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Ecopetrol Group Releases Its Financial Results for Third Quarter 2025

1. Ecopetrol's net income declined 29.8% in 3Q 2025. 2. Revenues dropped 13.8% in 3Q 2025 due to lower oil prices. 3. Coveñas Marine Terminal enhancements aim to secure gas supply. 4. Natural gas output from self-operated fields increases for energy security. 5. New solar farm boosts renewable capacity by 77% year-over-year.

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, /PRNewswire/ -- https://files.ecopetrol.com.co/web/esp/inversionista/reporte-3q25-eng.pdf During the first-nine-months of the year, we focused our efforts on strengthening the operation of our traditional business, maintaining rigorous capital discipline, driving sustainable value through the consolidation of strategic projects that enable the country's energy transition and reinforcing energy security. The robustness of these pillars and the savings plan have enabled us to successfully navigate crude prices and exchange rate volatility, mitigate environmental impacts, and remain committed to meeting our 2025's targets. The financial results reported reflect the strength of our market and portfolio diversification strategy, in addition to the efficient integration of the hydrocarbon business. During the third quarter, our financial outcome was: revenues of COP 29.8 trillion, EBITDA of COP 12.3 trillion with a 41% EBITDA margin, and a Net Income of COP 2.6 trillion. During the nine months of the year, revenues totaled COP 90.9 trillion, EBITDA stood at COP 36.7 trillion to an EBITDA margin of 40.4%, and Net Income stood at COP 7.5 trillion. As part of our contribution to national energy security, we advanced towards increasing natural gas output from our self-operated fields, the development of offshore reserves in the Caribbean, and optimized midstream infrastructure to enable gas transportation from coastal facilities to inland demand centers. We have secured environmental clearance from the ANLA (National Environmental Licensing Authority) to execute LNG import and regasification activities through the retrofit of existing assets at the Coveñas Marine Terminal. This includes the planned deployment of a Floating Storage and Regasification Unit (FSRU), which positions Coveñas as a strategic natural gas hub in the Colombian Caribbean. This critical infrastructure will enhance supply-demand balancing and ensure reliable gas availability across the country. The commercial segment, capitalized market opportunities, maximizing the Group's financial results. In the third quarter, a sound trading differential was upheld to -3.9 USD/bbl, resulting from efficient, strategic management. In the hydrocarbons business, we reached a quarterly production of 751 mboed, driven by key fields in Colombia such as Caño Sur, CPO-09, and the Permian in the United States. Transported volumes reached 1,118 mbd, leveraged by maximizing infrastructure usage, higher third-party volumes, and the reversal of the Coveñas–Ayacucho system. Refining throughputs reached 429 mbd driven by the completion of major maintenance work in Barrancabermeja and operational improvements during the first half of the year. In the Energy Transition business line, we started operations of La Iguana Solar Farm, a new project with a capacity of 26 MW, which is expected to strengthen power supply of the Barrancabermeja refinery and to contribute towards the decarbonization of its operations. With this facility, our installed renewable energy capacity in operation reached 234 MW by the end of 3Q 2025, representing a 77% increase compared to the 132 MW available in 3Q 2024. Furthermore, we successfully completed the first phase of gas commercialization from the Floreña field, executing 39 sales agreements with 22 off-takers. We are pleased to share our progress in measuring organizational culture and workplace environment through the Great Place to Work Institute, which ranked us at the 'Highly Satisfactory' level, improving from 60 points in 2024 to 68 points in 2025 on the Workplace Environment Index. This achievement reflects our commitment to employee well-being, sustainable development, and value creation. In line with our commitment to transparency, sustainable value creation, and a fair and equitable energy transition for the country, we became the first Colombian company to voluntarily publish our first 2024 Financial Sustainability Report, incorporating reference elements from the International Sustainability Standards Board (ISSB). The results achieved during this period position us strongly to deliver on our operational and financial targets for 2025. We will continue to enhance our operational flexibility and uphold the fundamentals of each business line, with the clear purpose of navigating market challenges and safeguarding value creation for all our shareholders. Ricardo Roa BarragánPresident of Ecopetrol S.A.  Stable operations in the refining segment, control of operating expenditures ("opex"), and improved results in Interconexión Eléctrica S.A. ("ISA" and together with its subsidiaries) translated into 42% recovery in net profit compared to 2Q 2025, amid an environment of low prices and a lower exchange rate. During the first nine months of 2025, the Ecopetrol Group generated a net profit of COP 7.5 trillion, EBITDA of COP 36.7 trillion, and an EBITDA margin of 40%. The results were leveraged by increased crude oil production, the efficiency program, and improved differentials between the basket and Brent, despite lower market prices, challenges in the hydrocarbon sector, and scheduled maintenance at the Barrancabermeja Refinery. Table 1: Income Statement Financial Summary - Ecopetrol Group Billion (COP) 3Q 2025 3Q 2024 ∆ ($) ∆ (%) 9M 2025 9M 2024 ∆ ($) ∆ (%) Total sales 29,840 34,607 (4,767) (13.8 %) 90,875 98,536 (7,661) (7.8 %) Depreciation and amortization 3,954 3,811 143 3.8 % 12,042 10,857 1,185 10.9 % Variable cost 10,509 13,611 (3,102) (22.8 %) 33,812 36,452 (2,640) (7.2 %) Fixed cost 5,407 5,222 185 3.5 % 15,882 14,978 904 6.0 % Cost of sales 19,870 22,644 (2,774) (12.3 %) 61,736 62,287 (551) (0.9 %) Gross income 9,970 11,963 (1,993) (16.7 %) 29,139 36,249 (7,110) (19.6 %) Operating and exploratory expenses 2,635 2,657 (22) (0.8 %) 7,787 7,606 181 2.4 % Operating income 7,335 9,306 (1,971) (21.2 %) 21,352 28,643 (7,291) (25.5 %) Financial income (loss), net (2,046) (2,051) 5 (0.2 %) (6,549) (6,143) (406) 6.6 % Share of profit of companies 187 116 71 61.2 % 585 502 83 16.5 % Income before income tax 5,476 7,371 (1,895) (25.7 %) 15,388 23,002 (7,614) (33.1 %) Income tax (1,710) (2,264) 554 (24.5 %) (4,933) (8,418) 3,485 (41.4 %) Net income consolidated 3,766 5,107 (1,341) (26.3 %) 10,455 14,584 (4,129) (28.3 %) Non-controlling interest (1,203) (1,458) 255 (17.5 %) (2,953) (3,547) 594 (16.7 %) Net income attributable to owners of Ecopetrol 2,563 3,649 (1,086) (29.8 %) 7,502 11,037 (3,535) (32.0 %) EBITDA 12,326 13,976 (1,650) (11.8 %) 36,720 42,266 (5,546) (13.1 %) EBITDA Margin 41.3 % 40.4 % - 0.9 % 40.4 % 42.9 % - (2.5 %) The figures included in this report are unaudited and are expressed in billions Colombian pesos (COP), or US dollars (USD), thousand barrels of oil equivalent per day (mboed), or tons, as indicated where applicable. For purposes of presentation, some figures in this report were rounded to the nearest decimal place. The comparison periods correspond to those of the previous year, unless a different period is referred to. Forward-looking statement: This release may contain forward-looking statements related to business prospects, estimates for operating and financial results and growth of Ecopetrol within the meaning of the safe harbor provisions of the U.S. Private Securities Litigation Reform Act of 1995. These are projections and, as such, are based solely on management's expectations regarding the future of the Company and its permanent access to capital to fund its business plan. Actual results could differ materially from those expressed or forecasted in any forward-looking statements as a result of a variety of factors. Such forward-looking statements depend, basically, on changes in market conditions, government regulations, competitive pressures, the performance of the Colombian economy and the industry, among other factors; therefore, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information or for any other reason. Accordingly, readers should not place undue reliance on forward-looking statements. I. Financial and Operating Results Sales revenues Sales revenue totaled COP 29.8 trillion in 3Q 2025, a decrease of 13.8% or COP -4.8 trillion compared to 3Q 2024, due to: Lower sales volume (COP -2.2 trillion, -91.6 mboed), mainly due to: i) increased crude oil inventory volumes, ii) lower availability of crude oil associated with higher requirements from refineries, and iii) decreased domestic gas sales volume. Lower weighted average sales price of crude oil and products of -4.3 USD/bbl (COP -1.9 trillion), in line with the decrease in Brent price, partially offset by better crude oil and product differentials. Negative exchange rate effect (COP -0.5 trillion), associated with a lower average exchange rate. Lower income from energy and road transmission services (COP -0.2 trillion). Cumulative sales revenue in 9M 2025 of COP 90.9 trillion showed a decrease of 7.8% corresponding to COP -7.7 trillion versus 9M 2024, as a net result of: i) lower weighted average selling price of crude oil and products of -6.9 USD/bbl (COP -7.8 trillion), due to the factors explained above, ii) a decrease in sales volume (COP -2.3 trillion, -32.2 mboed) due to increased crude oil inventory volumes and lower domestic gas sales, iii) an increase in the average exchange rate, which had a positive impact on revenues (COP +2.3 trillion), and iv) higher revenues from energy and road transmission services (COP +0.1 trillion). Table 2: Volumetric Sales - Ecopetrol Group Domestic Sales Volume - mboed 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Medium distillates 186.9 184.6 1.3 % 186.2 183.7 1.4 % Gasolines 129.3 126.2 2.5 % 129.5 129.2 0.2 % Natural Gas  69.4 86.4 (19.7 %) 69.1 86.4 (20.0 %) Petrochemicals and Industrial  20.2 17.6 14.8 % 19.2 18.2 5.5 % LPG and Propane 11.8 15.0 (21.3 %) 12.7 15.6 (18.6 %) Crude oil (0.1) 0.1 (200 %) 0.0 0.0 - Fueloil 0.2 0.2 0.0 % 0.2 0.2 0.0 % Total Local Volumes 417.7 430.1 (2.9 %) 416.9 433.4 (3.8 %) Export Volumes - mboed 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Crude oil 403.1 477.7 (15.6 %) 421.9 440.0 (4.1 %) Products 117.2 123.8 (5.3 %) 109.9 110.7 (0.7 %) Natural Gas*  17.2 15.2 13.2 % 17.2 14.0 22.9 % Total Export Volumes 537.5 616.7 (12.8 %) 549.0 564.8 (2.8 %) Total Sold Volumes 955.2 1,046.8 (8.8 %) 965.9 998.1 (3.2 %) *Natural gas exports correspond to local sales by Ecopetrol America LLC and Ecopetrol Permian LLC. The total volume sold during 3Q 2025 amounted to 955 mboed, 8.8% less vs. 3Q 2024 (91.6 mboed), mainly because of a lower export sales volume.  Sales in Colombia decreased by 2.9% (-12.4 mboed) compared to 3Q 2024, mainly due to:  Decrease of 20% (-17.2 mboed) in gas sales explained by lower quantities contracted in Cusiana - Cupiagua due to the natural decline of the fields.   Decrease of 21.3% (-3.2 mboed) in LPG and Propane sales explained by less quantities offered, mainly in Cusiana and Cupiagua. Increase in fuel sales of 5.4 mboed due to greater product availability. Increase in petrochemical product sales by 2.6 mboed due to higher demand for asphalt, polypropylene, and lubricant bases.  