#1KKK PTTEP Investor Presentation Thailand Focus 2022 25 August 2022#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#3KKK PTTEP Company Introduction#4PTTEP Overview | E&P Flagship of PTT Group Shareholding Structure Operating Framework 3,969.9 PTT 64% Local Institutions 20% Million shares Foreign Institutions 11% Retails 5% As of latest book closing Aug 2021 Stock Quote Market Capitalization Sales Revenue Cash Cost PTTEP > 17 Billion USD > 90% SEA & ME ~ 15 USD/BOE High Performance HPO Organization Be Smart GRC and Compliance Governance, Risk Management Be Good Strategy E&P Growth Create Value from Existing Assets Maintain Competitive Unit Cost Expand Gas portfolio Drive LNG business PTTEP PTTEP Sustainable Organization Stakeholder SVC Value Creation Be Responsible Decarbonization E&P Net Zero 2050 GHG Emission Reduction and Technology Development CCS Projects Renewable and Future energy at operation sites Emission Offsetting and Ocean for Life Dow Jones Sustainability Indexes THSI THAILAND SUSTAINABILITY INVESTMENT 2020 FTSE4Good 2014-2021 2016-2021 2016-2021 MSCI Level "A" CDP DISCLOSURE INSIGHT ACTION Level "B" Technology Beyond E&P Power Business Business Opportunities and Future Energy In-house Technology 4#5PTTEP Overview | Diversified asset portfolio Central Asia Kazakhstan • Dunga onshore oil field (acquired from Partex in 2019) North America Oil Opportunities in an early phase: • Deepwater exploration in Mexico Book Value of Assets by region Total assets USD 24.19 billion Others 3% Middle East 14% Africa 17% As of Jun 2022 Southeast Asia 26% Thailand 40% . Note: As of June 2022 Subject to local security situation Oil Piped Gas Oil Gas/LNG Oil PTTEP Thailand Home Base • 62% of total sales volume (6M2022) • Key producing assets include G1/61, G2/61, Bongkot, Arthit, Contract 4 and S1 • G1/61 (Erawan) transition completed • G2/61 (Bongkot) transition in process (1st 200mmscfd commenced in Apr 2022) GAS/LNG Southeast Asia Strategic Area • 22% of total sales volume, mainly from Malaysia and Myanmar (6M2022) • Multiple petroleum discoveries in Malaysia including Lang Lebah in SK410B • New exploration block in Malaysia, Sabah SB412 • Other producing assets in Vietnam (oil) and Indonesia (gas) I 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 with recent 1st oil production in Jun 22. • Mozambique LNG project target 1st cargo in late 2025* Middle East Strategic Area in Oman and UAE • 16% of total sales volume (6M2022) • 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 LO 5#6KKK PTTEP Business Update#72022 Half-year Highlights G1/61 Thailand Operatorship transfer completed 24 Apr 2022 Operatorship transfer completed 20 Jul 2022 Yadana Myanmar New Assets Malaysia SB412 UAE Sharjah Area C MTJDA annexation PTTEP Safeguard National energy security G1/61 Erawan +21 KBOED Arthit +10 KBOED Oman Block 61 +10 KBOED New Volume (Y.O.Y.) Drive growth New Assets & Volume Net Zero 2050 Target set and roadmap identified Own Projects and Business collaboration (PTT Group / Inter. Partners) 281,747 tCO₂e CO2 reduction from company's operations Paid to Thai Govt in form of tax, royalty, and other renumerations 7 Decarbonization CCS Net Zero 2050 and CCS Continuous contribution ~50,000 Social & Environmental MMTHB#8Strategy Refinement E&P Growth Decarbonization Beyond E&P Create Value from Existing Assets Maximize Production Accelerate Development Turn Discovery to Production Competitive Unit Cost Expand Gas portfolio Drive LNG business E&P Net Zero GHG Emission Reduction & Technology Development CCS Projects Renewable and Future energy at operating sites Emission Offsetting and Ocean for Life Technology ARV, In-house Tech Power Business G2P, L2P, Renewables Business Opportunities and Future Energy CCUS, H2 G1/61 and Yadana Ops Transfer HBR 1st Oil Phase 1 MZB 1st LNG Cargo (Late 2025) Develop SK410 LLB (FID 2023) Develop HBR Phase 2 (FID 2026) Development Sarawak clusters Key Activities CCS at Arthit, Sinphuhom, Lang Lebah Energy Efficiency Zero Routine Flare Reforestation Scale up ARV Develop G2P (FID 2023) Solar S1 (COD early 2023) Seeking opportunity in Renewables, OCCUS and H2 8 PTTEP#9Projects Update Thailand E&P • Maintain production G1/61 and speed up activities FY2022 FY2023 FY2024 200-250 MMSCFD 300-500 MMSCFD 500-800 MMSCFD • Technical review Bidding round 2022 (G1/65, G2/65, G3/65) • SK410B LLB FEED in progress, FID 2023 AI AND ROBOTICS VENTURES varuna Malaysia . Participating in Bid Round 2022 • Drilling campaigns SK314A, SK405B, SK438 in progress Myanmar • Yadana operatorship transfer completed 20 July 2022 • Yetagun withdrawal completed 31 May 2022 SKYLLER Mozambique • MZA1 pending site re-enter, 1st LNG cargo late 2025 CARIVA Algeria • HBR 1st Oil commenced Jun 2022, estimated sales volume 7 KBPD during Q3-Q4/22 UAE • Offshore 2 exploration well was successfully drilled and discovered approximately 2.5-3.5 TCF of raw gas Explore farm-in opportunities, new bidding rounds 9 ROVULA Beyond E&P MOU with Krungthai Bank to pilot ASEAN's first National Corporate Identification (NCID) platform, digitizing the Corporate KYC process for bank account opening Delivered the Green area management web application for the "OUR Khung BangKachao” project, for Chaipattana Foundation to implement Smart Farming • MOU with Nam Thuan Energy Investment JSC for cooperation on the technology and use of smart drone solutions for renewable energy projects in Vietnam ⚫ MOU with Thyssenkrupp to expand and develop engineering and industrial markets in Thailand, Germany and Southeast Asia Launched "Arvic" application for personal health assistant platform that aggregates health data from various sources into one place, "Beaut" for wellness marketplace connecting customers and wellness service providers, and "Nextcercise" for personal exercise tracking Successfully demoed subwater inspection by inhouse tech "XPLORER" to EGAT at Sirindhorn Dam (the world largest floating solar plant) PTTEP wanaunuGuñinno easoudr V SKYLLER MO IGNINGEREMO 口 00 390#10CCS - Key contributor to Net Zero Assessment criteria Capacity CO₂ Injectivity to store CO2 Enablers Technical Infrastructure and Technology used for CCS Containment Effectiveness Measurement, monitoring, and verification (MMV) Environment & Public Public awareness Environmental impacts monitoring ART CCS for EPNET ZERO Production Platform Natural Gas Natural Gas PTTEP CO CO CO₂ Pipeline CO₂ CO₂ Membrane Removal Transportation Gas Processing 10 * 000 PTTEP Business Model & Cost TEAM Investment vs Return, Possible reduction credits STANDARDS REGULATIONS POLIC Policy & Regulations Govt. Policies, Subsidy, and Legal framework around CCS Storage Reinjection Platform & Wells Saline Aquifer Depleted Reservoir#11KKK PTTEP Financial Results#12Profit and Loss Q2/2022 Key events Start-up of G1/61 and G2/61 PSC On 24 April 2022 QoQ 318 570 Algeria Hassi Bir Rekaiz 1st oil In June 2022 Withdrawal from Yetagun project PTTGL divestment in Myanmar, effective 31 May 2022 YOY 600 Net Profit 647 -47 -252 P/L from normal operation PTTEP Unit: million USD 600 647 P/L from non-operating items 222 349 -47 -127 Q1/22 Q2/22 Q2/21 P/L from +9% G1/61 PSC +8% +8% Global oil price trend Upfront OPEX of G1/61 normal operation +77m$ (+14%) Average Sales Volume Average Selling Price Unit Cost P/L from normal operation +298m$ (+85%) +5% G1/61 PSC Q2/22 +32% +6% Global oil price trend Upfront OPEX of G1/61 Average Sales Volume Average Selling Price Unit Cost Non- operating items +205m$ (+81% Less oil price hedging losses QoQ 12 Non- operating items +80m$ (+63%) Less oil price hedging losses YoY#13Volume and Price PTTEP 465,459 UNIT: BOED 443,126 446,519 416,141 427,368 77,207 413,168 Volume Mix 400,000 68,068 71,308 55,993 65,344 45,867 Rest of World Gas Liquid 98,166 102,239 97,885 95,766 97,600 93,774 Other SEA 300,000 27% 28% 200,000 Thailand & 73% 72% 290,086 264,382 264,424 272,819 277,326 273,527 MTJDA 100,000 0 Q1 2022 Q2 2022 Product Price 2021 Q1 22 Q2 22 Q2 21 6M 2022 6M 2021 Gas ($/MMBTU) 5.69 6.07 6.10 5.59 6.08 5.60 Revenue Mix Liquid ($/BBL) 66.70 91.19 105.47 63.98 98.72 60.52 Weighted Avg. ($/BOE) 43.49 51.35 55.61 42.19 53.59 41.35 48% 52% Avg. Dubai ($/BBL) 69.39 96.21 108.22 67.02 102.17 63.62 Avg. HSFO ($/BBL) 64.42 87.96 104.67 61.21 96.32 58.98 52% 48% (High Sulphur Fuel Oil) Note: Include sales volume from ADNOC Gas Processing (AGP) Exclude Oman Block 61 deemed sales volume from tax payment by government 13 Q1 2022 Q2 2022#14Unit Cost Unit: $/BOE 40 28.79 28.52 27.72 30 26.54 27.24 27.57 Cash Cost Unit Cost 20 15.46 13.25 13.11 11.62 14.34 ☑ 11.84 ☑ 10 2021 Q1 22 Q2 22 Q2 21 6M 2022 6M 2021 DD&A 15.27 13.43 13.33 15.62 13.38 15.73 Finance Cost 1.33 1.35 1.50 1.27 1.43 1.33 Royalties 3.49 4.27 4.22 3.42 4.24 3.42 G&A 2.22 2.23 2.47 1.97 2.36 2.03 Exploration Expenses 0.54 * 0.15 0.40 0.19 0.28 0.16 Operating Expenses. 