Duke Energy Corporation (DUK)
Servicios públicos / Electricidad y gas natural (generación, transmisión y distribución regulada, seis estados)
A regulated electricity and natural gas utility across six states in the southeastern and midwestern United States: a territorial monopoly in most of its markets and a return on capital set case by case by the regulator. The largest of its rate cases just closed: Duke Energy Carolinas agreed with the North Carolina commission, on July 17, 2026, on a 9.8% ROE with a 53% equity ratio, against the 10.95% it had requested. At ~$118 the 5-year base value is around ~$143 (+4%/year in price, +8% with the dividend): Fairly valued - a business with a solid regulatory moat, trading in line with the group of premium regulated utilities.
Moat Compounder estimates the intrinsic value of Duke Energy Corporation (DUK) at $143 per share on a five-year horizon. With the stock at $117.69 at 2026-10-12 close, the expected total return is 7.7% per year: fairly valued. The analysis draws on 10-K FY2025 and 10-Q second quarter 2026 (trailing twelve months to Jun 30, 2026). Analysis dated 2026-08-04.
- Price
- $117.69
- Intrinsic value (5y, base)
- $143
- Total annual return (5y)
- 7.7%
- Status (nominal)
- Fairly valued
- Margin of safety
- +13%
The essentials
- A regulated utility with two businesses of the same nature (no sum-of-the-parts by business type): Electric Utilities and Infrastructure (EU&I, ~92% of segment revenue) serves ~8.7 million electric accounts across North Carolina, South Carolina, Florida, Ohio, and Indiana; Gas Utilities and Infrastructure (GU&I, ~9%) distributes natural gas across the Carolinas and Ohio/Kentucky. The Tennessee gas business is no longer part of the segment: the sale to Spire Inc. closed on March 31, 2026, for ~US$2,500 million in cash.
- The engine is expansion of the regulated rate base, and the company translates it into explicit guidance it reaffirmed on August 4, 2026: adjusted EPS of US$6.55 to US$6.80 for 2026 and long-term growth of 5% to 7% annually through 2030 over the 2025 midpoint of US$6.30, with management expecting to land in the upper half of that range starting in 2028. The projected path anchors there (Section 5 R1) and does not extrapolate the FY2024 net income jump (+59% off a depressed FY2023 base, well above revenue and EBIT growth in the same period).
- At ~$118 it trades at 18× trailing-twelve-month attributable net income - in line with the group of premium regulated utilities (Southern (SO) trades at a similar forward multiple), below NextEra but above the industry's simple average. The base return (+8% total) hinges on whether that multiple holds while growth decelerates toward the regulated-utility band: Fairly valued.
Intrinsic value — two valuation methods
Total return at 5 years: 7.6%/year = 4.0% appreciation + 3.6% dividend. The target price ($143) is ex-dividend; the $23 in dividends collected over 5 years are added separately.
By both methods, the value today (DCF $199 · Multiples $135) exceeds the market price ($118).
Pillars of the analysis
The verdict — today vs 5 years
Today — fairly valued: at $118 trades ~12.8% below its value discounted to today (~$135); the discount is positive but does not reach the margin of safety we require (≥38%).
At 5 years — En valor: the target price ($143) plus dividends yield between the 4% floor and the 10% average return — a reasonable return, though without the margin of a great investment.
The bridge: the return at 5 years exceeds the risk-free rate (4.5%) — but the discount does not reach the required margin of safety (≥38%). To require a 15% annual return, it would need to be bought at ~$86.
Thesis
The business
Duke Energy is a regulated electricity and natural gas utility with a solid regulatory moat: a monopoly in most of its territories (except for competitive electric supply in Ohio), an average authorized ROE of ~9.8% in recent cases, margin-stabilization mechanisms in most jurisdictions, and a nuclear fleet (11 reactors) that is hard to replicate. The largest open rate case closed by settlement on July 17, 2026, with a 9.8% ROE for Duke Energy Carolinas; the Duke Energy Progress case remains pending, with an order expected in November 2026.
The valuation
A utility is valued by P/E on attributable net income, with the value anchored to growth in the regulated rate base. For Duke Energy, attributable net income ($5,247M in the trailing twelve months to June 30, 2026, XBRL) and adjusted earnings (non-GAAP) are close to each other —unlike a utility with a large-scale unregulated renewables arm, where the mark-to-market adjustment can be large—, so attributable net income is a reliable base without needing a major adjustment: the reconciliation for the first half of 2026 shows a net adjustment of just +$5M, because $189M of legal and regulatory settlement charges nearly offset the $171M net gain on the sale of the Tennessee business and $13M of discontinued operations. The path is anchored to the guidance the company reaffirmed on August 4, 2026 (adjusted EPS of US$6.55 to US$6.80 in 2026 and 5% to 7% annual growth through 2030) and does not extrapolate the +59% jump in FY2024 net income: it starts at ~7.0% of attributable earnings —equivalent to ~6.3% per share, within the guided band— decelerating to ~5.0% by year 5, with the multiple compressing from 18× today to ~16.5× (within the regulated-utility band, 15-18×) → ~$143/share → price CAGR +4%, +8% with the dividend (3.7%).
