#1Investor Presentation 13 May 2022 KKK Member of Dow Jones Sustainability Indices PTTEP Powered by the S&P Global CSA HE ERLQ1 ERLO2#2Cautionary Statement Forward-looking Information PTTEP 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#3Company Introduction ERLQ1 KKK Member of Dow Jones Sustainability Indices PTTEP Powered by the S&P Global CSA HE ERLO2#4PTTEP Overview | E&P Flagship of PTT Group Operating Framework Shareholding Structure High Performance HPO Organization Be Smart GRC Be Good and Compliance Risk Management Governance, PTTEP Sustainable Organization Stakeholder SVC Value Creation Be Responsible 3,969.9 Million shares Business Strategy PTTEP PTT Group 64% Local Institutions 20% Foreign Institutions 11% Retails 5% As of August 2021 HPO & Thrive in Lower Carbon Future Sustainable E&P business Diversification beyond E&P Greenhouse Gas Management Sustain Business Integrity Excellence Smart Assurance GRC in Common Sense Optimize Resources and Create Shared Values Circular Model for E&P Ocean for Life Dow Jones Sustainability Indexes THSI THAILAND SUSTAINABILITY INVESTMENT 2020 FTSE4Good 2014-2021 2016-2021 2016-2021 CDP MSCI DISCLOSURE INSIGHT ACTION Level "A" Level "B" Stock Quote Market Capitalization Sales Revenue Cash Cost PTTEP > 15 Billion USD >90% SEA & ME < 14 USD/BOE 13 AFFORDABLE AND CLEAN ENERGY CLIMATE ACTION 4 8 DECENT WORK AND ECONOMIC GROWTH 12 RESPONSIBLE CONSUMPTION AND PRODUCTION 14 LIFE BELOW WATER 16 PEACE, JUSTICE AND STRONG INSTITUTIONS#5Business Update ERLQ1 KKK Member of Dow Jones Sustainability Indices PTTEP Powered by the S&P Global CSA HE ERLO2#6Transition | G1/61 and G2/61 Note: ARAA Asset Retirement Access Agreement ATA Asset Transfer Agreement OTA PSC SAA Operations Transfer Agreement Production Sharing Contract Site Access Agreement Operatorship transfer completed G1/61 - Erawan Initial production rate 200-250 mmscfd Sole Investment 100% 2019 G1/61, G2/61 PSC signed G1/61 OTA, SAA, ARAA signed G1/61 Prelim Facility Access Agreement signed G2/61 ATA Signed 2020 2021 2022 G1/61 Site Access Delay - G2/61 - Bongkot Transition of 200mmscfd completed Proceed for additional 500mmscfd in Mar 2023 Production rate 700mmscfd G1/61, G2/61 Petroleum sales agreements signed with PTT G1/61, G2/61 PSC effective 24APR202 G2/61 Transition PSC remaining areas G1/61 reaches 800mmscfd 2023 - G1/61 Preparation and Production Ramp-up - 2024 2025 ->#7Our Net Zero Ambition PTTEP 2020 Base Year 2030 30% GHG Intensity* Reduction 2040 50% GHG Intensity Reduction 2050 NET ZERO Greenhouse Gas Emissions E&P, Operational Control SCOPE 1 & 2 用白 பஃ *Intensity refers to GHG released in Tonne CO₂e per thousand tonnes of hydrocarbon production 7#8Pathway to Net Zero GHG Emissions GHG Composition CO, 2 CH HFCS PFCS N₂O SF 6 Net Zero Roadmap NF3 Exploration for Lower Carbon E&P Portfolio E P Net Zero 2050 ~4% >95% Methane Carbon dioxide Greenhouse Gas 2021 2030 ~1% Others Greenhouse Gas generated from PTTEP GHG Management Concept Emission Avoid & Mitigate Remaining Emission Offset NET ZERO Mitigate Avoid Offset Internal Carbon Price Onshore Solar Power Plant Flare Gas / Energy Optimization PTTEP Production and Planet in Balance Roadmap & Key Milestones 2040 Lower Carbon E&P Portfolio Management 2050 NET ZERO Greenhouse Gas Emissions E&P, Operational Control SCOPE 1 & 2 Zero Routine Flare Methane Emission CCS at ART & LLB- Reduction via Tech. Maximize --Renewable Energy Apply Other in Operation Future Clean Energies 8 Forestation Program and Blue Carbon Project Other Offset Program through Ocean for Life#9Business Update | E&P G1/61 Thailand Myanmar Yadana Transition and Operatorship transfer completed 24 Become new operator with 37% interest by 20 July 2022 APR 2022. Proceed to ramp-up activities to achieve 800MMSCFD in 24 months G2/61 Transition of 200MMSCFD completed On track for additional 500 MMSCFD in Mar 2023 Malaysia C UAE Sharjah Onshore Area C 25% stake acquisition completed 1 March 2022 On progress of seismic activity SB412 Obtained new block SB412 from MY Bid Round 2021. PSC signed in March 2022. SK410B Prepare to drill 1 more exploration well in 2022 For LLB-FID expected in 2023 MZA 1 Mozambique 1st Cargo expected in 2025 awaiting local security situation 9 Algeria HBR-Phasel 1st Oil expected in Q2/2022 at 4 KBOED PTTEP#10Business Update | Beyond E&P Green Methanol 24 Jan 2022 Signed a MOU with multiple international firms to explore Green Methanol value chain, with plan of 50KTPA methanol production plant in Singapore What is Green Methanol? CCS 12 January 2022: Established Thailand CCS Project Task Force to develop CCS initiatives 25 April 2022: Signed a MOU with INPEX and JGC to explore on CCS project in Thailand Solar Farm 1st Pilot Solar energy project of PTTEP ~10 MWp, FID mid 2022 and COD early 2023 • 100% owned by FST, 100% offtake by S1 PTTEP Completed FEED and started application of permits . and licenses Total Area 40 acres (113 Rai) in Kampangpetch, NE Thailand Renewable Energy Biogenic CO2 CO CH₂OH Marine Transportation Jt Electrolysis to H₂ H₂ Methanol Synthesis to E-Methanol Northern powerplant Central Industrial Complex Eastern Industrial Complex Southern powerplants Selected CO2 sources 10 ARV 21 April 2022 Establishment of B-Med X, a JV between Cariva, a subsidiary of ARV, and BJC Healthcare, subsidiary of BJC To develop an aesthetic marketplace application and expand to healthcare