#1KKK PTTEP HYDROGE HYDROGEN H2 Investor Presentation Non Deal Roadshow London, United Kingdom | 28 - 29 November 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#3ME PTTEP Company Introduction#4PTTEP Overview | E&P Flagship of PTT Group Shareholding Structure 3,969.9 Million shares PTT 64% Local 18% Institutions Foreign Institutions 15% Retails 3% As of latest book closing Aug 2022 Stock Quote Market Cap. Sales Revenue Cash Cost PTTEP > 17 Billion USD > 90% SEA & ME ~ 15 USD/BOE PTTEP Sustainability Framework High Performance HPO Organization SVC Governance, GRC Risk Management and Compliance Sustainable Value Creation ►Sustainability Dow Jones Sustainability Indexes THSI THAILAND SUSTAINABILITY FTSE4Good INVESTMENT 2022 2014-2021 2016-2022 2016-2022 MSCI Level "AA" CDP DISCLOSURE INSIGHT ACTION Level "B" Drive Value Key Strategies Strengthen E&P and ensure Thailand energy security Maximize Production Expedite development Monetize discovery Enhance competitiveness of unit cost Expand gas-weighted portfolio and LNG in upstream and midstream business Decarbonize E&P Net Zero 2050 Execute GHG emission reduction plan Accelerate CCS projects Maximize use of renewables and future energy in operation Pursue emission offsetting and ocean for life Diversify ■ Scale up Al and Robotics Ventures (ARV) Capture gas-to-power and renewable energy opportunity Explore CCUS, H2, and Future Energy Commercialize in-house technology 4#5PTTEP Overview | Diversified asset portfolio Oil Rest of the World • Small presence in Kazakstan's Dunga oil field • Small presence in Australia, Mexico for exploration blocks. Africa Oil Book Value of Assets by region Total USD 24.7 billion Others 2% Middle East 13% Africa 17% Thailand 43% Growth opportunity • <1% of total sales volume • Key assets include oil fields in Algeria's Bir Sebah and Hassi Bir Rakaiz projects • Large LNG project in Mozambique under development phase • Small presence in Angola oil field block 17/06 Southeast Asia 25% As of September 2022 Oil 10 Oil Thailand Home Base • 61% of total sales volume • Mainly piped gas business • Key assets: G1/61 (Erawan), G2/61 (Bongkot), Contract 4, and Arthit offshore in the Gulf of Thailand and S1 onshore oil field. Piped Gas Oil GAS/LNG Gas/LNG Middle East Strategic Locations • 15% of total sales volume • Focus Oman and UAE Key assets: Oman Block 61, PDO Block 6, and other exploration blocks and UAE 3 offshore and 1 onshore exploration blocks LO 5 PTTEP Southeast Asia Strategic Locations • 24% of total sales volume mainly from Malaysia and Myanmar with small presence in Vietnam and Indonesia • Production of gas and crude oil • Key assets include Zawtika, Yadana in offshore Myanmar, and SK309/SK311, Block K, Block H in offshore Malaysia.#6ME Business Update PTTEP#7Energy Trilemma Key to the future energy source is to find the RIGHT BALANCE SECURE (Uninterrupted) Source: Rystad Crude Oil Natural Gas BALANCE POINT SUSTAINABLE (Clean & Responsible) Renewables Wind, Solar, Hydro 7 Coal AFFORDABLE#8THB/MMBTU Deliver Security & Affordable Energy to Thailand 2022 Thailand Gas Demand ~4,300 mmscfd Sourcing of Natural Gas PTTEP PTTEP Gas supply to Thailand Field mmscfd 969 LNG THAI mmscfd LNG 686 mmscfd Myanmar O 16% 22% 62% 2,680 mmscfd Domestic MYANMAR Yadana Source: EPPO (auw.) and ERC (nnw.) Zawtika Natural Gas Price 1600 TH Gas Pool 1400 PTTEP GOT Price 1200 Spot LNG-JKM 1000 800 600 400 200 0 MW Jan-20 Apr-20 Jul-20 Oct-20 Jan-21 Apr-21 Jul-21 Oct-21 Jan-22 Apr-22 Jul-22 8 SPH & Nam Phong THAILAND Pailin Bongkot MALAYSIA Erawan Arthit MTJDA Myanmar Thailand Erawan (G1/61) 210 800 by 2024 Bongkot & G2/61 850 Pailin 420 Arthit 330 MTJDA 33 Yadana Zawtika 580 240 Based on daily production rate in October 2022#9Projects Update Q3/2022 PTTEP Thailand Malaysia G1/61 Erawan Current gas production 210 MMSCFD. 1st ramp-up target mid 2023. Total 4 WHPs have been installed with additional 4 WHPS within 2022. MTJDA Granted rights for additional exploration area and 10-year PSC extension to 2039. Add gas volume to Thailand at least 30 MMSCFD until 2025. SK410B Continue exploration campaign, another exploration well under result evaluation. Zawtika Minimal impact from gas pipeline leakage, fully repaired within 2 weeks. Continue drilling activities to maintain production with new phase 1D. * Myanmar G2P Ongoing preparation works PTTEP is participating in 24th Gulf of Thailand Bid Round PSC Scheme • Exploration 6 + 3 Yrs. Production 20 + 10 Yrs. • Abu Dhabi Offshore 1 and 3 UAE Abu Dhabi Offshore 2 Currently being evaluated for petroleum potential for future exploration Announced gas discovery approx. 