The margin of safety
It trades close to intrinsic value, far from the required margin of safety. The base return (+8% total: +4%/year in price and +4% from dividends) is measured against the average return on equities (~10%, the method's bar). The verdict is Fairly valued: a business with a real and predictable regulatory moat, trading in line with the premium regulated utility group (Southern (SO) trades at a similar forward multiple) — neither at an evident discount nor at a marked premium. The dividend (target payout 60-70% of adjusted EPS, +2%/year, 99 consecutive years paid) contributes a stable and growing portion of total return.
What to watch
Three things. The Duke Energy Progress rate case, still pending: the evidentiary hearing began on August 11, 2026 and the order is expected in November, with first-year rates requested to take effect no later than January 1, 2027; the Duke Energy Carolinas settlement (9.8% ROE, $496M cumulative) is the reference framework the parties committed to replicate. Whether net income growth normalizes without the one-time FY2024 jump and holds within the 5% to 7% per-share range the company guides through 2030 - the first full fiscal year without that boost is the real test of the trajectory. And execution of the combined capital plan (>US$58,000 million 2026-2028), including data-center interconnection, now financed in part with third-party capital: the sale of a 9.19% stake in Florida Progress for ~US$2,800 million and the ~US$2,500 million in proceeds from the sale of the Tennessee business displace common stock issuance.
Educational / informational. Does not constitute investment advice.
Valuation by multiples
The multiple is applied to the metric per share (EPS / Core FFO): that metric already reflects the evolution of the share count (buybacks or issuance), so the share count does not enter as a separate step. The implied equity (~$111.8 bn) is the metric carried to the equivalent of today's share count — the detail is in the piece's (i).
Discounted cash flow to present value (DCF)
Earnings power (owner earnings: after-tax operating income + depreciation and amortization − maintenance capex ≈ depreciation and amortization, using the FY2025 XBRL effective tax rate, 11.2%). The reported trailing-twelve-month effective rate (13.3%) is not used because it is inflated by the non-deductible tax on the gain from the sale of the Tennessee business: the release’s own reconciliation publishes an adjusted rate of 11.5% for the first half of 2026 and 11.5% for the first half of 2025, which corroborates the 11.2%. Reported free cash flow (trailing-twelve-month operating cash flow $11,562M − total capex $15,836M ≈ −$4,274M) is negative because growth capex (~$8,089M above maintenance) absorbs additional cash funded with debt, share issuance, and proceeds from asset sales — this is regulated investment by design, not cash stress. The valuation anchor remains P/E on attributable net income. as the base. Move the assumptions: the value recalculates live. The verdict remains anchored by multiples; the DCF contrasts it at present value.
Risk does not inflate the rate: protection is required separately, as a margin of safety over the value. The floor avoids discounting at the pace of a depressed market rate.
| Year | Projected FCF | Discount factor | Present value |
|---|---|---|---|
| 1 | $8.7 bn | 0.957 | $8.4 bn |
| 2 | $9.3 bn | 0.916 | $8.5 bn |
| 3 | $9.9 bn | 0.876 | $8.7 bn |
| 4 | $10.5 bn | 0.839 | $8.8 bn |
| 5 | $11.2 bn | 0.802 | $9 bn |
Reverse DCF — what growth the price discounts
The inverse approach: instead of projecting growth to obtain the value, the market price ($118) is taken as given and it solves for what annual owner-earnings growth would need to hold for 5 years for the present value —at the method's rate (4.5%, no-growth terminal)— to equal that price. It is the disconfirmation test: the expectations the price already pays for, contrasted against the method's projection.
The market discounts less growth (-0.2%/year) than we project (6.5%/year) → if the base case holds, there is margin: perception is more pessimistic than the estimated reality.
That growth implies ~$8.1 bn of owner earnings in year 5 (vs ~$11.2 bn of our base case). It recalculates if the DCF assumptions are edited.
