Enbridge Inc. (ENB:CA) Q4 2025 Earnings Call Transcript
Access earnings results, analyst expectations, report, slides, earnings call, and transcript.
Overview
The earnings call summary reveals strong financial performance, substantial product development, and a positive market strategy. Management's focus on long-term contracts and high-return renewable projects is promising. Despite some unclear responses, the company shows robust expansion plans and a commitment to dividend growth, which enhances shareholder confidence. The Q&A section supports the positive sentiment with management addressing growth opportunities and storage demands effectively. Overall, the company's strategic initiatives and optimistic guidance suggest a positive outlook for stock price movement.
Key Financial Performance
EBITDA Record financial results, exceeding the midpoint of 2025 guidance for both EBITDA and DCF per share. Adjusted EBITDA is up $83 million year-over-year in Q4 2025. Reasons include strong mainline volumes, annual escalators, and lower power costs.
Debt-to-EBITDA Remains within the leverage range of 4.5 to 5x, maintaining a strong investment-grade credit profile. No specific year-over-year change mentioned.
Dividend Increased for 31 consecutive years. No specific percentage change mentioned, but it extends the company's status as a dividend aristocrat.
Capital Sanctioned $14 billion of capital sanctioned across all businesses in 2025, a 35% growth in the backlog since March 2025. Reasons include growth opportunities in Liquids, Gas Transmission, Utilities, and Renewable Power.
Mainline Transportation Transported approximately 3.1 million barrels per day on average in Q4 2025. No specific year-over-year change mentioned, but it highlights strong demand.
Gas Transmission Texas Eastern hit new peak records, transporting over 15 Bcf per day in January 2025. Algonquin pipeline saw 9 of its top 25 all-time volume days this winter. Reasons include increased demand and energy infrastructure needs.
Gas Distribution Enbridge Gas Ohio hit its third highest throughput day in the company's 128-year history. Reasons include colder weather and increased demand.
Renewable Power Added $3 billion of capital in 2025 to support technology and data center operations. Reasons include partnerships with companies like Meta and demand for renewable energy.
Adjusted EPS Increased by $0.13 year-over-year in Q4 2025. Reasons include strong mainline volumes, rate escalations, and favorable spreads at Aitken Creek.
DCF per Share Increased by $0.06 year-over-year in Q4 2025. Reasons include lower maintenance costs, investment tax credits, and benefits from U.S. tax legislation changes.
You have reached the limit. Sign up to access full content
Get started
Operating Highlights
Renewable Power Projects: Sanctioned Cowboy Phase 1 and Easter Wind projects, supplying over 500 MW of renewable power to support data center operations. Cowboy Phase 1 includes a 365 MW solar and 135 MW battery energy storage project in Wyoming, with a CapEx of USD 1.2 billion, expected to enter service in 2027. Easter Wind is a 152 MW onshore wind project in Texas with a CapEx of USD 400 million, secured by a renewable power purchase agreement with Meta.
Gas Transmission Projects: Sanctioned Bay Runner extension of the Whistler pipeline to supply gas to Rio Grande LNG facility, with a total capacity of up to 5.3 Bcf per day. Upsized Eiger Express pipeline from 2.5 Bcf per day to 3.7 Bcf per day, supported by long-term customer contracts.
Market Expansion in Gas Transmission: Advancing over 50 potential data center opportunities requiring up to 10 Bcf per day of natural gas. Expanding U.S. gas transmission modernization program into 2029 and advancing Appalachia to Market II project.
Indigenous Community Partnerships: Historic investment in West Coast pipeline system by 38 First Nations groups, aligning with indigenous communities and advancing economic reconciliation.
Operational Utilization: Mainline transported approximately 3.1 million barrels per day on average, with double-digit apportionment in early 2026. Gas systems saw peak demand days, including Texas Eastern transporting over 15 Bcf per day in January.
Contract Renewals: Achieved 100% contract renewal rate on major gas transmission pipelines and extended contracts on LP assets.
Capital Allocation: Sanctioned USD 14 billion of capital across all businesses in 2025, with a growth backlog increasing by 35% since March 2025. Expecting to reach FID on another USD 10-20 billion of growth projects over the next 24 months.
Dividend Growth: Increased dividend for 31 consecutive years, maintaining status as a dividend aristocrat in the sector.
