Enbridge Reports Record 2025 Financial Results, Reaffirms 2026 Financial Guidance, and Grows Secured Backlog to $39 Billion

Enbridge Inc. (Enbridge or the Company) (TSX: ENB) (NYSE: ENB) today reported fourth quarter 2025 financial results, reaffirmed its 2026 financial guidance and provided a quarterly business update. Highlights(All financial figures are unaudited and in Canadian dollars unless otherwise noted. * identifies non-GAAP financial measures. Please refer to Non-GAAP Reconciliations Appendices.) Full-year GAAP earnings attributable to common shareholders of $7.1 billion or $3.23 per common share, compared with GAAP earnings attributable to common shareholders of $5.1 billion or $2.34 per common share in 2024 Full-year adjusted earnings* of $6.6 billion or $3.02 per common share*, an increase of 9% and 8% respectively, compared with $6.0 billion or $2.80 per common share in 2024 Full-year adjusted earnings before interest, income taxes and depreciation and amortization (EBITDA)* of $20.0 billion, an increase of 7%, compared with $18.6 billion in 2024 Full-year cash provided by operating activities of $12.3 billion, compared with $12.6 billion in 2024 Full-year distributable cash flow (DCF)* of $12.5 billion, an increase of 4%, compared with $12.0 billion in 2024 Achieved financial guidance for the 20th consecutive year, reflecting continued business resilience and predictability across all franchises Increased the 2026 quarterly dividend by 3% to $0.97 ($3.88 annualized) per share, reflecting the 31st consecutive annual increase Reaffirmed 2026 full year financial guidance and multi-year financial outlook Placed $5 billion of organic growth capital into service in 2025 Sanctioned $14 billion of organic growth projects during 2025 Sanctioned Mainline Optimization Phase 1 (MLO1), adding 150 kbpd of Mainline system capacity and 100 kbpd of Flanagan South Pipeline (FSP) capacity under long-term take-or-pay contracts, supporting full-path demand, for US$1.4 billion Sanctioned the Bay Runner extension to the Whistler Pipeline and upsized the previously announced Eiger Express Pipeline from 2.5 Bcf/d to 3.7 Bcf/d Sanctioned Cowboy Phase 1, a 365 MW solar facility and a 135 MW battery energy storage system (BESS), expandable up to 200 MW, under long-term agreements to support a global technology company's operations in Cheyenne, Wyoming, for US$1.2 billion Sanctioned Easter, a 152 MW onshore wind project in Amarillo, Texas supporting Meta Platforms, Inc. (Meta)'s data center operations under a long-term power purchase agreement, for US$0.4 billion Exited the year with Debt-to-EBITDA* of 4.8x, providing significant financial flexibility CEO COMMENTGreg Ebel, President and CEO commented the following: "With the changing dynamics we see in today's energy sector, our all-of-the-above approach to energy and incumbent asset footprint positions us to capitalize on growing energy demand. This past year, Enbridge continued to benefit from our size and capacity, securing $14 billion of projects across our four businesses. Sanctioned projects addressed a range of energy demand themes, advancing incremental WCSB egress, expanding natural gas transmission capacity in the U.S. Northeast, bolstering our natural gas storage businesses on the Gulf Coast and in British Columbia, and building on our partnership with Meta in the power space. I'm pleased with the progress we've made towards the commitments laid out last Enbridge Day, ahead of the timelines shared just under a year ago. Today, our total secured backlog sits at $39 billion, up approximately 35% since Enbridge Day, and we'll continue to advance our suite of opportunities across natural gas, liquids, and renewable power to meet growing energy demand in North America and beyond. "Despite tariffs and geopolitical tension, 2025 showcased our low-risk commercial framework delivering predictable results amid macroeconomic uncertainty. We're proud to announce that Enbridge has once again achieved record EBITDA and DCF per share, marking the 20th consecutive year of achieving or exceeding financial guidance. "In Liquids, Mainline volumes averaged 3.1 MMbpd in 2025, and the system was apportioned for nine months of the year. This quarter we sanctioned Mainline Optimization Phase 1, which will add 150 kbpd of incremental WCSB egress and is expected to enter service in 2027. The project includes a 100 kpbd expansion of our Flanagan South Pipeline system, adding critical full-path service to the