$VST

@jasonl_capitalMay 22, 2026 · 12:41 PM

5. $VST - Vistra Nuclear and natural gas power across the country. Three 20-year PPAs with Meta across its nuclear fleet. Acquiring 5,500 MW of natural gas capacity through Cogentrix for $4.7B to bridge the gap while new nuclear comes online. 2026 EBITDA guidance: $6.8B-$7.6B. https://t.co/TFQHd54dzU

@mrmikeinvestingMay 18, 2026 · 10:32 PM

The $NVDA CEO, Jensen Huang just revealed the full 5 layer stack the AI super cycle is built upon… These 5 layers include: 1. Energy ~ $CEG, $VST, $OKLO, $EOSE, $GEV 2. Chips & Computing ~ $NVDA, $AMD, $TSM, $MU, $ARM 3. Cloud & Data Centers ~ $NBIS, $IREN, $CRWV, $APLD, $CIFR 4. AI Models ~ $MSFT, $GOOGL, $META, $AMZN, $ORCL 5. Applications ~ $PLTR, $TSLA, $NOW, $SNOW, $CRM Without these companies there is no AI; which is exactly why these names will continue to see massive long term growth. Save this for later…

@thevalueistMay 13, 2026 · 5:40 PM

I agree with this and the merchant names have still traded awfully this year. I’m long $CEG $VST $TLN and will continue to hold, not add, for the time being.

@investmentguru_May 11, 2026 · 2:39 AM

AI IS THE MEGA-DRIVER → 1 ChatGPT query ≈ 10× the electricity of a Google search → Hyperscalers have announced nuclear PPAs exceeding 10GW since 2023 → The wave thesis plays out in layers: W1 → Semiconductors ($NVDA $AMD) — well known ✅ W2 → Memory ($MU $SNDK) — catching up ✅ W3 → Photonics ($COHR $AAOI $FN $CRDO) — mid-innings 🔄 W4 → ⚡ Energy ($CEG $VST $OKLO $ETN $GEV) — early innings. We are HERE 🎯 W5 → Robotics/Physical AI — next wave 🔜

@investmentguru_May 10, 2026 · 1:00 PM

The market is up. Oil is at $100+. Inflation is sticky. And bonds are whispering something equities are ignoring. Here’s what’s actually going on- OIL SHOCK REALITY ➜ Geopolitical tension pushed oil sharply higher earlier this cycle ➜ Supply risk around key shipping routes tightened sentiment ➜ Energy inflation became a second-wave macro driver This is not a clean disinflation environment anymore. WHY EQUITIES ARE STILL RISING ➜ Index strength is narrow, not broad ➜ AI capital expenditure is doing the heavy lifting ➜ Hyperscalers are still committing massive spend into 2026 ➜ Earnings growth is increasingly concentrated in AI-linked infrastructure In simple terms: It’s not “the market.” It’s a handful of mega themes. INFLATION IS NOT FULLY DEAD ➜ CPI has re-accelerated from early-year lows ➜ Producer pricing pressure remains elevated ➜ Services inflation is sticky ➜ Energy volatility keeps headline risk alive The “easy disinflation” phase is likely behind us. WHAT BONDS ARE REALLY SAYING ➜ 10Y yield ~4.4% | 2Y ~3.9% | 30Y ~5% ➜ Yield curve is positively sloped again But here’s the nuance: ➜ The curve was inverted for an extended period (2022–2024) ➜ Historically, recessions often follow 1–6 months after un-inversion ➜ We are now inside that window ➜ Credit spreads remain tight → complacency in risk pricing Translation: Bonds are not confirming the equity narrative. THE MESSAGE FROM CREDIT MARKETS ➜ Growth expectations exist ➜ But compensation for risk is historically low ➜ The system is not pricing stress properly That gap is where volatility usually forms. BASE CASE OUTLOOK ➜ Inflation remains sticky in H1, moderates in H2 if energy stabilizes ➜ Rates stay “higher for longer” ➜ Volatility increases around macro data shocks ➜ Returns become more sector-specific, less index-driven WHERE PERFORMANCE IS STILL WORKING The names that work in this environment: ➜ AI infrastructure ($PLTR, $NVDA, $CRDO, $MRVL) ➜ Data center power ($GEV, $ETN, $VST, $CEG) ➜ Photonics & optical networking ($COHR, $FN, $AAOI) ➜ Energy itself ($CCJ, $OKLO, $SMR) This isn’t a “buy everything” rally. It’s a precision rally in a minefield. Know what you own and why. FINAL THOUGHT Equities are pricing stability. Bonds are pricing uncertainty. When those diverge this far — one side eventually adjusts. Not financial advice. DYOR.

