#1PTTEP MEMBER OF Dow Jones Sustainability Indices In Collaboration with RobecoSAM Investor Presentation Thailand Focus 2021 26 August 2021#2Disclaimer PTTEP Forward-looking Information The information, statements, forecasts and projections contained herein reflect the Company's current views with respect to future events and financial performance. These views are based on assumptions subject to various risks. No assurance is given that these future events will occur, or that the Company's assumptions are correct. Actual results may differ materially from those projected. Petroleum Reserves Information In this presentation, the Company discloses petroleum reserves that are not included in the Securities Exchange and Commission of Thailand (SEC) Annual Registration Statement Form 56- 1 under "Supplemental Information on Petroleum Exploration and Production Activities”. The reserves data contained in this presentation reflects the Company's best estimates of its reserves. While the Company periodically obtains an independent audit of a portion of its proved reserves, no independent qualified reserves evaluator or auditor was involved in the preparation of reserves data disclosed in this presentation. Unless stated otherwise, reserves are stated at the Company's gross basis. This presentation may contain the terms "proved reserves" and "probable reserves". Unless stated otherwise, the Company adopts similar description as defined by the Society of Petroleum Engineers. Proved Reserves - Proved reserves are defined as those quantities of petroleum which, by analysis of geological and engineering data, can be estimated with reasonable certainty to be commercially recoverable, from a given date forward, from known reservoirs and under current economic conditions, operating methods, and government regulations. Probable Reserves - Probable reserves are defined as those unproved reserves which analysis of geological and engineering data suggests are more likely than not to be recoverable. 2 Energy Partner of Choice#3PTTEP MEMBER OF Dow Jones Sustainability Indices In Collaboration with RobecoSAM Corporate Introduction#4PTTEP - The Largest E&P company in Thailand Government of Thailand 63.3% Thailand's National energy company 65.29% ptt As of March 2021 PTTEP E&P arm of PTT Group Established 1985 Market Cap. > 14bn USD SET Listed since 1993 Sales Revenue > 90% SEA & Middle East Cash Cost < 13$/BOE Cost Competitive STANDARD & POOR'S RATINGS SERVICES MCGRAW HILL FINANCIAL BBB+ / Stable Stand-alone at BBB MOODY'S Fitch Ratings BBB+ / Stable Stand-alone at BBB TRIS RATING Baa1 Stable Stand-alone at Baa2 4 AAA / Stable High Performance HPO Organization Be Smart GRC and Compliance Be Good Governance, Risk Management PTTEP Sustainable Organization Stakeholder SVC Value Creation Be Responsible Dow Jones Sustainability Indexes 2014-2020 FTSE4Good 2016-2020 THSI THAILAND SUSTAINABILITY INVESTMENT 2020 2016-2020#5Consistent Performance Historical Sales Volume and Net Income Dividend Payment History Sales volume (KBOED) 500 Net Income (MMUSD) 2,000 413 THB per share 351 400 354 1,600 6.00 1H 2H 6.00 320 299 306 5.00 300 1,569 1,200 4.25 4.25 720 4.00 3.75 200 594 1,120 598 800 3.25 3.25 372 2.75 2.75 2.00* 100 400 2.00 2.50 2.25 1.50 1.75 2.00 1.50 0.75 2016 2017 Sales volume (MBOED) 2018 2019 2020 6M21 Net Income (MMUSD) 0.00 2016 2017 2018 2019 2020 1H2021 * 1H2021 Dividend: XD Date 11 August 2021 Record Date 13 August 2021 Payment Date 27 August 2021 EBITDA margin 80 68 75 Payout Ratio (% of net income) 98 88 55 55 49 77 40 Payout Ratio (% of recurring net income) 79 83 63 51 53 53 71 38 38 (% of sales 71 70 73 71 revenue) Unit Cost 30.46 29.05 31.69 31.71 30.5 27.57 (USD/BOE) LO 5#6PTTEP MEMBER OF Dow Jones Sustainability Indices In Collaboration with RobecoSAM Energy Transition & PTTEP Strategy#7Energy Transition 2 Global 1 Climate change is Top Agenda GHG Reduction to sustain E&P business • Gas is a transition fuel ⚫ Electrification is the future Stakeholders demanding lower carbon footprint • New Policy & Incentives for green investment Easy Access & Cheap Funding from Investor - - Thailand • 2030 GHG reduction target 20% • Net-zero emission year being defined • Climate Change Act being prepared • Govt. plans to Change fuel mix Support goods from - low-carbon processes Encourage Carbon Capture and Storage Hydrogen H₂ zero emission Shifting to low carbon energy Renewables growing at 10% CAGR from 2010- 2040 H₂ Society becomes aspiration for many countries ⚫ Renewables growing at 2-3% CAGR (2019-2050) • H, Symposium & H₂ Thailand Working Group established among private sectors Fossil Fuel demand will peak ⚫ Peak Oil: 2028-2040+ by speed of growth in EVs • Peak Gas: 2037-2040+ by growth in renewables Peak Oil: 2034 by clean energy & policy • Peak Gas: 2040+ by technology development 7 PTTEP Energy Partner of Choice Source: Various Org. Consultant (IEA, McKinsey, Wood Mac, BCG, Rystad, etc.) and PTT TTS #2 cloud scenario#8PTTEP's Position towards Energy Transition Strategy Last man standing Emission Targets Minimal adhere to regulations Core Oil & Gas Business PTTEP's Future Portfolio Mix Cautious diversified Low-carbon adopter Energy transition frontrunner & NI from Non-EP Business (projected in certain year) 100% Commitment but not Net Zero Net zero target Aggressive 2°C goal Focused Maintain Reduced Divested + Offset activities + Offset activities + Offset activities Net Income New Business Minimal Minor Increased Focused 2021 Company Mapping Source: McKinsey, Wood-Mackenzie ConocoPhillips MURPHY CNPC OIL CORPORATION ExxonMobil Chevron Santos equinor PETRONAS TOTAL Orsted bp أدنوك woodside ADNOC OXY 00 8 CO2 S 20% PTTEP Year 2030 2025 ARV, Tech. & Future Energy Growth Platform Power Business Protection from Oil Price Fluctuation E&P Business Core and Foundation for Growth * Average ROCE between 2020 - 2030#9PTTEP's Directions and Long-Term Targets • • . Sustainable E&P Business Execute & Expand Production CAGR 5% in 2030, maintain @700 KBOED after 2030 • R/P> 5 years ⚫ Unit Cost < 25 $/BOE GHG emission intensity reduced by 25% in 2030 • PTTEP's visibility as "Guardian of the Ocean" Diversification