International sales decreased by12.8% (-79.2 mboed) versus 3Q 2024, mainly due to: Decrease of 15.6% (-74.6 mboed) in crude exports due to greater throughput at the refineries (+28 mboed), and variation in inventories in the logistics chain (45 mboed). Table 3: Basket Realization Prices - Ecopetrol Group USD/bbl 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Brent 68.2 78.7 (13.3 %) 69.9 81.8 (14.5 %) Gas Sales Basket 28.8 26.8 7.5 % 28.2 27.4 2.9 % Crude Sales Basket 64.3 74.0 (13.1 %) 65.3 75.4 (13.4 %) Product Sales Basket 81.8 84.1 (2.7 %) 82.3 89.2 (7.7 %) Crudes: During the 3Q 2025, there was a decline of 9.7 USD/bbl in crude oil basket prices, mainly related to the weakening of Brent by 10.5 USD/bbl.  This effect was partially offset by the company's ability to capture a better differential (0.8 USD/bbl) driven by the uncertainty generated internationally by the imposition of tariffs, as well as from the better positioning in more profitable markets through the commercial offices in Houston and Singapore. Refined products: Despite the weakening of Brent by USD 10.5 USD/bbl during 3Q 2025 , the product sales basket weakened by only USD 2.3 USD/bbl. This variation was mitigated thanks to the strengthening of indicators versus Brent, especially in gasoline, diesel, and fuel oil, generated by low inventories, higher demand, and logistical disruptions in the Middle East, all together with the sale of more valuable products within the group's product basket. Natural Gas: The price of gas sales strengthened by 2.0 USD/bbl, rising from USD 26.8 USD/bbl to 28.8 USD/bbl, mainly due to the strengthening of domestic prices in line with contract indexation. Sale Costs Costs of sales decreased by 12.3%, equivalent to COP -2.8 trillion in 3Q25 and by 0.9%, equivalent to COP -0.6 trillion in 9M 2025 compared to the same periods of the previous year: Variable Costs Variable costs decreased by 22.8%, equivalent to COP -3.1 trillion in 3Q25 compared to 3Q 2024, explained by: Decrease in purchases of crude oil, gas, and products (COP -2.4 trillion), due to: i) lower purchase volume (COP -1.1 trillion, -40.4 mboed), mainly of fuels, given operational stability at the refineries, which allowed domestic demand to be met with more of our own product, ii) lower weighted average purchase price of -USD 7.7 USD/bbl, associated with the lower Brent reference price (COP -1.1 trillion); and iii) positive effect on purchases due to lower average exchange rate (COP -0.2 trillion). Higher inventory levels and other items (COP -0.7 trillion), with sales expected to be realized in subsequent months. Variable costs decreased by 7.2%, equivalent to COP -2.6 trillion in 9M 2025 compared to 9M 2024, explained by the net effect between: i) lower weighted average purchase price of -7.7 USD/bbl, associated with the lower Brent reference price (COP -3.6 trillion), ii) a decrease in purchase volume (COP -0.1 trillion, -5.8 mboed), and iii) a negative effect on purchases due to a higher average exchange rate (COP +1.1 trillion). Fixed Costs Fixed costs increased by 3.5% (COP +0.2 trillion) in 3Q 2025 compared to 3Q 2024, associated with: i) greater construction activity in ISA; ii) increase in contracted services and other general costs, mainly due to inflationary effect on contract rates; partially offset by iii) control and capture of cost efficiencies; and iv) lower average exchange rate. Fixed costs in 9M 2025 increased by 6.0%, (+0.9 trillion) due to: i) increased construction activity by ISA, and ii) increased maintenance, general, and other costs associated with increased activities to support operations, the inflationary effect on contract rates, and higher average exchange rate costs. The foregoing was partially offset with iii) control and capture of cost efficiencies. Depreciation and Amortization D&A increased by 3.8% (COP +0.1 trillion) in 3Q 2025, due to higher level of capital investment and local crude production and by 10.9%, equivalent to COP +1.2 trillion in 9M 2025 compared to the same periods of last year. In addition to the factors explained above, the cumulative figure as of September 30, 2025, was impacted by a negative exchange rate effect on the depreciation of Ecopetrol S.A.'s ("Ecopetrol") – subsidiaries which use the US dollar as their functional currency, given the higher average exchange rate.  Operational and Exploratory Expenses, net of Other Income Operating and exploration expenses, net of other income, decreased by 0.8%, equivalent to COP 22 billion in 3Q 2025 compared to 3Q 2024, mainly due to: i) a decrease in exploration expenses due to lower recognition in the results of exploration assets, and ii) higher taxes due to the decree declaring a state of internal commotion, inflationary effect, and provision updates in ISA. Operating and exploration expenses, net of other income, increased by 2.4%, equivalent to COP 0.2 trillion in 9M 2025 vs. 9M 2024. In addition to the items explained above, it is worth noting the provision for the energy transmission and roads business line. Financial Results (Non-Operational) The financial result during 3Q25 remained in line with 3Q24, as a net result of improved financial performance due to portfolio valuation, offset by increased debt interest, mostly derived from higher short-term debt. Net financial result (expense) increased by 6.6% (COP 0.4 trillion) in 9M 2025 from  higher financial costs due to increased short-term debt and the effect of the average depreciation of the peso against the dollar, partially offset by foreign exchange gains from lower currency exposure and the financial update of long-term liabilities. Income Taxes The effective tax rate in 9M 2025 decreased to 32.1% from 36.6% in 9M 2024, mainly due to a lower income tax surcharge in 2025 (0%) vs. 2024 (10%) given the Brent price projection at the closing date. Meanwhile, the quarterly rate stood at 31.2%, at similar levels compared to 3Q 2024. Progress in the customs correction process started by the DIAN related to VAT on fuel imports During 3Q25, the DIAN ratified Opinion No. 100202208-2305 of 19 December 2024, which, according to its interpretation, stated that the imports and nationalization of gasoline and Diesel are subject to Sales Tax (VAT) at the general rate of 19%, with the cost of the products at customs being the base for calculating the tax. Regarding VAT on fuel imports for the taxable periods 2022 (partial) to 2024, and pursuant to the aforementioned doctrine, to date, the DIAN has notified the Cartagena Refinery of six Special Customs Requirements (REAs) worth COP 1.89 trillion in VAT, penalties, and interest. Four of these assessments are currently in the reconsideration appeal stage. In two cases, the DIAN ruled on the appeal, confirming and maintaining its initial position. Meanwhile, Ecopetrol has been notified of two official assessments totaling COP 9.39 trillion, including VAT, penalties, and interest. Ecopetrol has filed reconsideration appeals against these assessments. These total amounts may increase as additional requirements are received from the DIAN Ecopetrol and Refinería de Cartagena (together, the "Companies") disagree with the DIAN's interpretation that favors retroactive VAT collection, for reasons that have been duly explained to the DIAN in response to the REAs and, subsequently, in the appeals for reconsideration against the Official Correction Settlement LOCs (LOC for its initials in Spanish). In addition, the Cartagena Refinery and Ecopetrol have involved regulatory bodies such as the Attorney General's Office and the Comptroller General's Office to accompany DIAN's audit process and the review of DIAN's opinions and doctrine, as requested by the Companies. In its interpretation, the DIAN may continue with the collection process in accordance with the procedural rules of the customs regime and Tax Code, which includes coercive collection procedures. In accordance with the customs regime and the Tax Code, the Companies have exercised the corresponding administrative or judicial resources, in accordance with the same regulations. Although both companies plan to continue exercising these resources, any eventual enforcement action could have a material adverse effect on their operations, liquidity, and financial position, depending on the amount and duration of such actions. The filing of a preventive protection action (tutela) to safeguard the companies' rights would be enabled, as recently occurred in the case of the Cartagena Refinery, where such action is currently underway. In general terms, considering the DIAN questioning and based on the opinions issued by our external advisors, who consider that the probability of success is greater than 50%, the Companies believe that there are not grounds for establishing any accounting provision. The Companies reiterate their commitment to fully comply with their customs and tax obligations and will be respectful of the decisions that resolve this controversy before the corresponding authority. Financial Position Statement The assets of the Ecopetrol Group decreased by COP -2.7 trillion, equivalent to -0.9% between June and September 2025, mainly due to: i) he remeasurement effect of subsidiaries' assets with US dollar functional currency at a lower closing exchange rate versus the previous quarter, ii) the depreciation of assets for the period (COP -3.8 trillion), iii) the update of deferred tax and other items. This was offset by a higher level of CAPEX, recognition of the FEPC for the quarter, and an increase in cash and equivalents, driven by the positive effect on operating cash flow. Liabilities decreased by COP -4.2 trillion, equivalent to -2.2% during 3Q 2025, mainly due to the net effect between: i) the decrease in the balance of financial obligations for short-term debt payments added to the effect of restating the debt in US dollars at the closing exchange rate (COP -6.0 trillion), ii) higher current taxes for the period (COP +0.9 trillion), and iii) higher accounts payable and other liabilities (COP +0.9 trillion). The Ecopetrol Group's equity at the end of 3Q 2025 was COP 107.0 trillion, an increase of COP 1.4 trillion compared to 2Q25, mainly because of profits generated during the period, offset by the adjustment for the conversion of subsidiaries with USD as their functional currency at the closing rate. 75% of the equity corresponds to Ecopetrol shareholders and the remaining 25% to non-controlling interests. Cash Flow, Debt and FEPC Table 4: Cash Position - Ecopetrol Group Billion (COP) 3Q 2025 3Q 2024 9M 2025 9M 2024 Initial cash and cash equivalents 10,118 13,237 14,054 12,336 (+) Cash flow from operations 8,878 12,465 25,047 35,549 (-) CAPEX (5,073) (5,157) (14,063) (14,059) (-) Consideration paid for acquisition of assets 0 0 (1,109) 0 (+/-) Investment portfolio movement 1,249 (2,552) (1,009) (3,237) (-) Acquisition of subsidiaries, net of cash acquired (65) (159) (65) (158) (+) Other investment activities 762 596 1,567 1,646 (+/-) Adquisition, borrowings and interest payments of debt (4,858) (2,150) (2,427) (4,064) (-) Dividend payments (329) (2,741) (11,024) (14,933) (+/-) Exchange difference (cash impact) (318) 566 (607) 1,040 (-) Return of capital 0 (6) 0 (21) Final cash and cash equivalents 10,364 14,099 10,364 14,099 Investment portfolio 3,700 4,721 3,700 4,721 Total cash 14,064 18,820 14,064 18,820  Cash Flow At the end of 3Q 2025, the Ecopetrol Group closed with a cash flow of COP 14.1 trillion (23% COP and 77% USD). Operating cash flow for the quarter and the sales of short-term treasury securities (TCOs) covered: i) capex expenditures for the quarter, and ii) principal and interest payments on debt for the quarter. Debt At the end of 3Q 2025, the balance of debt on the balance sheet was COP 114.3 trillion, equivalent to USD 29,124 million (ISA's Group´s consolidated debt contributed USD 8,736 million), representing a decrease of COP 6.0 trillion compared to 2Q 2025. The decrease is explained by the combined effect of: i) prepayment of short-term financing operations, and ii) the restatement of financial obligations in US dollars at the closing rate, recognized mainly in equity through hedge accounting. The Ecopetrol Group's Gross Debt/EBITDA ratio at the end of September 2025 was 2.4 times, below the upper limit set for 2025 (2.5 times), while the Ecopetrol Group's Net Debt/EBITDA ratio closed at 2.1 times and the Debt/Equity ratio at the end of September remained at 1.1 times. Fuel Price Stabilization Fund – FEPC At the end of September 2025, the account receivable of the FEPC stood at COP 3.3 trillion. In 3Q 2025, there is an increase compared to 2Q 2025, due to the accrual of COP +0.8 trillion for the quarter.   