You have reached the limit. Sign up to access full content
Get started
Risk or Challenges
Regulatory and Legal Risks: The U.S. District Court ruling in favor of Enbridge on Line 5 and the U.S. Army Corps of Engineers issuing their final EIS are positive developments, but the ongoing legal and regulatory challenges surrounding Line 5 remain a risk. Any adverse rulings could impact operations and project timelines.
Economic and Market Risks: The company’s reliance on long-term contracts and regulated frameworks provides stability, but economic downturns or shifts in energy demand could impact revenue, particularly in the Liquids and Gas Transmission segments.
Project Execution Risks: The company has a significant backlog of $39 billion in growth projects. Delays or cost overruns in these projects, such as the Cowboy Phase 1 and Easter Wind renewable projects, could impact financial performance and strategic objectives.
Supply Chain and Operational Risks: The company’s operations, particularly in Gas Transmission and Renewables, are exposed to supply chain disruptions, which could delay project completions or increase costs.
Competitive Pressures: The energy sector is highly competitive, and Enbridge faces pressures from other companies in Liquids, Gas Transmission, and Renewables. Failure to secure new contracts or maintain existing ones could impact market share and revenue.
Rate Case Outcomes: The somewhat disappointing rate case decision in Ohio highlights the risk of unfavorable regulatory outcomes, which could impact financial performance in the Gas Distribution segment.
You have reached the limit. Sign up to access full content
Get started
Guidance & Outlook
Revenue and EBITDA Growth: The company reaffirmed its 2026 guidance, expecting full-year EBITDA between $20.2 billion and $20.8 billion and DCF between $5.70 and $6.10 per share. Growth is driven by $8 billion of new assets expected to enter service in 2026 and enterprise cost savings initiatives.
Capital Allocation and Investment Capacity: Annual investment capacity has grown to $10 billion to $11 billion, supporting $6 billion to $7 billion of organic growth projects annually, in addition to $4 billion of foundational capital for utility growth programs, gas transmission modernization, and liquids mainline capital investment.
Growth Projects and Backlog: The company expects to reach FID on another $10 billion to $20 billion of growth projects over the next 24 months. The current backlog of growth projects now sits at $39 billion, extending through 2033, with an average return on capital employed of approximately 11%.
Gas Transmission Opportunities: The Gas Transmission segment has the largest opportunity set, driven by industrial and power demand, LNG exports, and storage. Potential projects include expansions on Vector, Valley Crossing, Texas Eastern, Algonquin, and others, with additional storage expansions at Tres Palacios.
Liquids Segment Expansion: The company is advancing mainline optimization projects, including MLO1, MLO2, and MLO3, which could add significant egress capacity by 2028. The first phase of mainline optimization (MLO1) is expected to cost USD 1.4 billion and enter service by the end of 2027.
Renewable Power Projects: The company is advancing renewable power projects, including Cowboy Phase 1 and Easter Wind, supplying over 500 megawatts of renewable power. Cowboy Phase 1 is expected to enter service in 2027, with a CapEx of USD 1.2 billion. The Easter Wind project has a capacity of 152 megawatts and a CapEx of USD 400 million.
Dividend Growth: The company has increased its dividend for 31 consecutive years and expects to achieve 5% growth through the end of the decade, supported by $39 billion of secured growth capital.
You have reached the limit. Sign up to access full content
Get started
Shareholder Return Plan
Dividend Aristocrat Status: Enbridge has increased its dividend for 31 consecutive years, maintaining its status as a dividend aristocrat in its sector.
Dividend Growth: The company expects to achieve 5% growth in dividends through the end of the decade, supported by $39 billion of secured growth capital.
Dividend Payout: Enbridge plans to distribute $40 billion to $45 billion in dividends over the next five years, with a payout target range of 60% to 70% of DCF.
Share Buyback Program: No specific share buyback program was mentioned in the transcript.
You have reached the limit. Sign up to access full content
Get started
Key Q&A
Q:Noticed that the investment capacity increased by $1 billion, which makes sense. But the longer-term post '26 growth trajectory still looks around 5%. So just curious how those 2 reconcile. And also curious if there might be maybe some underappreciated upside in '27, '28 EBITDA growth given that 2026 was a little bit of a softer year, but you've got a lot more capital entering service in 2027.