to non-E&P • Net Income contribution 20% by 2030 • Resources Preparedness Resilient organization for both E&P and non-E&P Strategy: Domestic gas sales to ensure gas supply continuity Cost competitiveness of oil projects in Thailand & Malaysia Resources monetization of exploration and development assets "Go for Gas" growth in TMM & ME New LNG investment shift to medium-long term Strategy: GHG reduction initiatives e.g. CCS in Thailand & Malaysia Ocean for life initiatives e.g. Ocean data platform, Rig to reef, CSR around ocean Strategy: ARV superior growth Power Business in Vietnam / Myanmar In-house Tech Commercialization, CCU, Hydrogen H2 02 ENERGY 2 STORAGE Strategy: Efficient human resources and funding plan Spin-off non-E&P businesses 9 PTTEP Energy Partner of Choice#10Strategy Focus E&P Business Growth in Core Area & Strategic Partnership Oman and UAE • Monetize Discovered Resources • Accelerate Exploration Campaign • Grow through Expand to Strategic Partner Middle East Coming Home Thailand • Ensure domestic gas supply continuity • Accelerate resources recovery from onshore assets • Find new growth opportunity from OCA and bid round AI AND ROBOTICS VENTURES PTTEP Non-E&P Business Diversification: NI > 20% by 2030 ROVULA varuna Technology Business varu Go-to-Market activities HEALTHTECH SKYLLER Gas to Power LNG to Power Wind Solar Power Business Myanmar • Pursue growth in Western Corridor • Unlock full potential of existing assets • Closely monitor political situation Malaysia • Fully Explore and synergize with existing facilities • Focus on Lang Lebah (LLB) Development • Resources monetization from exploration blocks Potential Business Opportunities Carbon Capture Utilization Potential Products Methanol, Aggregate, Urea, CCU CO₂ Polycarbonates and Carbon Nanotube • Low carbon Initiative by turning CO2 waste through CCU technology 2 Hydrogen Energy Transition H2 Alternative energy • Future and clean energy 10 • Support GHG reduction goal Energy Partner of Choice#11PTTEP MEMBER OF Dow Jones Sustainability Indices In Collaboration with RobecoSAM SD Roadmap#12SD Roadmap - GHG and Ocean for Life GHG Reduction Roadmap for 2030 Target 25% GHG Intensity Reduction (base year 2012) GHG Reduction 16% 2021 25% 2030 Ocean for Life Guardian of the Ocean (via Ocean Data Platform) Major Activities Renewable in Operation Renewable Use at New WHP in Domestic S1 Solar WHP Equipped with Renewable in Domestic 1 Clean and Friendly Operation Efficiency Improvement Energy Optimization LNG Powered Wave Craft Production Fleet Kil 2 Ocean Health and Biodiversity Monitoring Flare Utilization Feasibility of Additional FGRU FGRU Installation in Domestic Assets Zero Routine Flare Carbon Capture and Storage (CCS) Feasibility Study on CCS CCS Initiative in TH CO₂ and MY Assets CCS PTTEP JOURNEY TOWARDS SUSTAINABILITY 12 PTTEP Offshore + Mid-Shore: Advanced Technology & Innovation 3 Ramp up CSR around Ocean Onshore + Nearshore: Offshore: Location Advantage Collaboration Network & CSR#13PTTEP MEMBER OF Dow Jones Sustainability Indices In Collaboration with RobecoSAM Operations Update#14Core E&P Business Update Assets Transition in Thailand PTTEP G1/61 (Erawan) Delayed Site Access YY Starting producing below PSC volume Remediation Plan (accelerate ramp-up and uplift other fields) On track towards 1st gas in 2022 G2/61 (Bongkot) WHP Construction IIII Awarded drilling rig (ready to drill in Nov) GSA Finalized Stronger foothold in Malaysia SK410B Project • Under field development study reflecting larger gas discovery volume and CO2 management as per GHG aspiration target • FID target on track • Several petroleum prospects under study with additional drilling planned in 2022 SK438 Project Evaluating petroleum potential at Mak Yong-1, after gas discovery at Kulintang-1 (1st exploration well) in April 2021 PM407 Project Conducting 3D Seismic Reprocessing and preparing for exploration drilling campaign in 2022-2023 Potential Development Cluster in Sarawak, Malaysia and Installation (complete in Nov) Production boost in Oman Oman Block 61 Ramp up production to full capacity from 27 June 2021 • Gas: 1,500 MMSCFD Condensate: 69,000 BBL/D New volume in Algeria Algeria HBR Construction and commissioning on progress 1st oil production expected in 2H/2021 with capacity 10-13KBPD OMAN 14 Thailand Legend Producing Explorations Petroleum Discoveries South Sarawak Cluster SK309-311, SK314A, SK438, SK405B Bongkot Arthit PM415 Peninsular PM407 North Sarawak Cluster SK410B & SK417 ISK410B - SK417 Block H PFLNG2 Block K Sabah SK438 SK314A SK405B SK309/311 MLNG complex Sarawak#15New Business Update - ARV AI AND ROBOTICS VENTURES ROVULA End-to-end Al-augmented Subsea Inspection Repair and Maintenance (IRM) varuna One-stop Service for Smart Farming and Smart Forestry Solutions 00° SKYLLER Cloud-based Asset Inspection and Mgmt. Platform via Drones & Al/ML services HEALTHTECH PTTEP Thailand's largest lifetime digital health ecosystem for illness and good-health. Products and Services ROV Inspection & repair Xplorer AUV Surveillance & inspection Nautilus Repair & Maintenance Cant Supercone Term AiAng Sprayer Drone AIM Platform Th IOT TEMPERATURE MORNINGS DONATIONS FOR MOPH ARVIC 64 1,240 120 IoT Temp Monitoring Business Highlights • • Software & Data Analytics & Insights Delivered ROV support for pipeline replacement to Mubadala Awarded for Zawtika pipeline survey Awarded for ME ROV support project • 9800-0-0 VARUN Platform 1,120 sq.km Varuna analytics performed in POC stage 31 AiAang sprayer drone confirmed orders in Q2 (to be delivered in Q3) • 5 sales opportunities in pipeline Drone Inspection . AeroSky JV established • • . • Ongoing discussion with 3 additional AiAang distributors • Awarded for 48 sq.km spraying service • • 14 sales opportunities in pipeline MOU signed for power sector Delivered POC for Telecom and Construction sectors Ongoing inspection services performed 2,000 km of PTT Pipeline Awarded for HMC long-term service • 12 sales opportunities in pipeline Health Ecosystem Platform Delivered 2,000 units of loT cold-chain device for Covid-19 vaccine Ongoing development of COVID-19 risk evaluator software (Thaisavefamily platform) for Department of Health Ongoing health ecosystem platform development (ARVIC) with potential 1.5m users on board Ongoing POC development of wellness platform with BJC Note: ME = Middle East market (via Mermaid Subsea Services), ROV = Remotely Operated Underwater Vehicle, AUV = Autonomous Underwater Vehicle, POC = Proof of Concept, AIM = Asset Inspection Management#16PTTEP MEMBER OF Dow Jones Sustainability Indices In Collaboration with RobecoSAM Q2/2021 Results & Outlook#17Results - Net Income Impressive recurring net income curbed by oil price hedging loss Q2/21 on Q1/21 (QoQ) Unit: million USD 376 222 94 349 282 Q1/21 Q2/21 -127 Recurring NI Non recurring NI -Net Income 6M2021 on 6M2020 (YTD) Unit: million USD 598 409 418 631 6M2020 Recurring NI 6M2021 Non recurring NI -33 Net Income Recurring (+67 MMUSD or +24%) +16% Mainly from Oman Block 61 Sales Volume and Sabah H $ Average Selling Price +4% Higher liquid price Recurring (+213 MMUSD or +51%) +20% $ Increase from Gulf of Thailand, Sales Volume Sabah H, and Oman Block 61 Average Selling Price -10% $ Lower unit costs ◉-3% $ Lower unit costs Non-recurring (-221 MMUSD or ->100%) Higher oil price hedging loss in Q2, and realization of gain from bargain purchase offset with exploration asset write-off in Q1 Non-recurring (-24 MMUSD or ->100%) +3% Higher liquid price offset with lower gas price Higher oil price hedging loss offset with a gain from bargain purchase in 2021 17 PTTEP Energy Partner of Choice#18Results - Sales Volume and Avg. Selling Price Solid volume addition from Oman Block 61 and Malaysia Sabah-H PTTEP UNIT: BOED 443,126 413,168 400,000 354,052 19,323 382,877 23,419 68,068 45,867 Volume Mix 327,004 345,207 20,443 Rest of World 85,215 102,239 24,790 93,774 Gas Liquid 300,000 85,248 82,692 Other SEA 80,401 29% 28% 200,000 Thailand & 274,243 249,481 272,819 273,527 100,000 221,813 242,072 MTJDA 71% 72% Q1 2021 Q2 2021 Product Price 2020 Q1 21 Q2 21 Q2 20 6M 2021 6M 2020 Revenue Mix Gas ($/MMBTU) 6.27 5.61 5.59 6.37 5.60 6.64 Liquid ($/BBL) 41.55 56.59 63.98 28.92 60.52 40.80 41% 43% Weighted Avg. ($/BOE) 38.92 40.38 42.19 34.97 41.35 40.15 Avg. Dubai ($/BBL) 42.27 60.21 67.02 30.72 63.62 40.72 59% 57% Avg. HSFO ($/BBL) 39.30 56.74 61.21 29.18 58.98 36.26 (High Sulphur Fuel Oil) Q1 2021 Q2 2021 Note: Include sales volume from ADNOC Gas Processing (AGP) Exclude Oman Block 61 deemed sales volume from tax payment by government 18 Energy Partner of Choice#19Results - Unit Cost Consistent decline in unit cost to meet long-term aspiration cost target Unit: $/BOE 40 30.50 30.25 30.62 27.96 27.24 27.57 30 Cash Cost Unit Cost 20 14.40 12.10 11.62 13.88 ☑ 14.33 11.84 10 2020 Q1 21 Q2 21 Q2 20 6M 2021 6M 2020 DD&A 16.10 15.86 15.62 16.37 15.73 16.29 Finance Cost 1.96 1.39 1.27 2.04 1.33 2.00 Royalties 3.17 3.41 3.42 2.63 3.42 3.20 G&A 2.33 2.12 1.97 2.02 2.03 1.98 Exploration Expenses 0.80 0.12* 0.19 1.03 0.16 1.10 Operating Expenses 6.14 5.06 4.77 6.16 4.90 6.05 Lifting Cost 4.47 4.15 3.91 4.59 4.02 4.42 Note: * Exclude Exploration assets write-off in Brazil for Q1 21 All Unit Cost shown above exclude costs related to new business The formulas for calculating ratios are provided in the supplementary section for your reference 19 PTTEP Energy Partner of Choice 5#20Results - Cash flows and Financial Position Robust operating cash flow with higher EBITDA margin 6M 2021 : Source and Use of Funds* 75% EBITDA Margin Cash flow from operations (Before tax payment) 3,804 2,098 4,052 Others 278 Free Cash flow 730 CAPEX 2,098 410 680 Tax payment Asset acquisition (Oman Block 61) 2,364 2020 Sources Note: * Include Short-term investment Uses Financial Position Unit: million USD 1,850 Jun-21 Net of adjustment for the effect of exchange rate changes on cash and cash equivalents D/E ratio 0.33x Weighted Average Cost of Debt (%) 3.44 Remark: Debt profile excludes Hybrid bonds 0.34x 3.31 PTTEP Unit: million USD 23,230 22,493 Total Assets 6,762 7,078 Other Liabilities 3,932 4,131 Interest-bearing Debt Equity 11,799 12,021 2020 JUN-21 Debt Profile Weighted Average Loan Life (Years) 14.08 12.86 Fixed: Floating 82:18 78:22 20 20 Energy Partner of Choice#21Financial Outlook 2021 Guidance Average Sales Volume* Average Gas Price KBOED USD/MMBTU ** Unit Cost USD/BOE ~405 Full year ~412 Q3 Credit Rating/Outlook Q3 & Full year ~5.7 Q3 & Full year ~28-29 EBITDA Margin % of Sales Revenue Q3 & Full year ~70-75% Note: * Include sales volume from ADNOC Gas Processing (AGP) Based on average Dubai oil price in 2021 at 67.6 $/BBL STANDARD & POOR'S RATINGS SERVICES MCGRAW HILL FINANCIAL BBB+ / Stable BBB stand-alone rating International Fitch Ratings BBB+ / Stable BBB stand-alone rating MOODY'S Baa1 Stable Baa2 stand-alone rating National TRIS RATING AAA / Stable 21 PTTEP Energy Partner of Choice#22KKK PTTEP @ [email protected] +66 2 537 4000 http://www.pttep.com Thank you and Q&A You can reach the Investor Relations team for more information and inquiry through the following channels#23PTTEP MEMBER OF Dow Jones Sustainability Indices In Collaboration with RobecoSAM Supplementary information Financial Results Q2/2021 24-26 Industry and Thailand Energy Updates 27-29 Reserves at Year-end 2020 30 Key Project Highlights by Region 31-36 Project Details 37-41 Organization Structure 42 42 Ratio and Formula 43#24Results - Net Income PTTEP Unit: million USD Statements of Income Q2 21 Q1 21 %QoQ Q2 20 % YoY 6M21 6M20 %YTD Total Revenues 1,768 1,779 (1%) 1,095 61% 3,546 2,779 28% Sales (1) 1,729 1,391 24% 1,041 66% 3,120 2,523 24% Sales Volume (BOED) (2) 443,126 382,877 16% 327,004 36% 413,168 345,207 20% Sales Price (US$/BOE) 42.19 40.38 4% 34.97 21% 41.35 40.15 3% Gain from a bargain purchase 350 (100%) 350 100% (3) Others 39 38 3% 54 (28%) 76 256 (70%) Total Expenses 1,548 1,405 10% 959 61% 2,953 2,382 24% Major Expenses: Operating Expenses Exploration Expenses G&A DD&A Loss on Financial Instruments 193 174 11% 183 5% 367 380 (3%) 7 149 (95%) 30 (77%) 156 69 >100% 83 75 11% 62 34% 158 128 23% 629 547 15% 488 29% 1,176 1,024 15% 125 98 28% 78 60% 223 100% Impairment Loss on Assets 47 (100%) 47 (100%) Income Tax Expenses 321 192 67% (68) >100% 513 