5.67 5.11 6.87 4.77 6.03 4.90 Lifting Cost 4.13 3.87 4.35 3.91 4.12 4.02 Note: * Exclude Exploration assets write-off in Brazil for Q2 21, 6M 21, and 2021 All Unit Cost shown above exclude costs related to new business The formulas for calculating ratios are provided in the supplementary section for your reference 14 PTTEP#15Cashflow, Financial Position, and Interim Dividends Cashflow & Financial Position Interim Dividend Unit: million USD Inflow Outflow Tax paid CAPEX 1,117 Cash flow from operations 2,737 (Before tax payment) 784 Dividend paid Others 361 228 2,559 EBITDA Margin 76% PTTEP XD Date Record Date Payment Date 15 Aug 22 16 Aug 22 26 Aug 22 Unit: THB per share 6.00 2,806 6.00 1H 2H 5.00 5.00 Beginning cash 4.25 4.25 (Dec-21) Ending cash 4.00 3.75 Note: * Include Short-term investment (Jun-22) 3.25 3.00 2.75 2.75 Net of adjustment for the effect of exchange rate changes on cash and cash equivalents 2.00 23,445 24,189 Total Assets Other Liabilities 6,923 7,122 4,094 Interest-bearing Debt 12,428 Equity 12,824 4,243 4.25 2.25 1.50 1.75 2.00 1.50 0.00 2017 2018 2019 2020 2021 1H2022 Payout Ratio % of Net Profit 88 55 49 77 50 50 % of Profit from Normal Operation 63 33 51 53 71 41 11 38 Dec-21 Jun-22 15#16Guidance, Debt Profile and Ratings PTTEP Outlook Ratings TRIS Q3 2022 FY 2022 RATING AAA Stable BBB+ STANDARD & POOR'S RATINGS SERVICES MCGRAW HILL FINANCIAL Stable BBB stand-alone rating Sales Volume (KBOED) ~481 ~465 MOODY'S Baa2 stand-alone rating Baa1 Stable BBB+ Fitch Ratings Stable BBB stand-alone rating Gas Price (US$/MMBTU) ~6.4 ~6.4 Debt Profile 2021 Q2' 2022 Unit Cost (US$/BOE) Profitability (EBITDA Margin) -29-30 Debt to Equity 0.33 0.33 Debt to EBITDA 0.80 0.69 Average Cost of Debt 3.38% p.a. 3.73% p.a 70-75% Average Loan Life 12.7 Yrs 13.4 Yrs Interest Rate (Fixed: Float) 83:17 83:17 * Based on average Dubai oil price in 2022 at 99 $/BBL 16#17PTTEP Member of Dow Jones Sustainability Indices Powered by the S&P Global CSA Thank you and Q&A @ +66 2 537 4000 [email protected] http://www.pttep.com#18Supplementary information Profit and Loss Statement KKK PTTEP 19 Reserves 20 Finance 21-22 SD/ESG 23-26 Thailand Oil & Gas Market 27-29 Projects Information 30-43 Organization Structure 44 Ratio and Formula 45#19Results | Profit and Loss Statement Total Revenues Sales (1) Sales Volume (BOED) (2) Sales Price (US$/BOE) Gain from a bargain purchase Others (3) Total Expenses Major Expenses: Unit: million USD PTTEP Q2 22 Q1 22 %QoQ Q2 21 % YoY 6M 22 6M 21 %YTD FY2021 2,469 2,083 19% 1,767 40% 4,543 3,546 28% 7,314 2,383 2,030 17% 1,729 38% 4,413 3,120 41% 6,731 465,459 427,368 9% 443,126 5% 446,519 413,168 8% 416,141 55.61 51.35 8% 42.19 32% 53.59 41.35 30% 43.49 350 (100%) 342 86 53 62% 39 >100% 130 76 71% 241 1,882 1,776 +6% 1,548 22% 3,649 2,953 24% 6,118 Operating Expenses Exploration Expenses G&A DD&A Loss on Financial Instruments 291 197 48% 193 51% 488 367 33% 861 17 6 >100% 7 >100% 23 156 (85%) 226 112 93 20% 83 35% 205 158 30% 355 565 517 9% 629 (10%) 1,082 1,176 (8%) 2,202 245 (100%) 125 (100%) 237 223 6% 234 Impairment Loss on Assets 183 Income Tax Expenses 610 497 23% 321 90% 1,106 513 >100% 1,287 Share of profit (loss) from associates and JV 13 11 18% 2 >100% 24 5 >100% 15 Net Profit 600 318 89% 222 >100% 918 598 54% 1,211 Profit (Loss) from normal operation 647 570 14% 349 85% 1,217 631 93% 1,479 Profit (Loss) from non-operating items (47) (252) 81% (127) (63%) (299) (33) >100% (268) Non-operating items breakdown: Oil Price Hedging (38) (240) 84% (141) 73% (278) (248) (12%) (284) (11) (2) (>100%) (100%) (13) (9) (44%) (10) 2 (10) >100% 14 (86%) (8) 19 (>100%) 12 (183) (145) 100% (145) 350 (>100%) 342 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 (3) Consisted of Revenue from Pipeline, Gain from FX, Forward Contract, and Gain from Oil price Hedging. 19#20PTTEP 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 1,140 500 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 20 20 PTTEP#21Finance | 5-year Sales Volume & Investment Budget (announced December 2021) CAGR +5% PTTEP In KBOED 600 467 463 473 493 528 416 35 7 8 9 22 400 2 Sales Volume 167 164 166 171 205 150 Rest of World 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 2,300 OPEX 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 2,568 2,556 2,172 2,123 1,625 2021 2026 CAPEX (Dev & Pre-sanction projects (2) CAPEX (Producing projects (3) 5 Years (2022-2026) 2022 2023 2024 2025 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 Note: Subject to regulatory approval and FID timing Algeria HBR (phase I): 1H Capacity 10-13 KBPD (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 21 21 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 Not included Sole Investment in G1/61 (Erawan)#22As of June 2022 USD Millions Finance | Debt Maturity Profile 700 600 500 400 300 200 100 0 2022 2023 2024 2025 Note: Excludes Hybrid bonds Unit: USD