Evergy

Phase A — Understand the business

Company Overview

Evergy is a regulated electric utility holding company — incorporated in Missouri in 2017 out of the 2018 merger of Great Plains Energy and Westar Energy, HQ Kansas City, MO; Nasdaq: EVRG. It sells electricity to ~1.7 million customers across Kansas and Missouri through three integrated regulated operating utilities:

• Evergy Kansas Central (Kansas; includes Kansas South sub) — the largest unit, FY2025 operating revenue $3,060.3M.
• Evergy Metro (Missouri + Kansas City metro on the Kansas side) — FY2025 op. rev. (KCP&L legacy).
• Evergy Missouri West (Missouri).

Plus equity-method transmission JVs: 13.5% of Transource (with AEP) and 50% of Prairie Wind (with AEP + Berkshire Hathaway Energy).

How it makes money: the classic regulated model — Evergy invests capital in generation, transmission and distribution ("rate base"), state regulators (KCC in Kansas, MPSC in Missouri) set rates that let it recover that capital plus an authorized return on equity of ~10.5% on a ~52% equity layer (the ROE requested in both the 2025 KCC and 2026 MPSC cases). Earnings grow by growing rate base. Fuel and purchased-power costs (~$1.4B/yr) pass through to customers via fuel-recovery mechanisms with minimal net-income impact — so the relevant top-line is "utility gross margin (non-GAAP)" of $4,111.2M in FY2025, not headline revenue.

Revenue mix by customer class (FY2025): Residential 37%, Commercial 33%, Industrial 11%, Wholesale 5%, Transmission 9%, Other 5%. Retail revenue $: Residential $2,198.6M, Commercial $1,950.5M, Industrial $649.9M.

Contract structure: historically month-to-month tariff billing. The structural change of the decade is the Large Load Power Service (LLPS) rate plans (approved KCC Nov 2025, MPSC Nov 2025) — 12-year terms for new loads >75 MW, minimum monthly bill = 80% of expected capacity demand, termination fees, and two years of collateral posted at signing. These convert data-center demand from speculative pipeline into contracted, take-or-pay-like backlog.

Supply Chain

Upstream inputs → Evergy → end customer, with named stakeholders:

Fuel/energy upstream: coal, uranium (nuclear), natural gas, plus renewable PPAs and open-market power purchases. Fuel purchase commitments $1,369.2M and power commitments $668.0M (total, multi-year). Generation fleet ~15,800 MW owned + PPA capacity, including:

• Wolf Creek nuclear (94% Evergy share; $4,444.6M plant-in-service, 1,106 MW accredited) — operated within a co-ownership structure; refueling outages every ~18 months (last Oct–Nov 2025, next spring 2027). IRA nuclear PTC eligible through 2032 — potential cash upside.
• Coal: La Cygne (100%, 1,426 MW), Iatan 1 & 2, Jeffrey Energy Center (JEC, ~92% via Kansas Central 8% hedged share noted separately).
• Gas/oil: 4,229 MW total; growing — three new plants planned (see Lens 5).

The grid: ~10,200 circuit-miles transmission; ~44,600 mi overhead + ~16,700 mi underground distribution. Operates inside the Southwest Power Pool (SPP) RTO — SPP network transmission costs ($438.0M FY2025) pass through to customers. New-generation supply chain runs through EPC contractors and turbine OEMs (CCGT turbines for the Viola/McNew plants).

Downstream / end customers (the chokepoint that flipped to a tailwind): retail residential + commercial + industrial in KS/MO. The named large-load buyers driving the thesis: Meta (data center, KC-area MO, operational 2025), Google, Panasonic ($4B De Soto, KS EV-battery plant, operational 2025), Beale Infrastructure. Single-source dependency risk is generation adequacy — SPP resource-adequacy rules force new build to serve the new load.