A:Management explained that the 5% growth trajectory aligns with the increased investment capacity as more projects come online. They highlighted confidence in achieving the 5% growth rate, supported by strong project backlogs and favorable conditions in the Western Canadian Sedimentary Basin. They also noted potential upside in gas transmission and distribution, as well as power CapEx exceeding estimates.
Q:Is it fair to characterize the framework being all right, there's growth in the WCSB. That growth will, in all likelihood, fill up TMX. And then after that, any growth that materializes and there should be growth that's already baked into the cake as projects going to be sanctioned, that needs to clear via your full path to the Gulf Coast, and that's what gives you confidence in advancing MLO2 and then mentioning MLO3 today.
A:Management agreed with the framework, emphasizing the need for heavy crude on the Gulf Coast and the increasing utilization of the mainline. They highlighted the iterative expansion of the mainline as a winning formula and noted that MLO2 addresses the 2028 egress bottleneck. They also mentioned the potential for a West Coast solution in the future.
Q:Given the project backlog, which could include $10 billion to $20 billion of projects sanctioned here over the next 2 years, how do you think about the potential to exceed the $10 billion to $11 billion of annual investment capacity and relying on other sources of funding to capture what is an increasingly growth-rich environment?
A:Management expressed confidence in their ability to manage the backlog within the $10 billion to $11 billion annual investment capacity, noting that projects are spread over time. They highlighted the potential for capacity growth as EBITDA grows and mentioned opportunities for recycling capital to create additional buffer.
Q:It doesn't appear that Venezuela slowed down MLO2 at all. However, when we think about MLO3 and the timing for that project, could we need to see increased clarity on either increased exports out off to the Gulf Coast, what the Venezuela situation looks like? Or do you think in any case, Canadian crude will find a home in the Gulf Coast and that MLO3 has a good chance of moving forward?
A:Management stated that MLO3's progress depends on Canadian policy changes to support oil and gas production growth. They noted that Venezuelan barrels are a supplement, not a replacement, for Canadian crude. They also emphasized the flexibility of their system to adapt to various scenarios and highlighted the importance of production growth before pipeline expansion.
Q:Greg, on your last point about potential expansion capability or pushing further WTI volumes out of Ingleside should the Gulf Coast refining heavy up their crude feedstocks. Curious to hear what kind of expansion capability do you have there beyond what you sanctioned thus far? And to what extent would that necessitate expansion of your own pipeline feeding that facility versus barrels potentially going on competitor's pipelines in that area?
A:Management highlighted significant headroom at Ingleside, including additional dock space, storage capacity, and ongoing expansions of pipelines like Gray Oak. They emphasized the ability to optimize utilization of VLCCs and other docks, ensuring flexibility and efficiency in handling increased volumes.
Q:On the heels of so many questions about the geopolitical backdrop, understanding that the situation is still evolving. And with your commercialization efforts on MLO2 and 3, how should we think about how the discussion of the marginal all-in rates are coming to terms is -- as the projects come to fruition late decade and beyond? And how do those economics compare versus the current committed and spot rates on mainline as we think about the upcoming renegotiation for the system, the ROE color over the next couple of years?
A:Management stated that their tolls are competitive and cost-informed, with expansions being inherently efficient. They emphasized that MLO2 provides a full path to the Gulf Coast and highlighted the flexibility of their incremental builds to adapt to market and geopolitical developments.
Q:Not only have we seen apportionment on the mainline, but the level of apportionment has increased pretty meaningfully over the last few months. Has mainline demand surprised you to the upside? And have you observed sort of an increased sense of urgency from your customers given the high apportionment in February? And to the extent that you have a view, how are you thinking about Alberta storage levels going forward?
A:Management acknowledged strong demand for the mainline, driven by Canadian supply growth and optimizations by producers. They noted that consolidation among producers has improved economics and production rates. They also highlighted the importance of political and policy support for continued growth.
Q:You mentioned the $10 billion of projects in the near-term opportunity bucket. Can you just speak to the growth rate of the segment currently. Obviously, it significantly exceeds the corporate average. And how sustainable do you see that sort of outsized growth rate for the segment specifically.
A:Management emphasized the long runway for natural gas, driven by affordability, reliability, power demand, and LNG exports. They highlighted opportunities across regions, including the Northeast, Southeast, and Gulf Coast, and noted strong demand for storage and pipeline capacity. They expressed confidence in sustaining growth through selective capital allocation and high-return projects.