Millions or equivalent after cross currency swap 600 2026 182 2027 22 22 2028 648 2029 379 2030 350 2031-2041 179 2042 2043-2058 490 2059 650 PTTEP#23Our 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 *Intensity refers to GHG released in Tonne CO2e per thousand tonnes of hydrocarbon production 23 23#24SD & ESG | Disclosure and Ratings Human Social Development Resource Human Economic Rights ESG Climate & Disclosure Environment Health & Safety Innovation & Technology Supply Chain ESG Standards Governance, Risk Management & Compliance GRI Global Reporting Initiative Reporting Standards (GRI Standards) Oil and Gas Sector Disclosures (OGSD) As of December 2021 ESG Ratings S&P Global Ratings ESG Rating MSCI 100 80 AAA equinor Woodside ESG Rating HESS MOODY'S ESG Credit Impact CDP DISCLOSURE INSIGHT ACTION Climate Change SUSTAINALYTICS a Morningstar company A 1 AA PTTEP Woodside HESS re TotalEnergies 60 REPSOL Santos 2 REPSOL PTTEP A 160. TotalEnergies eni bp equinor Chevron eni BBB ExxonMobil Chevron HESS Woodside equinor PTTEP eni bp A- B B- bp equinor REPSOL 0-10 PTTEP en TotalEnergies HESS 10-20 ESG Risk Rating Source: S&P Global, MSCI, Moody's, CDP, SUSTAINALYTICS' websites 24 REPSOL TotalEnergies ExxonMobil 20-30 Chevron 40 ExxonMobil Santos PetroChina 20 20 PTTER BB B CCC Woodside REPSOL equinor PTTEP re eni TotalEnergies HESS PetroChina D D- 30-40 ExxonMobil Santos bp 5 No Response Chevron Woodside PetroChina ExxonMobil Santos 40+ Chevron PetroChina#25SD & ESG Update 13 CLIMATE ACTION Decarbonization GHG Intensity Reduction Target 25% By 2030 (2012 base year) Net Zero By 2050 PROGRESS Reduction of GHG Emission Intensity As of Q2/2022, 25.2% Reduction (2012 base year) (0.28 MMTCO₂e Reduction since Jan 2022) Flare Gas Recovery Recover excess gas to production process Energy Efficiency Operation efficiency and energy saving Fugitive & Vent Leak monitoring and preventing RESPONSIBLE CONSUMPTION 128 AND PRODUCTION Circular Model Zero Waste to Landfill by 2030 ≥50% of Main Structure Reuse by 2030 ♦PROGRESS◆ Waste to Landfill 2020 Zero Hazardous waste to landfill 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 aau АРТТЕР MOU signed with Hydro- Informatics Institute (HII) on Ocean Data Platform 2025 Zero Industrial waste to landfill 2030 Zero waste to landfill An denamiesti งาน Renteenee-TE OCEAN 225 DATA PLATFORM Smart Logistics Logistics operation efficiency improvement EP Net Zero 2030 2040 2020 Base Year 30% 50% GHG Intensity Reduction GHG Intensity Reduction wwwww Carbon Capture Storage Trap from flare and inject it into suitable storage site Upcycling High Volume Waste Sand to Zeolite: Completed prototype study result to turn sand waste from petroleum production at Zawtika project to nano silica and zeolite with good moisture absorption rate 2050 NET ZERO GHG Emissions E&P, Operational Control SCOPE 1 & 2 Oil sludge conversion to Graphene: Completed lab scale unit fabrication Exploring for Lower Carbon E&P Portfolio EP Production and Planet in Balance Blue Carbon Initiatives on mangrove, seagrass, seaweed, seashell and coral to potentially support GHG offsetting and increasing biodiversity Ramp Up CSR around Ocean Flagship Projects Phetchaburi Prachuap Samut Songkhram Chumphon Surat Thani New Rayong Nakhon Si Thammarat Songkhla (3 Centers) Pattani ⚫ 2 Aquatic Animal Hatchery Learning Centers Established (Phetchaburi and Prachuap Khiri Khan) • More than 10 km² Conservation Area & Fish Home • Seafood Product Value Enhancement to improve community income 25 25#26SD Update – Ocean for Life 14 LIFE BELOW WATER TARGET: - Net Positive Impact of Biodiversity & Ecosystem Services in Offshore Operations (Compare to 2019 base year) by 2030 ≥50% Increase Community Income for Local Community that Participated in our Program (Compare to Before Project Implementation) by 2030 Guardian of the Ocean Offshore + Mid-Shore CLEAN & FRIENDLY OPERATION OCEAN HEALTH & PROGRESS ฺสสน APTTEP พิธีลงนามบันทึกข้อตกลงความร่วมมื การพัฒนาแพลตฟอร์มข้อมูลวิทยาศาสตร์ทางทะเล ระหว่าง บริษัท ปตท. ารวจและผลิตปิโตรเลียม จํากัด (มหาชน) และ สถาบันสารสนเทศทรัพยากรน้ำ (องค์การมหาชน) Sugnfl 29 unnu 2565 OCEAN DATA PLATFORM aau PTTEP MOU signed with Hydro- Informatics Institute (HII) to Develop the Ocean Data Platform and Ensure Sustainable Marine Resources Ramp Up CSR around Ocean Flagship Projects Ocean Waste Management Mangrove Forestation PTTEP Ocean Health & Biodiversity Monitoring Blue Carbon Initiatives on mangrove, seagrass, seaweed, seashell and coral to potentially support GHG offsetting and increasing biodiversity KU PTTEP KASEI SART UNIVERSITY