Competitive Advantages (moats)

A regulated electric utility's moat is a legal monopoly franchise, not product differentiation. Evergy has "all material franchise rights necessary to sell electricity within its retail service territory" — no competitor can string a parallel wire to the same homes. The durable moats:

• Regulated-monopoly franchise + rate base — captive ~1.7M customers, cost-of-service recovery. The deepest moat in the economy; the trade-off is the regulator caps the upside (ROE ~10.5%).
• Irreplaceable physical network — 10,200 mi of transmission and a generation fleet you cannot duplicate.
• Constructive (improving) regulatory mechanisms — Kansas PISA (defer 85% of depreciation + return on qualifying plant between rate cases), property-tax trackers, fuel adjustment, FERC transmission formula rates, and now Missouri SB4 (2025) allowing CWIP in rate base for new gas plants (earn a return during construction rather than waiting). These shrink regulatory lag — a real, recently-strengthened moat.
• Location moat (new): KS/MO offer cheap land, water and SPP interconnection — a genuine pull for hyperscalers. Evergy is the only game in town for that load.

Bargaining power: over residential/commercial customers, near-total (monopoly). Over the regulator, weak-to-balanced — the binding constraint. Over large-load customers, improved via LLPS collateral + minimum-bill + termination protections, which shift the demand risk onto the data center, not the ratepayer or Evergy.

Segments

Evergy formally reports as one segment ("the Evergy Companies assess financial performance and allocate resources on a consolidated basis"). The economically meaningful split is by operating utility and customer class:

By operating utility (FY2025 operating revenue):

• Evergy Kansas Central: $3,060.3M (+$53.2M YoY) — over half the consolidated $5,961.6M.
• Evergy Metro + Evergy Missouri West: the balance.

By customer class (FY2025 retail revenue + GWh):

The trend that defines the thesis: core retail revenue was flat-to-down in FY2025 (total retail −$30.9M), and industrial revenue and volume were declining (−$32.1M, −191 GWh). This is a mature, low-growth Midwest utility whose organic load was going sideways — until the data-center ESAs. The entire growth story is the bridge from this stagnant base to a 7–8% load-CAGR future. Transmission revenue (+$38.0M, to $520.6M) was the lone organic grower, driven by the Kansas Central FERC transmission formula rate.

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Phase B — Measure performance

Earnings Result (latest print + FY2025)

Q1 FY2026 (qtr ended 2026-03-31, the latest print):

• Operating revenue $1,443.7M (vs $1,374.5M; +5.0%).
• GAAP net income attributable $151.5M (vs $125.0M; +21%); diluted EPS $0.64 (vs $0.54).
• Adjusted EPS $0.69 (vs $0.55; +25%) — beat consensus ~$0.63.
• Drivers: new Kansas Central retail rates (effective Oct 2025), higher non-regulated energy-marketing revenue, higher equity AFUDC + COLI proceeds, lower tax; partly offset by higher D&A, interest, O&M.
• Adjustment: $10.3M pre-tax loss on convertible-note repurchase backed out of non-GAAP.

FY2025 (full year):

• Operating revenue $5,961.6M (+$114.3M).
• Income from operations $1,532.9M (+$64.9M); interest expense $616.3M (+$53.2M — rising-rate/issuance drag).
• GAAP net income attributable $855.6M, diluted EPS $3.66 (vs $873.5M / $3.79 — down YoY).
• Adjusted EPS $3.83 (vs $3.81) — the clean number; GAAP fell mainly on $48.7M of losses/impairments from non-regulated early-stage clean-energy investments (Evergy is exiting these).
• Utility gross margin (non-GAAP) $4,111.2M (+$114.7M), driven by +$133.7M new retail rates and +$38.0M transmission.

