Proven Performance, Assets and Opportunity. October 2017

Transcription

1 Proven Performance, Assets and Opportunity October 2017

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3 Latin American Platform: Track-Record, Value and Upside SYSTEMATIC LONG TERM CONSERVATIVE APPROACH MEXICO Zero to 29,000+ boepd net, 50,000+ boepd operated Track-record of growing production, reserves and cash flow 2P RESERVES 1 (MMBOE) NPV10 1 ($MM) 143 1,887 Effective multi-country, multi-project, risk-balanced portfolio approach Shareholders and Management aligned: 40+% of share ownership held by Board and Management 6 81 Brazil 30, Peru Chile COLOMBIA PRODUCTION GROWTH: 36% / Year (CAGR 06 16) PRODUCTION MIX: 80% Oil / 20% Gas 27,000 25,000 PERU BRAZIL 67 1 D&M December ,006 Colombia LARGE RISK BALANCED PROJECT INVENTORY IN PROVEN HYDROCARBON BASINS Base production and cash flow: 29,000+ boepd, 80% oil Discovered oil and gas with development opportunities: 3P Reserves of 235 million boe High potential upside: Exploration Resources of billion boe Unconventional resource potential: million boe New project opportunities ARGENTINA E Colombia Chile Brazil 20,000 15,000 10,000 5,000 0 Average Daily Production (boepd) 3

4 Proven Business Model: Capabilities Across Full E&P Value Chain EXPLORER OPERATOR Leading oil and gas finding team in Latin America with 25+ year discovery trackrecord: 800+ MMboe discovered to date (240+ MMboe within GeoPark) 0 to 143 MMboe 2P reserve growth increased every year for 10+ years Deep multi-disciplined teams with defined methodology, local knowledge, state-of-art tools, reservoir engineering and secondary recovery experience Pioneered new geological play-types and formations in Colombia, Chile and Argentina Growth strategy based on finding and developing oil and gas reserves in low cost, low risk, high potential exploration projects and underperforming assets in proven hydrocarbon basins CONSOLIDATOR Unique regional platform and risk-balanced portfolio across Latin America Proactive and conservative long term technical approach to develop positions in targeted proven hydrocarbon basins with infrastructure and regulatory stability with new project inventory of $2+ billion Proven track-record of finding and closing projects on good terms and converting projects into successful valuegenerating assets Partnerships with NOCs (Petrobras, Petroperu, ENAP, YPF and Ecopetrol) and strategic alliances with LG and IFC Cost efficient, innovative, solutions-oriented operator with proven ability to execute 0 to 29,000+ boepd net production growth - with 50,000+ boepd gross operated production (85% of own production operated) ~200 wells drilled with 70+% success rate and continuously improving well costs (among best in industry) Safety and environmental record superior to Latin American oil and gas industry index Flexible work programs adaptable to market conditions and with methodology to ensure capital allocated to highest value-adding projects 4

5 Explorer: Successful Oil and Gas Finder GEOPARK OIL AND GAS DISCOVERIES (GROSS 2P MMBOE) Cumulative Total Chile Colombia GEOPARK EXPLORATION METRICS 2P Gross MMBOE Discovered ( ) 2P RRI 1 (2016) Exploration Success Rate (2006-2Q2017) GeoPark Consolidated GeoPark Llanos 34 2P RLI 2 (2016) 2P F&D 3 (2016) GeoPark Consolidated GeoPark Llanos % 70% +95% 17.4 $1.7 $0.9 /boe /boe 1 RRI: Reserves Replacement Index 2 RLI: Reserves Life Index 3 F&D: Excluding FDC 5