Aquatic Animal Hatchery Learning Center Sea Turtle Conservation Coastal Conservation Area & Fish Home Seafood Product Value Enhancement Onshore + Nearshore: Collaboration Network & CSR BIODIVERSITY MONITORING Offshore RAMP UP CSR AROUND OCEAN 68,488 kg. Waste Collected (Accumulated 99,570 Kg.) 1,000 Rais with 2,750 tCO2 Absorption 26 26 2 New Centers Established (Accumulated 8 Centers) Renovated Buildings and Provided Medical Equipment in 3 Provinces 17 Locations in 9 provinces (Accumulated 10.3 Km²) 48% of Community Income Increased from 2 Provinces Information as of July 2022#27Thailand | Market Update Thailand Energy Overview Natural Gas Supply FY 2020 FY 2021 5M 2022 FY 2020 FY 2021 5M 2022 MMSCFD Domestic Myanmar LNG 4,378 Domestic Myanmar LNG 4,726 Domestic Myanmar LNG 4,699 0 1,000 2,000 3,000 4,000 5,000 Natural Gas Consumption MMSCFD Electricity Industry GSP NGV 4,339 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 5M 2022 o Increase in energy demand & become closer to demand before COVID-19 pandemic, along with high level of energy prices o As of May 2022, compared with the same period of last year: significantly declined in domestic supply, while gas from Myanmar and LNG imports remained constant. Electricity Generation 55% 39 38 37 36 35 34 33 32 31.3 31 30.0 30 GWH 29 20 3% 16% 15% 11% 33,123 54% 2% 17% 16% 11% 209,717 55% 2% 18% 14% 10% 206,034 Natural Gas Imported | Hydro Electricity Renewable Energy Coal & Lignite 22 27 32.1 Exchange Rate Movement (USD/THB) Q1 Q2 Q3 2021 33.9 PTTEP 37.5 36.5 (High) 35.5 35.3 35.0 (Average) 34.0 33.3 33.5 (Low) 33.4 74 Q4 Q1 22 Q2 Q3 Q4 2022 Consensus on the exchange rate mostly depends on o General investor risk-off sentiment from persistent inflation and supply chain disruptions 。 Bank of Thailand and Federal Reserve monetary policy tightening schedule o Thailand tourism recovery as lockdown measures ease and countries reopen Source: Bank of Thailand, Bloomberg Forecast based on Bloomberg Consensus as of 14 July 2022#28Thailand | Energy Value Chain 5M 2022 Thailand's Oil and Gas Demand Crude Oil & Condensate ~ 1.1 m BOE/D Imports ~87% Domestic 13% Natural Gas ~ 0.8 m BOE/D Imports - 36% Domestic ~ 64% Source: Energy Policy and Planning Office (EPPO) and Department of Mineral Fuels (DMF) 6M 2022 Thailand Petroleum Production % by Petroleum Type and Area Onshore 10% Gas 74% Offshore 90% Liquid 26% Midstream Gas: operated by PTT Transmission Pipelines Gas Separation Plants Oil: PTT participates through subsidiaries % Production by Company Refineries 28 PTTEP 53% Others 47% Downstream Petrochemicals Oil and gas marketing PTTEP#29Thailand | Oil and Gas Balance Oil Balance*** Maintains stability supply through adequate refining capacity SALES PRODUCTION SUPPLY Import (88%) 1032 KBD Gulf of Thailand (53%) Indigenous (12%) 146 KBD Imported Refined Petroleum Products 60 KBD Crude/ Condensate 972 KBD Total Refining Capacity in Thailand 1,242 KBD Crude/ Condensate 130 KBD PTT's Associated Refineries 770 KBD (TOP, PTTGC, IRPC) Other Refineries 472 KBD (SPRC, ESSO, BCP) Refined Products Refined 1,054 KBD * Products 165 KBD Domestic 957 KBD ** Export 181 KBD Crude Export 16 KBD Source: PTT Note: * ** Refined product from refineries = 971 KBD, including domestic supply of LPG from GSPs and Petrochemical Plants = 83 KBD Not included Inventory ***Information as of 3M 2022 **** Information as of 3M 2022 MMSCFD @ Heating Value 1,000 Btu/ft³ 29 PTTEP 49% Others 51% Natural Gas Balance* **** Main driver of the Thailand economy Onshore (2%) 2,346 MMSCFD Bypass Gas 171 MMSCFD 6 Gas Separation Plants Total Capacity 2,870 MMSCFD 846 MMSCFD (19%) Import (45%) LNG 63% Myanmar 37% @Actual Heat 108 MMSCFD 1,950 MMSCFD Petrochemical Ethane Propane Feedstock LPG (12%) NGL Industry Household LPG Transportation NGL (7%) Methane 1,329 MMSCFD Power (60%) Industry (18%) NGV (3%) PTTEP#30Projects | Thailand, Myanmar and Malaysia Myanmar Production Zawtika (80% WI) Operate Zawtika project, start up in March 2014 with current gas supply of 322 MMSCFD for 6M2022 Yadana (37.1% WI) Become an operator of Yadana project on July 20, 2022 Exploration M3 (100% WI) Awaiting development MYANMAR $1 Sinphuhom Thailand E5 Production/Ramp-up Projects Yadana M3 THAILAND Bongkot (66.6667% WI) Zawtika Average natural gas and condensate sales volume of 751 MMSCFD and 20 KBPD in 6M2022 MD7 B8/32 & 9A S1 (100% WI) The largest onshore crude oil production field in Thailand with 6M2022 average crude oil sales volume of 25 KBPD Arthit (80% WI) Average sales volume in 6M2022 was 287 MMSCFD of natural gas and 16 KBPD of