MDU Resources Group, Inc. (MDU) | The Buildout — AI Infrastructure
The Verdict
MDU Resources is a pure-play regulated energy delivery business. It generates, transmits and distributes electricity and provides natural gas distribution, transportation and storage services across the Upper Midwest. That position places it directly in the path of AI infrastructure: data centers and AI factories in its service area need electric service, and power generation needs natural gas transportation. The company is an enabler, not an AI pure-play.
| Market Cap | — |
| Revenue (TTM) | $1.8B |
| Revenue Growth | −2.1% |
| EBITDA Margin (TTM) | 27.8% |
| Net Debt | $2.5B |
| Earnings Beats | 4 of 7 |
| P/E (TTM) | — |
| EV/EBITDA (TTM) | — |
What We Like
- Bakken East now has executed agreements with all customers that submitted binding open-season interest, with contracted capacity of nearly 1.2 Bcf/d against design capacity of 1.4 Bcf/d.
- The State of North Dakota signed a firm capacity commitment of $50 million annually for 10 years as a Bakken East anchor.
- Signed data-center load grew from 580 MW in Q1 2026 to over 1 GW in Q2 2026; about 240 MW is online.
- The Applied Digital Polaris Forge 3 electric service agreement adds up to 430 MW at full buildout, pending North Dakota PSC approval.
- The capital-light data-center model gives the average retail customer a roughly $70 per year bill credit, potentially over $200 per year when all volumes are online.
What We’re Watching
- Bakken East FERC Section 7(c) filing slipped from Q3 to Q4 2026; FID is expected before that filing.
- The Applied Digital Polaris Forge 3 ESA is not yet in guidance and awaits North Dakota PSC approval.
- A 50 MW data-center ramp previously expected in 2027 moved to 2028.
- Pipeline earnings declined in both Q1 and Q2 2026; the FERC rate case requests a $31 million annual revenue increase but rates remain subject to refund.
The thesis is strengthening at the forward-option level, even though near-term pipeline earnings drifted lower. Bakken East went from about 40% signed to all binding open-season customers executed in one quarter, and signed data-center load crossed 1 GW. The open question is whether board FID, the Q4 2026 FERC filing, and pending regulatory approvals convert those signed opportunities into contracted cash flows on the stated timeline.
Earnings Beat
MDU reported Q2 2026 consolidated net income of $21.3 million, up 55.5% from $13.7 million in Q2 2025; EPS rose 42.9% to $0.10 from $0.07. Full Q2 revenue and margin tables were not reproduced in the call transcript; the most recent fully detailed quarter is Q1 2026, with consolidated revenue of $606.0 million and a computed gross margin of 25.0%. Signed data-center load crossed 1 GW during Q2, the quarter's standout forward metric.
| Metric | Q1 FY2026 | Q4 FY2025 | Q1 FY2025 | YoY |
|---|---|---|---|---|
| Revenue | $606M | $534M | $675M | −10.2% |
| Gross margin | 25.0% | 25.5% | 30.1% | -510bps |
| EBITDA | $170M | $159M | $164M | +3.5% |
| EPS | $0.39 | $0.37 | $0.40 | −2.4% |
| Signed data-center load | Over 1 GW | 580 MW | n/a | — |
During the quarter, we did enter into an electric service agreement with Applied Digital to serve Polaris Forge 3, an AI factory near Center, North Dakota. At full capacity, the campus would require 430 megawatts of electricity. Approval of the ESA and other regulatory filings by the North Dakota Public Service Commission is pending.— , August 6, 2026
Management tone: Management shifted from describing Bakken East as a speculative open season to a substantially de-risked project with executed agreements. They were direct and precise about what remains unresolved—FID timing, Polaris Forge 3 exclusion from guidance, and the Q4 7(c) filing—and Milestone-oriented without overpromising on dates.
Management Guidance
Management reaffirmed 2026 EPS guidance of $0.93 to $1.00. Assumptions include normal weather and economic conditions for the remainder of the year, continued utility customer growth of 1% to 2% annually, successful execution of approved capital investment and rate recovery plans, and continued execution of debt and equity financing plans. The long-term EPS growth objective of 6% to 8% and dividend payout ratio target of 60% to 70% were also reaffirmed.
Trajectory
Consolidated revenue in Q1 2026 was $606.0 million, down from $674.8 million a year earlier; gross margin was 25.0%, down from 30.1%, while EBITDA margin expanded from 24.3% to 28.0%. The revenue decline is largely pass-through natural gas cost recovery—purchased gas sold fell from $317.2 million to $239.4 million—not a demand collapse. Electric commercial volumes rose even as residential volumes fell on weather. Pipeline transportation volumes were nearly flat at 143.2 MMdk versus 143.5 MMdk, while pipeline earnings slipped.
The Model
The model projects FY+1 revenue of $1,840 million and EBITDA of $554 million, for a 30.1% EBITDA margin. FY+2 rises to revenue of $1,935 million and EBITDA of $594 million, for a 30.7% margin. The projections reflect modest sequential revenue growth and modest EBITDA margin expansion from FY+1 to FY+2.
| Metric | FY2025 | Next FY (E) | Following FY (E) |
|---|---|---|---|
| Revenue | $1.9B | $1.8B | $1.9B |
| YoY Growth | — | −1.9% | +5.2% |
| EBITDA | $497M | $554M | $594M |
| EBITDA Margin | 26.5% | 30.1% | 30.7% |
Projections are the median of 5 independent model runs. The model’s revenue sits 8.9% below analyst consensus.