6 Operator: Proven Execution Unlocks Economic Value SUPERIOR OPERATIONS LEAD TO SUPERIOR RETURNS Jacana x-1 Jacana Selected projects 1 Ache x-1 Jacana 3 Jacana 4 Jacana 5 Colombia: >500% average $40 /BBL 6-month payback period Tigana 4 Tigana Sur Development wells Exploration / Appraisal wells 1 Company estimates as of December 2016 Payback Period (Months) SPEED In-house designed integrated value and performance system GEOPARK OPERATING METRICS Gross Operated Production (BOEPD) OPEX/BOE 1H2017 GeoPark Consolidated GeoPark Llanos 34 Cash Costs/BOE H2017 Future Development Capital 2 GeoPark Consolidated GeoPark Llanos 34 Drilling & Completion Cost per Well ($MM) 4Q2014 2Q2017 GeoPark Llanos 34 GeoPark Llanos ,000 $7 $4 $31 $15 $5.1 $2.6 /boe /boe $5.0 $3.4 2 Estimated D&M 2016 for 2P Reserves in Colombia, Chile and Brazil 6

7 Consolidator: Assembling the Right Portfolio in Latin America STEADY AND PATIENT GROWTH IN TARGETED BASINS MID-TERM OUTLOOK Growing Base Production Reserves Cash flow Mexico Peru Argentina Brazil Colombia Chile E Indicates country entry date Estimated entry date Production in Chile Production in Colombia Production in Brazil Production in Argentina Expected production in Peru Expected production in Mexico High-value long-life diversified reserve and resource inventory with short, medium and long term projects Exploration and appraisal development in Colombia, Chile, Brazil and Argentina Opportunities with NOCs in Brazil, Colombia, Argentina and Mexico Expected first oil in Peru and Brazil GEOPARK BUSINESS DEVELOPMENT METRICS ( ) Country Platforms Total Basins Blocks Added Exploration Resources Added (MMBOE) Net Acres Added (MM)

8 Financial Profile: Profitable Assets at Low Oil Prices SUCCESSFUL COST REDUCTION EFFORTS CASH COSTS PER BOE DOWN 52% ($/BOE) 85% OF PRODUCTION CASH FLOW /BBL % PRODUCTION VS. OIL PRICE , % Production (boepd) 10,000 Oil ($40-50 /bbl) Oil ($25-30 /bbl) 85% H2017 OPEX Selling & Other G&A 0 Gas (Unaffected by oil price) 20% -56% -71% -38% 1H2017 OPERATING NETBACK ($/BOE) OIL: $53 /BBL, GAS: $5 /MCF 2017 OPERATING NETBACK GUIDANCE ($/BOE) HEDGING COVERING APPROX 50% OF 2017 OIL PRODUCTION Colombia Chile Brazil Consolidated Oil Price/bbl $50-55 Oil Hedge Floor $ $45-50 Production Hedged (bopd) 12,000 in 2H2017 ($50-54 in 3Q2017; $50-51 in 4Q2017) 11,000 in 1Q2018, 8,000 in 2Q2018 Operating Netback Selling Expenses & Royalties Vasconia Differential and Other Discounts OPEX Transportation Operating Netback 8

9 Financial Profile: Strong Balance Sheet ASSETS LIABILITIES Cash of $77 million to support operational flexibility Trafigura up to $100 million committed facility provides enhanced financial flexibility ($15 million drawn and outstanding as of June 2017) $40 million of other, undrawn uncommitted facilities 2P NPV $1.9 billion (D&M December 2016) Recently issued long-term maturing Bond $425 million due in 2024 (issued September 2017) Successful placing of $425 million Bond under Regulation S and Rule 144 A, maturing in September 2024 with a 6.5% coupon To extend debt maturities and reduce cost of capital Funds used to repay existing debt, provide financial flexibility and general corporate purposes Rated single B by both Standard & Poor s and Fitch Ratings Offering oversubscribed by more than 4x with top-tier and high quality investors EFFECTIVELY MANAGED DEBT GROWING OUT OF LEVERAGE Long Term Maturity Profile ($MM)*: x 3.6x 3.5x 2.2x Q E 2024 Bond * Assumes $40 million applied to repay existing loan with Itau (expected Sept. 29, 2017) Net Debt / Adj EBITDA Ratio Incurrence Covenant GeoPark 2024 Bond 9