condensates Contract 4 (60% WI) Average sales volume in 6M2022 was 393 MMSCFD of natural gas and 15 KBPD of condensate G1/61 (60% WI) • Operatorship transfer completed. First year production rate of 200-250MMSCFD. • Sole investment 100% G2/61 (100% WI) • GBN transition completed. Production rate at 200 MMSCFD Contract 4 Production phase Exploration phase G1/61 Arthit Bongkot & G2/61 MALAYSIA PTTEP South China Sea SB412 Sabah H Sabah K SK417 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 6M2022 was 25 KBPD of crude oil and 28 MMSCFD of natural gas SK309 and SK311 Project: (59.5% WI) For East Patricia field (42% WI) • Average production volume in 6M2022 was 198 MMSCFD of natural gas and 18 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 6M2022 at 256 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 MTJDA | SK410B PM415 SK438 SK405B PM407 80 30#31Projects | Vietnam and Indonesia Production projects Pre sanction projects VIETNAM INDONESIA Vietnam 52.97 Bac Lieu PTTEP Vietnam 16–1 (28.5% W) Average sales volume of crude oil was 13 KBPD in 6M2022 • 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 187 MMSCFD in 6M2022 31#32Projects | Middle East UAE Oman PTTEP 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 • Operated by ADNOC (68% interest) Persian Gulf Abu Dhabi offshore 3 Sharjah AGP Onshore Area C PDO (Block 6) OLNG Block 61 Mukhaiza (Block 53) Abu Dhabi Offshore 1 U.A.E.O Abu Dhabi Offshore 2 OMAN Oman Onshore block 12 *Block awarded in 2019 **Block awarded in 2020 Production phase Exploration phase Midstream PDO (Block 6) • Largest asset covering around 1/3 of the country · . Mukhaizna (Block 53) Largest single onshore producing field in Oman Average oil production volume of 94 KBPD for 6M2022 · • Long-life asset, produced only 15% of reserves in-place Operated by Occidental . Average oil production volume of 660 KBPD for 6M2022 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) . Petroleum (47% interest) Oman Block 61 Largest tight gas development in Middle East • Gas and condensate production capacity of 1,500 MMSCFD and 65,000 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) 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 Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) Operator Production PTTEP 80% 289 16 Chevron 20% MOECO 4% Operator Production PTTEP 100% 1 Arthit 2 B6/27 JV Production 3 B8/32 and 9A PTTEP Chevron 25.01% 51.66% 47 10 MOECO 16.71% KrisEnergy 4.63% Palang Sophon 2% 4 Bongkot Operator Production PTTEP TotalEnergies 66.67% 33.33% 751 20 20 Production PTTEP 60% 398 Chevron 35% MOECO 5% JV Production PTTEP 20% 7 EXXON MOBIL 80% JV 5 Contract 4 (Pailin) M 16 E5 Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during 6M2022 Status: OP=PTTEP operatorship/ JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner DCQ Daily Contractual Quantity 34 =4 160 . Latest Status PTTEP Increase Sales Gas DCQ from 220 to 280 MMSCFD in Feb'22 Select as a pilot project for CCS and completed CCS conceptual study in Q2 2022 Decommissioning activities in progress Ensure gas deliverability level at DCQ Drill development wells • Block 15 ended the concession on 23 Apr 2022 and operates under G2/61 project. Block 16 and Block 17 has maintained production until end of concession on 7 March 2023. Infills drilling for BKT Sole investment Maintain production level as planned Carry out wells plug and abandonment Ensure gas deliverability level at DCQ Drill development wells Ensure gas deliverability level at DCQ#35Projects Details | Thailand Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) 7 G4/43 JV Production 1 Sales Vol Liquid (KBPD) 2 PTTEP 21.375% Chevron 51% MOECO 21.25% Palang Sophon 6.375% 8 G4/48 JV Production 1 PTTEP 5% Chevron 71.25% MOECO 23.75% 9 L53/43 & L54/43 OP Production 0.5 PTTEP 100% 10 PTTEP1 OP Production PTTEP 100% 11 S1 0.2 OP Production PTTEP 100% 8 Crude: 25 KBPD LPG: 175 MTon/Day 12 Sinphuhorm OP Production 96 PTTEP 55% Apico 35% EXXON MOBIL 10% 13 L22/43 OP Production PTTEP 100% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during 6M2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 35 85 0.3 Latest Status PTTEP Deliver production volumes as nominated from the buyer and oil production as planned Decommissioning activities in progress Completed 6-well drilling in Apr 22 and commence 1st oil production in Jun'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 are on-going for business plan and work activities identification. Ensure gas deliverability at CDC high nomination On-going the drilling campaign for 2 development wells in 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 Facility Readiness for Additional Gas to Thailand for 30-50 MMSCFD Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid Latest Status (MMSCFD) (KBPD) 14 MTJDA JOC Production 258 8 PTTEP 50% Petronas Carigali 50% 15 G9/43 OP Exploration PTTEP 100% 16 G1/61 (Erawan) OP Production 88 PTTEP 60% 88 Mubadala 40% 2 Activity suspended Successful transition to become operator on 24 April 2022 Production ramp-up in progress with installing 2 WHPS of Phase 1A Development and another 6 WHPs to be installed within 2022. 