Year-by-year model — utility (equity)
A regulated utility is valued on P/E over adjusted earnings (equity-level): the value sits in the regulated base (rate base), which grows with capex at an allowed ROE. GAAP can be depressed by the mark-to-market of hedges → the adjusted figure is used. It returns capital via dividend (a dividend aristocrat); it may issue some equity to fund capex. Total return adds the dividend collected along the way. In edit mode, the metric, shares, dividend, and exit multiple can be adjusted.
| US$ bn / per share | TTM | +1a | +2a | +3a | +4a | +5a |
|---|---|---|---|---|---|---|
| Operation (editable: metric, shares) | ||||||
| Utilidad neta atribuible ($bn) | 5.247 | 5.615 | 5.979 | 6.337 | 6.686 | 7.019 |
| growth | — | +7% | +6% | +6% | +6% | +5% |
| ROE ganado (consolidado, aprox.) | 9.7% | 9.8% | 9.9% | 9.9% | 9.8% | 9.8% |
| Capex combinado EU&I+GU&I, guía+extrapolación ($bn) | 15.8 | 17.4 | 19.1 | 20.8 | 21.9 | 23.0 |
| EPS | $6.73 | $7.15 | $7.56 | $7.96 | $8.34 | $8.69 |
| Shareholder return (dividend + buyback) | ||||||
| Dividend / share | 4.26 | 4.34 | 4.427 | 4.515 | 4.606 | 4.698 |
| Payout (div / metric) | 63% | 61% | 59% | 57% | 55% | 54% |
| Shares (M) | 780 | 785.457 | 790.954 | 796.491 | 802.068 | 807.685 |
| Multiples at today's price (equity, no EV) — how they compress | ||||||
| P/E (price / per share) | 17.5x | 16.5x | 15.6x | 14.8x | 14.1x | 13.5x |
| Value curve (per share × P/E exit multiple by year) | ||||||
| Value / share | — | $125 | $132 | $139 | $142 | $143 |
| Total return vs price | — | (+10%) | (+10%) | (+9%) | (+8%) | (+8%) |
A 100%-regulated electricity and natural-gas utility (with no unregulated renewables arm or material competitive segment, unlike NEE/AEP) is valued on P/E over attributable net income (XBRL, already net of noncontrolling interest), close to the non-GAAP adjusted earnings that Duke does guide: the reconciliation for the first half of 2026 shows a net adjustment of just +$5M, because $189M of legal and regulatory settlement charges nearly offset the $171M net gain on the sale of the Tennessee gas business and $13M of discontinued operations. Rolling grid: the base year is the real trailing twelve months to June 30, 2026 ($5,247M, built by levels as FY2025 $4,968M + first half of 2026 $2,642M − first half of 2025 $2,363M, from the 10-Q filed August 4, 2026), and the projection is 12-month windows (+1y…+5y). The gap against after-tax operating income is the interest expense ($3,773M in the trailing twelve months on $88,908M of gross debt), not a nonrecurring item. The path is anchored to the guidance the company reaffirmed on August 4, 2026 (§5 R1): adjusted EPS of US$6.55 to US$6.80 for 2026 and long-term growth of 5% to 7% annually through 2030 over the 2025 midpoint of US$6.30, with management expecting to land in the upper half of the range from 2028 on. The jump in net income from FY2023 to FY2024 (+59%) starts from a depressed FY2023 base and is not extrapolated: the path starts at ~7.0% of attributable earnings —equivalent to ~6.3% per share, within the guided band and above the 2026 guidance midpoint— decelerating to ~5.0% by year 5 (~4.3% per share), where the durable rate for a regulated utility governs rather than the guidance, whose horizon ends in 2030 (§5 R2). The year-1 boost no longer comes from an improved authorized return: on July 17, 2026, Duke Energy Carolinas closed its North Carolina rate case by settlement, with a 9.8% ROE and a 53% equity ratio —against the 10.95% requested— and a net retail revenue increase of $286M in the first year and $210M in the second, $496M cumulative (+7.4%). The Duke Energy Progress case is still pending: the request was cut to ~$610M over two years, evidentiary hearings began August 11, 2026, an order is expected in November, and first-year rates were requested effective no later than January 1, 2027; the parties agreed to seek a substantially similar framework. The trailing-twelve-month earned ROE (~9.7%: $5,189M available to common over $53,778M of common equity at period end) sits just below the ~9.8% authorized average. Shares grow ~0.7%/year (real dilution via the at-the-market equity program of up to US$6,000 million in effect through September 2028, which funds capex), partially offset by third-party capital already executed: ~US$2,500 million from the closing of the sale of the Tennessee business to Spire Inc. on March 31, 2026, and ~US$2,800 million for the 9.19% stake in Florida Progress transferred to a Brookfield affiliate within an agreement of up to US$6,000 million with staged investments through 2028 — EPS grows from ~$6.73 to ~$8.69 over five years. The driver carries total trailing-twelve-month capex ($15,836M) in the base year and the combined EU&I+GU&I 10-K guidance in years 1 through 3 (EU&I $16,275M→$18,000M→$18,925M plus GU&I $1,125M→$1,150M→$1,900M), with moderate extrapolation in years 4 and 5. The multiple compresses toward 16.5× (within the regulated-utility band, 15-18×).
Today's multiple compresses on its own going forward as the metric per share grows. The exit multiple at 3 years is higher than the terminal at 5 years —at 3 years there is more growth still ahead—. Total return adds the dividend collected; the required return is applied to the base scenario.