10 Investing in the Best Value-Adding Projects for Shareholders CAPITAL ALLOCATION CRITERIA, EFFICIENCY, AND DISCIPLINE METHODOLOGY HIGHLIGHTS Wide portfolio of opportunities 150+ projects in 5 countries were reviewed for 2017 CAPEX plan Projects generated by local teams responsible for execution Funds allocated to the highest value adding projects Colombia Brazil 2017 BUSINESS APPROACH 2017 CAPEX $60-65 MM CAPITAL ALLOCATION: 2017 CAPEX $5-7 MM Dynamic program can be adapted to reflect changing oil prices environment and performance Strong financial position in any oil price environment Hedging in place securing minimum $50-54/bbl Brent price 12,000 bopd in 2H2017 ($50-54 in 3Q2017; $50-51 in 4Q2017) / $50-52 minimum Brent price for 11,000 bopd in 1Q2018 and $52 minimum Brent Price 8,000 bopd in 2Q2018 Large opportunity base provides increased flexibility to adapt to changes in oil prices Scenarios Oil Price Low Case Base Case Upper Case $40- /bbl $45-50 /bbl $50+ /bbl Chile Argentina Project Portfolio Peru 2017 CAPEX $10-12 MM 2017 CAPEX $5-7 MM Production growth % % % 2017 CAPEX $0.5-1 MM CAPEX $50-60 MM $80-90 MM $ MM 10

11 Colombia: Leading Oil Story in Latin America HIGHLIGHTS Grown Llanos 34 Block (GeoPark operated) from 0 to 50,000+ bopd gross in 5 years PANAMA Building value by introducing new paradigms both above and below the ground with new geological play-type and community approach Discovered new oil fields with 200+ MMbbl 3P gross reserves VIM-3 VENEZUELA Successful appraisal drilling in Jacana Field in 2016 materially expanded field size Pacific Ocean COLOMBIA LLANOS 34 LLANOS BASIN LA CUERVA 8 Blocks Acreage 2P Net Reserves 1 Net Exploration Resources 2 3Q2017 Net Production 2P RLI 3 2P NPV 4 Identified Drilling Locations 4 5 operated (98% of production) 0.7 MM acres 67.4 MMbbl MMbbl 22,367 bopd 11.8 years $1,006 MM Work Program (Base Case): $60-65 MM Focus: develop, appraise and explore potential in Tigana / Jacana oil play gross wells (70% development wells) + facilities ECUADOR 2P RESERVES (MMBBL): 56% / YEAR (CAGR 12 16) NET RESERVES AND PRODUCTION GROWTH 200km PRODUCTION (BOPD): 46% / YEAR (CAGR 12 16) Short Term Outlook: Continue development and appraisal of big undeveloped fields in Llanos 34 Block providing low risk, low cost, high returns and quick payback Opportunity to convert 3P (95 MMbbl net) to 1P reserves 1 PRMS D&M Dec GCA Dec Considering 2016 production 4 D&M Dec ,440 6,491 10,807 13,189 15,590 20, M

12 Colombia: Largest Oil Find in 20+ Years PRODUCTION HISTORY LLANOS 34 BLOCK (GEOPARK OPERATED WITH 45% WI) 45,000,000 55,000 40,000,000 50,000 35,000,000 MULTIPLYING VALUE 30X IN 4 YEARS 45,000 40,000 Cummulative Production (bbl) 30,000,000 25,000,000 20,000,000 15,000,000 Oil Production Cumulative Production 35,000 30,000 25,000 20,000 Daily Production (bopd) 15,000 10,000,000 LLANOS 34 BLOCK 1Q P Net reserves 0 62 MMbbl 10,000 5,000,000 Purchase price $30 MM 0 2P NPV 0 $900+ MM 5,000 0 Jun-12 Dec-12 Jun-13 Dec-13 Jun-14 Dec-14 Jun-15 Dec-15 Jun-16 Dec-16 Jun-17 0 Sep-17 12

