Alliant Energy

Phase A — Understand the business

Lens 1 · Company Overview

The business model in plain terms. Alliant earns a regulated return on invested capital ("rate base"). It builds and operates poles, wires, pipes and power plants; state commissions (the Iowa Utilities Commission, IUC, and the Public Service Commission of Wisconsin, PSCW) set customer rates that let it recover prudently-incurred costs plus an authorized return on equity. Growth = rate-base growth. There is essentially no merchant/commodity exposure on the bottom line: fuel and purchased-power costs flow through automatic cost-recovery riders, "which significantly reduce commodity risk". So the P&L is an annuity that grows with capex, gated by regulators.

Structure:

• IPL — Iowa electric + gas. ~505,000 electric / ~230,000 gas retail customers. Regulated by the IUC.
• WPL — Wisconsin electric + gas. ~505,000 electric / ~205,000 gas retail customers. Regulated by the PSCW.
• Corporate Services — shared administrative entity (billed at cost to IPL/WPL).
• AEF (Alliant Energy Finance) — the non-utility bucket: a 16% interest in American Transmission Company (ATC, a for-profit transmission-only utility) + 20% of ATC Holdco; Travero (short-line rail, barge terminal, freight brokerage — a supply-chain solutions business); the 347 MW Sheboygan Falls gas plant leased to WPL through 2044; a 50% stake in a 225 MW Oklahoma wind farm; corporate venture investments; and development-ready industrial sites.

Key products/services: regulated electricity (the dominant earnings driver — $3,697M of FY2025 revenue) and regulated natural gas distribution ($525M).

Customers, suppliers, competitors. Customers are the ~1M+ retail meters plus wholesale buyers in MISO. The contract structure that matters now is the new large-load "individual customer rate" tariffs for data centers — IUC orders in May and October 2025 approved individual customer rates for data centers in IPL's territory; WPL has a parallel filing pending (PSCW decision expected Q2 2026). As a monopoly franchise, Alliant has no direct retail "competitor"; the competitive threats are structural — behind-the-meter generation, co-located resource arrangements, and customers self-supplying (flagged explicitly in the forward-looking risk list).

Take-or-pay / recurring / concentration. Revenue is recurring and rate-regulated. No single customer was ≥10% of consolidated revenue in 2025. The data-center agreements are structured as long-term electric-service agreements with contracted peak demand (~3.4 GW aggregate across five executed agreements as of Q1 2026); importantly, transmission-infrastructure cost guarantees protect the utility if a project is cancelled before in-service (IPL ~$163M, WPL ~$75M of reimbursement guarantees).

Lens 2 · Supply Chain

Map: upstream inputs → Alliant → end customer, with named stakeholders.

Upstream (fuel & equipment):

• Coal / natural gas suppliers + transporters — minimum future commitments at 3/31/2026: natural gas $1,019M, coal $150M. Commodity cost is a pass-through, so the risk is operational/delivery, not price.
• Solar & storage equipment supply chain is the live chokepoint. The 10-K repeatedly flags tariff risk on "solar project materials and equipment from certain countries," antidumping/countervailing duties, and supplier manufacturing constraints as direct threats to building generation on time/on budget. Material relief landed in 2026: in February 2026 the Supreme Court ruled IEEPA does not authorize the executive tariffs, and the Court of International Trade ordered refunds of previously-collected IEEPA tariffs — Alliant's suppliers (importers of record) may be eligible for refunds of tariffs previously capitalized into project cost, though Alliant has not recognized any recovery as it is "not probable" yet.
• MISO (Midcontinent ISO) — the wholesale market operator; sets resource-adequacy and capacity-accreditation rules that govern how/when Alliant's new solar is credited with capacity. A change in MISO's seasonal accreditation could force Alliant to add resources or buy capacity in the market.
• ATC (American Transmission Company) — supplies transmission to WPL and is also a 16%-owned equity affiliate; WPL paid ATC $162M in 2025.

Midstream (Alliant's own assets): ~2,957 MW of IPL gas + 1,302 MW IPL wind + solar/storage; WPL's 1,089 MW Wisconsin solar (2022-2024) and gas fleet; the West Riverside and Sheboygan Falls gas centers. Plus Travero, Alliant's own logistics arm (short-line rail in Iowa, a Mississippi River barge/rail/truck terminal in Illinois) — vertical integration into freight that can move coal/equipment.

