Detailed narrative
Financial results and reaffirmed guidance
Q3 delivered record third-quarter adjusted EBITDA, up $66M versus Q3 2024, on a full quarter of U.S. gas utilities and organic gas-transmission growth. DCF per share was relatively flat YoY as higher financing and maintenance costs from the Enbridge Gas North Carolina acquisition offset operating gains, and EPS declined to $0.46 from $0.55 on gas-utility seasonality (flat interest and depreciation against seasonally lower Q3 EBITDA).
Management reaffirmed all 2025 metrics: EBITDA in the upper half of $19.4B-$20B and DCF/share at the midpoint of $5.50-$5.90. Leverage was 4.8x, within the 4.5-5x range.
Liquids — record mainline and multi-path egress expansion
The mainline moved a Q3-record ~3.1 million bbl/d, apportioned the entire quarter, and Enbridge expects to hit the top of its performance collar ahead of plan while earning maximum allowable returns under the tolling settlement. Growth centers on a 'southbound playbook' of capital-efficient brownfield projects: the sanctioned Southern Illinois Connector (100,000 bbl/d full-path to Nederland, TX), MLO1 (+150,000 bbl/d, FID this quarter, 2027) and an upsized MLO2 (+250,000 bbl/d, 2028) using Dakota Access with Energy Transfer.
Together these advance ~400,000 bbl/d, with MLO3/MLO4 under study should a larger Canada-U.S. energy trade deal materialize. Downstream Mid-Con/USGC volumes were temporarily soft on strong PADD II refining absorption.
Gas Transmission — sanctioning wave and LNG-driven storage build-out
Since March's Enbridge Day, Enbridge announced over $3B of new gas-transmission projects against a $23B opportunity set. Q3 sanctions include the Canyon system expansion for bp's Tiber development (Tiber ~US$300M; total Canyon ~US$1B; 2029), the AGT Enhancement on Algonquin (US$300M; 2029), the 2.5 Bcf/d Eiger Express in the Permian (2028, via the Whistler JV where $2B is invested plus $1B newly sanctioned through 2028), and Egan/Moss Bluff salt-cavern storage expansions (+23 Bcf; ~$500M at 5-6x EBITDA builds; phased through 2033).
With Aitken Creek, Enbridge is adding over 60 Bcf of new storage adjacent to LNG centers as 17+ Bcf/d of LNG-related demand arrives by 2030; it now holds 600+ Bcf and has sanctioned over $10B of LNG-adjacent projects.
Gas Distribution — rate settlements and the power/data-center tailwind
Enbridge reached positive settlements in North Carolina (ROE 9.65% on 54% equity, rev-req +$34M, quick-cycle capital riders, interim rates effective Nov 1) and Utah (rev-req $62M, order expected before year-end, rates Jan 1, 2026). Data-center and power-generation demand is accelerating across the utility footprint — roughly 7 Bcf/d of opportunities (Ontario, Ohio, Utah baseload, plus North Carolina coal-to-gas), including up to 8 GW of early-stage and 6+ GW of mid-stage development in Ohio and Utah alone, with almost 1 Bcf/d already secured.
Data center/power is ~20% of GDS capital; core modernization and major projects (Panhandle ~$360M, NC 215 Phase 1&2 ~US$1.2B, Ottawa reinforcement ~$200M) fill the rest.
Renewable Power — disciplined solar growth with hyperscaler offtake
Enbridge highlighted over 2 GW across four projects contracted to Amazon and Meta: Fox Squirrel and Orange Grove operational, Sequoia Solar entering service in 2026 and Clear Fork (Meta, ERCOT) in 2027. Interconnection-ready projects in strong locations — notably Project Cowboy in Wyoming — retain heavy customer interest while the production tax credit window remains open.
Management stressed investment discipline amid policy cross-currents and a low-risk profile.
Capital allocation and the growth flywheel
Enbridge added $3B of newly sanctioned capital this quarter within its $9B-$10B annual growth capacity, keeping a $35B secured program that underpins ~5% growth to decade-end. Over 200 asset streams sit under regulated or take-or-pay frameworks, 95%+ of customers are investment-grade, commodity exposure is negligible, and most EBITDA is inflation-protected.
Management sees no capital-sequencing bottleneck: near-term (2027) in-service capital is being complemented by 2029-2030 gas-transmission and storage projects, and every incremental $1 of EBITDA adds $4-$5 of balance-sheet capacity.
Permitting momentum — Line 5, DAPL and policy
Line 5 permitting is regaining momentum: the Wisconsin reroute (awaiting an ALJ finding) targets completion in 2027 with the Michigan tunnel a few years behind. For MLO2, no new presidential permit is needed and management is confident the Dakota Access EIS will clear in the spirit of energy security.
In Canada, most projects are short-cycle and permit-light, so Enbridge has not routed any through the new Canadian major-projects office, though it maintains a dialogue there. Federal policy is a swing factor for upside oil-production growth beyond the base-case ~1 million bbl/d by 2035.
Woodfibre LNG and Western Canada storage
Woodfibre LNG is ~50% complete with a strong path to a 2027 in-service date; the toll is set close to in-service, limiting Enbridge's exposure to cost overruns, and Canadian budget accelerated bonus depreciation for low-emission LNG could aid returns. In BC, Enbridge is the sole storage operator at Aitken Creek (77 Bcf existing) and is adding 40 Bcf — 50% contracted at announcement, construction starting early next year — plus West Coast system expansions (Birch Grove on T-North) tied to LNG Canada ramp and potential Phase 2.