@investmentguru_May 10, 2026 · 12:16 PM

EVERY BUCK STOPS AT ENERGY — The Bottleneck Nobody Talks About Enough. The real constraint on AI isn’t chips. It isn’t bandwidth. It isn’t capital. It’s electrons. Here’s the full breakdown NUCLEAR — The Baseload Beast → Only energy source delivering 24/7 carbon-free power at hyperscaler scale → Microsoft, Google, Amazon signing direct nuclear PPAs — unprecedented → Legacy fleet life extensions: cheapest, fastest path to zero-carbon baseload → SMR wave building: factory-built, faster deploy, co-locatable with data centers → Uranium supply chain revival underway — enrichment is the chokepoint Tickers: $CEG $VST $OKLO $SMR $CCJ $LEU $LTBR GRID — The Invisible Backbone → US grid built in the 1950s–70s. Not designed for 300MW data center campuses → 2,600 GW stuck in interconnection queues — more than entire installed US capacity → Large power transformers: 2–3 year lead times, barely made domestically → FERC Order 1920 mandated long-term transmission planning for first time ever → Grid hardware demand is a decade-long supercycle, not a trade Tickers: $ETN $GEV $PWR SOLAR — The Cost Curve Winner → ~99% cost decline since 1976 — cheapest new electricity in history → Constraint has shifted: no longer cost, it’s permitting + interconnection + storage → Solar + BESS is now the standard utility build → IRA credits extending economics through the 2030s → $FSLR only major US-based module manufacturer — direct IRA beneficiary Tickers: $FSLR $ENPH $ARRY $TE BATTERY STORAGE — The Enabler Layer → Renewables without storage are weather-dependent. Storage makes them dispatchable → LFP BESS: $1,200/kWh (2010) → ~$100/kWh (2024) → ~$60/kWh projected (2030) → 4-hour duration now standard. Long-duration (100hr+) is the unsolved problem → Iron-air, flow batteries, green hydrogen all competing for the long-duration crown → V2G sleeper thesis: 300M EVs by 2035 = massive distributed grid storage network $FLNC $EOSE $QS $BE RENEWABLES — Wind, Hydro & Geothermal → Offshore wind: world-class US East Coast resource, but capex + financing challenged → Pumped hydro still 95% of ALL global grid storage — massively underappreciated → Enhanced Geothermal Systems (EGS): Fervo Energy proved commercial scale — dark horse → Geothermal = 24/7 baseload, zero emissions, geography no longer a hard limit $PLUG AI IS THE MEGA-DRIVER → 1 ChatGPT query ≈ 10× the electricity of a Google search → Hyperscalers have announced nuclear PPAs exceeding 10GW since 2023 → The wave thesis plays out in layers: W1 → Semiconductors ($NVDA $AMD) — well known ✅ W2 → Memory ($MU $SNDK) — catching up ✅ W3 → Photonics ($COHR $AAOI $FN $CRDO) — mid-innings 🔄 W4 → ⚡ Energy ($CEG $VST $OKLO $ETN $GEV) — early innings. We are HERE 🎯 W5 → Robotics/Physical AI — next wave 🔜 RISKS TO WATCH → IRA rollback attempts — policy is the #1 overhang → Permitting timelines remain brutal (10–15 years for transmission lines) → Nuclear cost overruns — historical pattern, balance sheet quality matters → Rate sensitivity — these are long-cycle capex-heavy businesses → Supply chain concentration (China dominates solar, battery manufacturing) Not financial advice.