384 34% Share of profit (loss) from associates and JV 2 2 (2) >100% 5 12 (58%) Net income 222 376 (41%) 134 66% 598 409 46% Recurring Net Income 349 282 24% 128 >100% 631 418 51% Non-recurring Net Income (127) 94 (>100%) 6 (>100%) (33) (9) (>100%) Non-recurring Net income breakdown: Oil Price Hedging (141) (107) (32%) (26) (>100%) (248) 140 (>100%) Tax from Effect of FX (9) 100% 122 (100%) (9) (103) 91% Effect from FX and others 14 5 >100% (43) >100% 19 1 >100% Impairment Loss on Assets Exploration assets write-off (47) >100% (47) 100% (145) 100% (145) (100%) Gain from a bargain purchase 350 (100%) 350 100% Note: (1) Include Oman Block 61 deemed sales revenues from tax payment by government (28 MMUSD for Q2 21 and 6M21) (2) Exclude Oman Block 61 deemed sales volume from tax payment by government 24 (3) Consisted of Revenue from Pipeline, Gain from FX, Forward Contract, and Oil price Hedging Energy Partner of Choice#25Five-Year Plan: Sales Volume Maximize value of existing assets, accelerate G1/G2 transitions & maintain key milestones for key projects Figures have not yet reflected Oman block 61 PTTEP In KBOED CAGR +6% 466 500 462 436 446 Rest of World 400 354 375 Other SEA 300 Sales Volume 200 100 Thailand & MTJDA 0 2020 2021 2022 2023 2024 2025 In MMUSD 6,000 5,617 4,779 4,934 686 4,196 34 73 4,111 OPEX 63 62 (Decommissioning) 4,000 2,900 1,896 1,771 1,778 OPEX 1,545 Investment 30 1,710 554 768 819 493 2,000 1,480 481 233 2,481 2,095 2,206 2,264 1,858 1,157 (exclude decommissioning) CAPEX (Dev & Pre-sanction projects (3) CAPEX (Producing projects (4)) 5 Years (2021-2025) 2020 2021 2022 2023 2024 2025 CAPEX 14,020 OPEX TOTAL 9,617 23,637 Key Project Start-up Block H: 1H Capacity 270 MMSCFD Algeria HBR (phase I): 2H Capacity 10-13 KBPD G1/61: April (2) Capacity 800 MMSCFD G2/61: April (2) Capacity 200 MMSCFD 25 G2/61: March Capacity 700 MMSCFD (2) Mozambique LNG: 1H Capacity 13 MTPA Algeria HBR (Full phase): 2H SK410B (1) Southwest Vietnam: 2H (1) Capacity 50-60 KBPD Initial Capacity 600-800 MMSCFD Capacity 490 MMSCFD Note: (1) Subject to regulatory approval and FID timing (2) According to Production Sharing Contracts signed on 25 February 2019 (3) Development & Pre-sanction projects include Mozambique LNG, Algeria HBR, SK410B, and Southwest Vietnam (4) Includes exploration and appraisal in all projects and head office CAPEX#26Debt Maturity Profile As of June 2021 USD Millions 700 600 500 400 300 200 200 100 2021 2022 2023 480 2024 Note: Excludes Hybrid bonds Unit: USD Millions or equivalent after cross currency swap 2025-2026 600 2027 26 26 2028 500 2029 2030 349 350 2031-2041 2042 2043-2058 490 2059 Energy Partner of Choice 650 PTTEP#27Thailand Updates Higher gas volume with recovering demand constraint; THB fluctuation continues FY 2019 FY 2020 5M 2021 FY 2019 FY 2020 5M 2021 Thailand Energy Overview Natural Gas Supply 34 MMSCFD 33 32.7 Domestic Myanmar LNG 5,023 ○ Domestic Myanmar LNG 4,699 Domestic Myanmar LNG 5,017 Recovering energy demand, which rebounded to the same level of pre COVID-19 As of April 2021: Higher domestic supply, while LNG imports decreased slightly and a decline from Myanmar piped gas imports due to natural decline 32 31 30.9 30 30.2 29 0 1,000 2,000 3,000 4,000 5,000 Natural Gas Consumption MMSCFD Electricity Industry GSP NGV 4,625 Electricity Industry GSP NGV 4,368 Electricity Industry GSP NGV 4,762 0 1,000 2,000 3,000 4,000 5,000 Source: Energy Policy and Planning Office (EPPO) FY2019 FY2020 5M 2021 Electricity Generation GWH 57% 2% 16% 14% 11% 87,190 55% 2% 18% 14% 10% 205,995 57% 3% 17% 12% 10% 212,050 Natural Gas Imported Hydro Electricity Renewable Energy Coal & Lignite 27 Exchange Rate Movement (THB/USD) 32.1 31.7 31.3 30.0 28 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 PTTEP 33.0 (Highest) 31.5 (Average) 30.7 (Lowest) Consensus on the exchange rate mostly depends on 。 Efficacy of Covid-19 containment measures in Thailand and vaccine procurement and distribution timeline o Thailand's economic recovery which heavily depends on tourism recovery 。 Sustained fiscal and monetary policy support in Thailand and Federal Reserve tapering timeline Source: Bank of Thailand, Bloomberg Forecast based on Bloomberg Consensus as of 12 July 2021 Energy Partner of Choice#28Thailand's Energy Value Chain PTTEP contributes over 1/3 of Thailand's petroleum production 5M 2021 Thailand's Oil and Gas Demand Crude Oil & Condensate ~ 1.0m BOE/D Imports ~ 83% Domestic 17% Natural Gas ~0.9m BOE/D Imports - 30% Domestic ~ 70% Source: Energy Policy and Planning Office (EPPO) and Department of Mineral Fuels (DMF) 6M 2021 Thailand Petroleum Production % by Petroleum Type and Area Onshore 8% Gas 74% Offshore 92% Liquid 26% Midstream Gas: operated by PTT Transmission Pipelines Gas Separation Plants Oil: PTT participates through subsidiaries % Production by Company Refineries PTTEP 38% 28 Others 62% Downstream Petrochemicals Oil and gas marketing PTTEP Energy Partner of Choice#29Thailand's Oil and Gas Balance SALES PRODUCTION SUPPLY Source: PTT Note: * ** Oil Balance*** Maintains stability supply through adequate refining capacity Natural Gas Balance* Main driver of the Thailand economy **** Gulf of Thailand (64%) Onshore (2%) Import (34%) Import (83%) 919 KBD Indigenous (17%) 184 KBD Imported Refined Petroleum Products 41 KBD Crude/ Condensate 878 KBD Total Refining Capacity in Thailand 1,242 KBD Crude/ Condensate 166 KBD PTT's Associated Refineries 770 KBD (TOP, PTTGC, IRPC) Crude Export 18 KBD Other Refineries 472 KBD (SPRC, ESSO, BCP) Refined Products 1,000 KBD * Refined Products 186 KBD Domestic 853 KBD ** Export 203 KBD Refined product from refineries = 908 KBD, including domestic supply of LPG from GSPs and Petrochemical Plants = 92 KBD Included Inventory ** Information as of 6M21 **** Information as of 6M21 MMSCFD @ Heating Value 1,000 Btu/ft³ 29 29 PTTEP 40% Others 60% 2,981 MMSCFD Bypass Gas 405 MMSCFD 6 Gas Separation Plants Total Capacity 2,870 MMSCFD 958 MMSCFD (21%) LNG 51% Myanmar 49% @Actual Heat 111 MMSCFD 1,569 MMSCFD Petrochemical Ethane Propane Feedstock LPG (13%) NGL Industry Household LPG Transportation NGL (8%) Methane 1,618 MMSCFD Power (60%) Industry (16%) NGV (3%) PTTEP Energy Partner of Choice#30Reserves at the Year-end 2020 (not including Oman Block 61) Sustained reserve life at over 5 years target MMBOE 1,800 Reserves Life* 2020 by Geography 1,647 1,622 Domestic International 10 Years 1,622 507 548 1,074 47% 1,200 1,028 7 Years 50% 53% 351 50% 600 1,140 1,074 677 2018 2019 2020 Proved (P1) Probable (P2) 5-Year Average Proved Reserves Replacement Ratio (RRR) 2018 0.7x 2019 1.5X 2020 1.5X P1 P1 + P2 2020 by Product Type Gas Liquid 1,622 1,074 31% 27% 69% 73% P1 P1 + P2 • Based on total production of natural gas, condensate, and crude oil (including LPG) of 422 KBOED for the year ended December 31, 2020 Figures include reserves from equity method 30 80 PTTEP Energy Partner of Choice#31Diversified international portfolio Central Asia First presence in Kazakhstan: • Production: Dunga onshore oil field Oil sands from the acquisition of Partex in 2019 North & South America Opportunities in an early phase: • Deepwater exploration in Brazil and Mexico with prominent and prudent operators Book Value of Assets by region Total assets USD 23.23 billion Africa 17% Others 3% Middle East 16% Thailand 38% Southeast Asia 26% As of Jun 2021 (including Oman Block 61) Information as of 30 June 2021 Oil Oil Piped Gas Oil Gas/LNG Oil I Oil GAS/LNG PTTEP Thailand PTTEP's primary operational base • 66% of total sales volume • Key producing assets include Bongkot, Arthit, Contract 4 and S1 • Transition of operations for G1/61 (Erawan) and G2/61 (Bongkot) are in process to ensure production continuity under new PSCs Southeast Asia Second heartland to PTTEP • 23% of total sales volume, mainly from Malaysia and Myanmar • Recent multiple petroleum discoveries in Malaysia formed fundamental for cluster development potential • Other producing assets in Vietnam (oil) and Indonesia (gas) Africa An area for growth, key projects include: • Production: Algeria's Bir Seba oil field with current flow rate of approximately 17 KBPD • Development: Algeria's Hassi Bir Rakaiz with target 1st phase production in 2021 and Mozambique Area 1 with target first cargo in 2024 Middle East Strong presence in UAE and Oman: • 3 offshore exploration blocks in UAE, partnered with experienced operator • 4 onshore blocks in Oman including PDO (Block 6), largest producing oil asset, and Block 61, largest tight gas development • Stake in OLNG Australia Potential gas development • Sizable undeveloped gas resources in Timor Sea 31#32Thailand, Myanmar and Malaysia "Coming Home" strategy to maintain strong foundation and utilize expertise Myanmar • 3 producing gas fields supplying gas to both Thailand • and Myanmar: Yadana, Yetagun and Zawtika Operate Zawtika project, brought online in March 2014 with current gas supply of 340 MMSCFD in 6M2021 Project Status • Zawtika (80% WI) Production • Yadana (25.5% WI) • Yetagun* (19.3% WI) MOGE3 Appraisal • M3 (80% WI) Thailand Production/Ramp-up Projects Bongkot (66.6667% WI) Average natural gas and condensate sales volume of 919 MMSCFD and 22 KBPD in 6M2021 S1 (100% WI) The largest onshore crude oil production field in Thailand with 6M2021 average crude oil sales volume of 28 KBPD Arthit (80% WI) Average sales volume in 6M2021 was 243 MMSCFD of natural gas and 12 KBPD of condensates MYANMAR S1 Sinphuhom ၁ဝ M3 THAILAND Yadana Zawtika M11 Yetagun MD7 Contract 4 Production phase Contract 4 (60% WI) Exploration phase Average sales rate of 395 MMSCFD for natural gas and 16 KBPD for condensate in 6M2021 B8/32 & 9A E5 PTTEP South China Sea Sabah K SK417 Sabah H SK309 & SK311 SK314A Malaysia Production Block K Project: Kikeh (56% WI), Siakap North-Petai (SNP) (22.4% WI) and Gumusut-Kakap (GK) (6.4% WI) Average production volume in 6M2021 was 25* KBPD of crude oil and 25* MMSCFD of natural gas SK309 and SK311 Project: (59.5% WI) For East Patricia field (42% WI) • Average production volume in 6M2021 was 173* MMSCFD of natural gas and 17* KBPD of condensates and crude Block H Project: Rotan field (56% WI) Remaining Area (42% WI) • First gas delivered in early February 2021 with average production volume in 6M2021 at 142 MMSCFD of natural gas • Full capacity at 270 MMSCFD Exploration For Block K, gross production is net off utilization Sarawak SK410B Project (42.5% WI) • Multi TCF significant discovery . Expected Final Investment Decision (FID) announcement by end of 2022/beginning of 2023 Sarawak SK417 and Sarawak SK405B projects • New Petroleum discoveries with additional well drilling to assess upside potential Erawan Arthit Bongkot MTJDA SK410B MALAYSIA PM415 SK438 SK405B PM407 32 Note: WI-working interest Energy Partner of Choice#33Other South East Asia countries Expanding foothold in the region VIETNAM INDONESIA Vietnam Vietnam 16–1 (28.5% WI) Average sales volume of crude oil was 12 KBPD in 6M2021 • The project is preparing the drilling of additional development wells in order to maintain the production level in 2021. Southwest Vietnam Vietnam B & 48/95 (8.5% WI) Vietnam 52/97 (7% WI) • Field Development Plan was approved by Government • The project is currently in the negotiation process on commercial terms to put forward FID • First production target by end of 2024, and ramp up to full capacity of 490 MMSCFD Production projects Pre sanction projects . Indonesia Natuna Sea A (11.5% WI) • Average sales volume of natural gas was 214 MMSCFD in 6M2021 • The project is preparing the drilling of additional development wells in 2021. PTTEP 33 Energy Partner of Choice#34The Middle East Building strategic presence and gaining access to Upstream oil & gas asset as well as Midstream Complex UAE Oman Abu Dhabi Offshore 1,2 and 3 • High potential prospective resources with significant sizeable discoveries • Located North-west of Abu Dhabi Emirates, United Arab Emirates • Granted the award for exploration in January 2019-2020 • Operated by Eni Abu Dhabi B.V. (70% interest) Persian Gulf Abu Dhabi offshore 3 Abu Dhabi Offshore 1 AGP U.A.E. PDO (Block 6) ADNOC Gas Processing (AGP) • One of the largest gas processing complexes in the world (total capacity of 8 BCFD) JV: 3 plants with capacity of 1.2 BCFD Adnoc: 2 plants with capacity of 6.9 BCFD • Essential to Abu Dhabi and UAE's economy • Sizeable volumes of Propane, Butane and Naphtha offtake • Operated by ADNOC (68% interest) Abu Dhabi Offshore 2 Oman Onshore block 12 *Block awarded in 2019 **Block awarded in 2020 Production phase Exploration phase Midstream OMAN 34 PTTEP OLNG Block 61 Mukhaiza (Block 53) PDO (Block 6) • Largest asset covering around 1/3 of the country ⚫ Long-life asset, produced only 15% of reserves in-place • Average oil production volume of 627 KBPD in Q22021 • Operated by Petroleum Development of Oman (Joint Operating Company) • Mukhaizna (Block 53) • Largest single onshore producing field in Oman Average oil production volume of 96 KBPD in Q22021 • Operated by Occidental Petroleum (47% interest) Oman Onshore Block 12 • Located onshore central part of the Sultanate of Oman · Signed agreement with Oman's Ministry of Oil and Gas (MOG) for exploration and production rights in February 2020 • Operated by Total E&P Oman Block 12 B.V. (80% interest) Oman Block 61 Largest tight gas development in Middle East • Gas and condensate production capacity of 1,500 MMSCFD and 69,000 BPD respectively • Operated by BP Exploration (Epsilon) Limited (40% interest) Oman LNG • The only LNG facility in Oman Processing capacity 10.4 MTPA • • Contracted LNG sales to international buyers: Japan and South Korea • Government of Oman 51% (Operator) Energy Partner of Choice#35Mozambique Area 1 On the path of unlocking value from world class LNG asset MOZAMBIQUE Mozambique MOZAMBIQUE 17,000 Acre LNG Facility Site REPLACEMENT VILLAGE Anadarko Offshore Area 11 Substantial recoverable resources of approximately 75 tcf with scalable offshore development expending up to 50 MTPA GOING EXPORT JETTY AFUNGI MOF -40 KILOMETERS LNG PARK Anadarko Operated OFFSHORE AREA 1 Golfinho/Atum OFFSHORE AREA 4 Mamba Complex Prosperidade . Location and Cost Advantage Close proximity to shore High quality reservoirs capable of flow up to 200 mmcfd per well Access to Asian and European markets LAND AVAILABLE FOR ONSHORE DEVELOPMENT AREA 1 OPERATOR ◆ AREA 4 OPERATOR SHARED INTEREST TT ILLUSTRATION NOT TO SCALE Achievements Legal & Contractual Framework ✔ Plan of Development Approved Onshore & Offshore Contractors Awarded First Mover for the Marine Facility LNG SPAS ~11.1 MTPA FID FID in June 2019 with initial 2 trains of 13.1 MTPA capacity Next milestones Project Finance (2/3 Project Financed) Drilling & Completion Onshore Construction and Offshore Installation Operation Readiness LNG Shipping 35 35 1st Cargo expected 2024 Energy Partner of Choice PTTEP#36America: Mexico and Brazil Entry into high potential petroleum province at exploration stage . • . Mexico Deep-water with high petroleum potentials and attractive fiscal regime Mexico block 12 (2.4) Non-operating partner with 20% participating interest Located in the Mexican Ridges, western Gulf of Mexico Currently evaluating petroleum potential and preparing for an exploration well drilling in 2021 MEXICO • • Mexico block 29 (2.4) Non-operating partner with 16.67% participating interest Located in the Campeche, southern Gulf of Mexico Made two successful deep-water oil discoveries with good quality reservoirs in May 2020 The appraisal plan and exploration plan were approved by the Mexican regulators (CNH) on 25 March 2021. Preparing for exploration well and appraisal drilling. Block 12 善 gob.mx Block 29 Exploration phase Mexico block 12 (2.4) & Mexico block 12 (2.4) 36 88 Barreirinhas Basin BRAZIL Espirito Santo Basin Brazil Deep Water Barreirinhas AP1 • Farm-in 25% from BG Group in 2014 PTTEP • Operated by Shell Brasil (65% interest) . Four offshore exploration blocks: BAR-M-215, BAR-M-217, BAR-M-252 and BAR-M-254 Currently waiting for exploration wells drilling permit from the government BM-ES-23 • Acquired 20% interest from Shell in Q3 2014 • Partnered with Petrobras (65%, operator) and INPEX (15%) • Currently evaluating the petroleum potential for further development Energy Partner of Choice#37Project information 1/5 2021 Key Activities 12 • Ensure gas deliverability level at DCQ*** • Drill development wells • Prepare for decommissioning activities Project Status* Phase PTTEP'S Share Partners (as of April 2021) 6M2021 Average Sales Volume ** Gas (MMSCFD) Liquid (KBPD) Thailand and JDA 1 Arthit OP Production 80% Chevron MOECO 16% 243 4% 2 B6/27 OP Production 100% Chevron 51.66% MOECO 16.71% 3 B8/32 & 9A JV Production 25.001% 48 15 KrisEnergy 4.63% Palang Sophon 2% 4 Bongkot OP Production 66.6667% TOTAL 33.3333% 919 22 • K • Ensure deliverability of production volumes as nominated from the buyer • Drill development wells • Drill development wells • Maintain production level as planned Carry out wells plug and abandonment, and prepare for non-transferred wellhead platforms decommissioning Prepare for decommissioning activities • Ensure gas deliverability level at DCQ*** • Drill development wells Topside reuse • Ensure gas deliverability level at DCQ*** • Deliver production volumes as nominated from the buyer and oil production as planned Prepare for decommissioning activities • Maintain production plateau Explore for additional field potential i.e. new drilling well and EOR/IOR • Prepare for decommissioning activities • Maintain production plateau Contract 3 (Formerly JV Chevron 5 Production 5% Unocal III) MOECO 71.25% 23.75% 501 27 27 • Contract 4 (Formerly JV 6 Production 60% Pailin) Chevron MOECO 35% 395 16 5% • 7 E5 JV Production 20% ExxonMobil Chevron 80% 8 51% JV 8 G4/43 Production 21.375% MOECO 21.25% 1 3 JV 9 G4/48 Production 5% Palang Sophon Chevron MOECO 6.375% 71.25% 2 0.2 23.75% 10 L53/43 & L54/43 OP Production 100% 11 PTTEP1 OP Production 100% 12 S1 OP Production 100% 13 Sinphuhorm OP Production 55% Apico**** ExxonMobil ** Status: OP = PTTEP operatorship / JOC = PTTEP joint operatorship / JV = PTTEP as Joint Venture Partner Sales volume stated at 100% basis. *** DCQ Daily Contractual Quantity **** PTTEP holds indirectly and directly 80.48% participating interest in Sinphuhorm Project. APICO also holds 100% participating interest in Block L15/43 and Block L27/43. 