Efficiencies In 2025, the Ecopetrol Group continues materializing its comprehensive strategy of efficiencies and competitiveness with a contribution of COP 4.1 trillion at the close of 3Q 2025, of which 60% has had a direct impact on the EBITDA of COP 2.45 trillion (COP 1.27 trillion for efficiencies in Opex and COP 1.18 trillion for additional income generation), as detailed below: OPEX Savings of COP 270 billion through improvements in energy efficiency, self-generation, and energy purchasing were achieved, added to COP 265 billion in maintenance thanks to the reutilization of materials, optimization of artificial lift systems, and reliability strategies. Efficiencies of COP 244 billion through initiatives in digital solutions, service demand control, and insurance management, complemented by a more efficient procurement strategy that generated savings of COP 194 billion. Savings of COP 165 billion in crude evacuation and dilution, mainly for the early entry of the Caño Sur Este - ODL project. Revenue Production increase strategies contributed COP 347 billion through deferred reductions, operational improvements in well service, and process optimization in Piedemonte. Capture of synergies generated income for COP 155 billion in the crude transportation systems associated with the segregation and routing of crudes as well as for volumetric compensations for quality. Greater margins for crude exports (COP 105 billion), product imports (COP 99 billion) and the fee of the ANH purchases (COP 73 billion). Value creation in refining operations due to quality migration from HSFO to IFO-380 (COP 69 billion) and increased asphalt production in the Barranca refinery (COP 23 billion). From the point of view of unit costs, the efficiencies obtained during 9M 2025 were as follows: 52% of the efficiencies mentioned with an effect on Opex mitigated impacts on the cost of production by 0.91 USD/bbl. Efficiencies affecting refining cash costs and costs per barrel transported enabled reductions of 0.10 USD/bbl and 0.013 USD/bbl, respectively. Efficiencies of COP 1.05 trillion achieved in capex related to the optimization of project investment costs, seen at: In direct operation drilling and completion, efficiencies were achieved through improvements in design and engineering, optimization of services, rate negotiation, and reduction of processing times. Reductions in operating times and costs in Permian, thanks to new well designs, lower fracture pressures, and pumping times, which resulted in lower costs per foot drilled and per barrel pumped compared to the plan. As for surface facilities, efficiencies were achieved through the optimization of scopes in project design and engineering. Actions focused on improving working capital were implemented, with a positive cash impact of COP 0.6 trillion. This was achieved through advanced payment management with entities, avoiding debt, inventory optimization, and savings in the payment of inspection fees. Investments Table 5: Investment by Segment - Ecopetrol Group Ecopetrol Group InvestmentsBusiness Total 9M 2025 % Share Million USD Trillion COP Hydrocarbons* 2,582 10.7 62 % Energies for the Transition** 529 2.2 13 % Transmission and Toll Roads 1,068 4.4 25 % Total 4,179 17.3 100 % *Includes the total amount of investments in hydrocarbon transportation of each of the Ecopetrol Group Companies (Ecopetrol S.A. participation and non-controlling).Average exchange rate: 4,131.52**Includes investment in Gas and Energy TransitionIncludes only organic investments At the end of 3Q 2025, the Ecopetrol Group made investments totaling USD 4,179 million (COP 17.3 trillion); 62% percent in Colombia, while the remaining 38% went to international operations, mainly in Brazil (21%), the United States (12%), and other locations (5%). Hydrocarbons At 3Q 2025, investments in hydrocarbons accounted for 62% of the Ecopetrol Group's total, reaching USD 2,582 million (COP 10.7 trillion).1 Thus, USD 2,139 million (COP 8.8 trillion) was allocated to exploration and production activities, mainly in the department of Meta, in assets such as Caño Sur Rubiales, Castilla, and Chichimene. Internationally, investments were focused on the Permian basin (Midland, USA) and in Brazil, in the Orca Brazil project (formerly Gato do Mato). In the refining segment, USD 240 million (COP 1.0 trillion) have been invested, focused on operational continuity of the refineries (94%), as well as on strategic projects such as Sox Emission Control and Base Line of Fuel Quality of Fuels in the Barrancabermeja Refinery, in addition to major maintenance and plant shutdowns in both refineries. In turn, in the transport segment, investments amounted to USD 162 million (COP 0.7 trillion), mainly focused on ensuring the operational continuity of the different oil and polyduct systems in crossing activities, mechanical repairs and geotechnics. Energies for Transition In 3Q 2025, the Ecopetrol Group reaffirmed its commitment to the energy transition and allocated USD 529 million (COP 2.2 trillion) to investments in the Energy for Transition line, which represented 13% of total investment. To strengthen the value chain and gas supply, USD 425 million (COP 1.8 trillion) was invested, mainly in the GUAOFF-0 block, located in the Colombian offshore Caribbean, and in fields in the Piedemonte Llanero region, such as Floreña and Cupiagua, concentrated in the department of Casanare. Additionally, USD 104 million were allocated (COP 0.4 trillion) to energy efficiency and renewable energy projects. Transmission and Toll Roads In 3Q 2025, the Ecopetrol Group invested a total of USD 1,068 million (COP 4.4 trillion) in the Transmission and Roads business line, representing 25% of total investments.  Most of these investments (91%) were concentrated in the power transmission business, with a presence in Brazil, Peru, and Colombia. The road segment accounted for 8%, with outstanding projects such as Ruta del Este in Panama and, in Chile, the Ruta del Maipo and Ruta de los Ríos initiatives. The remaining 1% was destined to the telecommunications business in Colombia-. II. Business Lines Results For purposes of this report, the financial information included is organized by the following segments: (i) exploration and production, (ii) transportation and logistics, (iii) refining and petrochemicals, and (iv) energy transmission and toll roads, which is consistent with the Company's previous reports. Nevertheless, management is reviewing other options to update the Company's operating, management, and financial reporting model in line with Strategy 2040. 1.  HYDROCARBONS 1.1  Exploration, Development and Production Exploration: At the end of 3Q 2025, 10 exploratory wells had been drilled, 8 with investment from the Ecopetrol Group, and 2 drilled under association contracts, with 100% investment by the partner (see annexes – Table 11: Details of Exploratory Wells – Ecopetrol Group). In the onshore exploration activity, the following stands out: The declaration of commerciality on September 30, 2025, of the Toritos discoveries (includes the Curucutu-1 well) and Saltador wells (includes the Bisbita Este-1, Bisbita Centro-1 and Bisbita Oeste-1 wells) located in the LLA 123 block in the department of Meta.  Operated by Geopark in association with Hocol, these fields contribute a net production of 1.9 mboed crude ranging between 14° and 23° API. This approval is expected to allow us to certify proved reserves (1P) and contingent resources for the 2025 balance. Drilling continued on the Floreña N18Y well operated by Ecopetrol (100%), located in the Piedemonte, and Toritos Este-1 operated by Geopark (50%) in association with our subsidiary Hocol (50%), located in Los Llanos. Both wells are expected to reach final depth in 4Q 2025. To highlight, the offshore exploration activity with the progress of the Sirius project, regarding the contracting model and the ethnic, social and environmental feasibility activities; the environmental licensing process is expected to continue in a next stage. Internationally, activities related to the development of the Orca field in Brazil advanced in the execution of detailed engineering for the hull and topside facilities of the floating production, storage, and offloading vessel (FPSO).  In addition, the approval of the development plan, by the ANP is currently being processed, as well as the installation of the SURF subsea system and the drilling campaign of development wells planned for 2027. Production  Table 6: Gross Production - Ecopetrol Group Production - mboed 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Crude Oil 500.0 493.0 1.4 % 497.1 493.6 0.7 % Natural Gas 102.3 117.4 (12.9 %) 103.8 119.6 (13.2 %) Total Ecopetrol S.A. 602.3 610.4 (1.3 %) 600.9 613.2 (2.0 %) Crude Oil 21.5 17.9 20.1 % 21.5 17.9 20.1 % Natural Gas 13.7 16.4 (16.5 %) 14.2 17.3 (17.9 %) Total Hocol 35.2 34.3 2.6 % 35.6 35.2 1.1 % Crude Oil 7.9 6.2 27.4 % 7.9 7.2 9.7 % Natural Gas 1.0 0.9 11.1 % 0.9 0.9 0.0 % Total Ecopetrol America 8.9 7.2 23.6 % 8.8 8.1 8.6 % Crude Oil 54.9 58.0 (5.3 %) 57.3 55.6 3.1 % Natural Gas 50.1 44.6 12.3 % 48.2 39.6 21.7 % Total Ecopetrol Permian 105.0 102.6 2.3 % 105.5 95.2 10.8 % Crude Oil 584.3 575.1 1.6 % 583.7 574.3 1.6 % Natural Gas 167.1 179.3 (6.8 %) 167.1 177.4 (5.8 %) Total Ecopetrol Group 751.5 754.4 (0.4 %) 750.9 751.7 (0.1 %) Note 1: Gross production includes royalties and is prorated by Ecopetrol's holding in each company. The Natural Gas data includes Gas and Blanks (LPG, propane and butane).Note 2: Consolidated data presented in rounded up figures.Note 3: The table of this report includes 100% production of Arauca-8 for both 2024 and 2025 figures. The owner of the Arauca Agreement is Ecopetrol; therefore, 100% of the ownership of the production of the Arauca Agreement Area is in the hands of Ecopetrol; however, by virtue of the private agreement (Bussiness Collaboration Agreement (BCA), entered into between Ecopetrol and Parex, once the hydrocarbons of the Arauca Agreement are produced, Ecopetrol, immediately transfers to Parex 50% of all the production obtained in the contracted area.Note 4: Quarterly production figures subject to minor updates due to ministerial forms to the ANH of associated fields and closures in international subsidiaries.Note 5:  2025 figures include production from the El Niño, Guando and Guando SW fields (4.3 mboed in 3Q 2025) in the Hocol subsidiary, given the transfer made by Ecopetrol S.A. in late 2024, in line with the Ecopetrol Group's presence strategy in the Department of Tolima through this subsidiary. The Ecopetrol Group's production in 3Q 2025 was 751 thousand barrels of oil equivalent per day (mboed), 3 mboed less than in the same period of the previous year, mainly due to the net effect of: i)  (+30 mboed) Growth of Caño Sur supported by the increase in fluid treatment capacity at the Centauros Station and the acquisition