@investmentguru_May 10, 2026 · 11:26 AM

The Complete Data Center Stack: Where the AI Infrastructure Money Flows Most investors still think AI is just about GPUs. That’s incomplete. AI is an infrastructure buildout, and the real opportunity spans the entire data center stack. Every inference, every training run, and every deployed model depends on multiple layers working together. Here’s the breakdown: 1. Compute Silicon (The Brain) Tickers: $NVDA, $AMD, $AVGO, $INTC This is the foundation. GPUs, CPUs, accelerators, and custom silicon power training and inference. Why it matters: - Compute demand keeps rising with larger models - AI workloads are forcing faster chip innovation - Custom ASICs are becoming a major trend 2. Server OEMs & Solutions (The Hardware Layer) Tickers: $SMCI, $DELL, $HPE, $VRT, $ETN, $MOD Chips need systems. These companies assemble and deliver the physical AI servers and power systems. Why it matters: - AI racks are denser and hotter - Power distribution is now critical - Cooling is becoming a competitive advantage 3. Memory & Storage (The Hidden Bottleneck) Tickers: $SNDK, SK Hynix, $MU, $WDC, $P, Samsung, $NTAP AI models consume massive amounts of memory bandwidth and storage. Why it matters: - High-bandwidth memory is becoming strategic infrastructure - Data storage demand rises with AI deployment - Faster access = better model performance 4. Networking & Connectivity (The Nervous System) Tickers: $ANET, $CSCO, $MRVL, $CRDO, $CIEN, $NOK AI clusters must communicate at ultra-high speed. Why it matters: - Faster networking reduces latency - Data movement is becoming expensive - Scale depends on interconnect efficiency Key idea: AI cannot scale without bandwidth. 5. Neoclouds & Physical Infrastructure (The New Builders) Tickers: $NBIS, $IREN, $CRWV, $APLD $CIFR $DGXX These companies provide specialized AI infrastructure and hosting. Why it matters: - Cloud alternatives are growing - AI-native infrastructure is becoming valuable - Capacity shortages create pricing power 6. Energy (The Ultimate Constraint) Tickers: $CEG, $NEE, $EOSE, $GEV, $EQT, $VST $OKLO $BE $FLNC AI consumes enormous electricity. Power availability is becoming a limiting factor. Why it matters: - Grid demand is surging - Battery storage is essential - Reliable baseload power matters Final Thought The market often focuses on one winner. But AI infrastructure is an ecosystem. If you want to understand where capital flows next, follow the stack: Compute → Servers → Memory → Networking → Infrastructure → Energy The biggest winners in the AI cycle may not always be the obvious names. Sometimes the best opportunities are in the supporting layers that make the whole system possible.

@investmentguru_May 9, 2026 · 8:14 PM

Watch: $CEG · $OKLO · $SMR · $TLN · $VST · $BWXT · $GEV

@investmentguru_May 9, 2026 · 5:16 PM

NUCLEAR / SMRs: The Long-Term Power Trade for AI AI needs one thing more than chips: Reliable power. Hyperscalers are now locking 10–20 year nuclear deals to secure dedicated energy for data centers. Why? → 24/7 baseload power → Zero carbon → Scalable for massive AI demand SMRs could be the next big infrastructure wave as AI power demand accelerates. Watch: $CEG · $OKLO · $SMR · $TLN · $VST · $BWXT · $GEV The AI race isn’t just compute. It’s power security.

@investmentguru_May 4, 2026 · 11:18 AM

Earnings watchlist for the week: 𝗠𝗼𝗻𝗱𝗮𝘆 After Hours: $PLTR $FN $BWXT $AEIS $FLY $ADEA $ON 𝗧𝘂𝗲𝘀𝗱𝗮𝘆 Pre-Market: $SHOP $PYPL $ENLT $ETN After Hours: $AMD $ANET $LITE $ALAB $NVTS $NRGV $SU $WOLF 𝗪𝗲𝗱𝗻𝗲𝘀𝗱𝗮𝘆 Pre-Market: $UBER $FLEX $SOLS $NRG $HUT After Hours: $ARM $COHR $UUUU $FSLY $SEZL $AOSL $APP $IONQ $SNAP 𝗧𝗵𝘂𝗿𝘀𝗱𝗮𝘆 Pre-Market: $DAVE $HWM $VST $DDOG $BSKY After Hours: $NET $CRWV $RKLB $IREN $LASR $PDFS $OPEN 𝗙𝗿𝗶𝗱𝗮𝘆 Pre-Market: $WULF $UI