13 Colombia: Llanos 34 Block Source of Short / Mid Term Production Growth GEOPARK OPERATED WITH 45% WI Chachalaca Field Chiricoca Field Max Field Tilo Field Tigana Norte 4 Tigana Norte 3 Tigana Norte 2 Tigana Field Tarotaro Field Guaco 1 Tigana S 5 Tigana SW 7 Tigana SW 3 Tua Field Jacana 10 Jacana 9 Jacana 7 Jacana Field Aruco Field OPPORTUNITY FOR LOW RISK PRODUCTION GROWTH Jacana Sur 2 Curucucú Field Jacana 13 Jacana Sur 1 Jacana 8 Jacamar Field Jacana 17 Jacana 11 Jacana 12 1 Km Oil Fields (3P D&M 2016) Oil Fields discovered in 2017 Exploration Prospects and Resources Wells expected to be drilled in 2017 * Information included in the map above is subject to change on new information available and wells to be drilled may also be changed or subject to partner or regulatory approval 13

14 Colombia: High Performance Reservoirs and Fields PRODUCTION PROFILES IN LLANOS 34 BLOCK Large fields (Tigana / Jacana / Tua) represent 80% of Llanos 34 Block production Conventional oil wells in large fields have moderate water-cut increase Big inventory of wells to increase production, with >500% IRRs and 6 months payback at $40 /bbl oil price TIGANA / JACANA FIELDS KEY FEATURES Full field appraisal and delineation still to be completed Very attractive reservoir quality: 20-25% porosity; darcy permeability Low production decline experienced to date. Water encroachment of less than 20% (Dec Q2017) Low OPEX of $3-4 /bbl Estimated average per well recovery of MMbbl (some wells have already accumulated >2 MMbbl to date) TIGANA / JACANA FIELDS GROSS PRODUCTION (BOPD) TIGANA* (BFPD) 25,000 20,000 15,000 10,000 5,000 Discovered in Dec Dec-13 Jul-14 Feb-15 Sep-15 Apr-16 Nov-16 Jun Well Count JACANA* (BFPD) 20,000 15,000 10,000 5,000 Discovered in Aug Aug-15 Dec-15 Apr-16 Aug-16 Dec-16 Apr-17 Aug Well Count Water production (bwpd) Oil production (bopd) Well Count * Production, water and well count from Guadalupe formation 14

15 Chile: Continuous Cash Flow with Minimum Investment Pacific Ocean BOLIVIA ARGENTINA PARAGUAY FELL BRAZIL HIGHLIGHTS First private oil and gas producer in Chile Large fully-operated land base across the Magallanes Basin, with existing reserves, production, steady cash flow and minor capital requirements Attractive operating environment with existing infrastructure, facilities and transportation, supported by a long term gas contract Grown production from zero to stable production with the flexibility to target oil or gas depending on underlying commodity prices Long term large shale oil opportunity with secured acreage 3Q2017 Net Production Mix: Oil 32% - Gas 68% CHILE 6 Blocks Acreage 2P Net Reserves 1 Net Exploration Resources 2 Shale Oil Upside 3 3Q2017 Net Production 2P RLI 4 2P NPV 5 100% operated 0.9 MM acres 38.3 MMboe MMboe MMbbl 2,817 boepd 27.3 years $399 MM MAGALLANES BASIN Atlantic Ocean 2017 Work Program (Base Case): $10-12 MM Focus: gas growth opportunities and business optimization 2 development wells + 2 exploration wells + workovers + facilities Short Term Outlook: Maintain / increase production levels Primary focus on higher netback gas projects 1 PRMS D&M Dec GCA Dec Considering % recovery factor 4 Considering 2016 production 5 D&M Dec

16 Chile: Fell Block - Gas Strategy with Stable Pricing ACHE GAS FIELD ACHE X-1 WELL Discovered in identified drilling locations with 2P and 3P reserves of 30 bcf and 38 bcf, respectively (D&M December 2016) Well put on stream in 3Q2015 producing at a stable rates IRR of 100+% and payback in 12 months Long term gas sales contract with attractive pricing conditions PRODUCTION PROFILE (mmcf/d) 9 Rate (mmcf/d) 6 3 Temporary interruption in gas deliveries 0 Oct-15 Mar-16 Aug-16 Jan-17 Jun-17 Sep-17 ACHE GAS TREATMENT FACILITY 16