business such as remote healthcare system CARIVA ABJC#11Financial Results & Guidance ERLQ1 KKK Member of Dow Jones Sustainability Indices PTTEP Powered by the S&P Global CSA HE ERLO2#12Results | Profit and Loss QoQ 321 318 570 513 -192 -252 Q4/21 Q1/22 +2% +10% Increased DCQ for P/L from Average Higher liquid price Average normal operation +57m$ (+10%) Sales Volume Arthit project Selling Price -10% -113$mil Lower unit costs Extra Gains Q4'21: Block K redet and BKT Decom. adj Net Profit P/L from normal operation P/L from non-operating items P/L from normal operation +288m$ (+>100%) PTTEP YOY Unit: million USD 376 318 94 570 282 -252 Q1/21 Q1/22 +12% +27% Oman Block 61 Average Sales Volume and Malaysia SB-H Average Selling Price Higher liquid and gas price -5% Lower unit costs Non- Q1/22 Oil price hedging losses operating items Q4/21 Impairment losses - Mozambique, and Yetagun Non- operating items -346m$ (->100%) Q1/22 Oil price hedging losses Q4/21 Gain from bargain purchase offset with Losses from Brazil assets write-off and oil price hedging -60m$ (-31%) 12#13Results | Sales Volume and Product Price UNIT: BOED 420,965 427,368 416,141 382,877 400,000 55,993 67,360 65,344 Volume Mix 23,419 Rest of World 95,766 300,000 97,980 97,600 85,215 Other SEA Gas Liquid 29% 27% 200,000 Thailand & 264,382 255,625 264,424 274,243 MTJDA 71% 73% 100,000 Q4 2021 Q1 2022 Product Price 2021 Q4 21 Q1 22 Q1 21 Revenue Mix Gas ($/MMBTU) 5.69 5.81 6.07 5.61 Liquid ($/BBL) 66.70 76.17 91.19 56.59 47% 48% ASP ($/BOE) 43.49 46.87 51.35 40.38 Avg. Dubai ($/BBL) 69.39 78.27 96.21 60.01 53% 52% Avg. HSFO ($/BBL) 64.42 71.38 87.96 56.74 (High Sulphur Fuel Oil) Q4 2021 Q1 2022 Note: Include sales volume from ADNOC Gas Processing (AGP) Exclude Oman Block 61 deemed sales volume from tax payment by government ASP: Average Selling Price 13 PTTEP#14Results | Unit Cost Unit: $/BOE 40 30 28.52 29.51 26.54 27.96 Cash Cost 20 15.66 Unit Cost 13.25 Х 13.11 12.10 ✗ 10 DD&A Finance Cost Royalties G&A Exploration Expenses Operating Expenses Lifting Cost Note: 2021 Q4 21 Q1 22 Q1 21 15.27 13.85 13.43 15.86 1.33 1.31 1.35 1.39 3.49 3.69 4.27 3.41 2.22 3.05 2.23 2.12 0.54 0.51 0.15 0.12* 5.67 7.10 5.11 5.06 4.13 4.33 3.87 4.15 * Exclude Exploration assets write-off in Brazil for Q1 21 All Unit Cost shown above exclude costs related to new business The formulas for calculating ratios are provided in the supplementary section for your reference 14 PTTEP#15Results | Cash Flows and Financial Position Note: Cash Flows Unit: million USD 1,394 607 43 394 Others CAPEX Cash flow from operations 170 Tax payment (Before tax payment) 1,394 23,445 PTTEP Financial Position Unit: million USD 24,143 Total Assets 6,923 7,645 Other Liabilities 4,094 4,095 Interest-bearing Debt EBITDA margin 78% 3,346 2,559 Free cash flow 833m$ 12,428 12,403 Equity DEC 2021 Sources Uses MAR 2022 Include Short-term investment Net of adjustment for the effect of exchange rate changes on cash and cash equivalents 15 DEC 2021 MAR 2022#16Results | Financial Guidance and Debt Profile Financial Guidance Average Sales Volume Average Gas Price* KBOED Q2 USD/MMBTU Q2 ~467 ~467 Full Year ~6.2 ~6.4 Full Year * Based on average Dubai oil price in 2022 at 96 $/BBL, with sole investment in G1/61 (Erawan) Debt Profile 2021 Q1 2022 Debt to Equity 0.33 0.33 Debt to EBITDA 0.80 0.72 Average Cost of Debt 3.38% 3.38% Average Loan Life 12.7 Yrs Interest Rate 83:17 12.4 Yrs 83:17 (Fixed: Float) Note: Debt excludes Hybrid bonds 16 Unit Cost USD/BOE Q2 ~28-29 Full Year EBITDA Margin % of Sales Revenue Q2 82 ~70-75% Credit Ratings STANDARD & POOR'S RATINGS SERVICES MCGRAW HILL FINANCIAL BBB stand-alone rating International Full Year National MOODY'S Baa2 stand-alone rating TRIS RATING BBB+ Stable Fitch Ratings Baa1 Stable BBB stand-alone rating BBB+ Stable AAA Stable PTTEP#17Thank you and Q&A @ Member of Dow Jones Sustainability Indices PTTEP Powered by the S&P Global CSA +66 2 537 4000 [email protected] http://www.pttep.com#18B/A KKK Member of Dow Jones Sustainability Indices PTTEP Powered by the S&P Global CSA Supplementary information Q1/22 Financial Highlights Profit and Loss Statement Reserves SD/ESG Five-year Investment Plan Debt Maturity Profile Thailand Oil & Gas Market Projects Information Organization Structure Ratio and Formula 19 20 21 22-23 24 24 25 26-28 29-43 HE ERLQ1 R 44 45 49 ERLO2#19Results | Q1/22 Highlights $ % Terminology Change Q1'22 Highlights (QoQ) - Recurring Net income Non-recurring Net income Average Selling price +10% Liquid +20% Gas +4% Average Sales volume +2% (6KBOED) mainly from increased DCQ of Arthit project from 220 mmscfd to 280mmscfd Outstanding Oil Price Hedging volume $. Q1'22: 11.55 mmbbl Q4'21: 15.4 mmbbl Q4'21 Extra gains Other income from Malaysia Block K redetermination Reduction in DDA from Bongkot Decommissioning Liabilities adjustment 513 Profit (Loss) from normal operation Profit (Loss) from non-operating items PTTEP Profit (Loss) from normal operation Q1'22 vs Q4'21 Non-operating items in Q1'22 Unit: million USD Q4'21 Extra gains 170 54 Redeter. of Block K Increase P/L mainly from product price 59 Bongkot Decom. adjustment Q4 21 57 m$ increase P/L from normal operation 19 240 12 570 Oil price hedging losses Others 318 Q1 22 P/L from normal operation 252m$ Loss from non-operating items Q1 22 Net Profit#20Results | Profit and Loss Statement Total Revenues Sales (1) Sales Volume (BOED) (2) Sales Price (US$/BOE) Gain from a bargain purchase (3) Others Total Expenses Major Expenses: Unit: million USD PTTEP Q1 22 Q4 21 %QoQ Q1 21 % YoY FY2021 2,083 1,989 5% 1,779 17% 7,314 2,030 1,867 9% 1,391 46% 6,731 427,368 420,965 2% 382,877 12% 416,141 51.35 46.87 10% 40.38 27% 43.49 350 (100%) 342 53 122 (57%) 38 39% 241 1,776 1,671 6% 1,405 26% 6,118 Operating Expenses Exploration Expenses G&A DD&A Loss on Financial Instruments 197 275 (28%) 174 13% 861 6 20 (70%) 149 (96%) 226 93 125 (26%) 75 24% 355 517 420 23% 547 (5%) 2,202 245 7 >100% 98 >100% 234 Impairment Loss on Assets 183 (100%) 183 Income Tax Expenses 497 448 11% 192 >100% 1,287 Share of profit (loss) from associates and JV 11 3 >100% 2 >100% 15 Net Profit 318 321 (1%) 376 (15%) 1,211 Profit (Loss) from normal operation 570 513 11% 282 >100% 1,479 Profit (Loss) from non-operating items (252) (192) (31%) 94 (>100%) (268) Non-operating items breakdown: Oil Price Hedging (240) 5 (>100%) (107) (>100%) (284) Note: Tax from Effect of FX Effect from FX and others Impairment Loss on Assets Exploration assets write-off Gain from a bargain purchase (1) Include Oman Block 61 deemed sales revenues from tax payment by government (2) Exclude Oman Block 61 deemed sales volume from tax payment by government 20 (3) Consisted of Revenue from Pipeline, Gain from FX, Forward Contract, and Gain from Oil price Hedging, and Malaysia Block K redetermination of participating interest in Q4'21 1 (>100%) (9) 78% (10) (10) (15) 33% 5 (>100%) 12 (183) 100% (183) (145) 100% (145) 350 (100%) 342#21PTTEP Overview | Reserves MMBOE Reserves Life 2021 by Geography 2,500 Domestic International 2,123 11.7 Years 2,123 2,000 1,647 1,622 1,350 773 54% 1,500 7.5 Years 55% 507 548 46% 45% 1,000 1,350 500 1,140 1,074 • • As of December 2021 2019 2020 2021 Proved (P1) Probable (P2) 5-Year Average Proved Reserves Replacement Ratio (RRR) 2019 1.5X 2020 1.5X 2021 1.9X P1 P1 + P2 2021 by Product Type Gas Liquid 2,123 1,350 30% 26% 70% 74% P1 P1 + P2 Based on total production of natural gas, condensate, and crude oil (including LPG) of 495 KBOED for the year ended December 31, 2021 Figures include reserves from equity method 24 21 PTTEP#22SD & ESG | Disclosure and Ratings Social Human Development Resource Human Economic Rights ESG Climate & Disclosure Environment Health & Safety Innovation & Technology Supply Chain ESG Standards Governance, Risk Management & Compliance ESG Ratings S&P Global Ratings ESG Rating MSCI 100 80 AAA PTTEP Pe Woodside TotalEnergies 60 HESS REPSOL AA A equinor Woodside REPSOL ESG Rating HESS Santos PTTEP MOODY'S ESG Credit Impact 1 2 bp equinor Chevron BBB ExxonMobil bp Chevron eni TotalEnergies HESS Woodside PTTEP eni equinor bp Chevron GRI Global Reporting Initiative Reporting Standards (GRI Standards) Oil and Gas Sector Disclosures (OGSD) + CDP DISCLOSURE INSIGHT ACTION Climate Change SUSTAINALYTICS a Morningstar company ESG Risk Rating A A- B B- bp equinor REPSOL 0-10 PTTEP eni TotalEnergies HESS 10-20 Source: S&P Global, MSCI, Moody's, CDP, SUSTAINALYTICS' websites As of December 2021 REPSOL TotalEnergies ExxonMobil 20-30 40 ExxonMobil Santos PetroChina 20 20 PTTER BB B CCC Woodside REPSOL equinor PTTEP eni TotalEnergies HESS PetroChina D D- 30-40 bp ExxonMobil Santos 5 No Response Chevron Woodside PetroChina ExxonMobil Santos 40+ Chevron PetroChina#23SD & ESG | Targets and Progress Q1/2022 13 CLIMATE ACTION GHG Management GHG Intensity Reduction Target 25% By 2030 (2012 base year) Net Zero By 2050 PROGRESS Reduction of GHG Emission Intensity As of 2021, 24.1% Reduction (2012 base year) (2.35 MMTCO2e) Flare Gas Recovery 12 CONSUMPTION RESPONSIBLE AND PRODUCTION Circular Model Zero Waste to Landfill by 2030 ≥50% of Main Structure Reuse by 2030 2020 ♦PROGRESS◆ Waste to Landfill 2025 Smart Logistics Logistics operation Recover excess gas to Fugitive & Vent Zero Hazardous waste to landfill Zero Industrial waste to landfill 2030 Zero waste to landfill production process Leak monitoring and preventing Energy Efficiency Operation efficiency and energy saving efficiency improvement CCUS Study Carbon Capture Storage Trap from flare and inject it into suitable storage site 14 WATER LIFE BELOW Ocean for Life PTTEP Net Positive Impact of Biodiversity & Ecosystem Services in Offshore Operations vs baseline by 2030 ≥50% Increase in Local community income vs baseline by 2030 PROGRESS Ocean Health & Biodiversity Monitoring Pilot Project of Seagrass Plantation at Koh Samui and Koh Taen, Surat Thani Upcycling High Volume Waste Sand to Zeolite: Successfully synthesized prototype zeolite from nano-silica and further identify potential use case (moisture absorbent) Wave gauge & Water Level Auto-profiling and cleaning robot Multi-parameter water quality & Current profiler Develop Meteorological & Oceanographic (Met-Ocean) Data Station at ART Ramp Up CSR around Ocean Flagship Projects CNT from flare gas: Ongoing FEED Study for CNT Pilot Unit at S1 CO2 to carbonate-based product: Ongoing to fabricate prototype testing unit CCS: Ongoing CCS Pre-FEED at ART and LLB Oil sludge conversion to Graphene: Complete prototype unit fabrication 23 23 Phetchaburi Prachuap Samut Songkhram Chumphon Surat Thani • New 3 New Area Selection for Aquatic Animal Hatchery Learning Centers (Chonburi, Sumut Prakarn, Samut Sakorn) • 4,000 Rais Mangrove Forestation Area Selection (Chumphon, Surat Thani and Nakhon Si