Downstream (end customers) — the named hyperscalers: the demand surge is concentrated in a handful of named counterparties. Public reporting identifies QTS (Cedar Rapids, IA — two facilities), Google (Cedar Rapids, IA), and Meta (Beaver Dam, WI) as the anchor data-center loads, plus the new ~370 MW Iowa agreement signed in Q1 2026. The filings confirm "two new customers" in IPL territory and "one new customer" in WPL territory each constructing data centers, ~3 GW aggregate at year-end 2025, rising to ~3.4 GW after Q1 2026. Chokepoint / single-source dependency: the load is concentrated in a few hyperscalers — if one delays/cancels, the transmission build risk is partly hedged by reimbursement guarantees but the growth narrative is exposed (see Lens 13).

Lens 3 · Competitive Advantages (moats)

The moat is the regulated-monopoly franchise, and it is real but bounded.

• Regulatory monopoly + constructive jurisdictions. IPL and WPL are exclusive-franchise monopolies in their service territories. The durable advantage is the quality of the regulatory relationship: Iowa granted IPL advance rate-making principles for up to 1,000 MW of new wind in March 2026 (a fixed $3,020/kW cost cap with pre-approved cost recovery) — a structurally favorable mechanism that de-risks capex before it is spent. Wisconsin delivered a unanimous rate settlement for 2026-2027 in September 2025 (approved by PSCW). Constructive regulation is the closest thing a utility has to a moat.
• Scale economies in a building cycle. The strategy explicitly favors "larger scale natural gas facilities to capture economies of scale" and upgrading existing assets (advanced gas-path projects at Neenah and Sheboygan Falls in 2025) — cheaper marginal capacity than greenfield.
• Renewable tax-credit machine. Alliant's owned wind/solar generates transferable IRA tax credits — $285M of credits sold to other corporate taxpayers in 2025 (vs $216M in 2024, $98M in 2023). This is a genuine, compounding financing edge that lowers the customer bill and the effective tax rate (FY2025 produced a $149M income-tax benefit).
• Bargaining power. Over suppliers: moderate — Alliant is a meaningful buyer but exposed to global solar-equipment supply. Over customers: high for the captive retail base (monopoly), but the new data-center customers have real leverage — they can choose between Iowa and Wisconsin (one customer literally migrated its load from WPL to IPL in Q1 2026 ), and can threaten behind-the-meter self-supply. This is the one place the moat is thinning.

Verdict on the moat: durable but not special relative to peers — every regulated Midwest utility (WEC, Xcel, Ameren, CMS) has the same monopoly + the same data-center tailwind. Alliant's edge is execution + regulatory constructiveness, not a structural advantage competitors lack.

Lens 4 · Segments

Two reportable segments: IPL and WPL (Alliant recast to entity-segments in Q4 2024; "electric/gas/other" is no longer the segment cut). All figures `` unless noted.

Trend & cause:

• IPL drove the 2025 step-up (+$95M net income YoY): the Oct-2024 rate order ($185M annual base increase), solar placed in service, and updated depreciation rates, plus the non-recurrence of 2024's $60M Lansing asset-valuation charge. IPL net income grew 26% YoY — the engine.
• WPL grew +$56M on its Dec-2023 rate order ($60M increase) and solar/storage rate-base.
• Other/AEF deteriorated to $(48)M (from $(17)M) — an asset-valuation charge on the non-utility business (incl. a $16M write-down on Travero's suspended wind-turbine-blade recycling, Nov 2025), higher financing expense, and a state-tax-apportionment charge. The non-utility drag is small but persistently negative — a minor wart on an otherwise clean utility.

Geography: 100% U.S. (Iowa + Wisconsin). No international exposure.

By fuel/product (FY2025 utility revenue): Electric $3,697M (85%), Gas $525M (12%), Other utility $51M, Non-utility $89M. Retail electric MWh grew ~2% in 2025; retail gas volumes +14% (mostly weather).