U.S. Gulf Coast. Along with the expansion of FSP, our existing customers on that system also extended the majority of their existing contracts beyond 2040, showcasing long-term demand for our integrated system. Despite the uncertainty created by the events in Venezuela, our shippers have made it clear they remain interested in advancing further egress along the Mainline from Canada down to the Gulf Coast. The opportunity to deliver Mainline Optimization Phase 2 and create cost effective incremental egress in 2028 continues to advance with our customers. "In Gas Transmission, alongside our Whistler Parent JV partners, we sanctioned Bay Runner, an extension of the Whistler Pipeline. We continue to advance the pipeline that will serve the Rio Grande LNG facility, leveraging a combination of the previously sanctioned Rio Bravo Pipeline and the Bay Runner project. These projects will serve up to 5.3 Bcf/d of the natural gas demand for the Rio Grande project, providing supply from the Agua Dulce hub. This follows the upsizing of the Eiger Express Pipeline in November, driven by growing demand for Permian natural gas egress capacity. We continue to advance over 50 data center opportunities across North America, requiring up to 10 Bcf/d of new takeaway capacity in close proximity to our existing Gas Transmission assets and expect to sanction additional projects supporting power generation and data centers in 2026 and the years ahead. "In Gas Distribution, new rates have come into effect for both Enbridge Gas North Carolina and Utah, after each respective utility commission approved settlements filed in 2025. At Enbridge Gas Ohio, we filed a new rate case at the end of the year. We plan to continue to invest approximately $3 billion per year in growth capital across our four utilities, helping keep the systems operating safely and reliably into the future. "In Renewable Power, we are sanctioning two new projects that advance our growing partnership with global technology companies. Cowboy Phase 1 is a 365 MW solar project and a 135 MW battery energy storage system, expandable up to 200 MW, in Wyoming. Easter will provide an additional 152 MW of onshore wind power in Texas to support Meta's technology and data center operations. Both projects are secured by long-term power purchase agreements and are expected to be fully in service by 2027. We now have over 750 MW of power generation under construction to support Meta's operations that will also add new generation to the grid. "2025 was another milestone year for Enbridge and we are focused on capturing the next set of growth opportunities across the energy landscape. Our leverage remains within our 4.5x to 5.0x range and our annual investment capacity for additional growth projects is growing alongside the Company, now sitting between $10 billion and $11 billion. We have made significant progress towards the commitments laid out last Enbridge Day and will continue to win our share of attractive opportunities, positioning Enbridge as a first-choice investment opportunity." FINANCIAL RESULTS SUMMARY Financial results for the three and twelve months ended December 31, 2025 and 2024 are summarized in the table below: Three months endedDecember 31, Twelve months endedDecember 31, 2025 2024 2025 2024 (Unaudited; millions of Canadian dollars, except per share amounts; number of shares in millions) GAAP Earnings attributable to common shareholders 1,952 493 7,072 5,053 GAAP Earnings per common share 0.89 0.23 3.23 2.34 Cash provided by operating activities 3,111 3,662 12,270 12,600 Adjusted EBITDA1 5,213 5,130 19,952 18,620 Adjusted Earnings1 1,921 1,640 6,578 6,037 Adjusted Earnings per common share1 0.88 0.75 3.02 2.80 Distributable Cash Flow1 3,208 3,074 12,454 11,991 Weighted average common shares outstanding 2,181 2,178 2,180 2,155 1 Non-GAAP financial measures. Please refer to Non-GAAP Reconciliations Appendices. GAAP earnings attributable to common shareholders for the fourth quarter of 2025 increased by $1.5 billion, or $0.66 per share, compared with the same period in 2024. This increase was primarily due to non-cash, unrealized changes in the value of derivative financial instruments used to manage foreign exchange, interest rate and commodity price risks. In addition, the increased quarterly operating performance discussed below contributed to the higher earnings. On a full year basis for 2025, GAAP earnings attributable to common shareholders increased by $2.0 billion, or $0.89 per