Balance-sheet flags: CFO $2,045.2M (vs $1,983.7M) — but capex $2,796.9M (vs $2,336.6M), so the firm is structurally FCF-negative and funds the gap with debt + equity. LT debt rose +$1,230.0M to $13,439.7M; cash on hand just $19.8M (runs on commercial paper + a $1.1B-available master credit facility). Capital structure 43% equity / 57% debt. Goodwill $2,336.6M (merger), tested, no impairment.

Guidance & market reaction: FY2026 adjusted-EPS guidance $4.14–$4.34 (mid $4.24) reaffirmed; tone upgraded — long-term growth target raised to 6–8%+ through 2030, >8% 2028–2030. Stock has responded: +14.7% YTD, +63.5% 5-yr TSR as of June 2026.

Earnings Calls (sentiment trend)

No transcripts on the research-layer shelf — our model saved none; sentiment is -sourced from Q1-FY2026 (May 2026) and Q4-FY2025 (Feb 2026) calls.

The tone has shifted decisively from "steady regulated utility" to "transformative demand growth" over the last 4–6 quarters. On the Q1-FY2026 call, CEO David Campbell framed the growth opportunity as extending "well into the 2030s," reported a fifth large-load ESA signed + two amended bringing the LLPS portfolio to ~2.5 GW steady-state (~3.0 GW including non-LLPS), flagged >10 GW of additional pipeline, and said ≥1 more ESA in 2026 would be upside to the plan. Recurring phrases now: "data center," "load growth," "6–8%+ EPS growth," "affordability safeguards." What management has stopped emphasizing: the old renewable-transition "Sustainability Transformation Plan" narrative — the story is now gas + grid + load, an "all-of-the-above" pivot. Caveat for calibration: management's tone is structurally promotional here because the entire equity story now depends on the market believing the pipeline converts.

Comps

Regulated electric peers (same SPP/Midwest regulated profile; pulled from sector context). Multiples are with date or n/a.

5-yr avg ROE: n/a precisely; note authorized ROE ~10.5% and FY2025 implied ROE ~ mid-single-to-double digits on a ~$2.0B common-equity base is not cleanly derivable from the shelf without the equity balance — n/a.

Read: EVRG forward P/E ~21.6x sits roughly in line with the US electric-utility average (~21.9x) but above a tighter regulated-peer average (~17.6x) cited by one source — the sources conflict on the peer set, so I surface both rather than pick. The honest synthesis: Evergy trades at a premium to its own pre-data-center history and at a growth-utility multiple, justified only if the 6–8%+ growth actually lands. EV/EBITDA ~12.1x is full for a regulated name.

Stock-Price Catalysts (>5% moves, ~5yr)

Pattern of what moves EVRG:

• 2020–21 — activist catalysts. Elliott Management (~10M-share economic interest) and Bluescape Energy Partners forced a strategic review; the resulting "Sustainability Transformation Plan" and board seats (C. John Wilder, Bluescape exec chairman) reset the capex/growth posture. This is the origin of today's growth narrative.
• 2024 — Panasonic + Meta confirmations + capex plan up. Disclosure of named hyperscaler/industrial load and a 24% capex-plan jump to $21.6B re-rated the stock toward a growth-utility multiple.
• Feb 2026 — four ESAs (Google/Meta/Beale), ~1,900 MW. Subsequent-event disclosure in the 10-KForm 10-KA company’s audited annual report to the US regulator. The most complete thing it publishes..
• Q1-FY2026 (May 2026) — guidance raise to 6–8%+, fifth ESA, >10 GW pipeline.
• Recurring sensitivities: rate-case outcomes (KCC/MPSC), interest rates (a bond-proxy: ~$616M interest expense and rising), and the data-center pipeline cadence. Macro rate moves and rate-case headlines move it as much as earnings.

The tape says the market reacts to (1) data-center load announcements and (2) the EPS-growth-rate guidance, far more than to in-line quarterly prints — classic for a re-rating story.

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Phase C — Judge people & books

Management

CEO: David A. Campbell (President & CEO since Jan 2021; Chairman since May 2024).