of 45% of Repsol's stake in block CPO9, in addition to the growth actions associated with the progressive entry of the Orotoy Station.ii)  (+5 mboed) Improved performance by Permian and Ecopetrol América.iii)  (-15 mboed) Lower gas production and blanks due to natural decline of the Cusiana-Cupiagua node, Recetor (Piedemonte Llanero), and higher-than-expected water intrusion in the Guajira and Gibraltar fields.iv)  (-23 mboed) in domestic crude oil due to electrical events in Meta and Magdalena Medio, public order issues, natural decline of fields, and delays in projects and drilling associated with blockades at the beginning of the year. In response to the effect on production caused by environmental events, during 3Q25 there was a cumulative impact of 369,000 barrels, with cumulative deferred production for the 9M 2025 amounting to 2.15 million barrels. The impacts in 3Q 2025 were mainly concentrated in the departments of Meta and Putumayo due to: i) permanent blockades in CPO-9 that lasted until October, and ii) operational and access road events in Cupiagua that affected the delivery of white products in August and September. As for drilling, at the end of September, 331 development wells were completed, with an average of 22 active drilling rigs over the period. Lifting and Dilution Cost  Table 7: Lifting and Dilution Cost - Ecopetrol Group USD/bbl 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) % USD Lifting Cost* 12.18 12.65 (3.8 %) 11.81 12.25 (3.6 %) 26.0 % Dilution Cost** 4.76 4.70 1.7 % 4.85 5.14 (5.6 %) 100.0 % Lifting Cost The lifting cost in 3Q 2025 decreased by -0.48 USD/bbl compared to the same period last year, mainly leveraged by the efficiencies achieved as follows: Exchange rate effect (+0.27 USD/bbl): negative effect due to the conversion of costs from pesos to dollars, given the lower average exchange rate, which went from 4,094 to 4,004 COP/USD. Considering that 74% of the costs are expressed in pesos, the peso indicator decreased by 6% from 51,795 COP/bbl to 48,755 COP/bbl. Cost Effect (-0.74 USD/bbl): Operating optimizations achieved include: Optimization of the operations and maintenance model for non-industrial areas. Energy optimization: optimization of self-generation mainly in Rubiales and Caño Sur, as well as a reduction in energy consumption thanks to the massification of more efficient technologies and operational control of production and injection facilities. Efficiencies in well maintenance, reutilization of materials for subsurface operations, optimization of artificial lift systems, and optimization of reliability strategies, among others. These efficiencies allowed us to partially offset the following cost increases: Cumulative inflation impact on operating service. Fluids treatment: Increase in volumes treated (+813 MBWPD)2. Increased subsurface activities associated with new treatment and production facilities. Dilution Cost The dilution cost increased by USD 0.08/Bl compared to 3Q24, mainly explained by: Cost effect (-0.02 USD/bbl): lower purchase price of naphtha associated with the Brent benchmark indicator at -11 USD/bbl. Volume Effect (0.10 USD/bbl): Fewer barrels of crude oil marketed. Financial Results  Table 8: Income Statement - Exploration and Production Billion (COP) 3Q 2025 3Q 2024 ∆ ($) ∆ (%) 9M 2025 9M 2024 ∆ ($) ∆ (%) Total revenue 17,378 20,474 (3,096) (15.1 %) 53,884 60,689 (6,805) (11.2 %) Depreciation, amortization and depletion 2,846 2,794 52 1.9 % 8,712 7,689 1,023 13.3 % Variable costs 6,889 7,439 (550) (7.4 %) 21,670 22,137 (467) (2.1 %) Fixed costs 3,259 3,560 (301) (8.5 %) 9,845 10,200 (355) (3.5 %) Total cost of sales 12,994 13,793 (799) (5.8 %) 40,227 40,026 201 0.5 % Gross income 4,384 6,681 (2,297) (34.4 %) 13,657 20,663 (7,006) (33.9 %) Operating and exploratory expenses 1,391 1,673 (282) (16.9 %) 4,267 4,778 (511) (10.7 %) Operating income 2,993 5,008 (2,015) (40.2 %) 9,390 15,885 (6,495) (40.9 %) Financial result, net (949) (991) 42 (4.2 %) (2,992) (2,951) (41) 1.4 % Share of profit of companies 3 9 (6) (66.7 %) 18 25 (7) (28.0 %) Income before income tax 2,047 4,026 (1,979) (49.2 %) 6,416 12,959 (6,543) (50.5 %) Provision for income tax (674) (1,320) 646 (48.9 %) (2,163) (5,654) 3,491 (61.7 %) Consolidated net income 1,373 2,706 (1,333) (49.3 %) 4,253 7,305 (3,052) (41.8 %) Non-controlling interest 20 23 (3) (13.0 %) 65 63 2 3.2 % Net income attributable to owners of Ecopetrol 1,393 2,729 (1,336) (49.0 %) 4,318 7,368 (3,050) (41.4 %) EBITDA 6,242 8,080 (1,838) (22.7 %) 19,363 24,456 (5,093) (20.8 %) EBITDA Margin 35.9 % 39.5 % - (3.6 %) 35.9 % 40.3 % - (4.4 %) Revenues decreased during 3Q 2025 and 9M 2025 compared to 3Q 2024 and 9M 2024, mainly due to a lower Brent reference price and lower sales volume associated to: i) increased crude oil inventory volumes and ii) decreased domestic gas sales volume, which are partially offset by the strengthening of the crude oil differential. As for 3Q 2025 compared to 3Q 2024, the lower average exchange rate had a negative effect, whereas for 9M 2025 compared to 9M 2024, this effect was favorable. The cost of sales duringe3Q25 compared to 3Q24 decreased due to: Efficiencies achieved in energy, optimization of the operation and maintenance model, and reduction in contract rates, offsetting the increase associated with the inflationary effect. Decrease in purchases from third parties mainly due to: i) lower reference price and ii) lower volumes purchased. In 9M 2025, cost of sales remained in line to those of 9M 2024 because of: The foregoing energy efficiencies are offset with the inflationary effect. Decrease in purchases from third parties mainly due to: i) lower reference price and ii) lower volumes purchased from royalties to the ANH. Offset by the increase in depreciation, amortization, and depletion associated with higher capex and increased production at foreign subsidiaries. Increase in transportation costs due to: i) higher average exchange rate, ii) increase in tariffs, iii) increased contingent operation in Banadía - Araguaney. Operating and exploration expenses during 3Q25 and 9M25 compared to 3Q24 and 9M24 decreased mainly due to lower exploration asset expenses and lower marketing expenses.  Net financial expenses in 3Q25 compared to 3Q 2024 decreased mainly due to the increase in financial income, offset by the exchange rate difference on the segment's passive position in US dollars. For 9M 2025 compared to 9M 2024, expenses were higher mainly due to the increase in interest expenses, offset by the exchange rate difference on the segment's net dollar liability position. The decrease in income tax expense for 3Q 2025 and 9M 2025 compared to 3Q 2024 and 9M 2024 was in line with the segment's results and a lower income surcharge given the current outlook for Brent prices. 1.2  Transport and Logistics  Table 9. Transported Volumes - Ecopetrol Group mbd 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Crude Oil 814.7 808.4 0.8 % 801.5 823.6 (2.7 %) Products 303.0 299.4 1.2 % 296.4 302.6 (2.0 %) Total 1,117.7 1,107.8 0.9 % 1,097.9 1,126.2 (2.5 %) Note: The reported volumes are subject to adjustments due to changes in the quality volumetric compensation (CVC for its initials in Spanish), associated with the officialization of volumetric balances. At the end of 3Q 2025, the total volume transported was 1,117.7 mbd (+10.1 mbd compared to 3Q 2024 and +33.7 mbd compared to 2Q25. For 9M 2025, there was a decrease of 28.3 mbd vs the same period of 2024. Crudes: Transported volumes grew by 0.8% in 3Q 2025 compared to 3Q 2024 and by 3.6% compared to 2Q25, showing progressive recovery after the external events in the first half year. This performance was driven by contingency operations that enabled inventory evacuation and guaranteed production continuity in the Llanos Norte area. In addition, third-party volumes were incorporated, including production from the Acordionero field, which was previously outside the pipeline network. During the 9M 2025, volumes fell by 2.7% due to lower third-party production, blockades, and infrastructure disruptions.  During 3Q 2025, the operational connection between Coveñas and the Barrancabermeja Refinery was initiated through the reversal of the Coveñas–Ayacucho system (16"), enabling the import of light crudes and optimizing the use of existing infrastructure. This first stage allows the import of 6 mbd of light crudes at a competitive tariff, expanding the basket of crudes available for refining and generating additional transported volumes for the transportation segment. Year-to-date, approximately 91.1% of the crude oil volume transported was owned by the Ecopetrol Group. Refined products: Transported volumes grew 1.2% during 3Q 2025 compared to 3Q 2024, driven by the recovery of deliveries following refinery maintenance in 1H25. In the 9M 2025, there was a 2% reduction due to lower deliveries from the refineries, partially offset by strategic imports to ensure supply in the interior of the country. Year to date, Ecopetrol S.A. products represented 31.9% of the total volume transported through polyducts. Third party affectation on transportation infrastructure: In the 9M 2025, 26 events were recorded (6 in 3Q 2025) compared to 30 in 9M 2024 (28 in 3Q 2024). In turn, in 3Q 2025, the removal of illicit valves increased by 40% compared to 3Q 2024, and by 10% for 9M 2025. Disruptions in the Caño Limón–Coveñas system (suspended in the Banadía–Ayacucho section since 3Q24) and on the Banadía–Araguaney alternate route (suspended for 90 days during 9M 2025) limited production and transportation by approximately 5 mboed during 9M 2025. Nevertheless, logistical continuity was ensured by activating alternate evacuation routes, using technology, promptly repairing affected sections, strengthening inter-institutional relations, and implementing operational plans that preserved the quality of the crude oil and transport capacity. Hence, approximately 11.5 million of barrels were mobilized via the alternate Banadía–Araguaney route (vs. approximately 2.5 million of barrels in 9M 2024), evacuation capacity in Araguaney was expanded to approximately 83 mbd at the end of 3Q 2025, and temporary redirectioning schemes were implemented to prioritize affected production, allowing refineries to be supplied, export commitments to be met, and production delays to be mitigated. The installation of illicit valves affected operations across various systems, particularly in Pozos–Galán, restricting approximately 15 mbd during 9M 2025 (+6.8 mbd compared to 9M 2024). Strategic Advancement in Gas Initiatives: In 3Q 2025, the Ecopetrol Group, through Cenit, consolidated key advances in strategic projects aimed at strengthening the country's energy security and optimizing the natural gas transportation infrastructure: Caribbean Gas Import Program: This program is planned to use the existing infrastructure of crude oil for mobilizing imported LNG (Liquefied Natural Gas) from the Caribbean coast to the interior or the country. Among the main milestones is the environmental authorization granted by ANLA for operations at the Coveñas Maritime Terminal, where a Floating Storage and Regasification Unit (FSRU) is expected to be installed. For the project's analysis and evaluation, competitive advantages were identified in relation to the availability of existing infrastructure, metocean conditions, timeliness, and reliability, positioning it as a new strategic natural gas hub in the Colombian Caribbean, key to balancing supply and demand and strengthening national supply security. Other Strategic Project s: Ecopetrol is advancing initiatives to connect the fields of the Lower Magdalena Valley (VIM) with the National Gas Transportation System (SNT) in Vasconia, a project prioritized by the Ministry of Mines and Energy within the Natural Gas Supply Plan (PAGN). Despite requiring regulatory definitions, the Company has focused its efforts on technical and engineering development, reducing uncertainties and preparing the final investment decision.  