2.5-3.5 TCF. Further drillings to appraise full block potential. Sharjah Onshore Area A Farm-in to acquire 25% stake. Project is in exploration phase. Algeria HBR Oil production commenced. Expect daily production in Q4/22 ~13 KBPD. Mozambique MZA1 Construction to resume pending security situation Brazil Portfolio Rationalization Divestment 9 Total 3 Blocks on Offer G1/65 ~84,000 sq.km. G2/65 ~15,000 sq.km. G3/65 11,500 sq.km. Feb 2023 Timeline Announcement of Successful Mid Sep 2022 Bid Submission May to Sep 2022 Data room Apr 2022 Announcement Bid Opening#10Pathway to Decarbonize « GHG Emissions Reduction (Avoid & Mitigate) PTTEP has continued to reduce GHG emissions since 2012. Fugitive & Vent Leak monitoring and preventing Energy Efficiency & Renewable Energy Improve energy efficiency and use more renewable energy Flare/Flash Gas Recovery Recover flare/flash gas to production process Process Optimization Improve & optimize process efficiency Chumphon: 1,551 rais วัดแก้วประเสls ทา ทุ่งยาง GHG Offsetting Ongoing 4,000 rais mangrove plantation in Surat Thani, Nakhon Si Thammarat and Chumphon with Department of Marine and Coastal Resources (DMCR). LCSB อบก TGO PTTEP "พิธีปิดโครงการแถลงผลสำเร็จโครงการประเมินและจัดระดับธุรกิจคาร์บอนต่า และย ประจําปี โดย องค์การบริหาร เก้าซเรือนกร - อบ การมหาชน) ในวันอังคารที่ 2C- 2565 -12.00 u. 2.77 MtCO2e Smart Logistics Logistics operation efficiency improvement Production Well Management E&P Portfolio Management Accumulated GHG Reduction from Jan 2012 - Sep 2022 S1 Solar Power Arthit CCS > 60% progress of S1 solar power construction (expected completion in Q2/2023) Ongoing CCS Pre-FEED Study Report (expected 1st injection in 2026) ineed oนาคารปู Nakhon Si Thammarat: 538 rais Surat Thani: 1,908 rais สุราษฎธา ท่าทอง 2022 Low Carbon and Sustainable Business Award (highest level) from the Thailand Greenhouse Gas Management Organization (TGO) E&P Portfolio Management GHG criteria for investment decision completed Completed pilot-scale seagrass plantation study in Koh Tean, Surat Thani with Kasetsart University Ongoing study of carbon absorption for seaweeds, seashells, and coral reefs in Thailand with Chulalongkorn University GUIDELINES 10#11ME Financial Results PTTEP#12Profit and Loss Q3/2022 Key events Exploration wells write- off in Australia MTJDA Production Period Extension Net Profit 600 QoQ 664 Tax incentives Malaysia Sabah-H Brazil Assets Divestment YOY 664 PTTEP Unit: million USD YTD 1,581 P/L from normal operation P/L from non-operating items 890 292 1,922 647 706 706 967 335 Profit from Normal Operations Sales Volume Average Selling Price Unit Costs -47 Q2/22 -42 Q3/22 +3% G1/61 1st Full Quarter, MTJDA -3% Lower liquid price +0.1% -43 Q3/21 Q3/22 +15% G1/61, Oman Block 61, Arthit +21% Higher gas and liquid price -2% -77 9M 21 +10% -341 9M 22 G1/61, Oman Block 61, Arthit +27% Higher gas and liquid price -1% Major Non-operating items Oil Price Hedging Impairment Asset Write-off Gain from Bargain Purchase Gain in Q3/22 vs Loss in Q2/22 Brazil Asset Impairment in Q3/22 12 Gain in Q3/22 vs Loss Q3/21 Brazil Asset Impairment in Q3/22 Less Hedging Loss in 9M22 Less Brazil Asset W/O in 9M22 Gain from Bargain Purchase in 9M21#13Volume and Price PTTEP UNIT: BOED 465,459 478,323 457,237 416,141 77,207 75,191 417,167 414,516 72,617 Volume Mix 400,000 55,993 64,548 52,163 Rest of World 101,076 Gas Liquid 98,166 98,960 95,766 95,019 Other SEA 300,000 97,469 28% 27% 200,000 Thailand & 72% 73% 290,086 302,056 285,660 264,382 255,150 267,334 MTJDA 100,000 0 Q2 2022 Q3 2022 Product Price 2021 Q2 22 Q3 22 Q3 21 9M 2022 9M 2021 Gas ($/MMBTU) 5.69 6.10 6.18 5.76 6.12 5.66 Revenue Mix Liquid ($/BBL) 66.70 105.47 97.94 69.16 98.44 63.40 Weighted Avg. ($/BOE) 43.49 55.61 53.68 44.25 53.62 42.34 52% 50% Avg. Dubai ($/BBL) 69.39 108.22 96.68 71.68 100.29 66.35 Avg. HSFO ($/BBL) 64.42 104.67 74.44 68.35 89.02 62.14 48% 50% (High Sulphur Fuel Oil) Q2 2022 Q3 2022 Note: Include sales volume from ADNOC Gas Processing (AGP) Exclude Oman Block 61 deemed sales volume from tax payment by government 13#14Unit Cost Unit: $/BOE 40 28.82 28.52 28.79 29.39 30 28.00 28.18 Cash Cost Unit Cost 20 15.46 14.50 13.25 13.61 14.29 12.43 ☑ 10 2021 Q2 22 Q3 22 Q3 21 9M 2022 9M 2021 DD&A 15.27 13.33 14.32 15.78 13.71 15.75 Finance Cost 1.33 1.50 1.42 1.35 1.43 1.34 Royalties 3.49 4.22 3.88 3.44 4.11 3.42 G&A 2.22 2.47 1.66 1.78 2.11 1.94 Exploration Expenses 0.54 * 0.40 0.95 1.31 0.51 0.55* Operating Expenses. 