Thammarat) Rayong Nakhon Si Thammarat Songkhla (3 Centers) Established 15 Conservation Areas & 7.8 km² Fish Home Areas Pattani#24Not included Sole Investment in G1/61 (Erawan) Finance | 5-year Sales Volume & Investment Budget PTTEP CAGR +5% In KBOED 600 467 463 473 493 528 416 35 22 Rest of World 7 8 400 2 Sales Volume 167 164 166 171 205 150 Other SEA & Middle East 200 264 293 291 298 300 288 Thailand &MTJDA 2021 2022 2023 2024 2025 2026 In MMUSD 5,774 6,000 5,666 5,371 5,633 5,429 5,065 OPEX 2,300 1,996 Investment 4,000 2,449 1,994 2,020 2,172 457 809 1,081 1,608 1,237 770 2,000 241 2,760 CAPEX 2,568 2,556 2,172 2,123 1,625 CAPEX (Dev & Pre-sanction projects (2) (Producing projects (3) 2021 2022 2023 2024 2025 2026 5 Years (2022-2026) G1/61: April CAPEX 16,533 OPEX TOTAL 10,631 27,164 (1) Capacity 800 MMSCFD G2/61: April Capacity 200 MMSCFD G2/61: March Capacity 700 MMSCFD Key Project Start-up Algeria HBR (phase I): 1H Capacity 10-13 KBPD Note: Subject to regulatory approval and FID timing (2) Development & Pre-sanction projects include Mozambique LNG, Algeria HBR, SK410B and Southwest Vietnam (3) Including exploration and appraisal in all projects and head office CAPEX, and new businesses 24 24 Mozambique LNG: 2H Capacity 13 MTPA SK410B: 1H (1) Initial Capacity 800-1000 MMSCFD Southwest Vietnam: 2H (1) Algeria HBR Capacity 490 MMSCFD (Full phase): 2H Capacity 50-60 KBPD#25As of March 2022 USD Millions Finance | Debt Maturity Profile 700 600 500 400 300 200 100 0 2022 2023 480 2024 2025 Note: Excludes Hybrid bonds Unit: USD Millions or equivalent after cross currency swap 600 2026 182 2027 25 2028 500 2029 349 350 2030 2031-2041 2042 2043-2058 490 2059 650 PTTEP#26Thailand | Market Update Thailand Energy Overview Natural Gas Supply FY 2020 FY 2021 2M 2022 FY 2020 FY 2021 2M 2022 MMSCFD Domestic Myanmar LNG 3,902 Domestic Domestic 35 34 。 Constant in energy demand, while the energy prices continue to soar 33 32 Myanmar LNG 4,726 31.3 31 Myanmar LNG 4,699 0 1,000 2,000 3,000 4,000 5,000 Natural Gas Consumption MMSCFD Electricity Industry GSP NGV 4,196 Electricity Industry GSP NGV 4,395 Electricity Industry GSP NGV 4,368 0 1,000 2,000 3,000 4,000 5,000 Source: Energy Policy and Planning Office (EPPO) FY2020 FY2021 2M 2022 o As of February 2022, compared with the same period of last year: significantly declined in domestic supply and lower LNG imports. Electricity Generation GWH 30 30 30.0 29 29 32.1 Exchange Rate Movement (USD/THB) 33.4 33.9 28 Q1 Q2 Q3 Q4 ठ 2021 33.3 Q1 Q2 32 PTTEP 34.2 (High) 33.5 33.2 Q3 Q4 2022 Consensus on the exchange rate mostly depends on 56% 3% 16% 13% 12% 33,123 o Thailand economic recovery in particular the tourism sector 54% 2% 17% 16% 11% 209,717 o Bank of Thailand and Federal Reserve monetary policy tightening schedule o Geopolitical tensions and uncertainty from the Russia-Ukraine war 55% 2% 18% 14% 10% 206,034 Natural Gas Imported Hydro Electricity Renewable Energy Coal & Lignite Source: Bank of Thailand, Bloomberg Forecast based on Bloomberg Consensus as of 31 March 2022 26 32.6 (Average) 31.5 (Low)#27Thailand | Energy Value Chain 2M 2021 Thailand's Oil and Gas Demand Crude Oil & Condensate ~ 1.1 m BOE/D Imports ~87% Domestic 13% Natural Gas ~0.7 m BOE/D Imports - 29% Domestic ~ 71% Source: Energy Policy and Planning Office (EPPO) and Department of Mineral Fuels (DMF) 3M 2022 Thailand Petroleum Production % by Petroleum Type and Area Onshore 9% Gas 74% Offshore 91% Liquid 26% Midstream Gas: operated by PTT Transmission Pipelines Gas Separation Plants Oil: PTT participates through subsidiaries % Production by Company Refineries 27 PTTEP 46% Others 54% Downstream Petrochemicals Oil and gas marketing PTTEP#28Thailand | Oil and Gas Balance Oil Balance*** Maintains stability supply through adequate refining capacity SALES PRODUCTION SUPPLY Import (87%) 1022 KBD Gulf of Thailand (62%) Indigenous (13%) 150 KBD Imported Refined Petroleum Products 72 KBD Crude/ Condensate 950 KBD Total Refining Capacity in Thailand 1,242 KBD Crude/ Condensate 135 KBD PTT's Associated Refineries 770 KBD (TOP, PTTGC, IRPC) Other Refineries 472 KBD (SPRC, ESSO, BCP) Refined Products 1,041 KBD * Refined Products 163 KBD Domestic 962 KBD ** Export 178 KBD Crude Export 15 KBD Source: PTT * Note: ** Refined product from refineries = 958 KBD, including domestic supply of LPG from GSPs and Petrochemical Plants = 83 KBD Not included Inventory *** Information as of 2M 2022 **** Information as of Year 2021 MMSCFD @ Heating Value 1,000 Btu/ft³ 28 PTTEP 42% Others 58% Natural Gas Balance* **** Main driver of the Thailand economy Onshore (2%) 2,733 MMSCFD Bypass Gas 322 MMSCFD 6 Gas Separation Plants Total Capacity 2,870 MMSCFD Import (36%) LNG 56% Myanmar 44% @Actual Heat 104 MMSCFD 1,583 MMSCFD 909 MMSCFD (20%) Petrochemical Feedstock Ethane Propane LPG (12%) NGL Industry Household LPG Transportation NGL (8%) Methane 1,502 MMSCFD Power (59%) Industry (18%) NGV (3%) PTTEP#29Projects | Diversified portfolio Kazakhstan Central Asia • Dunga onshore oil field (acquired from Partex in 2019) Oil sands North & South America Oil Opportunities in an early phase: • Deepwater exploration in Brazil and Mexico Book Value of Assets by region Total assets USD 24.14 billion Others 3% Middle East 14% Africa 17% As of Mar 2022 Southeast Asia 26% Thailand 40% Note: As of March 2022 *Subject to local security situation Oil Piped Gas Oil Gas/LNG Oil