share, due to the same non-cash, unrealized changes in the value of derivative financial instruments discussed above, partially offset by the absence of the 2024 gain on sale from the disposition of interests in Alliance Pipeline and Aux Sable and an impairment of rate-regulated assets in Enbridge Gas Ohio. The period-over-period comparability of GAAP earnings attributable to common shareholders is impacted by certain unusual, infrequent or other non-operating factors which are noted in the reconciliation schedule included in Appendix A of this news release. Refer to the Company's Management's Discussion & Analysis for 2025 filed in conjunction with the year-end financial statements for a detailed discussion of GAAP financial results. Adjusted EBITDA in the fourth quarter of 2025 increased by $83 million compared with the same period in 2024. This was due primarily to favorable Gas Transmission contracting and Venice Extension entering service, colder weather and higher rates and customer growth at Enbridge Gas Ontario, partially offset by the absence in 2025 of equity earnings related to investment tax credits from our investment in Fox Squirrel Solar. Adjusted EBITDA for the year ended December 31, 2025 increased by $1.3 billion compared with the same period in 2024. This was primarily driven by a full year of contributions from the U.S. Gas Utilities, colder weather, higher rates and customer growth at Enbridge Gas Ontario, higher contributions from our Gas Transmission segment from rate case settlements and favorable contracting, and Venice Extension entering service. These factors were partially offset by lower spot volumes on the Flanagan South liquids pipeline, the absence in 2025 of equity earnings related to investment tax credits from our investment in Fox Squirrel Solar, and the absence of contributions from Alliance Pipeline and Aux Sable due to the sale of our interests in April 2024. Adjusted earnings in the fourth quarter of 2025 increased by $281 million, or $0.13 per share, compared with the same period in 2024, due to EBITDA factors discussed above and lower income tax expense, mainly driven by lower effective U.S. tax rate primarily from the impacts of higher investment tax credits, partially offset by higher depreciation from assets placed into service since the fourth quarter of 2024. Adjusted earnings for the year ended December 31, 2025 increased by $541 million, or $0.22 per share, compared with the same period in 2024, primarily due to the same factors discussed above for the fourth quarter, partially offset by higher interest expense, primarily due to higher average debt balance outstanding. DCF for the fourth quarter of 2025 increased $134 million compared with the same period in 2024, primarily due to EBITDA factors discussed above in addition to lower maintenance capital spend related to supply chain optimization and lower current taxes due to higher investment tax credits, partially offset by higher average debt principal, resulting in higher interest expense. DCF for the year ended December 31, 2025 increased by $463 million, compared with the same period in 2024, primarily due to EBITDA factors discussed above, partially offset by higher interest expense primarily due to higher average debt balance outstanding, higher current taxes on higher earnings, and higher maintenance capital from the acquired U.S. Gas Utilities. Per share metrics in 2025, relative to 2024, are negatively impacted by the at-the-market (ATM) issuances of common shares in the second quarter of 2024 as part of the funding plan for the U.S. Gas Utilities. Detailed financial information and analysis can be found below under Fourth Quarter and Annual 2025 Financial Results. FINANCIAL OUTLOOK The Company reaffirms its 2026 financial guidance for adjusted EBITDA between $20.2 billion and $20.8 billion and DCF per share between $5.70 and $6.10. Enbridge increased its 2026 quarterly dividend by 3% to $0.97 ($3.88 annualized) per share, commencing with the dividend payable on March 1, 2026 to shareholders of record on February 17, 2026. This marks the 31st consecutive dividend increase for the Company. The Company also reaffirms its 2023 to 2026 near-term growth of 7-9% for adjusted EBITDA, 4-6% for adjusted earnings per share (EPS) and approximately 3% for DCF per share. Post 2026, adjusted EBITDA, EPS and DCF per share are all expected to grow by approximately 5% annually. FINANCING UPDATE In November 2025, Enbridge Inc. issued US$1.5 