Scenarios (bear / base / bull) — at 5 years
Value sensitivity
Value per share by growth scenario (rows) and the compression or expansion of the exit multiple (columns). The color shows whether it beats the required return.
| Growth ↓ / Multiple → | Compression−15% | Base multiple | Expansion+15% |
|---|---|---|---|
| BearThe Duke Energy Progress rate case is resolved below the framework agreed with Duke Energy Carolinas or with delay · base ~15×/14× (3y/5y) P/E — compression toward the floor of the regulated utility band | $93 -0.4% | $109 2.5% | $125 5.1% |
| BaseAttributable net income starting at +7.0% - equivalent to ~+6.3% per share · base ~17.5×/16.5× (3y/5y) P/E - within the Section 4 band for a regulated utility (15-18×), compressing from ~19.1× today | $122 4.5% | $143 7.6% · base case | $164 10.4% |
| BullDuke Energy Progress achieves a better outcome than the Duke Energy Carolinas framework · base ~18.5×/18× (3y/5y) P/E — toward the top of the band, sustained by execution of the capital plan | $138 6.9% | $162 10.1% | $186 12.9% |
Multiples — today
High today = growth is being paid for; they cheapen toward 3 and 5 years (see Projections).
Forward multiples
With today's price fixed and the metric growing, what multiple is being paid at 3 and 5 years. Today's high multiple is the price of growth: if the business grows, the entry multiple cheapens on its own.
Optionalities
They are valued separately, with their own rationale, and are not incorporated into the base or the verdict (they are excess return). When assigning them value — in Editmode —, the total with optionalities updates live, without moving the base.
The verdict, the base CAGR, and the margin of safety are always calculated on the base; optionalities do not alter them (with optionalities at $0 they do not move).
Maximum price to pay today — by required return
Each card fixes a required annual return and answers: if the business is worth $143 in 5 years, what is the maximum that can be paid today to obtain that return? Since it now trades at $118, the margin of safety is how much cheaper the market is than that maximum. The three thresholds: 4% covers inflation (the floor), 10% is the long-term average return, and 15% is the level of a great investment.
Return and margin of safety calculator
The maximum price to pay today to earn the required return, with the dividend collected as a separate flow. Both controls are editable.
With a target price of $143 in 5 years plus $23 of dividends collected (the dividend adds to the return, not to the price) and a required return of 4.5% annually, the maximum to pay today is $135. Against the current market price ($118), the margin of safety is 12.8% (trades below the maximum → there is margin) and the total return at that price would be 7.6% annually.
Valuation quality
- Multiple vs. the peer group. 18× trailing-twelve-month attributable net income, against a 15-18× band for a regulated utility.
- Growth vs. multiple. The multiple compresses 18×→16.5× as the path normalizes toward the band the company guides through 2030.
- Margin of safety. The base +4%/year in price (+8% with dividend) is measured against the average return (~10%); with no marked discount today.
ROIC vs the 10% bar — the compounding engine
The quality bar — return bands
The return on capital is judged against absolute bands; the value-creation floor is the market's opportunity cost (~10%). A stock's volatility does not measure business risk.
ROE 10% → below the 10% bar. The bar is a measure of business quality, not the method's discount rate: value is discounted to today at the risk-free rate, and protection is required separately, as a margin of safety.
Owner earnings — the waterfall
It charges maintenance capex (which EBITDA does not deduct). The growth capex ($8.1 bn) is voluntary and is not charged to the base — it depresses FCF today, creates value tomorrow.
Cash & reinvestment
Margins — trajectory
Each margin over sales, year by year: historical (solid line) → projection (dotted).
Owner earnings — the detail
Business quality
- ✕ ROIC exceeds the cost of capital (~10%)
- ✕ High incremental ROIC (compounding)
- ✓ CFROIC backs up the ROIC (100%, cash vs. accruals)
- ✓ Healthy balance sheet (low corporate debt)
- ✓ Durable competitive moat (multiple advantages)
Quality — cash · ROIC · reinvestment
- Regulated return (earned vs. authorized ROE). Approximate earned ROE ~9.7% (derived from the trailing twelve months) vs. an authorized average of ~9.8% - Duke earns just below the average, consistent with the regulatory lag typical of an accelerating capex cycle.
- Value creation (authorized ROE vs. the 10% bar). ~9.8% authorized average vs. the 10% bar: below it on average. The most recent cases do not change the picture - the July 2026 settlement set Duke Energy Carolinas at 9.8% against the 10.95% requested, and the two new Ohio cases request 10.5%.
- Earnings quality. GAAP net income and adjusted (non-GAAP) net income are close to each other: the first-half-2026 reconciliation shows a net adjustment of just +$5M, because the $189M of legal and regulatory settlement charges nearly cancel out the $171M net gain on the sale of the Tennessee business and the $13M of discontinued operations.