Table 10: Cost per Transported Barrel - Ecopetrol Group USD/bbl 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) % USD Cost per Transported Barrel 3.36 3.34 0.6 % 3.21 3.16 1.6 % 17.0 % Cost per Transported Barrel: The cost per barrel transported in 3Q 2025 showed a slight increase, settling at 3.36 USD/bbl. Exchange Rate effect (+0.07 USD/bbl): Negative effect due to lower average exchange rate -90 COP/USD going from 4,094 to 4,004 COP/USD for the conversion of the indicator from pesos to dollars. Volume Effect (-0.03 USD/bbl): Increased volume transported by 0.9%, equivalent to 10.1 mbd, due to the conditions mentioned above. Cost Effect (-0.02 USD/bbl): This was mainly associated with lower maintenance activity, coupled with cost control and optimization strategies implemented in the segment, which mitigated the impact of inflation on maintenance contract rates, support areas, and labor costs, added to the increase in emergency response expenses resulting from the aforementioned impacts. Financial Results  Table 11: Income Statement – Transport Billion (COP) 3Q 2025 3Q 2024 ∆ ($) ∆ (%) 9M 2025 9M 2024 ∆ ($) ∆ (%) Total revenue 3,836 3,775 61 1.6 % 11,684 10,968 716 6.5 % Depreciation, amortization and depletion 330 325 5 1.5 % 994 952 42 4.4 % Variable costs 204 204 0 0.0 % 616 619 (3) (0.5 %) Fixed costs 553 577 (24) (4.2 %) 1,522 1,526 (4) (0.3 %) Total cost of sales 1,087 1,106 (19) (1.7 %) 3,132 3,097 35 1.1 % Gross income 2,749 2,669 80 3.0 % 8,552 7,871 681 8.7 % Operating expenses 326 300 26 8.7 % 862 698 164 23.5 % Operating income 2,423 2,369 54 2.3 % 7,690 7,173 517 7.2 % Financial result, net (52) 0 (52) - (246) 183 (429) (234.4 %) Income before income tax 2,371 2,369 2 0.1 % 7,444 7,356 88 1.2 % Provision for income tax (887) (834) (53) 6.4 % (2,717) (2,568) (149) 5.8 % Consolidated net income 1,484 1,535 (51) (3.3 %) 4,727 4,788 (61) (1.3 %) Non-controlling interest (302) (293) (9) 3.1 % (953) (898) (55) 6.1 % Net income attributable to owners of Ecopetrol 1,182 1,242 (60) (4.8 %) 3,774 3,890 (116) (3.0 %) EBITDA 2,796 2,746 50 1.8 % 8,826 8,291 535 6.5 % EBITDA Margin 72.9 % 72.8 % - 0.1 % 75.5 % 75.6 % - (0.1 %) In 3Q 2025 compared to 3Q 2024, revenues increased due to the larger Banadía-Araguaney contingency operation, as well as higher volumes transported due to the integration of production from the Acordionero field into the transportation network, the release of inventories from Caño Limón, and the recovery of deliveries from refineries after the completion of maintenance, which partially offset lower third-party production in the country and the impact of a lower average exchange rate. Revenues in the 9M 2025 increased compared to 9M 2024 due to i) a higher average exchange rate, ii) the aforementioned operational factors, and iii) tariffs updates. These effects offset i) lower revenues associated with the release of contracted capacity under the "Ship or Pay" modality in the Bicentenario and Caño Limón-Coveñas oil pipelines, as well as ii) lower volumes transported compared to the previous period due to external impacts (blockades and damage to the infrastructure), lower production from third parties in the country and major maintenance at the Barrancabermeja Refinery. The cost of sales during 3Q 2025 decreased compared to 3Q 2024, mainly due to the reduction in maintenance activities, partially offset by the increase associated with the inflationary effect. For 9M 2025 compared to 9M 2024, it remained in line with the previous year, reflecting the effectiveness of the cost control and optimization strategies implemented in the segment. Operating expenses, net of other revenue, for 3Q 2025 and 9M 2025 increased compared to 3Q 2024 and 9M 2024, mainly due to higher emergency response expenses given the events in the environment. Additionally, in 3Q 2024 and 9M 2024, non-recurring revenue was recognized from the sale of excess line-fill volume at Ocensa to Ecopetrol S.A. Financial revenue (expenses) for 3Q 2025 and 9M 2025 showed higher expenses compared to 3Q 2024 and 9M 2024, mainly due to: i) the exchange rate effect on the segment's net dollar position, and ii) lower financial returns associated with the behavior of interest rates on deposits and investment.    1.3  Refining and Petrochemicals The segment's consolidated throughput reached 428.7 mbd, representing a 7% increase compared to the same period in 2024 (401.4 mbd), positioning 3Q 2025 as the second-highest quarterly throughput in the segment's history. The integrated gross refining margin stood at USD 14.3 per barrel, doubling the 3Q 2024 result (USD 7.0 per barrel), driven by a favorable pricing environment, higher demand, and improvements in operational efficiency. This performance was supported by tactical and commercial actions that allowed us to: i) mitigate the reduced availability of light crude because of attacks on the Caño Limón–Coveñas pipeline, ii) take advantage of the completion of shutdowns to increase throughput and improve operational indicators, iii) advance the fuel oil reduction strategy, with a new logistics operation that projects a 40% increase in solid asphalt exports, iv) launch the supply of marine fuel with biodiesel in the Colombian Caribbean, aligned with the sustainability and diversification strategy; and v) capture efficiencies in revenues, costs and investment, through new initiatives and operational optimizations.  During 3Q25, the Ecopetrol Group consolidated key advances for the Downstream relative to sustainability, operational efficiency and commercial expansion, through initiatives that strengthen its position in the regional energy market:  Marine fuel with biodiesel: On August 14, from the Cartagena Refinery, the distribution of 10,500 barrels per day with a 2% biodiesel blend began, contributing to the reduction of 27 thousand tons of CO₂e per year and positioning Colombia as a regional benchmark in low-carbon energy solutions. Reactivation of the UOP II plant: On 2 September, the major maintenance of the UOP II cracking plant in Barrancabermeja was successfully completed, with an investment of USD 123 million and the participation of more than 2,200 workers. Solid asphalt exports open new markets in Latin America. On 17 September, Ecopetrol started a multimodal logistics operation to export solid asphalt from Barrancabermeja and the Port of Cartagena to countries in the Caribbean, Central and South America that lack the infrastructure to handle liquid asphalt. This new alternative complements traditional operations, expands the Ecopetrol's commercial scope, and is estimated to generate profits of nearly USD 1.5 million annually. Cartagena Refinery In 3Q25, the Cartagena Refinery reached a throughput of 200.2 mbd, representing an increase of 8.2% compared to the same period in the previous year. In the first nine months of the year (9M 2025), the average throughput volume was 194.3 mbd, in line with the same period in 2024. This performance was explained by a diet focused on domestic crude, which compensated the lower volumes from Caño Limón, and by a more stable operation in the crude units, without the effects of maintenance and general shutdowns that occurred in 3Q24. In 3Q 2025, the gross refining margin was USD 12.8/bbl, almost double than the one recorded in 3Q 2024, driven by i) higher fuel prices (55%), ii) an optimized diet with heavy domestic crude (7%); and iii) better operating performance minimizing funds (38%). In 9M 2025, the margin reached 11.4 USD/bbl, a 15.2% higher than those in the same period in 2024, explained 22% by the strengthening of cracks and 78% by the optimization of the diet. Table 12: Throughput, Utilization Factor, Production and Refining Margin Cartagena Refinery Cartagena Refinery 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Throughput* (mbd) 200.2 185.0 8.2 % 194.3 194.5 (0.1 %) Utilization Factor (%) 84.8 % 65.3 % 29.9 % 82.8 % 81.2 % 2.0 % Refined Products Production 190.9 173.4 10.1 % 185.8 186.0 (0.1 %) Gross Margin  (USD/bbl) 12.8 4.6 178.3 % 11.4 9.9 15.2 % *Corresponds to actual throughput volumes processed, not received Barrancabermeja Refinery In 3Q25, the Barrancabermeja Refinery processed a throughput of 228.6 mbd, representing an increase of 5.7% compared to the same period in the previous year. This result was driven by the recovery of the operational availability of the Diesel Hydrotreating Unit and, once maintenance was secured, by the strategic decision to maximize throughput to increase production of gasoline, medium distillates and petrochemicals. In the 9M 2025, the average throughput was 218.6 mbd a 2.2% lower than that of the same period in 2024, affected by lower volumes of light blend and Caño Limón, as well as by restrictions in the supply of crude due to stoppages in the 20" Vasconia–Galán line. In 3Q 2025, the gross refining margin was 15.6 USD/bbl, 73.3% more than that of 3Q 2024, driven mainly by i) higher product prices (77%); and ii) better operating performance (23%) thanks to higher volumes of gasoline and diesel, as well as alkylation efficiency. In the 9M 2025, the margin reached 13.7 USD/bbl, 28% more than that of the same period in 2024. 93% of the increase is explained by the strengthening of prices and 7% by the optimization of the diet. These factors were partially offset by lower performance due to maintenance.  Table 13: Throughput, Utilization Factor, Production and Refining Margin - Barrancabermeja Refinery Barrancabermeja Refinery 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Throughput* (mbd) 228.6 216.3 5.7 % 218.6 223.5 (2.2 %) Utilization Factor (%) 81.3 % 77.7 % 4.7 % 74.1 % 77.5 % (4.4 %) Refined Products Production 231.6 220.4 5.1 % 221.0 227.2 (2.7 %) Gross Margin  (USD/bbl) 15.6 9.0 73.3 % 13.7 10.7 28.0 % *Corresponds to actual throughput volumes processed, not received Esenttia During 3Q 2025, Esenttia faced a challenging environment marked by moderate propylene demand and high international competition, especially from Asia, in a context of historically low prices. Despite these conditions, the company achieved sales of 118.1 Kton, which represented a 13.8% growth compared to that of 3Q 2024. This result was possible thanks to a disciplined execution of the business plan, which included market segmentation, tactical price adjustments and strengthening of customer relationships. Volume increases were noted in Brazil, Colombia, Venezuela, Mexico, and Canada. In 9M 2025, cumulative sales reached 325.2 Kton, 12.4% more than in the same period of 2024. To protect profitability, operational efficiency measures were implemented that generated savings of USD 9.3 million through cost optimization, energy efficiency, overhead rationalization, and investment prioritization. Table 14. Esenttia Sales Esenttia 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Total Sales (KTon) 118.1 103.8 13.8 % 325.2 289.2 12.4 % Refining Cash Cost  Table 15. Refining Cash Cost* USD/bbl 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) % USD Refining Cash Cost 5.56 5.72 (2.8 %) 5.62 5.57 0.9 % 16.4 % * Includes refineries in Barrancabermeja, Cartagena and Esenttia  The refining cash cost decreased by 0.16 USD/bbl in 3Q 2025 compared to 3Q 2024, explained by:   Volume Effect (-0.37 USD/bbl): Mainly due to high crude oil throughput at the refineries of 23.7 mbd. Cost Effect (+0.09 USD/bbl): Higher costs associated with inflationary effect (+0.31 USD/bbl), lower gas cost due to price effect and lower gas consumption for the use of substitutes, increasing availability for domestic supply (-0.31 USD/bbl) and higher operational activity in throughputs (+0.09 USD/bbl). Exchange Rate effect (+0.12 USD/bbl): Impact of lower exchange rate of -90 pesos per dollar, going from 4,094 to 4,004 pesos per dollar.  