billion of senior notes consisting of US$500 million of 3-year notes, US$500 million of 5-year notes, and US$500 million of 10-year notes. Proceeds from these offerings were used to pay down existing indebtedness, finance capital expenditures, and for general corporate purposes. The Company's rolling 12-month Debt-to-EBITDA metric at the end of the year was 4.8x, within our Debt-to-EBITDA target range of 4.5-5.0x. SECURED GROWTH PROJECT EXECUTION UPDATE Enbridge brought approximately $5 billion of growth projects into service in 2025, including: $2.2B of Gas Distribution's Utility Growth Capital across all four utilities US$0.7B of Gas Transmission's Modernization program US$0.6B Sequoia Solar Phase 1 $0.5B of Mainline Capital Investment US$0.3B Orange Grove Solar US$0.1B Appalachia to Market II US$0.1B of Enbridge Ingleside Energy Center VII and Gray Oak expansions Enbridge added approximately $14 billion of projects to its secured growth backlog in 2025: Liquids Pipelines $2.0B Mainline Capital Investment US$1.4B Mainline Optimization Phase 1 US$0.5B Southern Illinois Connector Pipeline US$0.3B Pelican CO2 Hub Gas Transmission US$0.5B U.S. Gulf Coast Storage program $0.4B Birch Grove Expansion US$0.3B Canyon System Expansion US$0.3B Algonquin Gas Transmission Enhancement $0.3B Aitken Creek Expansion US$0.2B Gas Transmission Modernization US$0.1B Line 31 Texas Eastern Expansion Gas Distribution and Storage $2.8B Utility Growth Capital Renewable Power US$1.2B Cowboy Phase 1 US$0.9B Clear Fork Solar US$0.4B Easter The secured growth backlog now sits at approximately $39 billion and we expect to place $8 billion into service in 2026. Financing of the secured growth program is expected to be provided through the Company's anticipated $10-11 billion of annual growth capital investment capacity. FOURTH QUARTER BUSINESS UPDATES Liquids Pipelines: Mainline Optimization Phase 1 During the quarter, Enbridge sanctioned Mainline Optimization Phase One, a US$1.4 billion expansion of the Mainline and FSP systems to meet customer demand for incremental egress, increasing deliveries of Canadian heavy oil to key refining markets in the U.S. Midwest (PADD II) and Gulf Coast (PADD III). MLO1 is expected to add 150 kbpd of Mainline system capacity, and 100 kbpd of FSP capacity via increased horsepower, upstream optimizations and terminal enhancements. The combined project is expected to enter service in 2027. The FSP expansion is underpinned by long-term, take-or-pay contracts providing full-path service from Edmonton, Alberta to Houston, Texas. In addition, the majority of existing customers also elected to extend their existing FSP full-path contracts beyond 2040. Gas Transmission: Permian Joint Venture Strategic Update Enbridge has sanctioned the Bay Runner extension to the Whistler Pipeline to serve natural gas demands from NextDecade's Rio Grande LNG development. This new system will offer incremental service between the Agua Dulce hub and Brownsville in combination with the Rio Bravo Pipeline project for a total capacity of up to 5.3 Bcf/d. In November, the Matterhorn joint venture announced it had upsized the previously sanctioned Eiger Express Pipeline to 3.7 Bcf/d from 2.5 Bcf/d, secured by additional firm transportation agreements. The new capacity will not impact the expected in-service date in 2028. Gas Distribution & Storage: Enbridge Gas Ohio Rate Case Application In December 2025, Enbridge Gas Ohio filed a base rate case application proposing an annual revenue requirement increase of US$163 million, to be effective in early 2027. The base rate increase was proposed to recover the investment in distribution infrastructure and other costs to serve, including operating expenses and debt servicing costs. Renewable Power: Cowboy Phase 1 Enbridge has sanctioned Cowboy Phase 1, a greenfield development in Cheyenne, Wyoming, consisting of 365 MW of solar generation capacity and 135 MW of battery energy storage, expandable up to 200 MW with further utility review and approval. Cheyenne Light Fuel and Power (CLFP), through Wyoming's Large Power Contract Service (LPCS) tariff, will deliver the power generated from the project to a global technology company under a long-term power purchase agreement. The BESS capacity is contracted to support the same customers' operations through a long-term fixed-price battery tolling agreement with CLFP through the same LPCS tariff, and the batteries will be supplied and maintained by Tesla. Enbridge expects