@mrmikeinvestingApr 30, 2026 · 11:18 PM

The White House is quite literally telling you to buy rare earth stocks… Last time this happened was with $INTC in August 25’ which was trading at $18, & is now $95+ US Government has taken heavy positions into $MP & $USAR which are ready to rocket 40/50%+ higher. Even Nancy Pelosi is buying $VST…

@investmentguru_Apr 26, 2026 · 1:19 PM

The AI Power Crisis Is Becoming the Trade of the Decade The narrative has shifted. It’s no longer about chips — it’s about electricity. Morgan Stanley estimates a 126 GW surge in global data center demand by 2028, with a ~49 GW shortfall in the U.S. alone. In Virginia, interconnection queues already exceed 5 years. And a new trend is emerging: Nearly 30% of new data center capacity by 2026 will be built off-grid — up from almost zero a year ago. The constraint is no longer silicon. It’s watts. Here’s how the entire power stack is shaping up: POWER GENERATION (Where electrons come from) $CEG — The nuclear anchor. Long-duration contracts with hyperscalers like Microsoft and Meta. Real, scaled nuclear exposure. $VST — High-growth merchant power mix (gas + nuclear + renewables). Strong earnings leverage to demand spikes. $TLN — Direct hyperscaler power supply agreements (AWS-linked data center buildouts). $NEE — Renewable giant with long-term contracted megadeals (including multi-GW deals with Big Tech). POWER INFRASTRUCTURE (Grid to chip) $GEV — The backbone play. Gas turbines today, SMR optionality tomorrow. Massive backlog growth driven by AI demand. $ETN — Power architecture leader. 800V DC systems + liquid cooling integration after major acquisitions. $NVT — Smaller, faster-growing power distribution player riding high-density AI load demand. THERMAL MANAGEMENT (Cooling the AI explosion) $VRT — Critical bottleneck winner. AI racks now pushing 10x+ power density vs 2023. Record backlog driven by hyperscalers. $SBGSY — Global industrial rival in the same cooling + infrastructure race. NEXT-GEN NUCLEAR (Long-duration optionality) $GEV — SMR development optionality alongside current cash flows $BWXT — Nuclear components + defense + SMR supply chain exposure $OKLO — High-risk, long-duration microreactor bet $NNE — Pure speculative nuclear startup exposure OFF-GRID / BEHIND-THE-METER (Bypassing the grid) $BE — Fuel cells powering on-site AI clusters $FCEL — Early-stage distributed energy systems • Microgrid and on-site generation adoption accelerating as grid queues stretch beyond 5–7 years THE BIG PICTURE Power is now the bottleneck of AI expansion. Not GPUs. Not software. Not demand. But electrons delivered at scale, on time, and on-site. Estimates suggest power constraints alone could unlock hundreds of billions in value redistribution across the energy and infrastructure stack. The AI trade is no longer just compute. It’s: 👉 Power generation 👉 Grid infrastructure 👉 Cooling systems 👉 On-site energy independence Final thought: Everyone sees the AI chip cycle. Few are pricing in the energy system rebuild underneath it. That’s where the next 3–5 year compounding likely sits. Not financial advice.