5.67 6.87 6.59 5.73 6.13 5.18 Lifting Cost 4.13 4.35 4.50 4.12 4.22 4.06 Note: * Exclude Exploration assets write-off in Brazil for 9M 2021, and 2021 All Unit Cost shown above exclude costs related to new business The formulas for calculating ratios are provided in the supplementary section for your reference 14 PTTEP#15Cashflows, Financial Position and Debt Profile Cashflow & Financial Position Cash flow from operations (Before tax) 2,559 Tax paid PTTEP Unit: million USD Inflow Outflow 23,445 24,684 Total Assets Other Liabilities 6,923 7,349 4,094 Interest-bearing Debt 4,274 Equity 12,428 13,061 1,347 CAPEX Dividend paid 4,591 1,296 Others 819 EBITDA Margin 76% 252 3,436 Dec-21 Ending cash Sep-22 (Sep-22) Beginning cash Note: (Dec-21) Include Short-term investment Net of adjustment for the effect of exchange rate changes on cash and cash equivalents Debt Profile Interest Rates 2021 Q3 2022 2021 Q3 2022 Debt to Equity 0.33 0.33 Average Cost of Debt 3.38% p.a. 3.73% p.a Floating 17% Fixed Debt to EBITDA 0.80 0.62 Average Loan Life 83% 12.7 Yrs 12.8 Yrs 15#16Guidance and Ratings Outlook Sales Volume (KBOED) Gas Price (US$/MMBTU) Unit Cost (US$/BOE) Profitability (EBITDA Margin) *Based on average Dubai oil price in 2022 at 97 $/BBL -------------------------------- Ratings AAA BBB+ TRIS FY 2022 RATING Stable Stable ~468 ~6.3 ~29-30 70-75% ------------------------------------…………… 16 MOODY'S Baa2 stand-alone rating PTTEP STANDARD & POOR'S RATINGS SERVICES MCGRAW HILL FINANCIAL BBB stand-alone rating Baa1 BBB+ Fitch Ratings Stable Stable BBB stand-alone rating#17KKKI Member of Dow Jones Sustainability Indices PTTEP Powered by the S&P Global CSA Thank you and Q&A @ +66 2 537 4000 [email protected] http://www.pttep.com#18Supplementary information • Profit and Loss Statement Reserves 20 19 120 . Finance 21-23 • E&P Business 24-26 • Beyond E&P Business 27-28 SD & ESD 29-31 • Thailand Energy Market 32-34 • Projects Information 35-44 • Organization Structure 45 Ratio and Formula 46 Conversion Table 47 PTTEP#19Results | Profit and Loss Statement Total Revenues Sales (1) Sales Volume (BOED) (2) Sales Price (US$/BOE) Gain from a bargain purchase Others (3) Total Expenses Unit: million USD PTTEP Q3 22 Q2 22 %QoQ Q3 21 % YoY 9M 22 9M 21 %YTD FY2021 2,617 2,469 6% 1,784 47% 7,008 5,331 31% 7,314 2,388 2,383 0.2% 1,744 37% 6,801 4,864 40% 6,731 478,323 465,459 3% 417,167 15% 457,237 414,516 10% 416,141 53.68 55.61 (3%) 44.25 21% 53.62 42.34 27% 43.49 350 (100%) 342 229 86 >100% 40 (>100%) 207 117 77% 241 1,936 1,882 3% 1,499 29% 5,433 4,453 22% 6,118 Major Expenses: Operating Expenses Exploration Expenses G&A DD&A Loss on Financial Instruments 300 291 3% 220 36% 789 586 35% 861 42 17 >100% 50 (16%) 64 207 (69%) 226 80 112 (29%) 72 11% 285 229 24% 355 631 565 12% 606 4% 1,713 1,782 (4%) 2,202 5 (100%) 84 228 (63%) 234 Impairment Loss on Assets 95 100% 100% 95 100% 183 Income Tax Expenses 468 610 (23%) 326 44% 1,575 839 88% 1,287 Share of profit (loss) from associates and JV (17) 13 (>100%) 7 (>100%) 6 12 (50%) 15 Net Profit 664 600 11% 292 >100% 1,581 890 78% 1,211 Profit (Loss) from normal operation 706 647 9% 335 >100% 1,922 967 99% 1,479 Profit (Loss) from non-operating items (42) (47) 11% (43) 2% (341) (77) (>100%) (268) Non-operating items breakdown: Oil Price Hedging Tax from Effect of FX Note: 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 19 (3) Consisted of Revenue from Pipeline, Gain from FX, Forward Contract, and Gain from Oil price Hedging. 94 (38) >100% (41) >100% (184) (289) 36% (284) (13) (11) (18%) (2) (>100%) (26) (11) (>100%) (10) (28) 2 (>100%) (100%) (36) 18 (>100%) 12 (95) (100%) (100%) (95) (100%) (183) (145) 100% (145) 350 (100%) 342#20E&P Business | 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 20 20 PTTEP#21Finance | 5-year Sales Volume & Investment Budget (announced December 2021) CAGR +5% PTTEP In KBOED 600 528 467 463 473 493 416 35 22 7 8 400 2 Sales Volume 167 164 166 171 205 150 Rest of World Other SEA & Middle East 200 293 291 298 300 288 264 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 2,568 2,556 2,172 2,123 1,625 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 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 CAPEX (Dev & Pre-sanction projects (2)) CAPEX (Producing projects (3) 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 September 2022 USD Millions Finance | Debt Maturity Profile 700 600 600 500 400 300 200 100 0 2022 2023 2024 2025 Note: Excludes Hybrid bonds Unit: USD Millions or equivalent after cross currency swap 2026 182 2027 22 22 2028 648 2029 379 350 2030 2031-2041 178 2042 2043-2058 490 2059 650 PTTEP#23PTTEP Dividend Payment History Finance | Key Ratios & Dividend Payment History Key Ratios Q2'2022 Q3'2022 EBITDA Margin 75% 76% Unit: THB per share 6.00 Debt to 0.33 0.33 Equity 6.00 1H 2H 5.00 5.00 4.25 4.25 4.00 3.75 3.00 3.25 Debt to 0.69 0.62 2.75 2.75 EBITDA 2.00 4.25 2.25 Current 1.85 1.96 Ratio 1.50 1.75 2.00 1.50 0.00 2017 2018 2019 2020 2021 1H2022 ROA 6.5% 7.9% Payout Ratio % of Net Profit 88 55 49 77 50 50 50 50 ROE 18% 21% % of Profit from Normal Operation 33 63 51 50 53 71 41 38 23 23#24E&P Business | Thailand, Myanmar and Malaysia Myanmar Production Zawtika (WI 80%) • Production Volume gas 319MMSCFD (9M2022) Yadana (WI 37.1%) • Production Volume gas 754MMSCFD (9M2022) Exploration M3 (WI 100%) • Pending development Malaysia Production Block K (WI Kikeh 56%, SNP 22.4%, GK 7.2%) • Production Volume crude 26KBPD and gas 30MMSCFD (9M2022) Block H (WI Rotan 56%, Others 42%) • Production Volume gas 260MMSCFD (9M2022) SK309 and SK311 (WI 42-59.5%) • Including East Patricia field • Production Volume gas 200MMSCFD, and crude 18KBPD (9M2022) Exploration • SK410B (LLB), SK417, SK314A, SK438, SK405B • PM415, PM407 PTTEP Thailand Myanmar S1 Sinphuhom E5 M3 Thailand Yadana Zawtika B8/32 & 9A MD7 G1/61 (Erawan) Arthit Contract 4 Bongkot & G2/61 MTJDA Sabah H Sabah K SK410B SK417 Malaysia SK438 PM415 SK405B PM407 SK314A SK309& SK311 Production G1/61 Erawan (WI 60%) • FY2022 daily gas production 200-220MMSCFD • Ramp-up in progress to 800MMSCFD in Apr 2024 • Sole investment 100% G2/61 Bongkot (WI 100%) • GBN Transition completed. Production 200MMSCFD. Bongkot (WI 66.67%) • Production volume gas 730MMSCFD and condensate 19KBPD (9M2022) • Remaining transition to G2/61 in Mar 2023 at 500MMSCFD Arthit (WI 80%) • Production Volume gas 298MMSCFD and condensate 16KBPD (9M2022) Contract 4 (WI 60%) • Production Volume gas 415MMSCFD and condensate 15KBPD (9M2022) S1 (WI 100%) • Production Volume crude oil 25KBPD (9M2022) MTJDA (WI 50%) • Production Volume gas 290MMSCFD (9M2022) Production Exploration 24 24#25E&P Business | The Middle East UAE Abu Dhabi Offshore 1 Exploration Abu Dhabi Offshore 1, 2, 3 (WI 30%) • High potential prospective resources with significant sizeable discoveries Operated by ENI (WI 70%) Sharjah Onshore Area C (WI 25%) . High gas & condensate potential with the possibility of integrating with surrounding fields Abu Dhabi Offshore 2 • Operated by ENI (WI 50%) Midstream ADNOC Gas Processing (WI 2%) • AGP is 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 economy • Sizable volume of Propane, Butane and Naphtha Operated by ADNOC (WI 68%) Production phase Exploration phase Midstream Sharjah Onshore Area C Abu Dhabi Offshore 3 AGP PDO (Block 6) UAE OLNG Oman PTTEP Production PDO Block 6 (WI 2%) • Largest asset covering around 1/3 of the country. Average oil production volume of 660 KBPD (9M2022) Operated by Petroleum Development of Oman Mukhaizna Block 53 (WI 1%) • Largest single onshore producing field in Oman. Average oil production volume of 94 KBPD (9M2022) • Operated by Occidental Petroleum (WI 47%) Block 61 (WI 20%) Largest tight gas development in Middle East • Gas and condensate daily production rate of 1,500 . MMSCFD and 61,000 BPD (9M2022). Operated by BP (40% interest) Exploration Onshore Block 12 (WI 20%) • Operated by Total E&P Oman (80% interest) Oman Onshore Block 12 Oman Block 61 OMAN • 25 25 Mukhaizna (Block 53) Midstream Oman LNG (WI 2%) • The only LNG facility in Oman. Processing capacity • 10.4 MTPA. Operated by Government of Oman (WI 51%)#26E&P Business | Africa Algeria Production Bir Seba (WI 35%) • Oil production consisting of block 433a, 416b • Operated by PVEP (WI 40%) • Production volume crude 16KBPD Hassi Bir Rekaiz (WI 49%) • HBR oil filed consisting of block 443a, 424a and 415ext 1st Oil in June 2022 and will start delivering sales volume in Q4/2022. • Operated by Groupment (WI 51%) • Production volume crude 13KBPD Angola Development Block 17/06 (WI 2.5%) • FID in July 2022 for Begonia offshore oil field in the Lower Congo Basin, estimated production capacity at 30KBPD. • Operated by Total Energies (WI 30%) Bir Seba ALGERIA Block 17/06 Production Development Hassi Bir Rekaiz ANGOLA 26 MOZAMBIQUE MZA1 PTTEP Mozambique Development MZA1 (WI 8.5%) • High quality reservoirs capable up to 200MMSCFD per well • Construction phase for LNG facility with capacity 13.1 MTPA (2 trains). . Currently under Force Majeure due to local security situation • Operated by Total Energies (WI 26.5%)#27Beyond E&P Business | Overall Decarbonization New Energies Corporate Venture Capital (CVC) Technology Enabler Carbon Capture & Utilization (CCU) CO₂-to-Methanol Value-added Technology H Carbon Capture & Storage (CCS) Initiative Support Decarbonization Demand HYDROGEN H2 Hydrogen/ Power-to-X DGE Act now for Future Energy/Fuel PTTEP Advanced Technology In-house Tech Commercialize in-house technology Power Business . Gas-to-Power • Renewables 0 AI AND ROBOTICS VENTURES Al & Robotic Foundation for new energies Growth in Technology Business 27#28Beyond E&P Business | ARV AI AND ROBOTICS VENTURES ROVULA Nextgen marine & subsea solutions for safety efficiency and reduced carbon footprint Xplorer AUV Surveillance & inspection RotoClimber Vertical Repair & Maintenance EVENT No. 1022 Nautilus Horizontal Repair & Maintenance PTTEP JOINT VENTURES ZEAQUEST XSpector Computer Vision Analytics & Insights with Mermaid Subsea Services SKYLLER Artificial Intelligence and Augmented Reality Solutions for critical infrastructure management UAS Data Capture and Inspection Asset Management Platform HORRUS Pilotless UAS systems For autonomous dispatch HIGHSIGHT Integrated teleoperations Solutions for surveillance and asset inspection aerosky with Aerodyne Group