1. Track record: ex-McKinsey partner → TXU (CFO during the 2004–07 turnaround that topped the S&P 500 Utilities Index) → CEO of Luminant (largest TX generator; top-decile capacity factors) → COO of Bluescape Resources (2013–14; negotiated the EME/Edison settlement) → CEO of InfraREIT (led its 2015 IPO and 2019 sale to Oncor). A genuinely heavyweight, deal-and-turnaround operator — unusual pedigree for a Midwest regulated utility. Note the Bluescape link — Campbell ran Bluescape before the same firm took an activist stake in Evergy; relevant to governance, see Lens 10/13.
2. Tenure & skin in the game: ~5 yrs as CEO. Insider ownership <1% (~71,904 shares, ~$5M) — typical-low for a utility CEO; alignment is via comp, not ownership.
3. Capital allocation: the defining act is the escalating capex program ($8.9B STP → $11.6B → $17.5B → now $21.6B through 2030), funding a 6–8%+ EPS-growth target via rate base. Dividend payout targeted 50–60% but currently running ~73% ($2.78 annualized / $3.83 adj-EPS) — high, constrains dividend growth until EPS catches up. Repurchasing convertible notes ($308.6M cost for $244.1M principal in early 2026) — deleveraging the dilutive converts.
4. Red flags: the Bluescape affiliation (FERC ruled Evergy and Bluescape affiliated) and consumer-advocate concern that hedge-fund influence drives capex/rate hikes. Comp ~$7.3M FY24 (~50x median employee) — middling for size.
5. Archetype: professional manager / financial operator, not founder — appropriate for a capital-intensive regulated re-rating; the risk is a financially-driven team over-building rate base faster than regulators/ratepayers tolerate.

CFO: Bryan Buckler (since Oct 2024; ex-OGE Energy CFO, ex-Duke IR/FP&A) — credible utility-finance background.

Forensic Red Flags

Accounting: clean for a regulated utility — the quality issues are structural, not manipulative.

• Regulated accounting / regulatory assets & liabilities: large balances by design; the risk is non-recovery if a regulator disallows costs — surfaced and probable-of-recovery per management. Watch the growing fuel under-collection regulatory asset (+$41.2M Missouri West).
• Cash flow vs earnings: CFO $2,045.2M vs $855.6M GAAP net income — healthy non-cash D&A coverage, no earnings-quality red flag, but FCF is deeply negative (capex $2.8B; plan $3.8–4.8B/yr) — the entire growth model rests on continuous access to debt + $3.3B planned equity 2026–2030. DilutionDilutionIssuing new shares, so each existing share owns a smaller slice of the same company. and rate-base recovery are the real risks, not accounting.
• Goodwill $2,336.6M (merger), one reporting unit, fair value "substantially exceeded" carrying — fine while the growth story holds; a thesis-break could pressure it.
• AROs $1,342.3M (Wolf Creek nuclear, ash ponds, wind) — long-dated, regulator-deferred.
• Non-GAAP hygiene: adjustments are modest and reasonable (early-stage-investment losses, JEC mark-to-market, note-repurchase loss) — not a flatter-the-number machine.
• Convertible notes: $1,155.9M of 4.50% converts remain after early-2026 repurchases — a known dilution overhang management is actively reducing.

Regulatory findings (required sub-section):