1 • 0.2 • . Explore for additional field potential i.e. new drilling well and EOR/IOR Prepare for decommissioning activities 8 Crude:28 KBPD LPG: 190 MTon/Day 35% 10% 97 0.3 • Maximize crude production by fully implemented the business plan and work activities as planned • 10 years strategy roadmap is being submitted to the management committee to ensure all focused strategic areas will be set up in the long term until end of concession in year 2031 • Ensure gas deliverability ⚫ Drill development well Sinphuhorm new Gas Sales Agreement is under Government's consideration and approval process 37#38Project information 2/5 Project Status* Phase PTTEP'S Share Partners 6M 2021 Average Sales Volume ** 2021 Key Activities (as of April 2021) Gas (MMSCFD) Liquid (KBPD) Thailand and JDA • Study to explore additional field potential 14 L22/43 OP Production 100% 15 MTJDA JOC Production 50% Petronas-Carigali 16 G9/43 OP Exploration 100% • Prepare for decommissioning activities 50% 263 8 • Ensure gas deliverability level at DCQ*** . Activity suspended 17 G1/61 (Erawan) OP Exploration 60% MP G2 (Thailand) Limited 40% 18 G2/61 (Bongkot) OP Exploration 100% Others SEA OP SK309 and SK311** 173 (except 6.4-80% Production/ Block K** SK309 and SK311** 17 1 Malaysia Gumusut- Kakap (GK) Exploration (varied by Varied by permits permits) 25 Block H** Block K** 25 in Block K) 142 TOTAL 31.24% JV 2 Yadana Production 25.5% Chevron 28.26% 767 MOGE 15% JV Petronas-Carigali 40.91018% 3 Yetagun Production 19.3178% MOGE 20.4541% Nippon Oil 19.3178% Myanma Oil and Zawtika 4 OP Production 80% Gas Enterprise 20% 340 (M9 & a part of M11) (MOGE) 5 Myanmar M3 OP Exploration 80% MOECO 20% 6 Myanmar M11 OP Exploration 100% 7 Myanmar MD-7 OP Exploration 50% TOTAL 50% 8 Myanmar MOGE 3 OP Exploration 77.5% Palang Sophon MOECO 10% 10% WinPreciousResources 2.5% *** Status: OP PTTEP operatorship / JOC = PTTEP joint operatorship/ JV = PTTEP as Joint Venture Partner Sales volume stated at 100% basis/ For Malaysia project, gross production is net off unitization DCQ Daily Contractual Quantity 38 • Awarded as an operator for Erawan field (Contract 1, 2 and 3) under PSC (after concession-end in 2022) • Preparing all transitional works including construction of facilities, staff recruitment, Gas Sales Agreement, and related procurement activities, aiming for successful transition and gas production as per commitment. • Awarded as a sole operator under PSC (after concession-end in 2022/2023) Drill appraisal and exploration wells • • Installation new wellhead platforms and drill production wells • Finalise Gas Sales Agreement and Prepare for seamless operation handover ⚫ SK309 and SK311: Pemanis Gas Development Topside Installation and South Acis Satellite infill oil development drilling • Block K: SNP Development Drilling • Block H: Maximize production at plateau 270MMSCFD after first gas in February 2021 • Drill 2nd production well • New DCQ*** proposal and negotiation with PTT • Suspended the production due to the feed gas was not sufficient for the minimum threshold level • Some activities are delayed and process under difficulty due to the political situation and COVID-19 in Myanmar • Waiting for approval of PSC Supplementary • FEED & OE and survey activities • Gas Sales Agreement negotiation Waiting for final termination document from MOGE Leftover material transferring to MOGE in progress (slow progress due to current situation in Myanmar) • Termination process in progress • Leftover material transferring to MOGE in progress (slow progress due to current situation in Myanmar) • Termination process in progress • Leftover material transferring to MOGE in progress (slow progress due to current situation in Myanmar)#39Project information 3/5 Partners Project Status* Phase PTTEP's Share (as of April 2021) Others SEA Vietnam 9-2 JOC Production 6M 2021 Average Sales Volume ** Gas (MMSCFD) Liquid (KBPD) 2021 Key Activities 25% PetroVietnam SOCO 50% 15 3 • Maintain production level 25% PetroVietnam 41% 10 Vietnam 16-1 JOC Production 28.5% SOCO OPECO 28.5% 8 12 2% • 11 Vietnam B & 48/95 JV Exploration 8.5% PetroVietnam MOECO 65.88% 25.62% 73.4% JV PetroVietnam 12 Vietnam 52/97 Exploration 7% 19.6% MOECO Development drilling study support • Maintain production level • Drill development wells • Under procurement process for Equipment and Services Negotiation process on commercial terms in order to push forward the Final Investment Decision (FID) • The first production target at the end of 2024 • Negotiation process on commercial terms in order to push forward the Final Investment Decision (FID) • The first production target at the end of 2024 Premier Oil 28.67% JV KUFPEC 33.33% 13 Natuna Sea A Production 11.5% 214 2 • Drill development wells Petronas Pertamina 15% 11.5% Middle East 1 Abu Dhabi Offshore 1 JV Exploration 30% Eni Abu Dhabi 70% 2 Abu Dhabi Offshore 2 JV Exploration 30% Eni Abu Dhabi 70% 3 Abu Dhabi Offshore 3 JV Exploration 30% Eni Abu Dhabi 70% • Being evaluated for petroleum potential to support future exploration, including G&G report . Preparation for exploration well which to be drilled in Q3/2021 • • Appraisal plan of Pre-existing discovery has been approved by ADNOC Project is on-going with G&G study. Government of Oman 60% 4 PDO (Block 6) JOC Production 2% Shell 34% 627** • Normal operations with daily production around 600 KBD Total 4% Occidental 47% OOCEP 20% 5 Mukhaizna JV Production 1% 96** • Normal operations with daily production around 95 KBD Indian Oil 17% Mubadala 15% 6 Oman Onshore Block 12 Total E&P Oman Block 12 JV Exploration 20% 80% B.V. • • 3D seismic reprocessing (original 3D) in progress Preparation of 3D seismic acquisition (new 3D) BP 40% Makarim Gas 30% 7 Oman Block 61 JV Production 20% Development LLC 647 31 • Completed production ramp up as planned PC Oman Ventures Limited (PETRONAS) 10% Status: OPPTTEP operatorship / JOC = PTTEP joint operatorship // JV = PTTEP as Joint Venture Partner Sales volume stated at 100% basis / For PDO (Block 6) and Mukhaizna projects, gross production is net off unitization 39 99#40Project information 4/5 Partners Project Status* Phase PTTEP's Share (as of April 2021) 6M 2021 Average Sales Volume ** Gas (MMSCFD) Liquid (KBPD) Other