and Digital Creations Technologies & Businesses Al and Robotics Ventures ARV is the venture building platform of PTTEP. We leverage artificial intelligence and robotics technologies to unlock value and create business growth opportunities across industries spanning air, land, and sea. Through innovation, R&D, go-to- market and partnership activities, we aspire to deliver unparalleled experiences to the ecosystems we engage with. varuna Crop Sustainability and Nature-based Carbon Solutions CARIVA Health Tech API Platform for life-changing personalized health innovation -> Precision Farming Remote Sensing Solutions for agri-land management NEXTCERCISE KANNA Retail Carbon Farming MAKARA Nature-based Carbon Solutions At ATI with Thaicom B-MED Fitness Monitoring BEAUT Personalized Care and Wellness ARVIC Health Ecosystem with BJC 28#29SD & ESG | Net Zero Ambition 2020 Base Year 用白 2030 30% GHG Intensity* Reduction *Intensity refers to GHG released in Tonne CO2e per thousand tonnes of hydrocarbon production PTTEP 2040 50% GHG Intensity Reduction 2050 NET ZERO Greenhouse Gas Emissions E&P, Operational Control SCOPE 1 & 2 20 29#30SD & ESG Update 13 CLIMATE ACTION Decarbonization GHG Intensity Reduction Target 30% By 2030 (2020 base year) Net Zero By 2050 PROGRESS Reduction of GHG Emission Intensity As of Q3/2022, > 124,000 TCO2e Reduction Fugitive & Vent since Jan 2022 Energy Efficiency & Renewable Energy Leak monitoring and Improve energy efficiency and preventing use more renewable energy Process Optimization Improve & optimize process efficiency Flare/Flash Gas Recovery Recover flare/flash gas to production process RESPONSIBLE 12 CONSUMPTION AND PRODUCTION Circular Model Zero Waste to Landfill by 2030 ≥50% of Main Structure Reuse by 2030 2020 ♦PROGRESS◆ Waste to Landfill 2025 Zero Hazardous waste to landfill Zero Industrial waste to landfill 2030 Zero waste to landfill Smart Logistics Logistics operation efficiency improvement 2030 EP Net Zero 2040 Production Well Management E&P Portfolio Management 2020 Base Year 30% 50% GHG Intensity Reduction GHG Intensity Reduction 2050 NET ZERO GHG Emissions E&P, Operational Control SCOPE 1 & 2 Exploring for Lower Carbon E&P Portfolio EP Production and Planet in Balance WHP Jacket Reuse Conduct a feasibility study for the reuse of Wellhead Platform (WHP) jacket in addition to the reuse of Wellhead Platform (WHP) topside Upcycling High Volume Waste Oil sludge conversion to Graphene: Completed lab scale unit fabrication 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 30 30 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 Conducting a pilot-scale seagrass plantation study in Koh Tean, Surat Thani Collaborated with Hydro-Informatics Institute (HII) & Kasetsart University to collect ocean data by deploying an ocean current mapper [1st time in Thailand] Ramp Up CSR around Ocean Flagship Projects Phetchaburi Prachuap • 4 Aquatic Animal Hatchery Learning Samut Songkhram Rayong Chumphon Surat Thani Nakhon Si Thammarat Songkhla Pattani Centers Established (Phetchaburi, Prachuap Khiri Khan, Samut Songkhram & Rayong) • More than 10 km² Conservation Area & Fish Home • Handed over the sea turtle conservation exhibition & sea turtle hatchery buildings to the Royal Thai Navy Sea (Chonburi)#31SD & ESG | Disclosure and Ratings Social Human Development Resource S&P Global Ratings 100 80 PTTEP re Woodside TotalEnergies 60 HESS REPSOL AA A Woodside REPSOL Santos PTTEP Economic Human Rights ESG AAA Climate & Disclosure Environment Health & Safety MSCI equinor HESS Innovation & Technology Supply Chain Governance, Risk Management & Compliance ESG Ratings MOODY'S 1 A 2 bp eni TotalEnergies bp equinor Chevron BBB ExxonMobil Chevron HESS Woodside PTTEP eni equinor bp Chevron A- B B- bp equinor REPSOL ESG Standards GRI Global Reporting Initiative Reporting Standards (GRI Standards) Oil and Gas Sector Disclosures (OGSD) # CDP DISCLOSURE INSIGHT ACTION 0-10 SUSTAINALYTICS a Morningstar company As of December 2021 Source: S&P Global, MSCI, Moody's, CDP, SUSTAINALYTICS' websites PTTEP eni TotalEnergies HESS 31 10-20 REPSOL TotalEnergies ExxonMobil 20-30 40 ExxonMobil Santos PetroChina BB BB B Woodside REPSOL equinor PTTEP eni TotalEnergies HESS PetroChina 20 20 D D- 30-40 bp ExxonMobil Santos PTTER 5 CCC No Response Chevron Woodside PetroChina ExxonMobil Santos 40+ Chevron PetroChina#32Thailand Energy Market | Overview FY 2020 FY 2021 8M 2022 FY 2020 FY 2021 8M 2022 Natural Gas Supply 39 MMSCFD 38 Domestic Myanmar LNG 4,335 Domestic Myanmar LNG 4,726 o Increase in energy demand & become closer to demand before COVID-19 pandemic, along with high level of energy prices 37 Domestic Myanmar LNG 4,699 0 1,000 2,000 3,000 4,000 5,000 o As of August 2022, compared with the same period of last year: significantly declined in domestic supply, while gas from Myanmar remained constant with increase in LNG import. Natural Gas Consumption Electricity Generation wwww www 36 35 34 33 32 MMSCFD Electricity Industry GSP NGV 4,270 32.1 31.3 31 30.0 30 GWH 29 29 53% 3% 16% 17% 10% 146,799 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 8M 2022 54% 2% 17% 16% 11% 209,717 55% 2% 18% 14% 10% 206,034 Natural Gas Imported Hydro Electricity Renewable Energy Coal & Lignite 32 Exchange Rate Movement (USD/THB) 33.9 33.4 33.3 35.3 PTTEP 37.9 38.5 (High) Q1 Q2 Q3 Q4 Q1 Q2 22 Q3 Q4 2021 2022 37.4 (Average) 36.3 (Low) Consensus on the exchange rate mostly depends on 。 