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Phase B — Measure performance

Lens 5 · Earnings Result

FY2025 (the annual print):

• Revenue $4,362M (+9.6% vs $3,981M in 2024).
• Operating income $1,025M (+15.7% vs $886M).
• Net income $810M (+17.4% vs $690M); diluted EPS $3.14 (vs $2.69) — a ~16.7% EPS jump, but flattered by the non-recurrence of 2024's $60M Lansing charge and a larger income-tax benefit.
• Income-tax benefit of $(149)M (vs $(114)M) — driven by production/investment tax credits; the effective tax rate is structurally negative, a feature, not an anomaly.
• Margins: operating margin 23.5% (2024: 22.3%). The right way to read a utility, though, is rate-base × allowed ROE, not GAAP margin.

Q1 2026 (the latest print):

• Revenue $1,184M (vs $1,128M).
• Operating income $249M (down from $257M — higher O&M and D&A outran revenue).
• Net income $224M; GAAP diluted EPS $0.87 (vs $0.83).
• But "ongoing" (non-GAAP) EPS was $0.82 vs $0.83 — a slight miss/flat, and the headline framing was "missed expectations" even as guidance was reaffirmed. Interest expense jumped to $142M (from $119M) — the financing-cost headwind from a growing debt load is the thing to watch.

Guidance / outlook:

• FY2026 ongoing EPS guidance $3.36–$3.46 (midpoint $3.41, +~6.6% over 2025), reaffirmed at Q1.
• Long-term CAGR raised: 2027–2029 targeted at "7%+" (vs the historical 6%+) — the data-center capex is what lifts the slope.
• Management noted Q1 delivered "~25% of ongoing guidance midpoint" — on track.

Balance-sheet flags:

• Operating cash flow $1,169M vs construction/acquisition capex of $2,483M → the utility is structurally FCF-negative by ~$1.3B/yr, funded by debt + ATM equity. This is normal and expected for a utility in a build cycle, but it is the entire risk surface: it only works if rates rise to cover it.
• Cash $556M (up from $81M — pre-funded). Long-term debt $10,954M + current maturities $1,074M + CP $88M ≈ $12.1B gross debt; net debt ~$11.6B. Debt-to-cap 59% (covenant ≤65%).
• Accounts receivable build of $(652)M in operating cash flow is a securitization artifact (offset by $628M cash receipts on sold receivables) — not a red flag.

Market reaction: the stock has risen through the print to ~$76.66 (June 2026) — the market is paying for the multi-year load story, not the in-quarter number. A "miss-and-reaffirm" that the stock shrugs off tells you sentiment is anchored on 2027-2030, not 2026.

Lens 6 · Earnings Calls (sentiment trend)

No transcripts on the local shelf (transcripts/ empty); this lens is ``.

• Consistent, confident, on-message. Across recent quarters management has hammered one theme: data-center-driven load growth converting into a raised capital plan and a raised EPS slope. CEO Lisa Barton, Q1 2026: "We are off to a strong start in 2026, delivering approximately 25% of our ongoing earnings guidance midpoint, and reaffirming our full-year ongoing EPS outlook".
• What they keep saying: "well-structured, long-term growth," "contracted demand," "affordability," "constructive regulatory outcomes." The recurring framing is that load growth lowers bills for existing customers (spreading fixed costs) — a deliberate affordability message to keep regulators on side.
• Tone shift over time: from "evaluating potential load" (2024) → "executed agreements totaling ~3 GW" (Q4 2025) → "~3.4 GW across five executed agreements" + filing individual customer rate cases (Q1 2026). The language has hardened from optionality to contracted backlog — a genuine de-risking of the narrative.
• What they've stopped emphasizing: the older "renewable transition" framing has been partly displaced by "dispatchable gas + storage to serve reliable 24/7 data-center load" — a pragmatic pivot toward gas (1,600 MW of new gas in the plan) that matters for the ESG framing but reads as realism.

Lens 7 · Comps

Peer set: large-cap regulated Midwest electric+gas utilities with the same data-center tailwind. Multiples are ``, dated June 2026; cells I could not source cleanly are marked n/a rather than fabricated.

ROE check (LNT): FY2025 net income $810M / average common equity (($7,004M + $7,334M)/2 = $7,169M) = ~11.3%. That is a healthy regulated-utility ROE, consistent with authorized returns in the ~9.5–10.5% range plus the tax-credit tailwind.