Q:When you think about your $10 billion to $20 billion of projects over the next 24 months, are we expecting these projects to have similar 10% to 11% levels? Or are the project mix so vastly different that might be outside of this range on a portfolio basis?
A:Management expressed confidence in achieving strong returns, noting that renewable projects are in the mid-teens and gas transmission projects are high-quality. They also highlighted opportunities to optimize base assets and improve returns through cost and technology enhancements.
Q:Given the Davos speech, geopolitical events, even the upcoming USMCA negotiations, have there been any signs in your regular engagement with the Canadian or Alberta governments on how they may support major energy infra projects, including perhaps backstopping cost overruns or financing?
A:Management noted positive signals from the Canadian and Alberta governments but emphasized the need for concrete actions. They highlighted the importance of stable policy and regulatory support for major projects and expressed reluctance to take on development risk in uncertain jurisdictions.
Q:Just wanted to dive a bit deeper on the power demand opportunity set. Obviously, you've talked about the focus is on best returns. But we've seen some of your peers go for chunkier power solutions, including some behind-the-meter opportunities. Just in the context of this growing investment capacity, how should we think about whether you'd consider these larger power-focused projects and then what those returns might look like?
A:Management emphasized their focus on long-term contracts and high-return renewable projects, noting that they prefer 15- to 20-year contracts over shorter-term IPP contracts. They highlighted their strong position in renewables, with significant opportunities in solar, wind, and battery projects, supported by tax credits and safe-harbored opportunities.
Q:Can you just talk a little bit about some of the storage economics out there and what you're hearing from customers? I think sometimes the storage opportunity gets overlooked, but I imagine it could be pretty sizable for you guys. So just any messaging there.
A:Management highlighted strong demand for storage, driven by LNG and power demand growth. They noted ongoing expansions in B.C. and the Gulf Coast, with storage rates and contract durations improving. They emphasized the strategic importance of storage in supporting reliability and affordability.
Q:I just wanted to see if you could follow up on your answers to Maurice's question and provide some updated views on the progress that you're seeing in the Alberta, Canada MOU and setting the right investment conditions for a pipeline to the West Coast?
A:Management pointed to the upcoming April milestone for resolving carbon charge and stringency issues as critical for Canadian competitiveness. They emphasized the need for concrete actions to support production growth and noted that MLO1 and MLO2 provide interim solutions while waiting for clearer policy direction.
Q:I wondered if we could have a progress update on wood fiber and how costs are tracking there versus expectations.
A:Management reported that the wood fiber project remains on track for late 2027 in-service, with construction 60% complete and no updates on costs or schedule.
Q:There's a lot of focus on Canadian heavy sour volume growth, but what is also growing out of Canada is light sweet crude, particularly if you look at some of the projections that CNQ is making. And one project which I find very interesting, which you kind of have been working on is trying to get like 250,000 barrels more to DAPL. I think you probably have to reverse the line that is going over there and then you probably work with it [ Ity ] to get more crude to DAPL. Can you talk a little bit about this particular project that gets more probably sweet crude from Canada into the U.S. refining system.
A:Management confirmed plans to move light sweet crude from Canada to the U.S. refining system via DAPL by reversing a cross-border pipeline. They highlighted the project's benefits, including utilizing DAPL's headroom and serving PADD II refining markets.
Q:Can you talk a little bit about gas storage opportunities in key target markets around the data centers. So if you could talk a little bit about that and how Enbridge could benefit from it?
A:Management emphasized the importance of gas storage in supporting power demand and data centers. They highlighted ongoing expansions in B.C., the Gulf Coast, and Ontario, with strong demand and improving storage rates. They also noted the strategic value of storage in stabilizing prices and supporting reliability.
Q:Can you add context on the total development portfolio that you have in gigawatts? And what are your plans in terms of do you want to replenish it or not going forward?
A:Management reported a total development portfolio of over 2 gigawatts, with 4.3 gigawatts in service or under construction. They expressed satisfaction with their current backlog and noted that they are not actively seeking additional assets at this time.
Q:You've -- in the past, you've all electric transmission, you got out, looks like the promise may be looking at competitive bidding projects. Is that something Enbridge will be potentially interested in going back in?
A:Management stated that they are not interested in re-entering the electric transmission business, citing its different risk profile. They emphasized their focus on renewable projects and other opportunities with better returns and risk profiles.