Financial Results Table 16: Income Statement - Refining  Billion (COP) 3Q 2025 3Q 2024 ∆ ($) ∆ (%) 9M 2025 9M 2024 ∆ ($) ∆ (%) Total revenue 16,631 17,061 (430) (2.5 %) 49,589 51,440 (1,851) (3.6 %) Depreciation, amortization and depletion 490 415 75 18.1 % 1,480 1,400 80 5.7 % Variable costs 14,691 15,967 (1,276) (8.0 %) 44,455 46,574 (2,119) (4.5 %) Fixed costs 799 686 113 16.5 % 2,398 2,081 317 15.2 % Total cost of sales 15,980 17,068 (1,088) (6.4 %) 48,333 50,055 (1,722) (3.4 %) Gross income 651 (7) 658 (9,400.0 %) 1,256 1,385 (129) (9.3 %) Operating expenses 691 631 60 9.5 % 1,890 1,744 146 8.4 %  Operating income (loss) (40) (638) 598 (93.7 %) (634) (359) (275) 76.6 % Financial result, net (230) (345) 115 (33.3 %) (794) (1,134) 340 (30.0 %) Share of profit of companies 56 52 4 7.7 % 153 150 3 2.0 % Loss before income tax (214) (931) 717 (77.0 %) (1,275) (1,343) 68 (5.1 %) Provision for income tax 92 400 (308) (77.0 %) 457 591 (134) (22.7 %) Consolidated net income (122) (531) 409 (77.0 %) (818) (752) (66) 8.8 % Non-controlling interest (56) (59) 3 (5.1 %) (152) (156) 4 (2.6 %) Net income attributable to owners of Ecopetrol (178) (590) 412 (69.8 %) (970) (908) (62) 6.8 % EBITDA 783 120 663 552.5 % 1,930 2,001 (71) (3.5 %) EBITDA Margin 4.7 % 0.7 % - 4.0 % 3.9 % 3.9 % - 0.0 % Income decreased during 3Q 2025 compared to 3Q 2024, due to lower prices and a lower exchange rate offset by higher throughput and strengthening of cracks. Likewise, revenues in 9M 2025 compared to 9M 2024 decreased mainly due to: i) the fall in product prices, and ii) lower sales volumes associated with scheduled plant shutdowns of the major maintenance cycle at the Barrancabermeja Refinery and operational events at the Cartagena Refinery; these were partially offset by the strengthening of the crack and the positive effect of a higher average exchange rate. The cost of sales for 3Q 2025 decreased compared to 3Q 2024 due to a reduction in diet costs resulting from a drop in Brent crude oil prices, in addition to a lower average exchange rate. Similarly, for 9M 2025 compared to 9M 2024, it decreased mainly due to: i) the fall in product prices, and ii) lower purchases due to the shutdown plan; this was partially offset by: iii) the exchange rate effect on purchases at the average exchange rate wholesale rate. Operating expenses during 3Q 2025 and 9M 2025 increased compared to 3Q 2024 and 9M 2024, mainly due to the effect of inflation, which was partially offset by the implementation of the efficiency plan. Financial net expenses for 3Q 2025 compared to 3Q 2024 and for 9M 2025 compared to 9M 2024, showed lower expenses mainly because of the exchange rate difference in the valuation of the segment's net position. 1.4  Commercial Management The strong performance of the commercial offices in Houston and Singapore, Ecopetrol US Trading (EUST) and Ecopetrol Trading Asia (ECPTA), stands out. During 3Q 2025, they traded 33.5 million barrels of crude oil and products (38% of EG's total sales), generating EBITDA of USD 63 million and net income of USD 43 million, thus accumulating a total of USD 156 million in EBITDA and USD 128 million in net income for 2025. These results are leveraged by the execution of forward contracts for the sale of Castilla crude oil and other products such as fuel oil and naphtha, which enabled logistical and market efficiencies. The sale of asphalt has enabled the Ecopetrol Group to consolidate its position as the leading exporter of this product in Latin America.  In 3Q 2025, it achieved an 18% increase compared to 3Q 2024, rising from 7.02 mboed to 8.26 mboed, based on a strategy of market and customer diversification. Continuing with the expansion of the commercial portfolio, in products and petrochemicals, the first export of solid asphalt was made through the Port of Cartagena, with FOB delivery terms for 256 tons to Chile. Likewise, in August 2025, deliveries of marine diesel with 2% biodiesel began from the Cartagena Refinery to domestic customers. The initiative contributes to the decarbonization of the maritime sector in Colombia, allowing Ecopetrol to become a benchmark in the region by standardizing national quality, delivering the same blend in the Pacific and the Caribbean. It should also be noted that, to continue improving the quality of our products and increase their competitiveness internationally, in January we started to market an improved quality of Barrancabermeja Fuel Oil with a viscosity of 380 cSt and an average metal content of 107 ppm. This improvement has translated into a higher valuation compared to the HSFO that had been marketed previously. Hedging Program: During 3Q 2025, Ecopetrol covered volumes of 3.1 million barrels based on export indicators and pricing windows. From Ecopetrol Trading Asia, tactical hedges were executed for 7.9 million barrels, while Ecopetrol US Trading covered 1.4 million barrels under similar conditions. In turn, the Cartagena Refinery did not perform tactical hedging during the quarter. 2. ENERGIES FOR TRANSITION Natural Gas In September 2025, the first phase of the gas commercialization process for the Floreña field was carried out, with deliveries scheduled for the period from June 2026 to November 2028. This was achieved after securing various measures that enabled the gas produced from this source to be marketed through the Cusiana field plant, which has the benefit of adding additional quantities to the domestic market. During the commercialization process, 39 contracts were signed with 22 customers, which are aimed at meeting essential demand, operating the compression stations of the National Transport System, and meeting the demand of residential users and small commercial users. Ecopetrol continues optimizing its natural gas consumption. So far this year, there has been a 12% reduction in consumption compared to estimates for the period (around 234 GBTUD) and an increase in the use of substitute energy sources, which account for around 12% of current consumption. Natural Gas Options The Ecopetrol Group obtained authorization from the National Environmental Licensing Authority (ANLA) to conduct activities for the receipt and storage of Liquefied Natural Gas (LNG) using the existing offshore infrastructure at the Coveñas Maritime Terminal in the department of Sucre, operated by the subsidiary Cenit.  This authorization, together with the results of technical studies conducted by Ecopetrol in conjunction with international experts during 2025, enables the development of a Floating Storage Regasification Unit (FSRU) terminal at the aforementioned terminal. Liquefied Petroleum Gas (LPG) During 3Q 2025, the Public Offer of Quantities (OPC) process for LPG was carried out, which allocated volumes to 83 companies for a total of approximately 28,000 tons per month, equivalent to 10.8 mboed. These quantities are expected to be delivered between September 2025 and February 2026, coming from the Cusiana, Cupiagua, and Dina fields, as well as the Cartagena and Barrancabermeja refineries. Coverage of the electricity demand of the Ecopetrol Group In 3Q25, the Ecopetrol Group's total electricity demand averaged approximately 23.46 GWh/day, equivalent to 10.6% of the electricity demand of Colombia's National Interconnected System (SIN).  59.3% of total demand for the period was met through self-generation and 40.7% through purchases from the Wholesale Energy Market (MEM). It is important to note that 79.2% of purchases from the MEM corresponded to contracts. Therefore, the Ecopetrol Group's demand was covered 91.57% through self-generation and contracts, minimizing exposure to market prices to 8.43%. In the same period of 2024, the percentage of energy supplied through self-generation and contracts was 79.92%. The increase in coverage through self-generation and contracts between 2024 and 2025 translates into stability in the cost of energy supply. Renewable energy At the end of 3Q25, the La Iguana Solar Farm, a new photovoltaic generation project with an installed capacity of 26 MW, began operations. This initiative is expected to strengthen the competitiveness of the electricity supply for the Barrancabermeja Refinery and nearby production fields, contributing to estimated savings of between 6% and 15% in total energy costs, depending on the level of coverage achieved in 2026, considering both self-generation and supply contracts. Including this addition, the total renewable energy capacity in operation at the Ecopetrol Group increased from 132 MW at the end of 3Q24 to 234 MW in 3Q25. In 3Q25, the engagement and socialization activities were carried out with the communities involved in the Windpeshi project in La Guajira, in coordination with government entities, local communities, and specialized teams. This has allowed Ecopetrol to enter the territory in an appropriate, agreed-upon, and informed manner, strengthening relationships of trust with the communities and other stakeholders involved in the project. Regarding the operation of the Brisas, Castilla, San Fernando, and La Cira solar farms, the Cantayús Small Hydroelectric Plant, and the solar farms in the transportation segment, at the end of 3Q25, there has been an accumulated reduction of around 35,700 tCO2e and energy cost savings close to COP 41.7 billion. Such economic savings amount to 104.7 billion, including specific purchases of renewable energy in the network. Hydrogen In August 2025, the construction of the Coral project began, which includes a green hydrogen plant with PEM (Proton Exchange Membrane) technology, which is expected to be located at the Cartagena Refinery. This project, which is part of the Ecopetrol Group's strategic hydrogen plan, is also expected be the largest of its kind in Latin America by 2026 and is expected to have a production capacity of 1 KFCD (800 tons/year) and a reduction in emissions of ~7.7 kton CO2e/year. Energy efficiency As of 3Q 2025, cumulative energy optimization of 3.52 PJ was achieved (vs. 2025 target of 2.94 PJ), with an estimated impact on emissions reduction of 269,017 tons of CO2e and savings of COP 106.33 billion in Ecopetrol Group operations. Since 2018, the accumulated energy optimization amounts to 23.43 PJ, equivalent to the annual electricity and natural gas consumption of more than 1.1 million Colombian households. Social Gas The Ecopetrol Group has connected 29,850 new households in socioeconomic strata 1 and 2 to natural gas service as of 3Q25. Since the start of this initiative in 2019, 105,115 physical connections have been installed in more than 20 departments across the country, providing them with clean energy and transforming their quality of life. Invercolsa So far in 2025, in relation with non-bank financing — one of the subsidiaries' growth drivers— loans totaling COP 83.7 billion were made, reaching a cumulative portfolio of COP 98.7 billion at the end of September. This portfolio is distributed among 55,286 clients, with an Overdue Portfolio Index (ICV por its initials in Spanish) > 90 days of 2.12%. 