Revenue trajectory
Values in US$ bn. The % over each bar is the year-over-year (YoY) growth — each year, historical and projected, vs the prior one (the TTM vs the TTM from a year ago). The path comes from the same source as the table; years without their own series in the model are interpolated between the anchors. Historical solid, projection in a lighter shade.
Where the growth comes from · by segment
Weight in revenue and year-over-year (YoY) growth, in reported USD.
Revenue splits EU&I ~91% (regulated electricity, growing with the rate base and volume +4.5% in 2025) and GU&I ~9% (regulated natural gas, growing faster in percentage terms +25.6% from a small base, driven by the jump in Duke Energy Midwest's distributed volume +16.3%). Weights calculated over the sum of the two reportable segments (excludes the holding/eliminations residual, ~-2% of consolidated revenue). Both businesses are of the same economic nature (cost-of-service regulated); the real driver of value is regulated rate-base growth × the authorized ROE by jurisdiction.
Growth engine — operating drivers
Annual levels from the official filing (10-K); the % over each bar is the year-over-year (YoY) growth vs the prior year.
Duke Energy's engine is the regulated rate base (electricity + gas) x the ROE authorized per jurisdiction (average ~9.8% in recent cases; the July 2026 settlement set Duke Energy Carolinas's at that same 9.8%, and the Duke Energy Progress case still awaits an order). Growth is funded with debt, share issuance (at-the-market program of up to US$6,000 million in effect through September 2028, ~0.7%/year of historical dilution), and third-party capital: the ~US$2,500 million in proceeds from the sale of the Tennessee gas business and the ~US$2,800 million from the 9.19% stake in Florida Progress. It is capital-intensive: growth capex (~$8,089M of the trailing twelve months above maintenance) exceeds what operations cover, which is why reported free cash flow is negative by design.
Projections
| Metric | FY23 | FY24 | FY25 | TTM | +1A | +2A | +3a | +4A | +5a |
|---|---|---|---|---|---|---|---|---|---|
Revenue | $28.7 bn | $30.1 bn (+5%) | $31.7 bn (+6%) | $32.6 bn | $34.3 bn (+5%) | $36.2 bn (+5%) | $38.1 bn (+5%) | $39.8 bn (+4%) | $41.6 bn (+4%) |
Operating income (EBIT) | $7.1 bn | $7.9 bn (+12%) | $8.6 bn (+9%) | $9.2 bn | $9.7 bn (+5%) | $10.2 bn (+5%) | $10.8 bn (+5%) | $11.4 bn (+6%) | $12.1 bn (+6%) |
Net income (attributable to Duke Energy common) | $2.8 bn | $4.5 bn (+59%) | $5 bn (+10%) | $5.2 bn | $5.5 bn (+6%) | $5.9 bn (+6%) | $6.2 bn (+6%) | $6.5 bn (+5%) | $6.9 bn (+5%) |
Total capex | $12.6 bn | $12.3 bn (-3%) | $14 bn (+14%) | $15.8 bn | $17.3 bn (+10%) | $19 bn (+10%) | $20.8 bn (+10%) | $21.9 bn (+5%) | $23 bn (+5%) |
The % are the annual (year-over-year) growth: each year —historical and projected— vs the prior one; the TTM (trailing 12m) vs the TTM of a year ago, to avoid overlapping windows. The historicals are exact figures from the official filings; the projected years come from the year-by-year model (the intermediate years without their own series are interpolated between the anchors). The projected columns (+1y…+5y) are 12-month windows counted from the TTM close (30-jun-2026): the projection starts from the most recently reported data, not the fiscal year. The projected base is realistic and unbiased — the risk discount is applied at the end, via the required return. The rationale for each metric is in the (i).
Growth quality
- Real, not nominal. Growth lives in the physical rate base (built generation, transmission, and distribution assets), not in monetary revenue or an easy comparison.
- Growth engine. Combined EU&I+GU&I 2026-2028 capital plan >US$58,000 million; the Duke Energy Progress rate case (order expected in November 2026) is the next regulatory milestone, with the Duke Energy Carolinas settlement - 9.8% ROE - as the reference framework.
- Sustainability. The FY2024 net income jump (+59%) started from a depressed FY2023 base - the sustainability of the organic pace is tested against the company's own guidance, 5% to 7% annually per share through 2030, reaffirmed on August 4, 2026.
Moat strength
The business and its moat
The business: two regulated utilities of the same nature (electricity and gas)
Duke Energy earns by charging regulated cost-of-service rates, approved jurisdiction by jurisdiction by state commissions (NCUC, PSCSC, FPSC, IURC, PUCO, KPSC) and, for wholesale sales and transmission, by FERC. In cases resolved between 2021 and 2025, the authorized ROE ranged from 9.5% (Ohio, 2021) to 10.3% (Florida, 2024; with a declared band of 9.3%-11.3%), with a simple average across the eight cases of ~9.8% and an authorized capital structure of around ~52-53% equity.