I Oil PTTEP Thailand Home Base • 63% of total sales volume (3M2022) • Key producing assets include Bongkot, Arthit, Contract 4 and S1 • G1/61 (Erawarn) transition completed • G2/61 (Bongkot) transition in process (1st 200mmscfd commenced in Apr 2022) GAS/LNG Southeast Asia Strategic Area •23% of total sales volume, mainly from Malaysia and Myanmar (3M2022) • Recent multiple petroleum discoveries in Malaysia including Lang Lebah • New exploration block in Malaysia, Sabah SB412 • Other producing assets in Vietnam (oil) and Indonesia (gas) Africa An area for growth, key projects include: . Algeria's Bir Seba oil field with current flow rate of approximately 17 KBPD • Algeria's Hassi Bir Rakaiz oil field target 1st oil production in Q2/22. • Mozambique LNG project target 1st cargo in late 2025* Middle East Strategic Area in Oman and UAE • 14% of total sales volume (3M2022) • Oman: 4 onshore blocks including PDO (Block 6), largest producing oil asset, and Block 61, largest tight gas development UAE: 3 offshore and 1 onshore exploration blocks Australia Potential gas development • Sizable undeveloped gas resources in Timor Sea 29 29#30Projects | Thailand, Myanmar and Malaysia Myanmar • 3 producing gas fields supplying gas to both Thailand and Myanmar: Yadana, Yetagun and Zawtika • Operate Zawtika project, start up in March 2014 with current gas supply of 326 MMSCFD for 3M2022 Project Status • Zawtika (80% WI) Production • Yadana (25.5% WI) • Yetagun* (19.3% WI) FDP • M3 (100% WI) MYANMAR S1 Sinphuhom MOGE3 Thailand ၁ဝ Production/Ramp-up Projects Bongkot (66.6667% WI) Yadana M3 THAILAND Average natural gas and condensate sales volume of 819 MMSCFD and 22 KBPD in 3M2022 Zawtika M11 MD7 Yetagun B8/32 & 9A S1 (100% WI) The largest onshore crude oil production field in Thailand with 3M2022 average crude oil sales volume of 25 KBPD Arthit (80% WI) Contract 4 Average sales volume in 3M2022 was 277 MMSCFD of natural gas and 15 KBPD of condensates Contract 4 (60% WI) • Average sales rate of 403 MMSCFD for natural gas and 16 KBPD for condensate in 3M2022 G1/61 (60% WI) • Operatorship transfer completed. Current production rate of 200-250MMSCFD. • Sole investment 100% G2/61 (100% WI) • GBS transition completed at production rate of 200 MMSCFD. Production phase Exploration phase 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) (7.2% WI) Average production volume in 3M2022 was 32* KBPD of crude oil and 27* MMSCFD of natural gas SK309 and SK311 Project: (59.5% WI) For East Patricia field (42% WI) • Average production volume in 3M2022 was 193* MMSCFD of natural gas and 20* KBPD of condensates and crude Block H Project: Rotan field (56% WI) Remaining Area (42% WI) • First gas early February 2021 with average production volume in 3M2022 at 275 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 gas discovery in Lang Lebah Field . Expected to reach Final Investment Decision (FID) in 2023 Sarawak SK417 and Sarawak SK405B projects • New Petroleum discoveries with additional well drilling to assess upside potential Sabah SB412 • New block awarded from 2021 Malaysia Bid Round • The project is under preparation for Exploration activities. Note: WI - working interest Erawan Arthit Bongkot MTJDA SK410B MALAYSIA PM415 SK438 SK405B PM407 30 30#31Projects | Vietnam and Indonesia Production projects Pre sanction projects VIETNAM INDONESIA Vietnam VIỆT NAM Vietnam 16–1 (28.5% WI) Average sales volume of crude oil was 13 KBPD in 3M2022 • In 2022, the project has plan to drill 2 development wells in Q3 Q4/2022. 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, with production capacity approximately 490 MMSCFD Indonesia Natuna Sea A (11.5% WI) Average sales volume of natural gas was 199 MMSCFD in 3M2022 31 PTTEP#32Projects | Middle East UAE Oman PTTEP Abu Dhabi offshore 3 Abu Dhabi Offshore 1 U.A.E. Abu Dhabi Offshore 2 OMAN Production phase Exploration phase Midstream Sharjah AGP Onshore Area C PDO (Block 6) 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 660 KBPD for 3M2022 Operated by Petroleum Development of Oman (Joint Operating Company) 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) · Mukhaizna (Block 53) Largest single onshore producing field in Oman Average oil production volume of 94 KBPD for 3M2022 • Operated by Occidental Petroleum (47% 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) 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) Sharjah Onshore Area C • High gas & condensate potential with the possibility of integrating with surrounding fields • Located in the central part of Sharjah Emirate, United Arab Emirates Operated by Eni Abu Dhabi B.V. (50% interest) • 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 Persian Gulf Oman Onshore block 12 *Block awarded in 2019 **Block awarded in 2020 • Operated by ADNOC (68% interest) Note: ADNOC: Abu Dhabi National Oil Company 32 32#33Projects | Rest of the World ALGERIA Algeria Bir Sebah • Block 433a & 416b • PVEP 40% (operator), PTTEP 35% Hassi Bir Rekaiz • Blocks 443a, 424a, 414ext & 415ext for Crude Oil. • Sonatrach 51% (operator), PTTEP 49% MOZAMBIQUE Mexico Mexico block 12 (2.4) Non-operating partner with 20% participating interest Located in the Mexican Ridges, western Gulf of Mexico • Currently evaluating the petroleum potential for further way forward Mozambique Mozambique Area 1 • High quality reservoirs capable up to 200mmscfd per well • LNG capacity 13.1 MTPA (2 trains) • TotalEnergies 26.5% (operator), PTTEP 8.5% • Construction phase . • Brazil Barreirinhas AP1 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 PTTEP Mexico block 29 (2.4) Non-operating partner with 16.67% participating interest Located in the Campeche, southern Gulf of Mexico 2 successful deep-water oil discoveries in May 2020 Currently undergoing a pre-development study MEXICO BRAZIL#34Projects Details | Thailand 1 Arthit PTTEP Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid Latest Status (KBPD) Operator Production PTTEP 80% 277 15 Increase Sales Gas DCQ from 220 to 280 MMSCFD in Feb'22 Chevron 20% MOECO 4% Operator Production PTTEP 100% . 