Monetary policies and rate hike schedules of the Bank of Thailand and Federal Reserve o Economic recovery of Thailand in particular the tourism sector 。 Market risk-off factors such as high inflation and supply chain disruptions Source: Bank of Thailand, Bloomberg Forecast based on Bloomberg Consensus as of 17 October 2022#33Thailand Energy Market | Value Chain 8M 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 -38% Domestic 62% Source: Energy Policy and Planning Office (EPPO) and Department of Mineral Fuels (DMF) 9M 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 33 PTTEP 57% Others 43% Downstream Petrochemicals Oil and gas marketing PTTEP#34Thailand Energy Market | Oil & Gas Balance Oil Balance*** Maintains stability supply through adequate refining capacity SALES PRODUCTION SUPPLY Source: PTT Note: * ** Import (87%) 1019 KBD Gulf of Thailand (54%) Indigenous (13%) 146 KBD Imported Refined Petroleum Products 57 KBD Crude/ Condensate 962 KBD Total Refining Capacity in Thailand 1,242 KBD Crude/ Condensate 132 KBD PTT's Associated Refineries 770 KBD (TOP, PTTGC, IRPC) Crude Export 14 KBD Other Refineries 472 KBD (SPRC, ESSO, BCP) Refined Products Refined 1,069 KBD * Products 181 KBD Domestic 949 KBD ** Export 195 KBD Refined product from refineries = 990 KBD, including domestic supply of LPG from GSPs and Petrochemical Plants = 79 KBD Included Inventory *** Information as of 6M 2022 **** Information as of 6M 2022 MMSCFD @ Heating Value 1,000 Btu/ft³ 34 Others 43% PTTEP 57% Natural Gas Balance* **** Main driver of the Thailand economy Onshore (3%) 2,315 MMSCFD Bypass Gas 182 MMSCFD 6 Gas Separation Plants Total Capacity 2,870 MMSCFD 804 MMSCFD (18%) Import (43%) LNG 63% Myanmar 37% @Actual Heat 109 MMSCFD 1,864 MMSCFD Petrochemical Ethane Propane Feedstock LPG (11%) NGL Industry Household LPG Transportation NGL (7%) Methane 1,329 MMSCFD Power (60%) Industry (19%) NGV (3%) PTTEP#35Projects Details | Thailand (as of September 2022) 1 Arthit 2 B6/27 Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) Operator Production PTTEP 80% 287 16 Ensure gas delivery per DCQ Chevron 20% MOECO 4% Operator Production PTTEP 100% • JV Production 3 B8/32 & 9A PTTEP 25.01% 47 10 Chevron 51.66% MOECO 16.71% KrisEnergy 4.63% Palang Sophon 2% 4 Bongkot Operator Production PTTEP TotalEnergies 66.67% 33.33% 701 19 Latest Status Prepare for decommissioning activities Normal operations PTTEP Block 15 ended the concession on Apr 23, 2022 and operates under G2/61 project. Block 16 and Block 17 has maintained production until end of concession on Mar 7, 2023 Maintain production level as planned 5 Contract 4 (Pailin) JV Production PTTEP 60% 405 16 Ensure gas delivery at DCQ Chevron 35% MOECO 5% JV Production 6 E5 PTTEP 20% 7 Ensure gas delivery 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 9M2022 Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner **** DCQ Daily Contractual Quantity 35#36Projects Details | Thailand (as of September 2022) PTTEP 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% Latest Status Deliver production volumes as nominated from the buyer and oil production as planned MOECO 21.25% Palang Sophon 6.375% 8 G4/48 JV Production 1 PTTEP 5% Decommissioning activities in progress Chevron 71.25% MOECO 23.75% 9 L53/43 & L54/43 OP Production PTTEP 100% 0.7 Normal operations 10 PTTEP 1 Ho OP Production PTTEP 100% 0.2 Maintain production plateau 11 S1 OP Production 8 PTTEP 100% Crude: 25 KBPD LPG: 175 MTon/Day Production optimization and long-term development are on-going 12 Sinphuhorm OP Production 97 0.3 PTTEP 55% Ensure gas delivery at DCQ Apico 35% EXXON MOBIL 10% OP Production 13 L22/43 PTTEP 100% Production suspended Pending drilling results to determine further production/development plans Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during 9M2022 *** Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 36#37Projects Details | Thailand (as of September 2022) PTTEP Project Name Status Phase 14 MTJDA Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid Latest Status (KBPD) JOC Production 276 9 PTTEP 50% Petronas Carigali 50% Granted extension of 10-year production period, as well as additional 30MMSCFD of gas production which will be delivered to Thailand until end of 2025 to serve Thai energy demand. 