The largest open proceeding has already been resolved: on July 17, 2026, Duke Energy Carolinas and the intervening parties filed a comprehensive settlement with the NCUC that closes all revenue requirement issues, with a 9.8% ROE and a 53% equity ratio, and a net retail revenue increase of $286M in the first year and $210M in the second, totaling $496M (+7.4%). The original request sought 10.95% and a cumulative increase of ~US$1,000 million, so the outcome lands at the currently authorized average and not above it. The Duke Energy Progress case remains pending: on July 24, 2026 the company reduced its request to ~$610M over two years (+12.3% cumulative), the evidentiary hearing began on August 11, 2026, the order is expected in November 2026, and first-year rates were requested to take effect no later than January 1, 2027; the parties agreed to seek a framework substantially similar to Duke Energy Carolinas's. In Ohio there are two new cases filed in 2026 (electric, ~$90M, with a requested ROE of 10.5%; gas, ~$102M, at 10.5%).
EU&I (~92% of segment revenue) integrates electric generation, transmission, and distribution: a diversified mix of natural gas/fuel oil (33.5% of 2025 generation), nuclear (27.5%), coal (14.5%), and hydro/solar (2.0%), plus 22.5% purchased power. It operates 11 nuclear reactors across 6 stations. GU&I (~9%) distributes natural gas to residential, commercial, industrial, and power-generation customers.
Scale and competitive position
Duke Energy serves ~8.7 million electric accounts and ~1.8 million natural gas accounts, with ~55,713 MW of owned generation capacity. In electricity, it operates as a regulated monopoly (sole provider) in nearly all of its territories, with the exception of Ohio, where electric supply is determined through competitive auctions and Duke Energy Ohio retains only the transmission and distribution margin. EU&I's total electricity sales grew to 264,008 GWh in 2025 (+2.1% vs. 258,668 GWh in 2024), driven by higher retail volume, favorable weather, and higher transmission revenue, partially offset by lower wholesale sales in Florida (-30.1%).
In natural gas, volume distributed by Duke Energy Midwest (Ohio/Kentucky) jumped +16.3% in 2025 (to 90.7 million MCF), while Piedmont (Carolinas/Tennessee) held roughly steady (-0.4%, with residential +5.0% and commercial +6.4% offset by industrial -2.3% and power generation -2.7%); the Tennessee business left the perimeter on March 31, 2026. The guided combined capital investment plan for 2026-2028 (EU&I + GU&I) exceeds US$58,000 million, with growing focus on generation (including ~7,500 MW of new natural gas generation projects under construction or seeking regulatory approval) and on data-center and industrial interconnection. Total trailing-twelve-month capex already stands at $15,836M, against $14,024M in FY2025.
The moat: regulatory, with margin-stabilization mechanisms
The moat is regulatory: exclusive service rights in most territories (with the exception of competitive electric supply in Ohio), reinforced by mechanisms that stabilize margins against weather and usage volatility — rate decoupling in North Carolina, weather normalization in South Carolina, Tennessee, and Kentucky, and a fixed monthly charge in Ohio. The diversified generation mix (gas/nuclear/coal/renewables) reduces exposure to any single fuel, and fuel-cost adjustment clauses, present in nearly every state, protect margins from commodity price volatility.
Eleven nuclear reactors across six stations are, in themselves, a replacement asset that is practically impossible to replicate (NRC regulatory barriers and construction costs); Duke has already obtained or is pursuing 20-year additional license renewals for several of them (Oconee through 2054, Robinson through 2050), and in July 2025 Duke Energy Carolinas asked FERC to extend the license of the Bad Creek pumped-storage station by 50 additional years, through 2077.
Moat direction and threats
The moat is stable: cost-recovery and margin-stabilization mechanisms are well established in most jurisdictions, and growing data-center and industrial demand reinforces Duke Energy's position as the required interconnection point within its franchised territory. The outcome of the North Carolina case is the best available indicator of where the regulatory negotiation with Duke's largest market is heading: the July 2026 settlement set Duke Energy Carolinas's ROE at 9.8%, i.e. the average already authorized in the rest of the jurisdictions and not the 10.95% improvement requested - sustained regulated return, without expansion. In parallel, Duke Energy Carolinas and Duke Energy Progress have petitioned the NCUC, the PSCSC, and FERC to merge the latter into the former, so as to operate a single electric utility across the territories of both Carolinas, with cost savings as the stated justification.
Declared structural risks: rate recovery of coal ash closure and remediation costs (CCR) under the EPA's 2015 and 2024 rules, with no guarantee of full and timely recovery; operating, licensing, and nuclear decommissioning-fund risk for the nuclear fleet; the highly variable demand profile of hyperscale data centers, which requires substantial grid investment with stranded-asset risk if that demand fails to materialize; execution of the merger of the two Carolinas utilities; and the phase-out of federal clean-energy incentives (residential solar tax credits already eliminated by 2025 legislation), which could affect the economics of the transition toward 2050.