to invest US$1.2 billion to construct both the Cowboy solar facility and the BESS, both of which are expected to enter service by the end of 2027. Renewable Power: Easter Enbridge has sanctioned Easter, an onshore wind project near Amarillo, Texas. Easter is expected to have 152 MW of wind generation capacity and Meta has signed a power purchase agreement for the renewable output from the project. Enbridge expects the project to cost US$0.4 billion with phased project completions expected in 2026 and 2027. FOURTH QUARTER AND ANNUAL 2025 FINANCIAL RESULTS GAAP Segment EBITDA and Cash Flow from Operations Three months endedDecember 31, Twelve months endedDecember 31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars) Liquids Pipelines 2,189 2,352 9,396 9,531 Gas Transmission 1,306 1,150 5,491 5,656 Gas Distribution and Storage 1,139 1,015 3,809 2,869 Renewable Power Generation 199 236 620 733 Eliminations and Other 333 (1,402) 1,161 (1,904) EBITDA1 5,166 3,351 20,477 16,885 Earnings attributable to common shareholders 1,952 493 7,072 5,053 Cash provided by operating activities 3,111 3,662 12,270 12,600 1 Non-GAAP financial measure. Please refer to Non-GAAP Reconciliations Appendices. For purposes of evaluating performance, the Company makes adjustments to GAAP reported earnings, segment EBITDA and cash flow provided by operating activities for unusual, infrequent or other non-operating factors, which allow management and investors to more accurately compare the Company's performance across periods, normalizing for factors that are not indicative of underlying business performance. Tables incorporating these adjustments follow below. Schedules reconciling EBITDA, adjusted EBITDA, adjusted EBITDA by segment, adjusted earnings, adjusted earnings per share and DCF to their closest GAAP equivalent are provided in the Appendices to this news release. Adjusted EBITDA By Segment Three months endedDecember 31, Twelve monthsended December 31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars) Liquids Pipelines 2,446 2,395 9,710 9,654 Gas Transmission 1,312 1,272 5,397 4,782 Gas Distribution and Storage 1,139 1,015 4,139 2,869 Renewable Power Generation 211 308 672 820 Eliminations and Other 105 140 34 495 Adjusted EBITDA1 5,213 5,130 19,952 18,620 Adjusted Earnings1 1,921 1,640 6,578 6,037 1 Non-GAAP financial measure. Please refer to Non-GAAP Reconciliations Appendices. Adjusted EBITDA generated from U.S. dollar denominated businesses was translated to Canadian dollars at a lower average exchange rate (C$1.39/US$) in the fourth quarter of 2025 when compared with the same quarter in 2024 (C$1.40/US$). On a full year basis, adjusted EBITDA generated from U.S. dollar businesses was translated at C$1.40/US$, compared with C$1.37/US$ in 2024. A significant portion of U.S. dollar earnings are hedged under the Company's enterprise-wide financial risk management program. The hedge settlements are reported within Eliminations and Other. Liquids Pipelines Three months endedDecember 31, Twelve monthsended December 31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars) Mainline System 1,410 1,339 5,506 5,342 Regional Oil Sands System 249 232 978 925 Gulf Coast and Mid-Continent Systems1 348 369 1,400 1,596 Other Systems2 439 455 1,826 1,791 Adjusted EBITDA3 2,446 2,395 9,710 9,654 1 Consists of Flanagan South Pipeline, Seaway Pipeline, Gray Oak Pipeline, Cactus II Pipeline, Enbridge Ingleside Energy Center, and others. 2 Other consists of Southern Lights Pipeline, Express-Platte System, Bakken System, and others. 3 Non-GAAP financial measure. Please refer to Non-GAAP Reconciliations Appendices. Liquids Pipelines adjusted EBITDA increased $51 million compared with the fourth quarter of 2024, primarily related to: higher Mainline System contributions as a result of higher demand, annual escalators and surchargeeffective July 1, 2025, and lower power costs from operational efficiencies and lower mill rates, net of earnings sharing; and higher contributions from Line 9 due to higher volumes; partially offset by lower contributions from the Gulf Coast and Mid-Continent Systems primarily due to lower spot volumes on the Flanagan South Pipeline. Full year 2025 Liquids Pipelines adjusted EBITDA increased by $56 million compared with 2024 and was primarily impacted by the same factors discussed above as well as: equity earnings attributable to a litigation settlement; and the favorable effect of translating U.S. dollar earnings at a higher average exchange rate in 2025,compared to 2024; partially offset by lower contributions from the Bakken System due to lower volumes. Gas Transmission Three months endedDecember 31, Twelve monthsended December 31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars) U.S. Gas Transmission 997 1,009 4,336 3,795 Canadian Gas Transmission 190 157 629 552 Other1 125 106 432 435 Adjusted EBITDA2 1,312 1,272 5,397 4,782 2 Other consists of Tomorrow RNG, Gulf Offshore assets, our investment in DCP Midstream, and others. 