Read: LNT trades right in the middle of the cohort — ~22-24x P/E sits between Ameren (cheapest at 19.9x) and Xcel (richest at 23.7x), and the ~2.8-2.9% yield is mid-pack. There is no valuation discount to arbitrage and no premium to fade. The whole group is priced for the data-center super-cycle. If you like the theme, LNT is a fair-priced, well-run way to own it; it is not a relative-value standout.

Lens 8 · Stock-Price Catalysts (what moves LNT >5%)

Detailed five-year tick-by-tick history wasn't on the shelf; this is `` + structural inference from the filings.

• Interest rates / the long bond — the dominant macro driver. As a 3% bond-proxy with $12B of debt, LNT trades inversely to 10-year yields. The 2022-2023 rate shock compressed all utility multiples (Morningstar: "Utilities Stocks Plunge…"); the 2024-2026 data-center narrative re-rated them back up.
• Rate-case outcomes — IUC and PSCW orders are the company-specific catalysts. The constructive Oct-2024 IPL order, the Sept-2025 WPL unanimous settlement, and the March-2026 Iowa advance-rate-making for 1,000 MW of wind are all positive prints. An adverse order (lower allowed ROE, disallowed costs) would be the negative version.
• Data-center announcements — each executed electric-service agreement and each individual-customer-rate approval is a discrete up-catalyst; the ~370 MW Iowa signing (Q1 2026) and the QTS/Google/Meta anchors moved the multi-year story.
• Capital-plan updates — the 17% raise to $13.4B (Q4 2025) was a major up-catalyst; future raises (management is "evaluating additional demand") would extend the EPS slope.
• Guidance / dividend actions — the annual EPS guide and the dividend raise (to $2.14, +5.4%) are scheduled, low-volatility catalysts.
• What the market actually reacts to: for LNT specifically, it is the slope of the multi-year growth algorithm (rate base × ROE × time) and rates — not the in-quarter EPS, which is why a Q1 "miss-and-reaffirm" did not dent the stock.

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Phase C — Judge people & books

Lens 9 · Management

unless noted.

• Lisa M. Barton — President & CEO since Jan 2024 (age 60). The defining fact about this management team: it is an American Electric Power (AEP) transplant. Barton was EVP & COO of AEP (a much larger, transmission-heavy utility) before joining Alliant as President & COO (Feb 2023) and ascending to CEO. Track record: deep transmission/grid operating background at AEP — exactly the skill set for a company about to spend $13.4B on generation and grid interconnection for data centers. She has been at the helm <2.5 years, so the track record at Alliant is short but the early read (load-growth contracting, capital-plan raise, constructive rate outcomes) is strong.
• Robert J. Durian — EVP & CFO since 2020 (age 55), CFO continuity since 2019. The financial steward through the build cycle; long tenure is a stability anchor.
• The AEP cluster: Raja Sundararajan (EVP & Chief Strategy Officer, ex-AEP), Antonio Smyth (EVP Power Generation & Gas Strategy, ex-AEP Grid Solutions), and others are AEP alumni. Interpretation: Barton has imported a grid/transmission-and-data-center playbook wholesale from a bigger utility. Bullish for execution capability; mildly concerning for groupthink and for whether AEP's scale-utility playbook over-fits a much smaller balance sheet.
• Rebecca Valcq — VP since Jan 2026 — the former Chair of the PSCW (Wisconsin's regulator) 2019-2024. Hiring the recent chair of your own regulator is a double-edged datum: deep regulatory fluency and relationships (a genuine asset for a rate-case-driven business), but an optics/revolving-door flag worth noting.
• Capital-allocation history: the model is reinvest-and-grow-the-dividend. Dividend per share: $1.81 (2023) → $1.92 (2024) → $2.03 (2025) → $2.14 target (2026) — a disciplined ~6%/yr raise, with a stated 60–70% payout-ratio goal. No large buybacks (the company is a net equity issuer via the ATM to fund capex) — appropriate for a growth-capex utility. ROE ~11.3% (Lens 7) is value-creating against an ~9-10% cost of equity.
• Red flags: none material. Comp is incentive-aligned (performance shares on TSR + net-income metrics). The revolving-door regulator hire and the AEP-monoculture are the only governance nuances.
• Archetype: professional managers running a regulated compounder — appropriate for the stage. No founder dynamic; this is a steward-operator team.