3. ENERGY TRANSMISSION AND TOLL ROADS 3.1  Energy Transmission  Projects awarded In Brazil, ISA Energía has been awarded two reinforcements to the transmission network in 3Q 2025; these reinforcements and improvements add up to a capex of USD 5 million (~COP 20 billion). In Colombia, ISA was awarded two expansions of the network. Entry into operation of projects In 3Q 2025 the following projects came into operation: In Colombia: The Copey–Cuestecitas and Copey–Fundación transmission lines, which cross 15 municipalities in the departments of La Guajira and Cesar. This project increases the installed capacity of the National Transmission System (STN), improves the reliability of the service in La Guajira, Cesar and Magdalena, and facilitates the connection of non-conventional renewable energy projects that are advancing in La Guajira. The connection of the Guayepo III solar park to the Sabanalarga substation, as well as the connection of the Valledupar I, II and III solar parks in the Caribbean region. These initiatives strengthen the security and reliability of the electricity service by integrating renewable energy into the National Transmission System (STN). In Brazil: 22 reinforcements and improvements were carried out on the ISA Energía Brasil network, with an estimated investment of USD 98 million (~COP 384 billion). 3.2  Toll Roads Regarding the Pan-American Highway East in Panama, the project is progressing in its construction phase according to the established work plan. At the same time, work continues for the financial closing, scheduled for December 2025. In Chile, the Southern Orbital Route is progressing according to schedule and is expected to begin its construction phase in 2028. In turn, on the Maipo Route, the completion of the Free Flow system on the southern access to Santiago is projected for the fourth quarter of 2025, while works related to regulations, comfort, and road safety will conclude in the second quarter of 2027. Financial Results  Table 17.  Income Statement – Energy Transmission and Toll Roads Billion (COP) 3Q 2025 3Q 2024 ∆ ($) ∆ (%) 9M 2025 9M 2024 ∆ ($) ∆ (%) Total revenue 4,158 4,396 (238) (5.4 %) 11,512 11,491 21 0.2 % Depreciation, amortization and depletion 287 277 10 3.6 % 854 815 39 4.8 % Fixed costs 1,562 1,358 204 15.0 % 4,602 3,998 604 15.1 % Total cost of sales 1,849 1,635 214 13.1 % 5,456 4,813 643 13.4 % Gross income 2,309 2,761 (452) (16.4 %) 6,056 6,678 (622) (9.3 %) Operating expenses 357 201 156 77.6 % 1,176 741 435 58.7 %  Operating income (loss) 1,952 2,560 (608) (23.8 %) 4,880 5,937 (1,057) (17.8 %) Financial result, net (804) (711) (93) 13.1 % (2,489) (2,237) (252) 11.3 % Share of profit of companies 125 55 70 127.3 % 411 327 84 25.7 % Loss before income tax 1,273 1,904 (631) (33.1 %) 2,802 4,027 (1,225) (30.4 %) Provision for income tax (241) (510) 269 (52.7 %) (511) (787) 276 (35.1 %) Consolidated net income 1,032 1,394 (362) (26.0 %) 2,291 3,240 (949) (29.3 %) Non-controlling interest (865) (1,129) 264 (23.4 %) (1,914) (2,556) 642 (25.1 %) Net income attributable to owners of Ecopetrol 167 265 (98) (37.0 %) 377 684 (307) (44.9 %) EBITDA 2,492 3,023 (531) (17.6 %) 6,572 7,511 (939) (12.5 %) EBITDA Margin 59.9 % 68.8 % - (8.9 %) 57.1 % 65.4 % - (8.3 %) In 3Q 2025, service revenues decreased compared to 3Q 2024 due to the favorable effect of the Periodic Tariff Review (RTP) in Brazil, recognized in 2024 in the energy transmission business. This impact was partially offset by: i) the application of contractual escalators in Brazil, Chile, and Colombia, ii) progress in construction projects, iii) higher returns in energy and road concessionaires, iv) the Annual Review Cycle RAP (Receita Anual Permitida) in Brazil, and v) the court ruling in favor of ISA in Brazil related to the Paulista concession. In turn, revenues for 9M 2025 increased compared to 9M 2024 in the energy transmission and road businesses due to i) the positive effect of contractual escalators in Brazil, Colombia, and Chile, ii) the Annual Review Cycle of RAP (Receita Anual Permitida, or Annual Permitted Revenue) in Brazil, and iii) a court ruling in favor of ISA in Brazil regarding the São Paulo concession. This increase is partially offset by the positive effect of the Periodic Tariff Review (RTP) recognized in 2024 and the negative effect in 2025 on the adjustment of the Basic Network of the Existing System (RBSE) in Brazil. The cost of sales for 3Q25 and 9M25 increased compared to 3Q24 and 9M24, mainly due to the inflationary effect on OPEX, increased construction activity, and the start-up of new projects. Operating expenses for 3Q 2025 and 9M 2025 increased compared to 3Q 2024 and 9M 2024 due to greater portfolio impairment during 2025 in the energy transmission business in Colombia, mainly the customer Air-E, and a positive effect in 2024 due to the update of the provision for major maintenance in the energy transmission business in Peru. Net Financial expenses of 3Q 2025 and 9M 2025 increased compared to 3Q 2024 and 9M 2024 mainly due to higher interest expenses related to increased indebtedness and greater monetary correction of IPCA-indexed debt in ISA Energía Brazil. III. Corporate Governance and Social Bodies Board of Directors During the third quarter, we continued to reaffirm our commitment to best practices in Corporate Governance, highlighting milestones such as the implementation of the Corporate Governance training program for Ecopetrol S.A.'s Board of Directors and Executive Committee in partnership with INALDE Business School. This initiative aims to promote cutting-edge knowledge in governance practices and equip the Board with the necessary tools to fulfill its role as a collegiate body. In 3Q 2025, Ecopetrol S.A.'s Board of Directors adopted, among others, the following decisions: Approved Ecopetrol's separate financial statements and the consolidated financial statements of the Ecopetrol Group for the second quarter of 2025. Made the following appointments: Sergio Andrés Moreno, confirmed as Corporate Vice President of Science, Technology and Innovation, effective July 28, 2025. Bayron Triana, confirmed as Executive Vice President of Energy for the Transition, effective August 1, 2025. In compliance with External Circular 012 of 2022 issued by the Colombian Financial Superintendence, the Company disclosed the following relevant information to the National Registry of Securities and Issuers (RNVE): On August 19, 2025, it was reported that during the Board meeting held on that date, Dr. Guillermo García Realpe submitted his voluntary resignation as Chairman of the Board for personal reasons. However, he will continue serving as a member of the Board and as Chair of the Compensation, Nomination, and Culture Committee. Consequently, the Board appointed Dr. Mónica de Greiff Lindo as the new Chair and Dr. Angela María Robledo Gómez as Vice Chair, effective August 20, 2025. On October 15, 2025, it was reported that, through a communication dated October 14, 2025, Dr. Mónica de Greiff Lindo expressed her intention to resign from her position as an independent member of the Board, a resignation that became effective on October 15, 2025. Considering that Dr. De Greiff Lindo served as Chair of the Board, her role will be assumed by the current Vice Chair, Dr. Angela María Robledo Gómez, as provided in the Board's current regulations. IV. Presentation of Results On Friday, November 14, 2025, management expects to hold a virtual conference with simultaneous transmission in Spanish and English to present its results. Included below are the times and connection details for participating in the conference: Conference 14 November 2202509:00 a.m. Colombian time09:00 a.m. New York time To access the webcast, interested parties should use the following link to select the language of the broadcast (Spanish or English): https://xegmenta.co/ecopetrol/gracias-conferencia-de-resultados-3t-2025/ Once the call broadcast begins, you can ask your questions by accessing the platform. The announcement of the results, the presentation, the webcast, and the recording of the conference will be available on the Ecopetrol website: www.ecopetrol.com.co. We recommend checking your browser's access to the webcast in advance and having the latest versions of Internet Explorer, Google Chrome, and/or Mozilla Firefox. Contact information: Head of Capital MarketsCarolina Tovar AragónEmail: [email protected] Head of Corporate CommunicationsMarcela Ulloa BeltránEmail: [email protected] Ecopetrol Group Appendices  Table 1: Income Statement - Ecopetrol Group Billion (COP) 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Revenue Local 14,590 15,198 (4.0 %) 44,158 46,372 (4.8 %) Export 15,250 19,409 (21.4 %) 46,717 52,164 (10.4 %) Total revenue 29,840 34,607 (13.8 %) 90,875 98,536 (7.8 %) Cost of sales Depreciation, amortization and depletion 3,954 3,811 3.8 % 12,042 10,857 10.9 % Variable depreciation, amortization and depletion 2,697 2,637 2.3 % 8,270 7,280 13.6 % Fixed cost depreciation 1,257 1,174 7.1 % 3,772 3,577 5.5 % Variable costs 10,509 13,611 (22.8 %) 33,812 36,452 (7.2 %) Imported products 4,449 5,517 (19.4 %) 15,296 14,819 3.2 % Local purchases 4,457 5,781 (22.9 %) 13,594 16,699 (18.6 %) Hydrocarbon transportation services 488 426 14.6 % 1,405 1,261 11.4 % Inventories and others 1,115 1,887 (40.9 %) 3,517 3,673 (4.2 %) Fixed costs 5,407 5,222 3.5 % 15,882 14,978 6.0 % Contracted services 1,256 1,274 (1.4 %) 3,559 3,658 (2.7 %) Construction services 987 824 19.8 % 2,779 2,411 15.3 % Maintenance 1,266 1,421 (10.9 %) 3,748 3,653 2.6 % Labor costs 1,112 1,070 3.9 % 3,299 3,209 2.8 % Other 786 633 24.2 % 2,497 2,047 22.0 % Total cost of sales 19,870 22,644 (12.3 %) 61,736 62,287 (0.9 %) Gross income 9,970 11,963 (16.7 %) 29,139 36,249 (19.6 %) Operating expenses 2,635 2,657 (0.8 %) 7,787 7,606 2.4 % Administration expenses 2,452 2,226 10.2 % 7,220 6,350 13.7 % Exploration and projects expenses 183 431 (57.5 %) 567 1,256 (54.9 %) Operating income 7,335 9,306 (21.2 %) 21,352 28,643 (25.5 %) Finance result, net (2,046) (2,051) (0.2 %) (6,549) (6,143) 6.6 % Foreign exchange, net (17) (11) 54.5 % 147 34 332.4 % Interest, net (1,677) (1,398) 20.0 % (4,802) (4,112) 16.8 % Financial income/loss (352) (642) (45.2 %) (1,894) (2,065) (8.3 %) Share of profit of companies 187 116 61.2 % 585 502 16.5 % Income before income tax 5,476 7,371 (25.7 %) 15,388 23,002 (33.1 %) Income tax (1,710) (2,264) (24.5 %) (4,933) (8,418) (41.4 %) Net income consolidated 3,766 5,107 (26.3 %) 10,455 14,584 (28.3 %) Non-controlling interest (1,203) (1,458) (17.5 %) (2,953) (3,547) (16.7 %) Net income attributable to owners of Ecopetrol 2,563 3,649 (29.8 %) 7,502 11,037 (32.0 %) EBITDA 12,326 13,976 (11.8 %) 36,720 42,266 (13.1 %) EBITDA margin 41.3 % 40.4 % 0.9 % 40.4 % 42.9 % (2.5 %) Table 2: Statement of Financial Position / Balance Sheet - Ecopetrol Group Billion (COP) September 30, 2025 June 30, 2025 ∆ (%) Current assets Cash and cash equivalents 10,364 10,118 2.4 % Trade and other receivables 14,286 13,797 3.5 % Inventories 10,539 10,398 1.4 % Current tax assets 17,185 16,927 1.5 % Other financial assets 3,370 4,222 (20.2 %) Other assets 4,019 3,694 8.8 % 59,763 59,156 1.0 % Non-current assets held for sale 7 14 (50.0 %) Total current assets 59,770 59,170 1.0 % Non-current assets Investments in associates and joint ventures 8,424 8,913 (5.5 %) Trade and other receivables 35,021 34,566 1.3 % Property, plant and equipment 104,148 104,913 (0.7 %) Natural and environmental resources 47,028 46,889 0.3 % Assets by right of use 979 984 (0.5 %) Intangibles 14,494 15,130 (4.2 %) Deferred tax assets 12,305 13,826 (11.0 %) Other financial assets 3,327 3,700 (10.1 %) Goodwill and Other assets 6,376 6,519 (2.2 %) Total non-current assets 232,102 235,440 (1.4 %) Total assets 291,872 294,610 (0.9 %) Current liabilities Loans and borrowings 12,455 15,640 (20.4 %) Trade and other payables 18,256 17,624 3.6 % Provision for employees benefits 3,163 2,988 5.9 % Current tax liabilities 2,783 1,938 43.6 % Accrued liabilities and provisions 1,289 1,408 (8.5 %) Other liabilities 1,164 1,091 6.7 % Total current