17 Brazil: Secure Gas Income - Positioned for Growth HIGHLIGHTS South Atlantic Ocean Acquired participation in Manati Gas Field, one of Brazil s largest Stable production, minimal capital required and 100% proved developed producing reserves Generates free cash flow, unaffected by oil prices BRAZIL POTIGUAR BASIN Exploration upside in Potiguar, Reconcavo and Sergipe Alagoas basins, mature proven basins and minimal capital requirements Attractive acquisition opportunities from Petrobras on-shore divestitures BOLIVIA SERGIPE ALAGOAS BASIN RECONCAVO BASIN CAMAMU - ALMADA BASIN 10 Blocks* Acreage 2P Net Reserves 1 Net Exploration Resources* 2 3Q2017 Net Production 2P RLI 3 2P NPV 4 9 operated 0.3 MM acres 5.6 MMboe (96% PDP) MMboe 3,141 boepd 5.2 years $81 MM PARAGUAY 2017 Work Program (Base Case): $5-7 MM Focus: onshore exploration drilling in Reconcavo and Potiguar Exploration wells and 3D Seismic reprocessing Manati gas field minor maintenance works ARGENTINA MANATI FIELD AND EXISTING INFRASTRUCTURE San Francisco Gas Plant Short Term Outlook: Monetize Manati gas field reserves development Exploration drilling in onshore blocks 1 PRMS D&M Dec GCA Dec Considering 2016 production 4 D&M Dec Gas Pipeline Compression Plant (2015) One of Brazil s largest gas producing fields MANATI *Including PN-T-597 block that is still subject to the entry into the concession agreement by the ANP, and new block awarded in Round 14 (2017) 17

18 Brazil: Manati Field - Stable Profitable Production HIGHLIGHTS Strategic asset in Brazil providing gas to the northern Brazilian industrial sector and power plants Long term gas sales contract with Petrobras at fixed price in Brazilian Reais covering 100% of booked reserves Attractive pricing conditions above global and regional benchmarks Fully developed field with stable production and minimal capital requirements Temporary reduction in volumes (since 2Q2016) expected to reverse as consumption recovers Contractual take or pay (TOP) provisions restrict volumes going below current levels 2Q2014-2Q2017 NET PRODUCTION (BOEPD) PRICING CONDITIONS ($/MCF) Manati gas price vs Henry Hub (2Q2014-2Q2017) 4,000 Compression Plant tie-in 8 3,500 3,000 2,500 2, ,500 1, Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q Gas (boepd) Annual TOP (boepd) Monthly TOP (boepd) Manati Gas Price ($/mcf) Henry Hub ($/mcf) 18

19 Argentina: High Impact Low Risk Oil Exploration Underway PARAGUAY HIGHLIGHTS CHILE BRAZIL Core technical team with strong track-record in Argentine basins, participating in many large oil and natural gas discoveries Exposure to low risk, low cost, high potential exploration plays in prolific Neuquen Basin Vaca Muerta exposure ARGENTINA Partnering with experienced regional players: Pluspetrol and Wintershall (BASF Group) Pacific Ocean NEUQUEN BASIN URUGUAY Atlantic Ocean Rio Grande Oeste oil field (CN-V Block) discovered in 2017 to provide with a reserve, production and cash flow base in Argentina 3 Blocks Acreage Net Exploration Resources MM acres MMboe 2017 Work Program (Base Case): $5-7 MM Focus: exploration drilling in Neuquen Basin 1 gross exploration well in CN-V Block (50% WI) 7 gross exploration wells in Sierra del Nevado / Puelen blocks (Non operated, 18% WI) MENDOZA Short Term Outlook: Initiate / increase production in Neuquen Basin 1 GCA Dec SIERRA DEL NEVADO CN-V PUELEN La Pampa Neuquen 19