2 B6/27 JV Production 3 B8/32 and 9A PTTEP 25.01% 60 50 Chevron 51.66% MOECO 16.71% KrisEnergy 4.63% Palang Sophon 2% 4 Bongkot Operator Production PTTEP 66.67% 819 TotalEnergies 33.33% 11 Prepare for decommissioning activities Ensure gas deliverability level at DCQ Drill development wells Preparation for wellhead platform reuse in 2022-23 22 22 Infills drilling for BKT Sole investment Maintain production level as planned Carry out wells plug and abandonment, Pipeline cleaning and Hg decontamination Wellhead platform & sealine and FSO1 PLEM Decommissioning (Non- transferred asset) Decommissioning activities JV Production 5 CT3 (formerly Unocal III) PTTEP Chevron 5% 71.25% 206 13 MOECO 6 OCT4 (formerly Pailin) JV Production . PTTEP 60% 403 16 Ensure gas deliverability level at DCQ . Chevron 35% MOECO 5% JV Production 7 E5 PTTEP 20% 8 Drill development wells Topside reuse Ensure gas deliverability level at DCQ EXXON MOBIL 80% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during Q1/2022 *** Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner **** DCQ Daily Contractual Quantity 34 =4#35Projects Details | Thailand PTTEP Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) 8 G4/43 JV Production 1 Sales Vol Liquid (KBPD) 2 Latest Status PTTEP 21.375% Chevron 51% Deliver production volumes as nominated from the buyer and oil production as planned MOECO 21.25% Palang Sophon 6.375% 9 G4/48 JV M Production 1 0.1 PTTEP 5% Decommissioning activities Chevron 71.25% MOECO 23.75% 10 L53/43 & L54/43 OP Production PTTEP 100% 11 PTTEP1 OP Production PTTEP 100% 12 S1 OP Production 8 PTTEP 100% 13 Sinphuhorm OP Production PTTEP 95 55% Apico 35% EXXON MOBIL 10% OP 14 L22/43 Production PTTEP 100% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during Q1/2022 Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 35 85 0.5 0.2 Crude: 25 KBPD LPG: 183 MTon/Day 0.3 On-going 5th drilled well Plan to complete 6 wells around mid of Apr’22 and commence 1st oil by Jul'22 Plan for production facilities debottlenecking and relocation projects to handle additional gross production from new wells. Maintain production plateau Relocate facilities from PTTEP1 to L54/43 to be minimized CAPEX cost Production optimization and long-term development plan are on-going for business plan and work activities identification according to 10 years strategy Ensure gas deliverability Preparing the drilling campaign for 2 wells during Q2 - Q4 2022 On-going execution plan of total 5 drilling wells scheduled in Q4 2022. Plan to prepare for the resume production or exit strategy in future after drilling results confirmed.#36Projects Details | Thailand PTTEP Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) Latest Status 15 MTJDA JOC Production 260 10 PTTEP 50% Facility Readiness for Additional Gas to DP1 (Thailand) for 30-50 MMSCFD Petronas Carigali 50% 16 G9/43 OP Exploration PTTEP 100% Activity suspended 17 G1/61 (Erawan) OP Exploration PTTEP 60% Mubadala 40% 18 G2/61 (Bongkot) OP Exploration PTTEP 100% PTTEP denotes respective PTTEP subsidiaries participating in the project Note: * ** Sales volume represent average volume for 100% of the project during Q1/2022 *** Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 36 96 Awarded as an operator for Erawan field (Contract 1, 2 and 3) under PSC (after concession-end in 2022) Preparing all transitional works including platform site survey under Site Access Agreement#2, construction of facilities, staff recruitment, and related procurement activities, aiming for successful transition and gas production as per commitment. Signed Gas, Crude and Condensate Sale agreements Awarded as a sole operator under PSC (after concession-end in 2022/2023) Signed Gas and Condensate Sale agreements Continue drilling development wells#37Projects Details | Myanmar, Malaysia, Other SEA Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) 1 Block K (Malaysia) OP (Kikeh & SNP) Production PTTEP - Kikeh JV (GK) - Siakap-North Petai field (SNP) Kikeh 56% SNP 22.4% GK 7.17% 32* 27 ** - Gumusut-Kakap field (GK) 2 Sarawak SK309 and SK311 OP Production PTTEP 42-59.5% 193 ** 20 ** (Malaysia) 3 Block H (Malaysia) OP Production PTTEP 42-56% 275 ** 4 Malaysia - Other projects OP Exploration PTTEP 42.5 - 80% (varied by permits) Latest Status PTTEP SNP Phase 2 development well commenced production. GK Phase 3 development drilling commenced by Unit Operator. Pemanis Gas Development and South Acis Satellite infill oil development drilling completed and commenced production Continue at higher production 280+ MMSCFD SK410B: Plan to drill 1 exploration well in 200 and expected FID in 2023 for LLB SK417, SK405B, SK438: Planning and preparing for the drilling of appraisal and exploration wells in 2022 exploration campaign. SB412 Preparing for exploration activities. Be appointed to be an Operator with effective in Jul'22. 