Lens 10 · Forensic Red Flags

Acting as a forensic analyst. This is, frankly, a clean set of books — which is what you expect from a regulated utility audited by Deloitte with effective ICFR. The genuine accounting-judgment surfaces:

• Regulatory assets/liabilities (the big estimate). $2,119M long-term + $155M current regulatory assets vs $1,113M + $88M regulatory liabilities. These exist because a regulator has signalled future recovery; a single adverse order can impair them. This is the central accounting risk for any utility and Alliant flags it as its #1 critical estimate.
• Tax-credit dependence. The $(149)M income-tax benefit and $285M of sold renewable tax credits mean a meaningful slice of "earnings" and cash is IRA-policy-dependent. The forward-looking section devotes enormous space to the risk of "repeal, modification, or reduced funding of the Inflation Reduction Act and the impact of the One Big Beautiful Bill Act" on these credits. If the credit regime is curtailed, both the tax rate and the financing math (credit transfers) worsen. This is the most underappreciated quantitative risk in the model.
• Cash-flow vs earnings divergence. Operating CF ($1,169M) << net income + D&A would suggest, because of the receivables-securitization mechanics and large deferred-tax movements. Reconciles cleanly once you net the $628M receivables cash receipts — not a quality-of-earnings flag, but it does mean reported OCF understates the run-rate.
• Capitalized tariff costs / AFUDC. Tariffs were capitalized into project cost; the company is now evaluating refunds but has not booked them (conservative). AFUDC (non-cash equity earnings on construction-in-progress) was $89M in 2025 — a normal-for-utilities but real component of "earnings" that isn't cash.
• Pension/OPEB: modestly under-funded ($173M obligation on the balance sheet); not a stress point.
• Goodwill/intangibles: not material. SBC: small ($30M unrecognized) — non-GAAP is not materially flattered by SBC, unlike a tech name.

Regulatory findings (required sub-section):

• SEC Litigation Releases & AAERs: None. Verified via SEC EDGAR EFTS (LR + AAER) search 2021-06-29 → 2026-06-29 — zero findings naming Alliant Energy.
• 10-K Item 3 (Legal Proceedings): "None" for material environmental proceedings above Alliant's $1M disclosure threshold; ordinary-course litigation only (referred to Note 16(c)).
• Non-SEC enforcement (web): The only material hits are environmental, not financial: the EPA noticed a proposed administrative penalty against IPL (Prairie Creek Generating Station) under the Clean Water Act, and there is a historic Wisconsin Power & Light EPA Consent Decree on record. Good Jobs First's Violation Tracker aggregates Alliant penalties (predominantly environmental/utility-regulatory). No FERC/NERC reliability civil penalty against Alliant surfaced in the 2024-2026 FERC penalty actions. Conclusion: no material accounting/securities enforcement; the legal/regulatory risk is ordinary environmental-compliance exposure (CCR, CSAPR, effluent rules, MGP remediation $11-34M), not malfeasance.

Net: clean books. The risk here is regulatory and policy (rate orders, IRA credits), not accounting integrity.

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Phase D — Project & stress-test

Lens 11 · Forward Projection (FY2026 → FY2028)

Built bottom-up from FY2025 actuals + management's own algorithm. Output ``; inputs labeled.

Anchors:

• FY2025 actual diluted EPS $3.14.
• FY2026 guidance $3.36–$3.46, midpoint $3.41.
• Long-term CAGR: 6%+ near-term, 7%+ for 2027-2029.
• Share count creeps ~+0.3-0.5%/yr from the ATM (funding capex) — a mild headwind already inside guidance.

Driver bridge (base): rate-base growth (+12%/yr × ~50% equity-funded at ~10% ROE) contributes the bulk; partially offset by rising interest expense (FY2025 $512M → growing as debt scales) and ~0.4% annual dilution. The single largest swing factor between base and bear is the IRA tax-credit regime — it is worth a meaningful chunk of EPS and is policy-exposed.