20 Peru: Discovered Light Oil Field with Major Oil Upside HIGHLIGHTS ECUADOR COLOMBIA Situche Central light oil field discovery with gross 83 MMbbl of 3P reserves following fields tests of 2 wells at combined rate of > 7,500 bbl/d Pacific Ocean MARAÑON BASIN 2,783 km of 2D seismic, 465 km 2 of 3D seismic, base camp and proximate pipeline that runs through the block Low risk, high reward optionality play with minimum commitments and similar play-type 3D exploration potential (Situche Complex) Regulatory approval for Morona Block obtained in 4Q2016 PERU BRAZIL 1 Block Acreage 1P Net Reserves 1 2P Net Reserves 1 Net Exploration Resources 2 2P NPV 3 Operated 1.9 MM acres 18.6 MMboe 31.5 MMboe MMboe $401 MM SITUCHE COMPLEX 3D SEISMIC AREA Maximum Structural Upside (SITUCHE HORST): 211 MMbbl Short Term Outlook: Environmental impact studies: $0.5-1 MM (2017) Put existing wells into production (2018 contingent on prices) 1 PRMS D&M Dec GCA Dec D&M Dec P Area SC 3X 2P Area SC 2X BOLIVIA SITUCHE CENTRAL FIELD Discovery Wells: Situche Central 2X and 3X (Short term tests of 2,400 bbl/d and 5,200 bbl/d of API oil) Sargento Puño base camp 20

21 Value Acceleration Path from Existing Assets HIGH-VALUE LONG-LIFE DIVERSIFIED RESERVE AND RESOURCE INVENTORY 8 BLOCKS 0.7 MM ACRES COLOMBIA 10 BLOCKS 0.3 MM ACRES DRIVERS OF ORGANIC GROWTH 28 blocks in 9 basins across 5 countries / 6 MM acres 3P reserve development opportunities: 235 MMboe Exploration resource opportunities: 0.8 to 1.5 Bn boe / 100+ leads and prospects Short, medium and long term prospects of varying size and risk PERU BRAZIL MULTI-PROJECT RISK-BALANCED PORTFOLIO* 1 BLOCK 1.9 MM ACRES Exploration Resources Unconventional Total Net Resources Bn boe ARGENTINA RISK 6 BLOCKS 0.9 MM ACRES CHILE 3 BLOCKS 1.8 MM ACRES 3P Reserves > 300 SIZE (MMBOE) Total Net 3P Reserves 235 MMboe Chile Colombia Brazil Peru Argentina *Graph represents an approximation to illustrate inventory of reserves and resources. Management s estimate for resources are by nature forward-looking statements, as they involve the implied assessment based on certain estimates and assumptions that the resources can be profitably produced in the future. 21

22 GeoPark Partner of Choice 22 22

23 Track-Record, Value and Upside Skilled explorer Low cost and effective operator Successful, patient consolidator Disciplined use of capital Strong culture with big entrepreneurial spirit 23