Business / sector quality
- Relevant in 10 years (recurrence). Electricity and natural gas are the most recurring form of demand; regulated service provides near bond-like predictability.
- Pricing power. Set by the regulator (authorized ROE over the rate base, average ~9.8% in recent cases) — this is not market pricing power, but it is a guaranteed return within the regulatory framework.
- Moat and its direction. Wide moat (regulatory + scale + nuclear fleet), stable. Margin-stabilization mechanisms well established in most jurisdictions.
- Cyclicality / sensitivity. Not very cyclical (stable regulated demand) but sensitive to rates (high leverage) and to the pace at which pending rate cases are resolved.
Solvency margin
Each pillar between danger and solid — the further right, the more room.
Reading for a regulated utility: it runs high leverage (5-7×) backed by a rate base that earns an allowed ROE and an investment-grade rating — it is not judged by an industrial company's thresholds. EBIT/interest coverage is thin by design (lots of cheap debt); EBITDA/interest coverage is higher.
Net cash position
In a regulated utility, debt is backed by a rate base that earns an allowed ROE and an investment-grade rating — it is low-cost funding for a regulated-return asset, not a vulnerability. High leverage is structural and healthy.
Debt composition
Not all debt is equal: only the structural needs refinancing; the rest is operational (self-liquidating).
Structural debt is what is exposed to the contraction phase of the cycle; operational debt (leases, matched funding) self-liquidates with the business.
Company health / solvency
- ✓Regulated return (earned vs allowed ROE)Earns 9.7% vs allowed 9.8%
- !Value creation (allowed ROE − 10% bar)-0.2pp
- ✓Leverage (net debt / EBITDA)5.2x
- ✓Predictability (% regulated + rate-base growth)100% regulated · rate base +$11.2 bn/year
A traffic-light interpreted by the method (not generic): float (negative WC) adds up, capex is judged by incremental ROIC (malinvestment test), and a lender is not subjected to corporate solvency. The (i) shows the derivation of each number.
Health — balance sheet risks
- Leverage (regulated lens). High by design ($88,908M of debt, ~5.2× net debt/EBITDA), backed by a regulated rate base - judged against utility thresholds, not corporate solvency.
- Credit quality. Duke Energy's specific credit rating was not captured in this light extraction — gap declared, pending verification against the filing or a rating agency.
- Cash flow. Reported free cash flow (operating cash flow - trailing-twelve-month capex) is negative (~-$4,274M) because growth capex exceeds maintenance - regulated investment by design, funded with debt, equity, and asset sales, not operating stress.
- Funding of the capex plan. Funded with debt, share issuance (at-the-market program of up to US$6,000 million in effect through September 2028, ~0.7%/year of dilution), and third-party capital: ~US$2,500 million from the sale of the Tennessee business and ~US$2,800 million for the 9.19% stake in Florida Progress.
Who runs it
- A recent, orderly CEO transition: Sideris was promoted internally to President in April 2024 and to CEO in April 2025, after 13+ years at the company in operating and regulatory roles (including the Florida state presidency).
- Capital is deployed almost entirely to regulated capex (rate base, ~$15,836M in the trailing twelve months) funded with debt and share issuance via an at-the-market program of up to US$6,000 million in effect through September 2028, with no share buybacks.
- Capital recycling executed over the past year: the sale of Piedmont's Tennessee gas business to Spire Inc. closed on March 31, 2026 for ~US$2,500 million, and a Brookfield affiliate has already transferred ~US$2,800 million for a 9.19% stake in Florida Progress under an agreement of up to US$6,000 million with staged investments through 2028. Both transactions displace common stock issuance.
Capital allocation — indicators
The quality test: it reinvests at 10% vs the 10% bar (market opportunity cost) → each $1 retained creates value.
Shares — ownership and dilution
Who owns the shares — the alignment and whether there is a controlling shareholder.
Minimal dilution: SBC represents less than 2% of value per year and the share count is ~flat — it does not erode value per share.
Management / capital allocation
- Skin in the game. Not identified in this light extraction — the DEF 14A proxy could not be anchored (non-standard format). Gap declared, pending a targeted reading of the filing.
- Capital allocation. Deploys capital almost entirely to the regulated rate base (trailing-twelve-month capex of ,836M) + the dividend (target payout of 60-70% of adjusted EPS); no buybacks. Recycled capital over the past year: closed the sale of the Tennessee gas business to Spire Inc. on March 31, 2026 (~US,500 million) and transferred a 9.19% stake in Florida Progress to a Brookfield affiliate for ~US,800 million.
- Integrity / candor. The 10-K details with precision the authorized ROEs by rate case and the recovery risks; the tone of the shareholder letter was not evaluated in this light extraction.