Per --watchlist rules, no forecast.ts create is logged in breadth mode. Suggested base forecast to log on promotion: "LNT FY2026 ongoing EPS ≥ $3.41, p≈0.62, resolves 2026-12-31."

Lens 12 · Bull vs Bear

Bull case. Alliant is a rare utility where the growth is contracted, not hoped-for: ~3.4 GW of executed hyperscaler load (QTS, Google, Meta) underwrites a 17%-raised $13.4B capital plan and ~12% rate-base growth, translating to a raised 7%+ EPS algorithm and ~6%/yr dividend growth — all inside two of the most constructive regulatory jurisdictions in the country (Iowa advance rate-making, Wisconsin unanimous settlement). The IRA tax-credit machine ($285M sold in 2025) lowers customer bills and the effective tax rate, keeping affordability — the regulator's chief concern — in check while earnings compound. An AEP-bred management team brings a proven grid/data-center playbook. You are buying a bond that grows ~7%/yr with a ~2.8% coupon, with optionality on further capital-plan raises as load materializes.

Bear case (permanent-impairment risks). (1) Financing-cost squeeze / regulatory lag. The model is structurally ~$1.3B/yr FCF-negative, funded by debt at a 59% debt-to-cap ratio and serial equity issuance. If rates stay higher-for-longer and rate cases lag the capex (the classic utility-death-by-regulatory-lag), EPS growth and the dividend both compress, and the multiple de-rates. (2) IRA tax-credit repeal. A material slice of earnings/cash is IRA-policy-dependent; "repeal, modification, or reduced funding" (explicitly flagged, including the "One Big Beautiful Bill Act") would raise the tax rate, break the credit-transfer financing, and dent affordability. (3) Data-center demand fails to materialize as contracted — overbuilt/under-utilized transmission, a hyperscaler cancellation, or behind-the-meter self-supply leaves Alliant with stranded capex and an over-promised growth slope.

Pre-mortem (18 months out, thesis broke). Most likely failure path: 10-year yields stayed elevated, the IRA credit regime was curtailed in a budget deal, interest expense (already +$23M YoY in Q1) outran rate relief, and one or two of the data-center loads slipped right by 12-24 months. The stock de-rated from ~23x to ~18x as the "7%+" algorithm was quietly cut back to "6%," and the dividend-growth rate slowed — a 20-25% drawdown without any operational disaster, purely multiple + slope.

Are multiples too high? Not egregiously — ~22-24x is the cohort norm and arguably justified for a utility with a genuinely faster, contracted growth slope. But it leaves no margin of safety: at $76.66 the stock is at the ~$76-79 consensus target, so you are underwriting flawless execution of the 7%+ algorithm to make a utility-like ~8-10% total return.

Contrarian view (what the market is refusing to see). The bull consensus treats the ~3.4 GW data-center backlog as money-good and the 7%+ algorithm as de-risked. The under-priced risk is affordability backlash + policy: as data centers push 50% peak-demand growth by 2030, residential customers and regulators may resist socializing transmission/generation costs for hyperscalers, and the IRA-credit cushion that currently keeps bills down is the very thing most exposed to Washington. The market is pricing the load and ignoring the political economy of who pays for it.

Lens 13 · Devil's Advocate (short-seller)

Dismantling the bull case.