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25 Disclaimer The material that follows comprises information about GeoPark Limited ( GeoPark or the Company ) and its subsidiaries, as of the date of the presentation. It has been prepared solely for informational purposes and should not be treated as giving legal, tax, investment or other advice to potential investors. The information presented or contained herein is in summary form and does not purport to be complete. No representations or warranties, express or implied, are made as to, and no reliance should be placed on, the accuracy, fairness, or completeness of this information. Neither GeoPark nor any of its affiliates, advisers or representatives accepts any responsibility whatsoever for any loss or damage arising from any information presented or contained in this presentation. The information presented or contained in this presentation is current as of the date hereof and is subject to change without notice, and its accuracy is not guaranteed. Neither GeoPark nor any of its affiliates, advisers or representatives makes any undertaking to update any such information subsequent to the date hereof. This presentation contains forward-looking statements, which are based upon GeoPark and/or its management s current expectations and projections about future events. When used in this presentation, the words believe, anticipate, intend, estimate, expect, should, may and similar expressions, or the negative of such words and expressions, are intended to identify forward-looking statements, although not all forward-looking statements contain such words or expressions. Additionally, all information, other than historical facts included in this presentation, regarding strategy, future operations, drilling plans, estimated reserves, estimated resources, future production, estimated capital expenditures, projected costs, the potential of drilling prospects and other plans and objectives of management is forward-looking information. Such statements and information are subject to a number of risks, uncertainties and assumptions. Forward-looking statements are not guarantees of future performance and actual results may differ materially from those anticipated due to many factors, including oil and natural gas prices, industry conditions, drilling results, uncertainties in estimating reserves and resources, availability and cost of drilling rigs, production equipment, supplies, personnel and oil field services, availability of capital resources and other factors. As for forward-looking statements that relate to future financial results and other projections, actual results may be different due to the inherent uncertainty of estimates, forecasts and projections. Because of these uncertainties, potential investors should not rely on these forward-looking statements. Neither GeoPark nor any of its affiliates, directors, officers, agents or employees, nor any of the shareholders or under shall be liable, in any event, before any third party (including investors) for any investment or business decision made or action taken in reliance on the information and statements contained in this presentation or for any consequential, special or similar damages. Statements related to resources are deemed forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the resources will be discovered and can be profitably produced in the future. Specifically, forward-looking information contained herein regarding "resources" may include: estimated volumes and value of the Company's oil and gas resources and the ability to finance future development; and, the conversion of a portion of resources into reserves. The information included in this presentation regarding estimated quantities of proved reserves in Chile, Colombia, Brazil, and Peru as of December 31, 2016; are derived, in part, from the reports prepared by DeGolyer and MacNaughton, or D&M, independent reserves engineers. Certified reserves refers to net reserves independently evaluated by the petroleum consulting firm, D&M. Certain reserves data, such as those based on the D&M report, were prepared under SEC standards, and certain other data were prepared under Petroleum Resources Management System (PRMS) standards. The information included in this presentation regarding estimated exploration resources in Chile, Brazil, and Peru as of December 31, 2015, and in Colombia as of December 31, 2016; are derived, in part, from the reports prepared by Gaffney, Cline & Associates, or GCA. The accuracy of any resource estimate is a function of the quality of the available data and of engineering and geological interpretation. Results of drilling, testing and production that postdate the preparation of the estimates may justify revisions, some or all of which may be material. Accordingly, resource estimates are often different from the quantities of oil and gas that are ultimately recovered, and the timing and cost of those volumes that are recovered may vary from that assumed. Prospective Resources are those quantities of petroleum that are estimated, as of a given date, to be potentially recoverable from undiscovered accumulations by application of future development projects. Prospective Resources have both an associated chance of discovery and a chance of development (per PRMS). Prospective Resources are further subdivided in accordance with the level of certainty associated with recoverable estimates, assuming their discovery and development, and may be sub-classified based on project maturity. There is no certainty that any portion of the Prospective Resources will be discovered. If discovered, there is no certainty that it will be commercially viable to produce any portion of the resources. Prospective Resource volumes are presented as unrisked. The risk or chance of finding a minimum hydrocarbon volume that can flow to surface is presented as Geological Chance of Success (GCoS). Certain data in this presentation was obtained from various external sources, and neither GeoPark nor its affiliates, advisers or representatives has verified such data with independent sources. Accordingly, neither GeoPark nor any of its affiliates, advisers or representatives makes any representations as to the accuracy or completeness of that data, and such data involves risks and uncertainties and is subject to change based on various factors. This presentation contains a discussion of Adjusted EBITDA, which is not an IFRS measure. We define Adjusted EBITDA as profit for the period before net finance cost, income tax, depreciation, amortization and certain noncash items such as impairments and write-offs of unsuccessful exploration and evaluation assets, accrual of stock options and stock awards and bargain purchase gain on acquisition of subsidiaries. Adjusted EBITDA is included in this presentation because it is a measure of our operating performance and our management believes that Adjusted EBITDA is useful to investors because it is frequently used by securities analysts, investors and other interested parties in their evaluation of the operating performance of companies in industries similar to ours. Adjusted EBITDA should not be considered a substitute for financial information presented or prepared in accordance with IFRS. Adjusted EBITDA, as determined and measured by us, should also not be compared to similarly titled measures reported by other companies. Rounding amounts and percentages: Certain amounts and percentages included in this document have been rounded for ease of presentation. Percentage figures included in this document 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 document 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 document may not sum due to rounding. 25

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27 Company Directory CONTACTS James F. Park Chief Executive Officer Andrés Ocampo Chief Financial Officer Stacy Steimel Shareholder Value Director Santiago, Chile Nuestra Señora de los Ángeles 179, Las Condes, Santiago, Chile Phone: +(56 2)

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