• SEC Litigation Releases / AAERs: None. 0 LR and 0 AAER naming Evergy in the 2021-06-30 → 2026-06-30 window per SEC EDGAR EFTS.
• 10-K Item 3 (Legal Proceedings): "parties to various lawsuits and regulatory proceedings in the ordinary course… for material lawsuits and proceedings, see Notes 4 and 15" — no standalone material litigation flagged; incorporated by reference to routine regulatory + environmental notes. Specific live item: Kansas Sky solar is under litigation (Grant Township et al. v. Board of County Commissioners) with a Dec 2024 injunction temporarily halting construction — a project-level, not enterprise, risk.
• Non-SEC enforcement (web search): no material FTC/DOJ/FDA/CFPB enforcement found. The live regulatory friction is consumer-advocate / ratepayer pushback — Kansas CURB and the Kansas Reflector report residential base rates rising ~9.6% (+~$8.47/mo for an average 900-kWh user) and ~8.6% bill increases to fund the new plants, with KCC publicly questioning Evergy on rate increases vs. Panasonic revenue. Not an "enforcement action," but the central political-economy risk.
• Conclusion: No material regulatory or accounting enforcement findings — verified via SEC EDGAR EFTS (LR, AAER), web search, and 10-K Item 3 as of 2026-06-30. The real risk is rate-case disallowance and affordability backlash, not fraud.

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Phase D — Project & stress-test

Forward Projection (FY2026–FY2028 EPS)

Built bottom-up from FY2025 actual adjusted EPS $3.83 and management's 6–8%+ framework.

Inputs (all labeled):

• Rate-base growth: $21.6B capex 2026–2030 vs ~$2.8B/yr historical — a ~24% step-up; PISA + SB4 CWIP shrink lag.
• Load: 3–4% in 2026, ramping to ~7–8% CAGR through 2030 as ESAs energize.
• Offsets: rising interest expense (~$616M and growing on $12.3B planned issuance), $3.3B equity issuance → share-count dilution, convertible-note dilution.

Consensus corroborates the base: FY2026 ~$4.33, FY2027 ~$4.64 — slightly above my base FY26 (I anchor to mgmt's $4.24 mid). All outputs; arithmetic shown.

Forecast log skipped — --watchlist loop does not commit a Brier forecast (per SKILL). Base case to log if promoted: "EVRG FY2027 non-GAAP EPS >= $4.55", resolves 2027-12-31.

Bull vs Bear

Bull case. Evergy is the rare regulated utility with a genuine secular growth driver: contracted data-center + industrial load ($8.7B in minimum contractual obligations already on the books, 10–17 yr terms, collateralized), in a region (KS/MO) hyperscalers actually want for land/water/SPP access. LLPS protections shift demand risk onto the customer. The $21.6B capex plan compounds rate base at a step-change rate, PISA + Missouri SB4 CWIP minimize regulatory lag, and management guides 6–8%+ EPS growth (>8% 2028–30) — top-quartile for a wires-and-poles utility. A heavyweight, deal-savvy CEO. Pipeline >10 GW means years of upside revisions. A bond-proxy that also grows earnings is a scarce asset if rates fall.

Bear case. Three permanent-impairment vectors: (1) Regulatory/affordability ceiling — residential bills are already rising ~9.6%, regulators are publicly skeptical, and a populist disallowance or a cap on large-load cost-shifting could strand capex returns; the moat is the regulator, and the regulator is getting pressure. (2) Financing risk — deeply FCF-negative, $12.3B debt + $3.3B equity to raise into 2030; if rates stay high or the equity comes at a depressed price, dilution eats the EPS growth. (3) Demand-conversion risk — the pipeline is signed ESAs to begin 2026–2028; if a hyperscaler delays/cancels (AI-capex digestion), the rate-base build outruns the load. Pre-mortem (18 months out, thesis broke): a 2027 Missouri rate case lands below ask, one large ESA slips, and the stock de-rates from ~21.6x to a ~17x regulated multiple — a ~20% derating even with EPS intact. Multiples too high? Yes vs. its own history and vs. a strict regulated-peer ~17.6x; defensible only on the growth rate landing. Contrarian view the market refuses to see: the data-center load is real and contracted (bears who say "vaporware" are wrong — see the $8.7B), but it is also already in the multiple — the surprise risk is asymmetric to the downside (regulatory/affordability) because the upside (pipeline) is consensus.