liabilities 39,110 40,689 (3.9 %) Non-current liabilities Loans and borrowings 101,815 104,619 (2.7 %) Trade and other payables 22 22 0.0 % Provision for employees benefits 14,322 14,361 (0.3 %) Non-current taxes 14,284 14,246 0.3 % Accrued liabilities and provisions 13,550 13,140 3.1 % Other liabilities 1,759 1,952 (9.9 %) Total non-current liabilities 145,752 148,340 (1.7 %) Total liabilities 184,862 189,029 (2.2 %) Equity Equity attributable to owners of the company 80,714 79,225 1.9 % Non-controlling interests 26,296 26,356 (0.2 %) Total equity 107,010 105,581 1.4 % Total liabilities and equity 291,872 294,610 (0.9 %) Table 3: Cash Flow Statement - Ecopetrol Group Billion (COP) 3Q 2025 3Q 2024 9M 2025 9M 2024 Cash flow provided by operating activities Net income attributable to owners of Ecopetrol S.A. 2,563 3,649 7,502 11,037 Adjustments to reconcile net income to cash provided by operating activities Non-controlling interests 1,203 1,458 2,953 3,547 Income tax 1,710 2,264 4,933 8,418 Depreciation, depletion and amortization 4,070 4,004 12,454 11,291 Foreign exchange (gain) loss 17 11 (147) (34) Finance costs recognized in profit or loss 2,541 2,396 7,768 7,158 Dry wells 126 342 394 947 Loss (gain) on disposal of non-current assets (5) 11 2 26 Impairment of current and non-current assets 71 117 265 164 Fair value (gain) on financial assets valuation (636) (1,164) (1,423) (1,270) Gain on financial derivatives (6) (45) (3) (46) Gain on assets for sale 2 6 3 22 (Gain) loss on share of profit of associates and joint ventures (187) (116) (585) (502) Exchange difference on export hedges and ineffectiveness (28) 69 97 29 Provisions and contingencies 233 (30) 478 211 Others minor items 12 2 14 0 Net changes in operating assets and liabilities (1,199) 1,024 (1,946) 3,274 Income tax paid (1,609) (1,533) (7,712) (8,723) Cash provided by operating activities 8,878 12,465 25,047 35,549 Cash flows from investing activities Investment in joint ventures 1 0 0 (12) Acquisition of subsidiaries, net of cash acquired (65) (159) (65) (158) Investment in property, plant and equipment (2,408) (2,153) (6,216) (5,892) Investment in natural and environmental resources (2,547) (2,776) (7,510) (7,549) Payments for intangibles (118) (228) (337) (618) Consideration paid for acquisition of assets 0 0 (1,109) 0 (Purchases) sales of other financial assets 1,249 (2,552) (1,009) (3,237) Interest received 293 432 945 1,215 Dividends received 433 30 554 243 Proceeds from sales of assets 35 134 68 201 Net cash used in investing activities (3,127) (7,272) (14,679) (15,807) Cash flows from financing activities Proceeds (repayment of) from borrowings (2,214) 37 4,440 1,975 Interest paid (2,500) (2,049) (6,432) (5,620) Lease Payments (144) (138) (435) (420) Return of capital 0 (6) 0 (21) Dividends paid (329) (2,741) (11,024) (14,933) Net cash used in financing activities (5,187) (4,897) (13,451) (19,019) Exchange difference in cash and cash equivalents (318) 566 (607) 1,040 Net (decrease) increase in cash and cash equivalents 246 862 (3,690) 1,763 Cash and cash equivalents at the beginning of the period 10,118 13,237 14,054 12,336 Cash and cash equivalents at the end of the period 10,364 14,099 10,364 14,099 Table 4: EBITDA Reconciliation - Ecopetrol Group Billion (COP) 3Q 2025 3Q 2024 9M 2025 9M 2024 Net income attributable to the owners of Ecopetrol 2,563 3,649 7,502 11,037 (+) Depreciation, amortization and depletion 4,070 4,004 12,454 11,291 (+/-) Impairment of long-term assets 0 1 3 9 (+/-) Financial result, net 2,046 2,051 6,549 6,143 (+) Income tax 1,710 2,264 4,933 8,418 (+) Taxes and others 734 549 2,326 1,821 (+/-) Non-controlling interest 1,203 1,458 2,953 3,547 Consolidated EBITDA 12,326 13,976 36,720 42,266 Table 5: EBITDA Consolidation by Segment (3Q 2025) Billion (COP) Upstream Downstream Midstream Energy Eliminations Consolidated Net income attributable to the owners of Ecopetrol 1,393 (178) 1,182 167 (1) 2,563 (+) Depreciation, amortization and depletion 2,863 514 333 361 (1) 4,070 (+/-) Financial result, net 949 230 52 804 11 2,046 (+) Income tax 674 (92) 887 241 0 1,710 (+) Other taxes 383 253 40 54 4 734 (+/-) Non-controlling interest (20) 56 302 865 0 1,203 Consolidated EBITDA 6,242 783 2,796 2,492 13 12,326 Table 6: Investment by Segment - Ecopetrol Group Million (USD) Ecopetrol S.A. Affiliates and Subsidiaries Total 9M 2025 % Share Hydrocarbons 1,980 1,074 3,054 73 % Production 1,572 799 2,371 56.7 % Downstream 165 76 241 5.8 % Exploration 201 34 235 5.6 % Midstream* 0 165 165 4.0 % Corporate 42 0 42 1.0 % Energies for the Transition** 52 6 58 1.4 % Energy Transmission and Toll Roads 0 1,067 1,067 25.6 % Energy Transmission 0 971 971 23.2 % Toll Roads 0 82 82 2.0 % Telecommunications 0 14 14 0.3 % Total 2,032 2,147 4,179 100.0 % * Includes the total investment amount for each Ecopetrol Group company (Ecopetrol S.A. share and non-controlling interest).** Includes only the total of organic investments. Ecopetrol S.A. AppendicesFollowing are the Income Statement and Statement of Financial Position of Ecopetrol S.A. Table 7: Income Statement Billion (COP) 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Local 13,888 15,029 (7.6 %) 42,402 46,733 (9.3 %) Exports 9,633 11,165 (13.7 %) 29,384 32,188 (8.7 %) Total revenue 23,521 26,194 (10.2 %) 71,786 78,921 (9.0 %) Variable costs 15,939 16,968 (6.1 %) 48,474 49,565 (2.2 %) Fixed costs 3,836 4,053 (5.4 %) 11,549 11,827 (2.4 %) Total cost of sales 19,775 21,021 (5.9 %) 60,023 61,392 (2.2 %) Gross income 3,746 5,173 (27.6 %) 11,763 17,529 (32.9 %) Operating expenses 1,371 1,034 32.6 % 3,940 3,362 17.2 % Operating income 2,375 4,139 (42.6 %) 7,823 14,167 (44.8 %) Financial income/loss (1,470) (1,628) (9.7 %) (4,610) (4,625) (0.3 %) Share of profit of companies 1,972 1,889 4.4 % 5,446 5,917 (8.0 %) Income before income tax 2,877 4,400 (34.6 %) 8,659 15,459 (44.0 %) Income tax (314) (751) (58.2 %) (1,157) (4,422) (73.8 %) Net income attributable to owners of Ecopetrol 2,563 3,649 (29.8 %) 7,502 11,037 (32.0 %) EBITDA 5,097 6,403 (20.4 %) 15,443 20,712 (25.4 %) EBITDA margin 21.7 % 24.40 % (2.7 %) 21.50 % 26.20 % (4.7 %) Table 8: Statement of Financial Position / Balance Sheet  Billion (COP) September 30, 2025 June 30, 2025 ∆ (%) Current assets Cash and cash equivalents 2,822 3,866 (27.0 %) Trade and other receivables 10,444 11,162 (6.4 %) Inventories 7,257 6,978 4.0 % Current tax assets 13,555 13,419 1.0 % Other financial assets 4,068 4,666 (12.8 %) Other assets 1,782 1,762 1.1 % 39,928 41,853 (4.6 %) Non-current assets held for sale 7 11 (36.4 %) Total current assets 39,935 41,864 (4.6 %) Non-current assets Investments in associates and joint ventures 86,398 86,169 0.3 % Trade and other receivables 656 623 5.3 % Property, plant and equipment 38,913 38,260 1.7 % Natural and environmental resources 28,579 28,315 0.9 % Assets by right of use 2,437 2,523 (3.4 %) Intangibles 527 547 (3.7 %) Deferred tax assets 5,547 7,082 (21.7 %) Other financial assets 1,883 2,263 (16.8 %) Goodwill and other assets 1,133 1,207 (6.1 %) Total non-current assets 166,073 166,989 (0.5 %) Total assets 206,008 208,853 (1.4 %) Current liabilities Loans and borrowings 10,024 12,543 (20.1 %) Trade and other payables 15,205 15,086 0.8 % Provision for employees benefits 2,782 2,677 3.9 % Current tax liabilities 1,443 874 65.1 % Accrued liabilities and provisions 848 950 (10.7 %) Other liabilities 454 458 (0.9 %) Total current liabilities 30,756 32,588 (5.6 %) Non-current liabilities Loans and borrowings 68,973 71,762 (3.9 %) Provision for employees benefits 13,877 13,892 (0.1 %) Non-current tax liabilities 549 560 (2.0 %) Accrued liabilities and provisions 10,863 10,547 3.0 % Other liabilities 276 279 (1.1 %) Total non-current liabilities 94,538 97,040 (2.6 %) Total liabilities 125,294 129,628 (3.3 %) Equity Equity attributable to owners of the company 80,714 79,225 1.9 % Total equity 80,714 79,225 1.9 % Total liabilities and equity 206,008 208,853 (1.4 %) Table 9: Export Destinations - Ecopetrol Group Crudes - mboed 3Q 2025 3Q 2024 % Share 9M 2025 9M 2024 % Share U.S. Gulf Coast 154.4 212.6 38.3 % 172.3 188.5 40.8 % Asia 177.7 218.8 44.1 % 186.1 224.2 44.1 % Central America / Caribbean 3.2 0.0 0.8 % 2.9 1.8 0.7 % Others 13.3 7.7 3.3 % 4.5 8.0 1.1 % Europe 20.0 21.5 5.0 % 24.6 10.3 5.8 % U.S. West Coast 8.9 8.0 2.2 % 15.8 2.7 3.7 % South America 0.0 3.9 0.0 % 0.0 2.6 0.0 % U.S. East Coast 25.6 5.3 6.4 % 15.7 1.8 3.7 % Total 403.1 477.7 100.0 % 421.9 440.0 100.0 % Products - mboed 3Q 2025 3Q 2024 % Share 9M 2025 9M 2024 % Share Central America / Caribbean 30.2 23.8 25.8 % 28.3 35.1 25.8 % U.S. Gulf Coast 39.2 44.8 33.5 % 40.0 41.0 36.4 % Asia 7.8 15.4 6.7 % 8.6 15.7 7.8 % South America 10.4 10.8 8.9 % 9.8 7.1 8.9 % U.S. East Coast 8.7 25.4 7.4 % 11.0 8.5 10.1 % Europe 2.0 3.5 1.7 % 4.8 3.0 4.4 % U.S. West Coast 0.0 0.0 0.0 % 0.0 0.0 0.0 % Others 18.8 0.1 16.1 % 7.3 0.3 6.6 % Total 117.1 123.8 100.0 % 109.9 110.7 100.0 % Note: The information is subject to modification after the quarter's close, as certain destinations may be reclassified based on the final export results. Table 10: Local Purchases and Imports - Ecopetrol Group Local Purchases - mboed 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Crude Oil 188.4 218.4 (13.7 %) 186.4 213.5 (12.7 %) Gas 4.8 6.6 (27.3 %) 4.1 6.6 (37.9 %) Products 3.3 3.2 3.1 % 3.2 3.3 (3.0 %) Total 196.5 228.3 (13.9 %) 193.7 223.4 (13.3 %) Imports - mboed 3Q 2025 3Q 2024 ∆ (%) 9M 2025 9M 2024 ∆ (%) Crude Oil 57.9 46.1 25.6 % 63.0 49.1 28.3 % Products 73.9 92.7 (20.3 %) 82.6 74.6 10.7 % Diluent 33.0 34.7 (4.9 %) 32.9 31.1 5.8 % Total 164.8 173.5 (5.0 %) 178.5 154.8 15.3 % Total 361.3 401.8 (10.1 %) 372.2 378.2 (1.6 %) Table 11: Details of Exploratory Wells - Ecopetrol Group # Quarter Name Initial Well Classification (Lahee) Block Basin Operator/Partner Status TD Date 1 First Toritos Oeste-1 A1 LLA123 Llanos Central Geopark 50%(operator) -Hocol 50% Under evaluation February 10/2025 2 First Currucutu-1 A3 LLA123 Llanos Central Geopark 50%(operator) -Hocol 50% Successful April 4/2025 3 First Sirius-2 ST2 A1 Gua Off-0 Caribe Offshore Petrobras 44.44% (operator) - Ecopetrol 55.56% Successful January 7/2025 4 First Andina Este-1 A3 Capachos Piedemonte Parex 50% (operator) - Ecopetrol 50% Dry February 4/2025 5 Second Buena Suerte-1 A3 Gua Off-0 Caribe Offshore Petrobras 44.44% (operator) - Ecopetrol 55.56% Dry June 3/2025 6 Second Toritos Sur-3 A1 LLA123 Llanos Central Geopark 50% (Operador) - Hocol 50% Successful April 19, 2025 7 Third Matraquero-1 A3 LLA123 Llanos Central Geopark 50% (Operador) - Hocol 50% Under evaluation August 18/2025 8 Third Toritos Norte-3 A1 LLA123 Llanos Central Geopark 50% (Operador) - Hocol 50% Under evaluation September 1, 2025 Wells drilled in Join Ventures 1 Third Guarilaque West-1 C2c Orocue  Llanos Central Perenco 100% (Operator) Dry March 12, 2025 2 Third Cosecha G-NE-1 A1 Cosecha Llanos Central Sierracol 100% (Operator) Successful May 4, 2025 Table 12: HSE Performance (Health, Safety and Environment) HSE Indicators* 3Q 2025 3Q 2024 9M 2025 9M 2024 Frequency of total registrable injuries (No. Recordable cases / Million man hours) 0.24 0.49 0.27 0.29 Environmental incidents** 0 2 2 2  * The results of the indicators are subject to change after the end of the quarter due to the fact that some of the accidents and incidents are reclassified according to the results of the investigations.   **Environmental incidents are those hydrocarbon spills greater than 1 barrel, with environmental impact. 1 Not including gas investments and energy efficiency projects.2 Increased water production in 3Q 2025 vs 3Q 2024 in fields directly operated by Ecopetrol S.A. SOURCE Ecopetrol S.A.

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