adjustments
37.1 35.7
25.3
Q1 2019 Q4 2019 Q1 2020
40%37%
34%
Q1 2019 Q4 2019 Q1 2020
(32)% (6)p.p.
Adj. EBITDA(1)
$MM
Adj. EBITDA Margin%
27
Consolidated Balance SheetAmounts expressed in $MM
As of March 31, 2020 As of December 31, 2019
Property, plant and equipment 953,608 917,066
Goodwill 28,484 28,484
Other intangible assets 34,437 34,029
Right-of-use assets 16,047 16,624
Trade and other receivables 14,375 15,883
Deferred income tax 357 476
Total non-current assets 1,047,308 1,012,562
Inventories 14,754 19,106
Trade and other receivables 79,841 93,437
Cash, bank balances and other short-term
investments205,257 260,028
Total current assets 299,852 372,571
Total assets 1,347,160 1,385,133
Deferred income tax liabilities 151,511 147,019
Leases liabilities 9,766 9,372
Provisions 18,557 21,146
Borrowings 382,467 389,096
Warrants 6,091 16,860
Employee defined benefit plans obligation 4,325 4,469
Accounts payable and accrued liabilities 213 419
Total non-current liabilities 572,930 588,381
Provisions 3,023 3,423
Leases liabilities 5,117 7,395
Borrowings 98,981 62,317
Salaries and social security payable 4,362 12,553
Income tax payable 2,908 3,039
Other taxes and royalties payable 3,354 6,040
Accounts payable and accrued liabilities 72,722 98,269
Total current liabilities 190,467 193,036
Total liabilities 763,397 781,417
Total equity 583,763 603,716
Total liabilities and equity 1,347,160 1,385,133
Consolidated Income StatementAmounts expressed in $MM
28(1) Adj. EBITDA = Net (loss) / profit for the period + Income tax (expense) / benefit + Financial results, net + Depreciation + Restructuring expenses + Other adjustments
Adjusted EBITDA(1) reconciliation
Adjusted EBITDA for Q1 2020 was 25.3 $MM, with an Adjusted
EBITDA margin of 34%
Net Result
Vista recorded a Net Result of (21.3) $MM for Q1 2020
Adjusted EBITDA Reconciliation ($M)
For the period
from January
1st to March
31, 2020
For the period
from January
1st to March
31, 2019
Net (loss) / profit for the period (21,332) (13,678)
(+) Income tax (expense) / benefit 4,571 5,705
(+) Financial results, net 7,335 19,970
(+) Investments results - -
Operating profit (loss) (9,426) 11,997
(+) Depreciation 33,467 24,471
(+) Restructuring expenses 1,244 667
Adjusted EBITDA 25,285 37,135
Adjusted EBITDA Margin (%) 34% 40%
For the period from
January 1st to March
31, 2020
For the period from
January 1st to March
31, 2019
Revenue from contract with
customers 73,320 93,727
Revenues from crude oil sales 61,985 73,271
Revenues from natural gas sales 10,113 19,075
Revenues from NGL 1,222 1,381
Cost of sales (67,996) (65,713)
Operating expenses (23,833) (27,769)
Crude oil stock fluctuation 449 1,326
Depreciation, depletion and
amortization(33,467) (24,471)
Royalties (11,145) (14,799)
Gross profit 5,324 28,014
Selling expenses (6,152) (5,695)
General and administrative expenses (9,367) (8,705)
Exploration expenses (131) (126)
Other operating income 2,153 627
Other operating expenses (1,253) (2,118)
Operating profit (loss) (9,426) 11,997
29
Mexican assets overviewFirst steps towards platform regionalization
C
AB
Key facts Background / development strategyLocation
TM-01
◼ State: Veracruz
◼ Net area: 8,944 acres(1)
◼ Fluid: Oil
◼ Fields: 3
◼ 3D Seismic coverage
◼ Wells Drilled: 40
◼ Lithology: Reef limestone
◼ 1Q20 net production: 0.0 Mboe/d(1)
◼ Quick production with workovers in existing wells and new drilling in Abra, Tamabra and San Andrés formations
◼ Exploration potential in underexploited, shallower sandstone reservoirs
◼ Upside through EOR implementation and facilities upgrades
C
CS-01
◼ State: Tabasco
◼ Net area: 11,758 acres(1)
◼ Fluid: Oil and Condensate
◼ Fields: 2
◼ Wells Drilled: 50
◼ Lithology: Sandstone
◼ 1Q20 net production: 0.2 Mboe/d(1)
◼ Incremental production through workover activities and new drilling prospects to produce undeveloped reserves at upper Zargazal and Amate formations which have original pressure and hydrocarbon saturation
◼ Future upside will come from field redevelopments, infrastructure upgrades and exploration of untested deeper formations
A
A-10
◼ State: Tabasco
◼ Net area: 42,915 acres(1)
◼ Fluid: Gas
◼ Fields: 4
◼ Drilled Wells: 19
◼ Lithology: Coarse Grained Sands
◼ 1Q20 net production: 0.2 Mboe/d(1)
◼ 13 wells have been drilled supporting assessment potential
◼ Exploratory area with gas potential in AmateFormation
◼ Tepetitán Field (Pemex) is used as analogous
B
Operator
Vista(2)
Vista(2)
Jaguar
(1) At Vista’s 50% working interest.(2) Vista will operate the field once approved by the National Hydrocarbons Commission “CNH”.