Devil's Advocate (short-seller)

What structurally breaks the money machine: the regulator turns. Evergy earns by convincing KCC/MPSC to let it recover an ever-larger rate base at ~10.5% ROE. Bills are climbing ~9–10%, consumer advocates (CURB) are organized, and there is a live narrative that ratepayers are subsidizing infrastructure for trillion-dollar tech firms — KCC already grilled Evergy on Panasonic economics. A single adverse rate order, an ROE cut, or a legislated affordability cap permanently lowers the earnings power of the whole $21.6B plan.

Revenue concentration shift: the growth is concentrating in a handful of hyperscaler ESAs. If Meta/Google digest AI capex and push out 1–2 GW (the same firms slashing elsewhere), Evergy is left with built/committed generation and a load that didn't show — exactly when SB4 CWIP has it earning on plants under construction (subject to refund). Moat weaker than bulls think? The franchise is bulletproof; the return on it is entirely regulator-granted and now politically contested. Most dangerous competitor bulls underestimate: not a competitor — it's behind-the-meter / co-located generation: if hyperscalers build their own gas/SMR power (the emerging pattern), the load bypasses Evergy's rate base entirely. Worst capital-allocation/governance: the Bluescape affiliation — a CEO who ran the activist firm now running the company it pressured, building the capex the activist wanted, while ratepayers foot the bill (FERC found them affiliated). Assumptions that must hold for ~$82: 6–8%+ EPS growth lands, equity raised near current price, no adverse rate order. If growth disappoints 20–30% (say 5% instead of 7%), the 21.6x multiple is unjustified → re-rate to ~17x → ~20–25% downside. Single permanent-impairment scenario: a populist Kansas/Missouri rate rollback + a large-load cost-allocation reversal — moderate-but-rising probability given the affordability politics.

Management Questions (ordered by information value)

1. Of the ~3.0 GW of signed ESAs, what is the firm, take-or-pay-protected MW that bills even if the data center never energizes — and what is the worst-case revenue if every transitional-load customer walks at the end of the 5-year ramp?
2. In the next Missouri (2026) and Kansas rate cases, what authorized ROE and equity ratio are you underwriting the $21.6B plan against — and what's the EPS sensitivity to a 50 bp ROE cut?
3. How much of the $21.6B capex is committed/irreversible vs. cancellable if the data-center pipeline slips, and what's the decommit cost?
4. With the dividend payout at ~73% vs. a 50–60% target, when do you expect to be back in range, and is dividend growth frozen until then?
5. What share count and price are you assuming for the $3.3B equity issuance through 2030, and how much EPS dilution is embedded in the 6–8%+ guide?
6. How are you defending against behind-the-meter / co-located generation — what stops Meta or Google from self-supplying and bypassing rate base?
7. On affordability: what is your modeled residential bill CAGR through 2030, and at what point does ratepayer/political backlash become a binding constraint on the capex plan?
8. How do you quantify and allocate the cost-shift protection for existing customers under LLPS — and can a regulator reopen it?
9. What is the monetization plan and cash value of the Wolf Creek nuclear PTC, and how much flows to customers vs. shareholders?
10. The >10 GW pipeline beyond the 3.0 GW signed — what conversion rate are you actually planning around, and what's the gating step?
11. How exposed is the gas-build (Viola/McNew CCGTs, ~$1.7B combined) to turbine supply-chain lead times and cost inflation, and are those costs pre-approved for recovery?
12. What's the plan for the remaining $1,155.9M of 4.50% convertible notes — full repurchase, or accept the dilution?
13. Given the Bluescape affiliation and FERC's ruling, how is the board ensuring capex serves ratepayers, not just shareholder/activist returns?
14. What's the contingency if SPP resource-adequacy rules force generation build faster than rate recovery is granted?
15. Where do you see emissions-reduction timing now that the strategy has pivoted to "all-of-the-above" gas — and what's the stranded-asset risk on new gas if carbon policy tightens?

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