5 Yadana JV M Production 732 PTTEP 25.5% (Myanmar) • TotalEnergies 31.24% Under process of operatorship transfer Chevron 28.26% MOGE 15% Yetagun 6 (Myanmar) Production PTTEP 44 19.3178% Maintain the production volume after resuming production in Oct'21. JV Petronas- 40.91018% Carigali MOGE Nippon Oil 20.4541% 19.3178% Zawtika M9 & a part of M11 Production PTTEP 326 80% Some activities are delayed and process under difficulty due to 7 (Myanmar) OP Myanma Oil and 20% the COVID-19 and political situation in Myanmar. Gas Enterprise (MOGE) Note: * ** *** PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during Q1/2022 except Malaysia (Production volume 100%) / For Block K, gross production is net off unitization Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 37#38Projects Details | Myanmar, Malaysia, Other SEA Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) PTTEP Latest Status M3 Exploration Waiting for approval of PSC Supplementary PTTEP 100% 8 (Myanmar) OP MD-7 Exploration PTTEP 50% Termination process in progress 9 (Myanmar) OP TotalEnergies 50% 10 9-2 9 JOC Production 12 4 Maintain production level PTTEP 25% (Vietnam) Vietnam Oil and 50% Procurement for drilling campaign of 1 development well Gas Group Pharos Energy 25% 11 16-1 JOC Production 2 13 PTTEP 28.5% (Vietnam) Vietnam Oil and 41% Maintain production level Procurement for drilling campaign of 2 development wells Gas Group Pharos Energy 28.5% OPECO 2% B & 48/95 JV Exploration PTTEP 8.5% 12 (Vietnam) Vietnam Oil and 65.88% Gas Group MOECO 25.62% 52/97 13 (Vietnam) JV Exploration PTTEP 7% Vietnam Oil and 73.4% Gas Group MOECO 19.6% 14 Natuna Sea A (Indonesia) JV M Production 199 1 Monitoring Power Plants progress Negotiation process on commercial terms in order to push forward the Final Investment Decision (FID) The first production target at the end of 2025 Monitoring Power Plants progress Negotiation process on commercial terms in order to push forward the Final Investment Decision (FID) The first production target at the end of 2025 Maintain production level PTTEP 11.5% Premier Oil 28.67% KUFPEC 33.33% Petronas 15% Pertamina 11.5% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during Q1/2022 *** Status: OP=PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 88#39Projects Details | Middle East PTTEP Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid Latest Status (MMSCFD) (KBPD) 1 Abu Dhabi Offshore 1 (UAE) JV Exploration PTTEP 30% Eni Abu Dhabi 70% 2 Abu Dhabi Offshore 2 (UAE) JV Exploration PTTEP 30% Being evaluated for petroleum potential to support future exploration, including G&G report Continued drilling the first exploration well Eni Abu Dhabi 70% 3 Abu Dhabi Offshore 3 JV Exploration I PTTEP 30% G&G study is on-going (UAE) Eni Abu Dhabi 70% 4 Sharjah Onshore Area C JV Exploration PTTEP 25% (UAE) Eni Abu Dhabi 50% Completed the acquisition of 25% interest on 1 March 2022 Seismic activity is on-going. SNOC 25% 5 PDO Block 6 (Oman) JOC Production 660 ** PTTEP 2% Normal operations with daily production around 600 KBD Government of Oman 60% Shell 34% TotalEnergies 4% 6 Mukhaizna (Oman) JV Production 94 ** PTTEP 1% Normal operations with daily production around 95 KBD Occidental 47% OOCEP 20% Indian Oil 17% Mubadala 15% 39 99 Sales volume represent average volume for 100% of the project during Q1/2022 except for PDO Block 6 and Mukhaizna (Production volume 100%) Status: OP = PTTEP operatorship / JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project#40Projects Details | Middle East Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid (MMSCFD) (KBPD) 7 Oman Onshore Block 12 JV Exploration PTTEP 20% Total E&P Oman Block 12 B.V. 80% 8 Oman Block 61 JV Production PTTEP BP 1,471 61 20% 40% Makarim Gas 30% Development LLC PC Oman Ventures 10% Limited (PETRONAS) Note: PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during Q1/2022 *** Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 40 40 Latest Status 3D seismic reprocessing (original 3D) in progress 3D seismic acquisition (new 3D) is in process for tendering PTTEP Full production capacity of natural gas and condensate in according to the Sales and Purchase Agreement#41Projects Details | Rest of the World Project Name Status Phase 1 PTTEP Australasia (PTTEP AA) Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) OP Exploration PTTEP 90%-100% 2 Mozambique Area 1 JV Development PTTEP 8.5% TotalEnergies, Mitsui, 26.5%,20% ENH, OVL 15%, 10% OVRL & Oil India, 10%, 10% Bharat 3 Algeria 433a & 416b (Bir Seba) JOC Production PTTEP 35% 17 ** PetroVietnam 40% Sonatrach 25% 4 Algeria Hassi Bir Rekaiz OP Development PTTEP 49% Sonatrach 51% 5 Mariana Oil Sands OP Exploration PTTEP 100% (Canada) 6 Brazil JV Exploration PTTEP 25% Barreirinhas AP1 Shell Brasil 65% Mitsui E&P Brasil 10% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during Q1/2022 except for Algeria 433a & 416b (production volume) *** Status: OP = PTTEP operatorship / JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 41 Latest Status PTTEP • • AC/RL7 (Cash Maple) and Oliver (AC/RL12) Field: under way to define proper direction in order to increase development opportunities Tenacious and Oliver: On-going for well abandonment campaign Other exploration projects: G&G studies