17 G2/61 (Bongkot) OP Production 80 3 Normal operations PTTEP 100% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during 6M2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 36#37Projects Details | Myanmar, Malaysia, Other SEA Project Name 1 Block K (Malaysia) - Kikeh Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) - Siakap-North Petai field (SNP) - Gumusut-Kakap field (GK) 2 Sarawak SK309 and SK311 OP Production PTTEP (Malaysia) 3 Block H (Malaysia) OP (Kikeh & SNP) Production PTTEP Kikeh 56% JV (GK) 28 ** SNP 22.4% 25* ** GK 7.17% 198 ** 18* 42 - 59.5% OP Production PTTEP 42 -56% 256 ** 4 - Malaysia Other projects OP Exploration PTTEP 42.5 -80% (varied by permits) 5 Yadana (Myanmar) JV Production 734 PTTEP 25.5% TotalEnergies 31.24% Chevron 28.26% MOGE 15% 6 Zawtika M9 & a part of M11 OP Production 322 PTTEP 80% (Myanmar) Myanma Oil and 20% Gas Enterprise (MOGE) 7 M3 OP Exploration PTTEP 100% (Myanmar) 8 MD-7 (Myanmar) OP Exploration PTTEP TotalEnergies 50% 50% Note: * ** *** PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during 6M2022 except Malaysia (Production volume 100%)/ For Block K, gross production is net off unitization Status: OPPTTEP operatorship / JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 37 . Latest Status PTTEP The inspection and maintenance were completed as planned and the Project continued drilling well in GK as part of field development phase 3 2 new infill wells have completed drilling, with expected production in Jul'22 Capable of producing up to 270 MMSCFD. SK410B: Plan to drill 1 wildcat well in Jul'22 and expected FID in 2023 for LLB SK417 Planning and preparing for the drilling of appraisal well (NANGKA-2) in 2022 exploration campaign SK405B, SK438, SK314A: Well planning in progress SB412 Preparing for exploration activities and focusing on seismic activity Became a new operator on 20 July 2022 Activities for transition performed in a safe and orderly manner for smooth and continuity of operation Maintain operations. Some activities are delayed due to COVID-19 and political situation. Waiting for approval of PSC Supplementary Closely monitor the situations to assess risks, as well as to prepare for an appropriate action plan Termination process in progress#38Projects Details | Myanmar, Malaysia, Other SEA Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) 9 9-2 JOC Production 12 3 PTTEP 25% (Vietnam) Vietnam Oil and 50% Gas Group Pharos Energy 25% 10 16-1 JOC Production 4 13 PTTEP 28.5% (Vietnam) Vietnam Oil and 41% Gas Group Pharos Energy 28.5% OPECO 2% 11 B & 48/95 (Vietnam) JV Exploration PTTEP 8.5% Vietnam Oil and 65.88% Gas Group MOECO 25.62% 12 52/97 (Vietnam) JV Exploration PTTEP 7% Vietnam Oil and 73.4% Gas Group MOECO 19.6% 13 Natuna Sea A (Indonesia) JV M Production 187 1 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 6M2022 *** Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 38 Latest Status Maintain production level Procurement for drilling campaign of 1 development well Maintain production level Procurement for drilling campaign of 2 development wells PTTEP 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#39Projects Details | Middle East 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% G&G study is on-going. Eni Abu Dhabi 70% 2 Abu Dhabi Offshore 2 (UAE) JV Exploration PTTEP 30% Completed the first exploration well drilling and wait for the result Eni Abu Dhabi 70% 3 Abu Dhabi Offshore 3 JV Exploration 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 659* ** PTTEP 2% Normal operations Government of Oman 60% Shell 34% TotalEnergies 4% 6 Mukhaizna (Oman) JV Production PTTEP 1% == 94 ** Normal operations Occidental 47% OOCEP 20% Indian Oil 17% Mubadala 15% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during 6M2022 except for PDO Block 6 and Mukhaizna (Production volume 100%) Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 39 88 PTTEP#40Projects Details | Middle East PTTEP Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid Latest Status (MMSCFD) (KBPD) 7 Oman