3 Non-GAAP financial measure. Please refer to Non-GAAP Reconciliations Appendices. Gas Transmission adjusted EBITDA increased $40 million compared with the fourth quarter of 2024, primarily related to: contributions from placing Venice Extension into service and the acquisition of an interest in Matterhorn Express Pipeline; higher revenues at Aitken Creek due to favorable storage spreads; and favorable contracting and successful rate case settlements on our U.S. Gas Transmission assets; partially offset by timing of operating costs on our U.S. Gas Transmission assets. Full year 2025 Gas Transmission adjusted EBITDA increased by $615 million compared with 2024 and was primarily impacted by the same factors discussed above as well as: higher earnings from our investment in DCP Midstream; and the favorable effect of translating U.S. dollar earnings at a higher average exchange rate in 2025,compared to 2024; partially offset by the absence of contributions from Alliance Pipeline and Aux Sable due to the sale of our interests inthese investments in April 2024; and lower earnings at Tomorrow RNG primarily due to lower RIN pricing and lower production volumes. Gas Distribution and Storage Three months endedDecember 31, Twelve monthsended December 31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars) Enbridge Gas Ontario1 586 502 2,246 1,872 U.S. Gas Utilities1 535 502 1,843 947 Other 18 11 50 50 Adjusted EBITDA2 1,139 1,015 4,139 2,869 1 Enbridge Gas Inc. doing business as Enbridge Gas Ontario. U.S. Gas Utilities consist of The East Ohio Gas Company (doing business as Enbridge Gas Ohio), Questar Gas Company (doing business as Enbridge Gas Utah) and Public Service Company of North Carolina Incorporated (doing business as Enbridge Gas North Carolina). 2 Non-GAAP financial measure. Please refer to Non-GAAP Reconciliations Appendices. Adjusted EBITDA for Enbridge Gas Ontario, Enbridge Gas Utah and Enbridge Gas North Carolina typically follows a seasonal profile. EBITDA is generally highest in the first and fourth quarters of the year. Seasonal profiles for Enbridge Gas Ontario, Enbridge Gas Utah and Enbridge Gas North Carolina reflect greater volumetric demand during the heating season and the magnitude of the seasonal adjusted EBITDA fluctuations will vary from year-to-year in Ontario reflecting the impact of colder or warmer than normal weather on distribution volumes. Enbridge Gas Ohio's earnings are largely decoupled from volumes and less impacted by weather fluctuations. Enbridge Gas Utah and Enbridge Gas North Carolina have revenue decoupling mechanisms that are not impacted by weather or gas volume variability, but revenues are shaped to align with the seasonal usage profile. Enbridge Gas Ontario revenue is affected by weather variability. Gas Distribution and Storage adjusted EBITDA increased $124 million compared with the fourth quarter of 2024 primarily related to: higher distribution margin resulting from an increase in rates and customer base at Enbridge Gas Ontario; higher storage optimization and pricing at Enbridge Gas Ontario; and increased revenue requirement from recovery of capital investments at Enbridge Gas Ohio and higher base rates at Enbridge Gas North Carolina. When compared with the normal forecast embedded in rates, the positive impact of weather to Adjusted EBITDA for Enbridge Gas Ontario was approximately $18 million in the fourth quarter of 2025, net of sharing, compared to a negative impact of approximately $23 million in the same period of 2024. Full year 2025 Gas Distribution and Storage adjusted EBITDA increased by $1.3 billion compared with 2024 and was primarily impacted by the same factors discussed above as well as a full year of contributions from the U.S. Gas Utilities and colder than normal weather in 2025 which positively impacted 2025 Enbridge Gas Ontario EBITDA by approximately $159 million year over year, net of sharing. When compared with the normal forecast embedded in rates, the positive