Management reaffirmed 2026 EPS guidance of $0.93 to $1.00. Assumptions include normal weather and economic conditions for the remainder of the year, continued utility customer growth of 1% to 2% annually, successful execution of approved capital investment and rate recovery plans, and continued execution of debt and equity financing plans. The long-term EPS growth objective of 6% to 8% and dividend payout ratio target of 60% to 70% were also reaffirmed.
What Could Go Right — and Wrong
- Bakken East board approves final investment decision before the Q4 2026 FERC 7(c) filing.
- Applied Digital Polaris Forge 3 receives North Dakota PSC approval, adding up to 430 MW of full-buildout load.
- Data-center ramp stays on schedule: 150 MW later in 2026, 100 MW in 2027, and 50 MW in 2028.
- Pipeline FERC rate case delivers the requested $31 million annual revenue increase with rates effective December 1, 2026.
- Rate-case stack recovers as filed: North Dakota electric $34.5 million, Montana $10 million settlement, Washington and Oregon gas cases.
- Bakken East FID slips or cost escalates; the $2.7–$3.2 billion range is not locked, and the 7(c) filing already moved from Q3 to Q4 2026.
- Polaris Forge 3 is denied or delayed by the North Dakota PSC, or data-center construction slips further.
- Pipeline earnings continue to decline; Q2 2026 was $14.4 million versus $15.4 million, with higher D&A and cost pressure.
- Adverse regulatory outcomes, refunds, or long cost-recovery lags reduce earned returns across the rate-case stack.
Looking Ahead
The next 12 months center on Bakken East: FID is expected before a FERC Section 7(c) filing now targeted for Q4 2026, and the normal November capital-plan update could incorporate a Bakken East working assumption if the board approves FID. On the data-center side, the scheduled ramp includes 150 MW later in 2026, 100 MW in 2027, and 50 MW in 2028, while the 430 MW Applied Digital Polaris Forge 3 ESA awaits North Dakota PSC approval. Regulatory dockets include North Dakota electric interim rates requested effective September 1, 2026 at $26.3 million annualized, and the pipeline FERC rate case with rates effective December 1, 2026 subject to refund.
- September 1, 2026North Dakota electric interim rates — Requested $26.3 million annualized increase; tests regulatory cost recovery.
- Q4 2026Bakken East FID — Board decision expected before the FERC 7(c) filing.
- Q4 2026Bakken East FERC 7(c) filing — Updated target after slipping from Q3 2026.
- November 2026Capital plan update — Normal cycle could add Bakken East working assumption if FID approved.
- December 1, 2026Pipeline FERC rate case — Requested $31 million annual revenue increase becomes effective, subject to refund.
- Late 2026Minnesota gas rate case filing — Expected later in 2026; no exact month disclosed.
Financials
Annual Summary
| Metric | FY2024 | FY2025 | TTM | YoY |
|---|---|---|---|---|
| Revenue | $1.8B | $1.9B | $1.8B | +6.7% |
| Gross Margin | 33.0% | 30.6% | 28.2% | 238bps |
| EBITDA | $466M | $497M | $6.5B | +6.7% |
| EBITDA Margin | 26.5% | 26.5% | 27.8% | +1bps |
| Net Income | $281M | $190M | $189M | -32.2% |
| Free Cash Flow | −$20M | −$319M | −$165M | — |
| Net Cash | — | — | — | — |
Key Ratios (Trailing)
- P/E TTM—
- EV/EBITDA TTM—
- EV/Revenue TTM—
- Price/FCF TTM—
- Gross Margin (TTM)28.2%
- EBITDA Margin (TTM)27.8%
- Net Margin (TTM)10.5%
- ROIC4.3%
- FCF Conversion-76.8%
- SBC / Revenue0.2%
The Company
MDU describes itself as a pure-play regulated energy delivery business. It generates, transmits and distributes electricity and provides natural gas distribution, transportation and storage services. The company operates through subsidiaries Montana-Dakota, Cascade, and Intermountain, serving 185 electric communities and 343 gas communities across eight states; its WBI Energy Transmission pipeline spans over 3,800 miles.
MDU is a regulated, rate-base-driven utility and pipeline operator, not an EPC or construction business after completing the separation of Everus on October 31, 2024. Its electric generation mix includes partially owned coal plants—Coyote Station at 25%, Big Stone at 22.7%, Wygen III at 25%—an 88 MW natural gas peaking unit, and the 250 MW Badger Wind Farm at 49.0% ownership. WBI Energy Transmission represented about 94% of pipeline segment revenue in 2025.
Business Segments
Competitive Landscape
MDU's electric segment operates as a regulated incumbent, but the 10-K identifies rural electric cooperatives, on-site generators, co-generators, and municipally owned systems as competitive counterparties in the electric business. The company's utility franchises therefore have competitive boundaries even within their service areas.
- Rural electric cooperativesNamed in the 10-K as electric-segment competitive counterparties.
- On-site generatorsNamed in the 10-K as electric-segment competitive counterparties.
- Co-generatorsNamed in the 10-K as electric-segment competitive counterparties.
- Municipally owned systemsNamed in the 10-K as electric-segment competitive counterparties.
Supply Chain
MDU sits between upstream fuel suppliers—coal and natural gas—and downstream utility customers and large-load users such as data centers. The 10-K documents coal supply contracts and the affiliate transportation relationship; most ecosystem relationships in the wiring map are inferred, not confirmed.
More on MDU: Earnings recap