15 G9/43 OP Exploration PTTEP 100% Activity suspended 16 G1/61 (Erawan) OP Production 123 5 PTTEP 60% On-going drilling and WHP installation activities. Total 8 WHP for 2022. Mubadala 40% 17 G2/61 (Bongkot) OP Production 115 4 PTTEP 100% On-going drilling and WHP installation activities. Note: * ** *** PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during 9M2022 Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 37#38Projects Details | Myanmar, Malaysia, Other SEA (as of September 2022) 1 Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) Malaysia Block K - Kikeh - Siakap-North Petai field (SNP) OP (Kikeh & SNP) Production PTTEP Kikeh 56% JV (GK) 26 ** 30 ** SNP GK 22.4% 7.17% - - Gumusut-Kakap field (GK) 2 Malaysia SK309 and SK311 OP Production PTTEP 42-59.5% 200 ** 18* 3 Malaysia Block H OP Production PTTEP 42-56% 260 ** 4 Malaysia - Other projects OP Exploration PTTEP 42.5 - 80% (varied by permits) 5 Yadana (Myanmar) JV Production 737 PTTEPI 37.1% Chevron MOGE 41.1% 21.8% 6 Zawtika: M9 & a part of M11 (Myanmar) OP Production 310 PTTEP Myanma Oil and Gas Enterprise (MOGE) 80% 20% Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project Sales volume represent average volume for 100% of the project during 9M2022 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 38 38 . . • Latest Status The inspection and maintenance were completed as planned Completed drilling wells in GK as part of field development Prepare for drilling in Kikeh in Q4/2022 PTTEP In the process drilling of 4 new infill wells on West Patricia Ensure gas delivery at DCQ Preparing for exploration wells drilling in early 2023 SK410B: Additional drilling completed in Sep 2022 and under result evaluation. For LLB, expect FID 2023. SK417 Planning and preparing for the drilling of appraisal well SK405B Sirung Pre-Development Study is ongoing SK438 Well planning in progress : SK314A Drilling preparation SB412 Preparing for exploration activities and focusing on seismic activity Operatorship transfer completed in July 2022 as planned On the development process of Phase 1D to maintain production level In the process of additional wellhead platform construction Reparation of onshore pipeline leakage was completed, caused 2-week interruption on gas imported to Thailand#39Projects Details | Myanmar, Malaysia, Other SEA (as of September 2022) Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) 100% Project Name Status Phase 7 Myanmar M3 OP Exploration PTTEP Latest Status Pending for Final Investment Decision (FID) 8 Vietnam 9-2 JOC Production 12 3 PTTEP 25% Maintain production level Vietnam Oil and 50% Prepare for dev. Drilling in Q4/2022 Gas Group Pharos Energy 25% 9 Vietnam 16-1 JOC Production 4 12 PTTEP 28.5% Maintain production level Vietnam Oil and 41% Prepare for dev. Drilling in Q4/2022 Gas Group Pharos Energy 28.5% OPECO 2% 10 Vietnam B & 48/95 JV M Exploration PTTEP 8.5% Final Investment Decision (FID) planned in 2023 Vietnam Oil and 65.88% Gas Group MOECO 25.62% 11 Vietnam 52/97 JV Exploration PTTEP 7% Final Investment Decision (FID) planned in 2023 Vietnam Oil and 73.4% Gas Group MOECO 19.6% 12 Natuna Sea A (Indonesia) JV M Production 175 1 PTTEP 11.5% Normal operations 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 9M2022 *** Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 39 89 PTTEP#40Projects Details | Middle East (as of September 2022) PTTEP Sales Vol Gas Sales Vol Liquid Project Name Status Phase Participating Interest* (%) (MMSCFD) (KBPD) 1 Abu Dhabi Offshore 1 (UAE) JV Exploration PTTEP 30% G&G study is ongoing Latest Status Eni Abu Dhabi 70% 2 Abu Dhabi Offshore 2 (UAE) JV Exploration PTTEP 30% Completed the first exploration well XF-002 Eni Abu Dhabi 70% 3 Abu Dhabi Offshore 3 (UAE) JV Exploration PTTEP I 30% G&G study is on-going Eni Abu Dhabi 70% 4 Sharjah Onshore Area C (UAE) JV Exploration PTTEP 25% Seismic acquisition completed, currently under seismic evaluation stage Eni Abu Dhabi 50% SNOC 25% 5 Oman Block 6 (PDO) JOC Production 660 ** PTTEP 2% Normal operations Government of Oman 60% Shell 34% TotalEnergies 4% 6 Oman Block 53 JV Production 94 ** PTTEP 1% 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 9M2022 except for PDO Block 6 and Mukhaizna (Production volume 100%) Status: OP = PTTEP operatorship/ JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 40#41Projects Details | Middle East (as of September 2022) Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) 7 Oman Onshore Block 12 JV Exploration PTTEP 20% Total E&P Oman Block 80% 12 B.V. 8 Oman Block 61 JV Production 1,504 60 PTTEP BP 20% 60 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 9M2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 41 PTTEP Latest Status Currently under G&G study Plan for exploration wells drilling in 2024 Normal operations#42Projects Details | Rest of the World (as of September 