impact of weather for Enbridge Gas Ontario was approximately $30 million in 2025, net of sharing, compared to a negative impact of approximately $129 million in 2024. Renewable Power Generation Three months endedDecember 31, Twelve monthsended December 31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars) Adjusted EBITDA1 211 308 672 820 1 Non-GAAP financial measure. Please refer to Non-GAAP Reconciliations Appendices. Renewable Power Generation adjusted EBITDA decreased $97 million compared with the fourth quarter of 2024 primarily related to: the absence in 2025 of equity earnings related to investment tax credits from our investment in Fox Squirrel Solar; partially offset by strong wind resources at European offshore wind facilities. Full year 2025 Renewable Power adjusted EBITDA decreased by $148 million compared with 2024 and was primarily impacted by lower equity earnings related to investment tax credits from our investment in Fox Squirrel Solar. Eliminations and Other Three months endedDecember 31, Twelve monthsended December 31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars) Operating and administrative recoveries 179 206 493 587 Realized foreign exchange hedge settlement (loss)/gain (74) (66) (459) (92) Adjusted EBITDA1 105 140 34 495 1 Non-GAAP financial measure. Please refer to Non-GAAP Reconciliations Appendices. Operating and administrative recoveries captured in this segment reflect the cost of centrally delivered services (including depreciation of corporate assets) inclusive of amounts recovered from business units for the provision of those services. U.S. dollar denominated earnings within operating segment results are translated at average foreign exchange rates during the quarter, and the impact of settlements made under the Company's enterprise foreign exchange hedging program are captured in this corporate segment. Eliminations and Other adjusted EBITDA decreased $35 million compared with the fourth quarter of 2024 due to: Lower investment income from our wholly-owned captive insurance subsidiary. Full year 2025 Eliminations and Other adjusted EBITDA decreased by $461 million compared with 2024 and was primarily impacted by the same factor discussed above in addition to higher realized foreign exchange losses on hedge settlements and lower investment income in 2025 compared to 2024 which benefited from the pre-funding of the U.S. Gas Utilities acquisitions. Distributable Cash Flow Three monthsended December31, Twelve monthsended December31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars; number of shares in millions) Liquids Pipelines 2,446 2,395 9,710 9,654 Gas Transmission 1,312 1,272 5,397 4,782 Gas Distribution and Storage 1,139 1,015 4,139 2,869 Renewable Power Generation 211 308 672 820 Eliminations and Other 105 140 34 495 Adjusted EBITDA1,3 5,213 5,130 19,952 18,620 Maintenance capital (336) (370) (1,184) (1,118) Interest expense1 (1,268) (1,247) (4,964) (4,475) Current income tax1 (243) (278) (1,014) (875) Distributions to noncontrolling interests and redeemable noncontrolling interest1 (101) (88) (377) (333) Cash distributions in excess of equity earnings1 68 47 403 394 Preference share dividends (108) (101) (419) (388) Other receipts of cash not recognized in revenue2 (29) 8 60 97 Other non-cash adjustments1 12 (27) (3) 69 DCF3 3,208 3,074 12,454 11,991 Weighted average common shares outstanding 2,181 2,178 2,180 2,155 1 Presented net of adjusting items. 2 Consists of cash received, net of revenue recognized, for contracts under make-up rights and similar deferred revenue arrangements. 3 Non-GAAP financial measures. Please refer to Non-GAAP Reconciliations Appendices. Fourth quarter 2025 DCF increased $134 million compared with the same period of 2024 primarily due to operational factors contributing to higher adjusted EBITDA discussed above, in addition to: lower maintenance capital spend related to supply chain optimization; and lower current taxes due to higher investment tax credits and benefits from the One Big Beautiful Bill Act; partially offset by higher debt principal resulting in higher interest expense. Full year 2025 DCF increased $463 million compared with 2024 results primarily due to operational factors contributing to higher adjusted EBITDA discussed above, partially offset by: higher debt principal resulting in higher interest expense; higher current taxes due to higher earnings; and higher maintenance capital from a full year of the acquired U.S. Gas