@investmentguru_Apr 25, 2026 · 11:41 AM

The AI Infrastructure Bottleneck AI demand isn’t slowing. It’s colliding with reality. Power costs are rising. Communities are pushing back. Permits are getting harder. Project cancellations are climbing. This isn’t weak AI demand. This is infrastructure hitting its ceiling. Compute scaled in 18 months what normally takes a decade. Data centers went from background infrastructure to the most power-hungry real estate on earth — almost overnight. Utilities weren’t ready. Grids weren’t ready. Permitting systems built for a slower world weren’t ready. So now you have the most capital-rich companies in history competing for a fixed, constrained resource: Megawatts. That collision created a new capital cycle: AI → Energy → Infrastructure The market hasn’t fully priced the downstream implications yet. When datacenter capacity gets delayed or cancelled, the reflex is to ask: “Is AI demand softening?” Wrong question. The right question is: “Who benefits when supply tightens?” Less derisked capacity doesn’t reduce demand. It concentrates it. And concentrated demand is a pricing event. When power supply tightens: → Frontier labs fight for compute at premium pricing → Hyperscalers delay expansion timelines, reshuffling capex → Chip, memory, ASIC, and CPU ecosystems feel the ripple — not because demand died, but because deployment slowed → Whoever controls reliable, permitted, grid-connected power becomes the most valuable asset in the AI stack This is the Silicon-to-Substation Shift. Just like bandwidth defined the internet era — whoever controlled the pipes controlled the economy — reliable power generation is becoming the defining constraint of the AI economy. The bottleneck has moved up the stack. The market always chases the obvious trade first. $NVDA. $AMD. Memory. Networking. The picks and shovels everyone already knows. But when the bottleneck shifts — the alpha moves too. Right now, the bottleneck isn’t silicon. It’s megawatts, transformers, transmission lines, and building permits. The second-order trade is where the real opportunity lives — across five infrastructure layers most investors haven’t rotated into yet: Power Generation Nuclear is back. Natural gas is back. Utilities signing 20-year offtake agreements with hyperscalers. The cleanest, most reliable, 24/7 baseload power is suddenly the scarcest commodity in tech. $VST → baseload + nuclear, direct hyperscaler relationships $CEG → largest nuclear operator in the US, massive AI offtake pipeline $SMR / $OKLO → next-gen modular nuclear, secular long-term positioning Grid Infrastructure Transformers. Substations. Transmission lines. The hardware between the power plant and the server rack is now a national bottleneck — with multi-year lead times. $PWR → grid construction & transmission at scale $ETN → electrical components backbone, transformer exposure, margin expansion Energy Storage Intermittent renewables can’t power AI campuses alone. Grid-scale battery storage and microgrid systems bridge the gap — especially as utilities demand more dispatchable flexibility before approving new load connections. $FLNC → utility-scale storage, growing backlog, grid stabilization play Cooling Infrastructure A 100MW AI cluster generates extraordinary heat density. Air cooling is dead at scale. Liquid cooling, immersion systems, and thermal management are now standard spec in every new hyperscale build — one of the most underappreciated sub-themes in the entire stack. Datacenter Construction & Power Systems Before a single GPU goes online — somebody pours the concrete, runs the conduit, installs the switchgear, and commissions the facility. Construction and power systems backlogs are extending years out. $STRL → datacenter construction, revenue inflecting hard $BW → industrial power systems, 1.2GW AI datacenter deployment The thesis is simple: AI isn’t running out of demand. It’s running into megawatts. Not financial advice.

@investmentguru_Apr 23, 2026 · 10:18 AM

THE ENERGY MAP: Every Source, Every Play Global energy investment just crossed $3.3T in 2025 — with $2.2T flowing into clean tech alone, 2× fossil fuels. The AI data center supercycle has changed everything. Power is now the bottleneck. Access to electricity > land, labor, connectivity. Here’s how the landscape is shaping up NUCLEAR — Highest Conviction The renaissance is real. Record generation, 63 reactors under construction, SMRs gaining traction with hyperscaler demand. → AI + baseload = nuclear wins Plays: $CEG $CCJ $OKLO $SMR $NNE $LEU $DNN $LTBR BATTERY STORAGE — High Conviction The backbone of 24/7 clean energy. Explosive growth + massive pipeline into 2030. → Solar pairing + grid stability + data center demand Plays: $TSLA $FLNC $STEM $AMPS $KULR $QS $MVST $AMPX GRID INFRASTRUCTURE — The Real Winner - No matter who wins, the grid must scale. Massive capex cycle just starting. → AI load + EVs + electrification = multi-year demand Plays: $CEG $NEE $ETN $PWR $VRT $HUBB $VST $AES SOLAR — Selective Still scaling globally, but policy shifts create winners & losers. → Data center PPAs absorbing higher costs Plays: $FSLR $ARRY $ENPH $NEE $RUN GEOTHERMAL — Stealth Play Underrated baseload. EGS unlocking new regions. → 24/7 clean energy = perfect for hyperscalers Plays: $CEG $ORKA $NEE NAT GAS / LNG — Bridge Fuel Not going anywhere. Reliability matters. → AI demand + LNG exports = strong tailwind Plays: $LNG $AR $EQT $SLB $HAL WIND — Watchlist Onshore steady, offshore challenged (policy + cost). → Europe still bullish Plays: $GEV $NEE $CWEN $BEP HYDROGEN — Speculative High risk, long-term potential. 2026 is pivotal. → Industrial demand is the key Plays: $PLUG $BE $LIN HYDRO — Stable Compounder Reliable baseload + long-duration storage. → Quiet outperformer in volatile markets Plays: $BEP $CWEN $NEP THE MACRO FRAME This is no longer just a climate transition. It’s a national security + AI infrastructure race. Capital flow trend: Semis → Memory → Photonics → Power & Energy → Robotics We are entering the Power wave Position accordingly. The grid wins regardless. Not financial advice. Like and share