2022) Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) Latest Status PTTEP 1 PTTEP Australasia OP Exploration PTTEP 90%-100% 2 Mozambique Area 1 JV Development PTTEP 8.5% TotalEnergies, Mitsui, 26.5%,20% ENH, OVL 15%, 10% • • 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 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 OVRL & Oil India, 10%, 10% Bharat 3 Algeria 433a & 416b JOC Production PTTEP 35% 16 ** Target to tie-in and produce from new wells starting from Q4/2022 (Bir Seba) PetroVietnam 40% Sonatrach 25% 4 Algeria Hassi Bir Rekaiz OP Production GHBR 49% Sonatrach 51% 5 Mariana Oil Sands (Canada) OP Exploration PTTEP 100% 6 Barreirinhas AP1 JV Exploration PTTEP 25% (Brazil) Shell Brasil 65% Mitsui E&P Brasil 10% 1st oil production 1 June 2022 with daily production rate 13 KBPD 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 Divestment is in progress Note: * PTTEP denotes respective PTTEP subsidiaries participating in the project ** Sales volume represent average volume for 100% of the project during 9M2022 except for Algeria 433a & 416b (production volume) Status: OP PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 42#43Projects Details | Rest of the World (as of September 2022) PTTEP Latest Status Project Name Status Phase Participating Interest* (%) Sales Vol Gas (MMSCFD) Sales Vol Liquid (KBPD) 7 Brazil BM-ES-23 JV Exploration PTTEP 20% Divestment is in progress Petrobras 65% INPEX 15% 8 Mexico block 12 (2.4) JV Exploration PTTEP 20% Evaluating the remaining petroleum potential PC Carigali Mexico 60% Ophir Mexico 20% 9 Mexico block 29 (2.4) JV M Exploration PTTEP Repsol Mexico 16.67% 30% Pre-development study in progress PC Carigali Mexico 28.33% Wintershal DEA 25% 10 Block 17/06 (Angola) JV Pre-development PTTEP 2.5% TotalEnergies 30% Obtained FID Approval of Begonia Oil Field Development Project on Jul 28, 2022, and production extension period for 20 years until 2045 Sonangol 30% SSI 27.5% Acrep 5% Falcon Oil 5% 11 Dunga (Kazakhstan) JV M Production 2 12 PTTEP 20% Normal operations 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 9M2022 Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 43#44Projects Details | Mid-stream (as of September 2022) Project Name Status Phase Participating Interest* (%) Sales Vol Gas Sales Vol Liquid (MMSCFD) (KBPD) 1 Oman LNG 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 (AGP) [UAE] JV Production PTTEP 2% Normal Operations 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 9M2022 *** Status: OP = PTTEP operatorship/JOC = PTTEP joint operatorship/ JV = PTTEP Joint Venture Partner 44 Latest Status PTTEP#45Organization 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 45 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#46Ratio and Formula PTTEP Oil and Gas Reserves Reserves Replacement Ratio Reserves Life Index (Year) 5-Yr Additional Proved Reserves/5-Yr Production Volume Profitability Success Ratio Sales Revenue Lifting Cost ($/BOE) Cash Cost ($/BOE) Unit Cost ($/BOE) EBITDA EBITDA Margin Return on Assets (ROA) Return on Equity (ROE) Total debt Net debt Debt to Equity Net Debt to Equity Leverage Total Debt to Capital Total Debt to EBITDA Net Debt to EBITDA EBITDA Interest Coverage Ratio Proved Reserves / Production Volume Number of wells with petroleum discovery / Total number of exploration and appraisal wells Sales + Revenue from pipeline transportation (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 (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 assets between the beginning and the end of the 12-month period Trailing-12-month net income / Average shareholders' equity between the beginning and the end of the 12-month period Short-term loans from financial institution + Current portion of long-term debts + Bonds + Long-term loans from financial institution Total debt-Liquidity Total debt/ Shareholders' equity Net debt/ Shareholders' equity Total debt / (Total debt + Shareholders' equity) Total debt / Trailing-12-month EBITDA Net debt/ Trailing-12-month EBITDA Trailing-12-month EBITDA / Trailing-12-month Interest Expenses & Amortization of Bond Issuing Cost 46#47Conversion Table Crude Oil To Convert Tonnes (metric) Kilolitres Barrels US Gallons Tonnes/year From Multiply by Tonnes (metric) 1 1.165 7.33 307.86 Kilolitres 0.8581 1 6.2898 264.17 Barrels 1.1364 0.159 1 42 US Gallons Barrels/day 0.00325 0.0038 0.0235 1 49.8 Natural Gas and LNG To Convert Billion cubic metres NG Billion cubit feet NG Million tonnes oil Million tonnes Trillion BTU MBOE equivalent LNG From Multiply by 1 billion cubic metres NG 1 35.315 0.86 0.735 34.121 5.883 1 billion cubic feet NG 0.028 1 0.024 0.021 0.966 0.167 1 million tonnes oil equivalent 1.163 41.071 1 0.855 39.683 6.842 1 million tonnes LNG 1.36 48.028 1.169 1 46.405 8.001 1 trillion BTU 0.029 1.035 0.025 0.022 1 0.172 1 MBOE 0.17 6.003 0.146 0.125 58 1 47 PTTEP