Onshore Block 12 JV Exploration PTTEP 20% Total E&P Oman Block 80% 3D seismic reprocessing (original 3D) in progress 3D seismic acquisition (new 3D) is in process for tendering 12 B.V. 8 Oman Block 61 JV Production PTTEP BP 20% 1,504 61 Normal operations 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 6M2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 40 40#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 17 ** PTTEP 35% PetroVietnam 40% Sonatrach 25% 4 Algeria Hassi Bir Rekaiz Ho OP Production PTTEP 49% Sonatrach 51% 5 Mariana Oil Sands OP Exploration PTTEP 100% (Canada) 6 Brazil JV M Barreirinhas AP1 Exploration PTTEP Shell Brasil 25% 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 6M2022 except for Algeria 433a & 416b (production volume) *** Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 41 Latest Status PTTEP Cash Maple (AC/RL7) and Oliver (AC/RL12): Defining proper direction in order to increase development opportunities Tenacious and Oliver: Well abandonment in progress • 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 Drilling of 8 infilled wells are on-going. Target to tie-in and produce new wells starting from Q4 2022 • Existing wells intervention • 1st oil production June 1, 2022 for the initial phase target 10,000-13,000 BPD Sales starting Q3 2022 Continue remaining drilling and construction work to be completed Phase 1 in Q2 2023 Reclamation activities in progress to return the area to Canadian government Pending exploration wells drilling permit from the government#42Projects Details | Rest of the World Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid (MMSCFD) (KBPD) 7 Brazil BM-ES-23 JV Exploration PTTEP 20% Petrobras INPEX 65% 15% 8 Mexico block 12 (2.4) JV Exploration PTTEP 20% PC Carigali Mexico 60% Ophir Mexico 20% 6 Mexico block 29 (2.4) JV M Exploration PTTEP 16.67% Repsol Mexico 30% PC Carigali Mexico Wintershal DEA 28.33% 25% 10 Block 17/06 JV M Pre-development PTTEP 2.5% (Angola) TotalEnergies 30% Sonangol 30% SSI 27.5% Acrep 5% Falcon Oil 5% 11 Dunga (Kazakhstan) JV M Production 2 12 PTTEP 20% TotalEnergies OOCEP 60% 20% Note:* ** PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during 6M2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 42 • Latest Status Evaluating the petroleum potential for development concept PTTEP Evaluating the remaining petroleum potential for future block way forward Pre-development study in progress FID plan in Q3 2022 for Begonia Oil Field Procurement process and design engineering compression package and Gathering Lines Continue Engineering of Utilities upgrade packages Fabrication of Flare packages#43Projects Details | Mid-stream Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid (MMSCFD) (KBPD) 1 Oman LNG [OMAN] Shareholder Production PTTEP 2% Normal Operations 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 Normal Operations 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 6M2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 43 Latest Status PTTEP#44Organization Chart Corporate Governance and Sustainable Development Committee Audit Committee Internal Audit Division Safety, Security, Health and Environment Division New Business Division Board of Directors Nominating and Remuneration Committee Risk Management Committee Chief Executive Officer Strategy and Business Development Group Geosciences, Subsurface and Exploration Group Engineering, and Development Group Domestic Production Asset Group 44 E&P Legal Division Enterprise Transformation Department International Production Asset Group Operations Support Group 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 Capital Total debt/(Total debt + Shareholders' equity) 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) US gallons Barrels/day Natural gas and LNG Tonnes (metric) Kilolitres Barrels US gallons Tonnes/year From Multiply by Tonnes (metric) 1 1.165 Kilolitres 0.8581 7.33 6.2898 307.86 264.17 Barrels 0.1364 0.159 1 42 0.00325 0.0038 0.0238 1 49.8 To convert Billion cubic Metres NG Billion cubic feet NG Million tonnes oil Million tonnes Trillion BTU MBOE equivalent LNG From Multiply by 1 billion cubic metres NG 1.000 35.315 0.860 0.735 34.121 5.883 Simple Effective Income tax expenses / Income before income taxes 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 Tax Rate 1 million tonnes oil equivalent 1.163 41.071 1.000 0.855 39.683 6.842 Total debt Short-term loans from financial institution + Current portion of long-term debts + Bonds + Long-term loans from financial institution 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