Q:Review of Unclear Management Responses
A:Management avoided providing direct answers or lacked clarity on several questions, including:
1. The specific impact of Venezuelan barrels on MLO3's timing and economics, as their response was broad and lacked detailed data.
2. The competitiveness of tariffs for MLO3 expansions under development, as their response was general and did not provide specific figures or comparisons.
3. The progress on Alberta and Canada MOU for West Coast pipeline investment conditions, as they emphasized signals and milestones but did not provide concrete updates or commitments from governments.
You have reached the limit. Sign up to access full content
Get started
Earnings Word Cloud
The most frequently occurring keywords in this quarter's earning call
Bcf day
Cowboy Phase
EVP
Gas Ohio
Line
MAG
Phase megawatt
Rio
Solar project
USD service
WCSB production
addition capital
affordability
agreement
asset gas
battery
capacity Bcf
company Meta
component
contract
cost saving
day expansion
day gas
event
fundamental
gas distribution
gas infrastructure
gas transmission
investment capacity
output
peak
power gas
production demand
project return
rate effect
role
technology
transmission modernization
utility Enbridge
ENB Transcript
Enbridge Inc. (ENB:CA) Q4 2025 Earnings Call Transcript
Positive2-13
The earnings call summary reveals strong financial performance, substantial product development, and a positive market strategy. Management's focus on long-term contracts and high-return renewable projects is promising. Despite some unclear responses, the company shows robust expansion plans and a commitment to dividend growth, which enhances shareholder confidence. The Q&A section supports the positive sentiment with management addressing growth opportunities and storage demands effectively. Overall, the company's strategic initiatives and optimistic guidance suggest a positive outlook for stock price movement.
Enbridge Inc. (ENB:CA) Q3 2025 Earnings Call Transcript
Positive11-7
The earnings call reveals strong financial performance, strategic expansions, and significant shareholder returns. Despite some vague responses in the Q&A, the company's optimistic guidance, record Mainline volumes, and substantial investments in renewables and LNG projects indicate a positive outlook. The sanctioned solar project with Meta and the expected completion of the Woodfibre LNG project further boost sentiment. Shareholder return plans and disciplined capital allocation reinforce confidence, likely resulting in a positive stock price movement over the next two weeks.
Enbridge Inc. (ENB) Q2 2025 Earnings Conference Call Transcript
Positive8-1
The earnings call summary indicates a positive outlook with strong financial performance, growth projects, and shareholder returns. The Q&A session further supports this sentiment, highlighting management's confidence in growth, strategic capital allocation, and strong customer demand for renewable projects. Despite some uncertainties, such as the Ohio utility impairment, the overall sentiment remains optimistic, with potential for stock price increase.
Enbridge Inc. (NYSE:ENB) Q1 2025 Earnings Call Transcript
Positive5-10
The earnings call highlights strong financial performance with an EPS increase and adjusted EBITDA growth. The acquisition of U.S. utilities is a positive catalyst, contributing to financial strength. The Q&A reveals optimism about future projects and strategic partnerships, though some management responses were vague. However, the commitment to dividend growth and a strong capital backlog supports a positive outlook. Despite some uncertainties, the overall sentiment is positive, likely leading to a stock price increase in the short term.
ENB Slides
ENB Report
Frequently Asked Questions
Where does this earnings call transcript come from?
All transcripts are sourced directly from the official live webcast or the company’s official investor relations website. We use the exact words spoken during the call with no paraphrasing of the core discussion.
How soon is the transcript available after the earnings call ends?
Full verbatim transcripts are typically published within 4–12 hours after the call ends. Same-day availability is guaranteed for all S&P 500 and most mid-cap companies.
Is the transcript edited or altered in any way?
No material content is ever changed or summarized in the “Full Transcript” section. We only correct obvious spoken typos (e.g., “um”, “ah”, repeated 10 times”, or clear misspoken ticker symbols) and add speaker names/titles for readability. Every substantive sentence remains 100% as spoken.
Why do some answers appear as “Unclear” or “Inaudible”?
When audio quality is poor or multiple speakers talk over each other, we mark the section instead of guessing. This ensures complete accuracy rather than introducing potential errors.
Who creates the AI Summary and Key Q&A highlights shown above the transcript?
They are generated by a specialized financial-language model trained exclusively on 15+ years of earnings transcripts. The model extracts financial figures, guidance, and tone with 97%+ accuracy and is regularly validated against human analysts. The full raw transcript always remains available for verification.