• What structurally breaks the model: regulatory lag in a high-rate world. A utility that must spend $13.4B it doesn't have, funded by debt and equity, only works if every rate case lands on time at a fair ROE. Interest expense already rose to $142M in Q1 2026 (+19% YoY) — if rate relief lags, the spread between allowed ROE and actual cost of capital compresses, and "7%+ EPS growth" quietly becomes 4%.
• Revenue concentration shift: the growth is concentrated in a handful of hyperscalers. One customer already moved its load from WPL to IPL in Q1 2026 — proof these counterparties are mobile and opportunistic. If AI-capex sentiment cools (the most-crowded macro trade of 2025-2026), data-center build-outs slip, and Alliant's entire raised-guidance narrative is exposed as built on contracts that customers can delay.
• Why the moat is weaker than bulls think: there is nothing here WEC, Xcel, Ameren, or CMS can't also do — same monopoly, same Midwest data-center tailwind, same IRA credits. Alliant is the smallest of the cohort (~$19.7B vs Xcel's $50.5B), so it has the least balance-sheet capacity to absorb a $13.4B plan and the most equity dilution to fund it.
• Most dangerous competitor bulls underestimate: not another utility — it's behind-the-meter / co-located generation. The 10-K explicitly flags that large customers may "source behind-the-meter generation directly from third parties or…participate in co-located resource arrangements". If hyperscalers decide to self-supply (gas turbines, on-site solar+storage, even SMRs) rather than pay regulated rates, the contracted-load thesis evaporates.
• Worst capital-allocation / governance nuances: hiring the recent PSCW chair (Valcq) as a VP and importing the entire C-suite from one prior employer (AEP) are mild governance flags; the persistent non-utility losses (AEF $(48)M, incl. the Travero recycling write-down) show the diversification dabbling destroys small amounts of value.
• What must hold for today's price: ~12% rate-base growth funded without ROE erosion, IRA credits intact, ~3.4 GW load arriving roughly on schedule, and rates not spiking. Miss any one and the 7%+ slope (and the multiple) re-rates down.
• Valuation if growth disappoints 20-30%: cut the algorithm from 7% to ~4.5% and de-rate from ~23x to ~18x on FY2027 EPS of ~$3.40 → ~$61 — a ~20% downside from $76.66, with the dividend still intact (the consolation prize).
• Single permanent-impairment scenario & plausibility: an IRA-credit repeal combined with a higher-for-longer rate environment — moderately plausible (call it 15-25%) given the explicit "One Big Beautiful Bill Act" reference in the filing — would permanently lower the earnings base and the growth slope simultaneously. Not a zero.

Lens 14 · Management Questions (ordered by information value)

1. Of the ~3.4 GW of contracted data-center demand, how much has binding take-or-pay / minimum-demand protection vs. demand that the customer can delay or walk away from, and what are the termination economics?
2. What allowed ROE and equity-layer are you assuming across the $13.4B plan, and how much of the plan has pre-approved cost recovery (advance rate-making) vs. recovery still to be litigated?
3. Quantify the EPS and operating-cash-flow sensitivity to a full repeal of IRA production/investment tax credits and the loss of the credit-transfer market — how much of the 7%+ algorithm survives?
4. How do you fund the ~$1.3B/yr FCF gap across 2026-2029 — what is the planned debt/equity split, expected annual ATM issuance, and the dilution already baked into the 7%+ EPS CAGR?
5. What is your sensitivity to interest rates: for every +100 bps of sustained higher financing cost, what is the drag to the EPS algorithm given the rate-case lag?
6. With one customer already migrating load from WPL to IPL, how mobile are these hyperscaler agreements, and what stops a customer from choosing behind-the-meter or co-located self-supply instead of regulated service?
7. On affordability: as data centers drive ~50% peak-demand growth by 2030, how do you ensure residential customers don't bear stranded-cost or rate-shock risk, and how exposed is that protection to the IRA credits?
8. What capacity-accreditation assumptions from MISO underpin the resource plan, and what happens to required capex if MISO's seasonal accreditation of your new solar is lower than planned?
9. The plan adds ~1,600 MW of new gas — how do you reconcile that with decarbonization commitments, and what is the stranded-asset risk if carbon policy tightens mid-life?
10. What is the realistic timeline and probability for converting the ~$3B of DOE conditional loan-guarantee commitments into actual low-cost financing, and what is plan B if federal action withdraws them?
11. How should we think about the non-utility (AEF) segment after the Travero recycling write-down — is there a case for divesting the non-utility holdings to simplify the story and stop the persistent losses?
12. What is the expected trajectory of consolidated debt-to-cap (currently 59% vs. 65% covenant) through the peak-capex years, and at what point does credit-rating pressure (BBB+/Baa2) constrain the plan?
13. On the ~720 MW Linn County gas EGU and the 1,000 MW Iowa wind — what are the cost-overrun and interconnection-delay risks, and how much of any overrun is recoverable given the $3,020/kW cap?
14. What is the realistic upside to the $13.4B plan if the additional large-load demand you're "evaluating" converts — i.e., how much more capex/EPS slope is plausibly on the table?
15. What is the path to recovering the previously-capitalized IEEPA tariff costs, and how material is it to project economics if recovery is ultimately deemed probable?

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