International 1 PTTEP Australasia (PTTEP AA) OP Exploration 100% Total, Mitsui, 26.5%,20% JV 2 Mozambique Area 1 ENH, OVL Development 8.5% 15%, 10% OVRL & Oil India, 10%, 10% Bharat Algeria 433a & 416b PetroVietnam 3 JOC Production 35% (Bir Seba) Sonatrach 2021 Key Activities PTTEP • AC/RL7 (Cash Maple) and Oliver (AC/RL12) Field under way to define proper direction in order to increase development opportunities • Other exploration projects: G&G studies • First Cargo is expected by 2024 (Under further assessment) • 1st Debt drawdown in project Finance • The Force Majeure has been declared by the operator for safety reason due to the security incident in Palma. • Project management under FM and study of impacts • Plan to resume the project after safety security • Drill development wells Existing wells intervention • Production respect OPEC+ policy . Drilling development wells • Expected first oil production for the initial phase of around 10,000-13,000 barrels per day (BPD) in 2021 40% 3 25% • Algeria Hassi Bir 4 OP Rekaiz Development 24.5% CNOOC Sonatrach 24.5% 51% 5 Mariana Oil Sands OP Exploration 100% 65% Shell Brasil 6 Barreirinhas AP1 JV Exploration 25% 10% Mitsui E&P Brasil • Waiting for exploration wells drilling permit from the government JV Petrobras 7 Brazil BM-ES-23 Exploration 20% INPEX 65% • Evaluating the petroleum potential for development concept 15% JV PC Carigali Mexico 60% 8 Mexico block 12 (2.4) Exploration 20% Ophir Mexico 20% Repsol Mexico 30% • JV 9 Mexico block 29 (2.4) Exploration 16.67% PC Carigali Mexico Wintershal DEA 28.33% 25% • The geophysical survey processing and interpretation are in progress for further petroleum potential evaluation . Drilling exploration wells Completed drilling of 2 exploration wells in 2020 with successful result. • The drilling operation for exploration well and appraisal drilling is ongoing, and it is expected to complete by Q4/2021. ** Status: OP = PTTEP operatorship / JOC = PTTEP joint operatorship/ JV = PTTEP as Joint Venture Partner Sales volume stated at 100% basis except for Algeria 433a & 416b (production volume) 40 40#41Project information 5/5 Project Status* Phase PTTEP's Share Other International Partners (as of April 2021) Total 30% Sonangol 30% 10 Block 17/06 JV Pre development 2.5% SSI 27.5% Acrep 5% Falcon Oil 5% 11 Potiguar OP Production 50% Petro reconcavo 50% 12 Dunga Midstream Project ** *** JV Production 20% Total OOCEP 6M 2021 Average Sales Volume ** Gas (MMSCFD) Liquid (KBPD) 2021 Key Activities Completed Begonia FEED study (in-house) • Maintain production plateau 0.2 60% 20% • 2 11 Government of Oman 51% Shell 30% Total 5.54% 1 Oman LNG Shareholder On line 2% Korea LNG 5% Mitsubishi 2.77% Mitsui 2.77% Itochu 0.92% ADNOC Gas On line 2 JV Processing (AGP) ADNOC 2% Shell Total Status: OP = PTTEP operatorship / JOC = PTTEP joint operatorship/ / JV = PTTEP as Joint Venture Partner Sales volume stated at 100% basis Products are propane, butane and naphtha. PTTEP • Continue to curb production per OPEC+ agreement to support price Procurement process for designing of Compression, Separation upgrade and Flare package • Engineering of Sea water and Export Line ⚫ Normal operations 68% • Perform midstream operation activities 15% *** 15% • Maintain production and plant integrity with maintenance work as planned . Improving plant's efficiency and capacity with plant debottlenecking as planned 41 Energy Partner of Choice#42Organization structure Ensuring transparency, integrity and good corporate governance President Corporate Governance and Sustainable Development Committee Audit Committee Internal Audit Division Safety, Security, Health and Environment Division Board of Directors CEO Production Non-E&P Business Management Department Asset New Business Development Group Department Operations Support Group Geosciences, Subsurface and Exploration Engineering, and Development Group Enterprise Mission Control Group Department 42 22 Nominating Committee Remuneration Committee Risk Management Committee Legal Division Strategy and Business Development Group Finance and Accounting Group Human Resources, Corporate Affairs and Assurance Group PTTEP Energy Partner of Choice#43Supplementary Index: Ratio & Formula Ratio Formula Lifting Cost ($/BOE) (Operating Exp. - Transportation Cost - Stock Variation - Other expenses not related to lifting) / Production Volume (Operating Exp. + Exploration Exp. + G&A + Royalties + Finance Cost) / Sales Volume (Operating Exp. + Exploration Exp. + G&A + Royalties + Finance Cost + DD&A) / Sales Volume Cash Cost ($/BOE) Unit Cost ($/BOE) Reserves Replacement Ratio Reserves Life Index (Year) Success Ratio Sales Revenue EBITDA EBITDA Margin Return on Equity Return on Capital Employed Simple Effective Tax Rate Total debt Net debt Debt to Equity Net Debt to Equity Total Debt to Capital Total Debt to EBITDA Net Debt to EBITDA EBITDA Interest Coverage Ratio 5-Yr Additional Proved Reserves / 5-Yr Production Volume Proved Reserves / Production Volume Number of wells with petroleum discovery / Total number of exploration and appraisal wells Sales + Revenue from pipeline transportation (Sales + Revenue from pipeline transportation) - (Operating expenses + Exploration expenses + Administrative expenses + Petroleum royalties and remuneration + Management's remuneration) EBITDA / Sales Revenue Trailing-12-month net income / Average shareholders' equity between the beginning and the end of the 12-month period (Trailing-12-month net income + Trailing-12-month Interest Expenses & Amortization of Bond Issuing Cost)/(Average shareholders' equity and average total debt between the beginning and the end of the 12-month period) Income tax expenses / Income before income taxes Short-term loans from financial institution + Current portion of long-term debts + Bonds + Long-term loans from financial institution Total debt-Liquidity Total debt/ Shareholders' equity Net debt / Shareholders' equity Total debt/ (Total debt + Shareholders' equity) Total debt/Trailing-12-month EBITDA Net debt/Trailing-12-month EBITDA Trailing-12-month EBITDA / Trailing-12-month Interest Expenses & Amortization of Bond Issuing Cost 43 PTTEP