Why it trades at this price
- There is no clearly identifiable source of discount: it trades at 18× trailing-twelve-month attributable net income, in line with the group of premium regulated utilities (Southern (SO) trades at a similar forward multiple) - this does not look like a case of missing buyers or motivated sellers.
- The FY2024 net income jump (+59% off a depressed FY2023 base) could lead the market to extrapolate a growth rate that the company's own guidance does not sustain: 5% to 7% annually per share through 2030 - a risk of paying today for growth that will not recur.
- This is a 'caution: it may not actually be cheap' case (Section 9): the price reflects a quality utility with a solid regulatory moat trading in line with its premium peers, not an obvious discrepancy between perception and reality. The outcome of the largest rate case - 9.8% ROE against the 10.95% requested - confirms a sustained regulated return, not one that is expanding.
Without an identifiable source of discount, the base return (+8% total) reflects a quality regulated business trading at full valuation within its group, not an evident value opportunity.
Return asymmetry — risk/reward
The annual return (CAGR at 5 years) in each scenario, with the total period return below — the margin of safety made visual: upside range wide, downside range narrow.
Even in the bear scenario, the return holds at +3%/year (+13% total): the margin of safety protects the downside. The bull (+10%/year, +61% total) exceeds it comfortably — a favorable asymmetry, with a narrow downside range and a wide upside range.
Bear case — disconfirmation
- The Duke Energy Progress rate case is resolved below the framework agreed with Duke Energy Carolinas (9.8% ROE, 53% equity ratio) or with delays beyond January 2027.
- Organic growth disappoints against the 5% to 7% per share the company guides through 2030, once the trailing twelve months move past the contribution of the capital-recycling transactions.
- Rate recovery of coal ash closure costs or nuclear investment faces regulatory friction in one or more jurisdictions, pressuring the earned ROE below the current ~9.7%.
- Financing the growing capex becomes more expensive with higher rates and leverage keeps rising from the current ~5.2× net debt/EBITDA, accelerating dilution beyond what is planned.
Bull case — the thesis for
- The Duke Energy Progress case is resolved above the Duke Energy Carolinas framework, improving the regulated return of Duke's largest market starting in January 2027.
- Data-center and industrial demand holds up or accelerates, and regulators recognize the associated capex in rates (including the ~7,500 MW of gas generation under development) without material friction.
- Brookfield's staged investments in Florida Progress through 2028 complete the US$6,000 million committed and displace common stock issuance, so EPS grows faster than aggregate earnings.
- The merger of Duke Energy Progress into Duke Energy Carolinas is approved and delivers the stated cost savings, and the earned ROE converges toward the top of the authorized band as the regulatory lag closes.
Risks — what breaks the base case
- Resolution of the Duke Energy Progress rate case. The central year-1 disconfirmer: the evidentiary hearing began on August 11, 2026 and the order is expected in November, with rates requested for January 1, 2027. The Duke Energy Carolinas settlement (9.8% ROE, $496M cumulative) sets the framework; an outcome below it cuts the regulated return of Duke's largest market.
- Coal ash closure costs (CCR). Significant asset-retirement obligations tied to the EPA's 2015 and 2024 rules, with no guarantee of full and timely rate recovery.
- Nuclear risk. Eleven reactors at six stations; license renewals still pending NRC approval for some of them, and the decommissioning fund subject to market fluctuations.
- Data-center demand variability. Requires substantial generation and grid investment with stranded-asset risk if projected demand fails to materialize as expected.
- Merger of Duke Energy Progress into Duke Energy Carolinas. Joint petition to the NCUC, the PSCSC, and FERC to operate a single electric utility across the territories of both Carolinas; the stated savings depend on approval and integration.
Lenses — the value investing thinkers
Each thinker's analytical framework applied to our data.
The price is attractive, but business quality is not unanimous.
- Buffett / Graham Quality + margin of safety
Fails the quality gate: ROE barely matches the 10% bar (the market's opportunity cost), no excess return.
- Peter Lynch Growth at a reasonable price (GARP)
A stalwart growing 7% at a PEG of 2.7 → expensive for its growth.
- Joel Greenblatt Cheap and high-return (Magic Formula)
Not applicable — the Magic Formula excludes financials and regulated businesses (EBIT/EV does not capture the operating leverage).
- Howard Marks Perception vs reality + cycle
The price discounts -0% vs our 7%: perception is more pessimistic than reality, with an identified source of the discount.
- Seth Klarman Capital protection (bear scenario)
Bear-scenario floor -2%/yr, bull-scenario ceiling +7%/yr over 5y → capital protected, asymmetry in your favor.
- Pat Dorsey Moat strength (Five Rules)
A wide moat, stable; sources: intangibles, efficient scale, cost advantage, switching costs → passes the Five Rules.
- Aswath Damodaran Expectations implied by the price
Justifying the price requires discounting -0%, within what we project (7%) — the story squares with the numbers.