Utilities. Adjusted Earnings Three monthsended December31, Twelve monthsended December31, 2025 2024 2025 2024 (unaudited; millions of Canadian dollars; except per share amounts) Adjusted EBITDA1,2 5,213 5,130 19,952 18,620 Depreciation and amortization (1,518) (1,434) (5,871) (5,353) Interest expense2 (1,277) (1,273) (5,007) (4,534) Income taxes2 (319) (630) (1,854) (2,120) Noncontrolling interests and redeemable noncontrolling interest2 (70) (52) (223) (188) Preference share dividends (108) (101) (419) (388) Adjusted earnings1 1,921 1,640 6,578 6,037 Adjusted earnings per common share1 0.88 0.75 3.02 2.80 1 Non-GAAP financial measures. Please refer to Non-GAAP Reconciliations Appendices. 2 Presented net of adjusting items. Adjusted earnings increased $281 million and adjusted earnings per share increased by $0.13 when compared with the fourth quarter in 2024 primarily due to higher adjusted EBITDA driven by operational factors discussed above, and: lower income tax expense driven by lower effective U.S. tax rates primarily from the impacts of higher investment tax credits; partially offset by higher depreciation from assets placed into service since the fourth quarter of 2024. Full year adjusted earnings increased $541 million and adjusted earnings per share increased $0.22 compared with 2024 due to the factors discussed above, partially offset by higher depreciation and higher debt principal from the U.S. Gas Utility acquisitions resulting in higher interest expense. Per share metrics were negatively impacted by ATM issuances in the second quarter of 2024, as part of the funding for the Acquisitions. CONFERENCE CALL Enbridge will host a conference call and webcast on February 13, 2026 at 9:00 a.m. Eastern Time (7:00 a.m. Mountain Time) to provide a business update and review 2025 fourth quarter results. Analysts, members of the media and other interested parties can access the call toll free at 1-800-606-3040. The call will be audio webcast live at https://events.q4inc.com/attendee/696756185. It is recommended that participants dial in or join the audio webcast fifteen minutes prior to the scheduled start time. A webcast replay will be available soon after the conclusion of the event and a transcript will be posted to the website. The replay will be available for seven days after the call toll-free 1-(800)-606-3040 (conference ID: 9581867). The conference call format will include prepared remarks from the executive team followed by a question and answer session for the analyst and investor community only. Enbridge's media and investor relations teams will be available after the call for any additional questions. DIVIDEND DECLARATION On December 2, 2025, our Board of Directors declared the following quarterly dividends. All dividends are payable on March 1, 2026 to shareholders of record on February 17, 2026. Dividend per share Common Shares1 $0.9700 Preference Shares, Series A $0.34375 Preference Shares, Series B $0.32513 Preference Shares, Series D $0.33825 Preference Shares, Series F $0.34613 Preference Shares, Series G2 $0.29836 Preference Shares, Series H $0.38200 Preference Shares, Series I3 $0.27432 Preference Shares, Series L US$0.36612 Preference Shares, Series N $0.41850 Preference Shares, Series P $0.36988 Preference Shares, Series R $0.39463 Preference Shares, Series 1 US$0.41898 Preference Shares, Series 3 $0.33050 Preference Shares, Series 44 $0.29034 Preference Shares, Series 5 US$0.41769 Preference Shares, Series 7 $0.37425 Preference Shares, Series 9 $0.35450 Preference Shares, Series 11 $0.34231 Preference Shares, Series 13 $0.33719 Preference Shares, Series 15 $0.35163 Preference Shares, Series 19 $0.38825 1 The quarterly dividend per common share was increased 3% to $0.9700 from $0.9425, effective March 1, 2026 2 The quarterly dividend per share paid on Preference Shares, Series G was decreased to $0.29836 from $0.32411 on December 1, 2025 due to reset on a quarterly basis. 3 The quarterly dividend per share paid on Preference Shares, Series I was decreased to $0.27432 from $0.29980 on December 1, 2025 due to reset on a quarterly basis. 4 The quarterly dividend per share paid on Preference Shares, Series 4 was decreased to $0.29034 from $0.31601 on December 1, 2025 due to reset on a quarterly basis. FORWARD-LOOKING INFORMATION Forward-looking information, or forward-looking statements, have been included in this news release to provide information... Read more

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