First Cargo is expected by 2025, subject to local security situation 1st Debt drawdown in project Finance Force Majeure was declared by the operator for safety reason due to the security incident in Palma. Plan to resume construction activities after security and safety restored in Cabo Delgado province Drilling of 2 development wells are on-going in Q1 2022. • Target to tie-in and produce 2 new wells in 2022 Existing wells intervention • Production respect OPEC+ policy • Continue drilling development wells Expected first oil production for the initial phase of around 10,000-13,000 barrels per day (BPD) in Q2 2022 Groupement (JOC) establishment in Q2 2022 Waiting for exploration wells drilling permit from the government#42Projects Details | Rest of the World PTTEP Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid Latest Status (MMSCFD) (KBPD) 7 Brazil BM-ES-23 JV Exploration PTTEP 20% Evaluating the petroleum potential for development concept Petrobras 65% INPEX 15% 8 Mexico block 12 (2.4) JV Exploration PTTEP 20% Evaluating the petroleum potential for further way forward PC Carigali Mexico 60% Ophir Mexico 20% 6 Mexico block 29 (2.4) JV M Exploration PTTEP 16.67% Field pre-development study is in progress. Repsol Mexico 30% PC Carigali Mexico 28.33% Wintershal DEA 25% 10 Block 17/06 JV (Angola) M Pre-development PTTEP 2.5% TotalEnergies 30% Sonangol 30% Plan to FID in the middle of 2022 for the eastern area Finalized Internal committees and Stakeholders alignment leading to Begonia FID SSI 27.5% • Launched Forsythia and Gardenia development study on 18 January 2022 Acrep 5% Falcon Oil 5% 11 Dunga (Kazakhstan) JV M Production 2 11 PTTEP 20% TotalEnergies OOCEP 60% Procurement process Compression package and Gathering Lines Engineering of Separation Upgrade, Flare package and facilities Facilities modification works 20% Note: ** *** PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during Q1/2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 42#43Projects Details | Mid-stream Note: PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during Q1/2022 Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) 1 Oman LNG [OMAN] Shareholder Production PTTEP 2% Government of 51% Oman Shell 30% TotalEnergies 5.54% Korea LNG 5% Mitsubishi 2.77% Mitsui 2.77% Itochu 0.92% 2 ADNOC Gas Processing [UAE] JV Production PTTEP 2% ADNOC 68% Shell 15% TotalEnergies 15% Note: PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during Q1/2022 *** Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 43 Normal Operations Latest Status PTTEP Perform midstream operation activities Maintain production and plant integrity with maintenance work as planned#44Organization Chart Corporate Governance and Sustainable Development Committee Audit Committee Internal Audit Division Safety, Security, Health and Environment Division New Business Division Strategy and Business Development Group Geosciences, Subsurface and Exploration Group Engineering, and Board of Directors Nominating and Remuneration Committee Risk Management Committee Chief Executive Officer Legal Division Enterprise Transformation Department Development Group Domestic Production Asset Group International Production Asset Group Operations Support Group 44 Human Resources, Corporate Affairs and Assurance Group Finance and Accounting Group PTTEP#45Ratio and Formula Lifting Cost ($/BOE) Cash Cost ($/BOE) Unit Cost ($/BOE) Reserves (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 5-Yr Additional Proved Reserves / 5-Yr Production Volume Replacement Ratio Net debt Debt to Equity Total debt-Liquidity Total debt/ Shareholders' equity Net Debt to Equity Net debt / Shareholders' equity Total Debt to Total debt/(Total debt + Shareholders' equity) Capital Total Debt to EBITDA Total debt / Trailing-12-month EBITDA Reserves Life Index Proved Reserves / Production Volume Net Debt to EBITDA Net debt/Trailing-12-month EBITDA (Year) Success Ratio Sales Revenue EBITDA Number of wells with petroleum discovery / Total number of exploration and appraisal wells Sales + Revenue from pipeline transportation EBITDA Interest Coverage Ratio Trailing-12-month EBITDA / Trailing-12-month Interest Expenses & Amortization of Bond Issuing Cost Crude oil To convert EBITDA Margin Return on Equity Return on Capital Employed (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) Simple Effective Income tax expenses / Income before income taxes Tax Rate Total debt Short-term loans from financial institution + Current portion of long-term debts + Bonds + Long-term loans from financial institution From Tonnes (metric) Kilolitres Barrels US gallons Barrels/day Natural gas and LNG Tonnes (metric) Kilolitres Barrels Multiply by US gallons Tonnes/year 1 1.165 7.33 0.8581 1 6.2898 0.1364 0.159 307.86 264.17 42 0.00325 0.0038 0.0238 To convert 49.8 Billion cubic Metres NG Billion cubic feet NG Million tonnes oil equivalent Million tonnes Trillion BTU MBOE LNG From Multiply by 1 billion cubic metres NG 1.000 35.315 0.860 0.735 34.121 5.883 1 billion cubic feet NG 0.028 1.000 0.024 0.021 0.966 0.167 1 petajoule NG 0.028 0.981 0.024 0.021 0.952 0.164 1 million tonnes oil equivalent 1.163 41.071 1.000 0.855 39.683. 6.842 1 million tonnes oil LNG 1.360 48.028 1.169 1.000 46.405 8.001 1 trillion British thermal units 0.029 1.035 0.025 0.022 1.000 0.172 1 million barrels oil equivalent 0.170 6.003 0.146 0.125 58.000 1.000 45