@thevalueistApr 16, 2026 · 3:10 PM

$CEG $VST $TLN $NRG ERCOT’s Load Filing Signals a New AI Power Regime in Texas, Not a Literal 367.8 GW Outcome https://t.co/a8xjftaRsP Bottom Line: ERCOT’s 367,790 MW 2032 headline should be read as the top of a conversion funnel, not as a bankable operating forecast. The right underwriting ladder runs from submitted MW, to filtered and financeable MW, to energizable MW, to realized coincident peak demand. ERCOT’s own materials already show that compression in 2026, where the 112,371 MW planning headline sits well above the roughly 90,500 MW to 98,000 MW expected summer range. The durable investment message is still highly constructive: Texas has entered a regime in which AI and data-center demand is large enough to reshape dispatchable power values, transmission planning, interconnection rules, and commercial contracting structures. That framing favors owners of credible gas, nuclear, powered-land, and customer-facing commercial platforms, especially where firm capacity and deliverability matter more than generic energy volume or speculative queue rhetoric.

@investmentguru_Apr 14, 2026 · 12:27 AM

Most investors are always chasing the last wave. The AI infrastructure cycle is playing out in layers — and each one is bigger than the last. Here’s the full roadmap: Wave 1: Semiconductors ✅ (Priced In) $NVDA. $AMD. $AVGO. The GPU arms race. Everyone knows this trade. Raw compute was the foundation. Most of the upside? Already captured. Wave 2: Memory & Storage ✅ (Confirming) More data. More inference. More throughput. Flash, DRAM, HBM all followed. $SNDK ’s recent move is the latest confirmation. The storage bottleneck is real — and the market is finally catching up. Wave 3: Photonics & Optical Networking 👀 (In Motion NOW) This is what most retail investors are still sleeping on. You cannot move AI workloads at scale with copper wire. Data centers need ultra-fast, low-latency interconnects — and photonics is the only answer. Silicon photonics is actively replacing copper-based communication inside and between hyperscaler campuses. The plays institutions are quietly accumulating: $AAOI — pure-play optical components, deep data center exposure $COHR — vertically integrated photonics at scale $LITE — transceivers powering the hyperscaler build-out $POET — integrated optical engines, early-stage, asymmetric upside $CIEN — backbone optical networking infrastructure $FN — precision optical manufacturing, best-in-class margins This wave is not coming. It is here. Wave 4: Power & Energy Infrastructure (Early Stage) AI doesn’t run on ambition. It runs on electricity. Data centers are projected to consume 8–10% of U.S. power by 2030. That is not a tailwind. That is a structural demand shock the grid is not prepared for. Nuclear is the only baseload solution that can sit next to a hyperscaler campus and deliver consistent, carbon-light power at scale. The plays: $CEG & $VST — utilities with nuclear-powered AI offtake contracts $CCJ — uranium supply, the fuel behind the revival $OKLO & $SMR — next-gen small modular reactors $VRT — liquid cooling and power management inside data centers The capex commitments from $MSFT, $AMZN , and $GOOG are already locked in. The power infrastructure just needs to catch up. This wave is early. That is the opportunity. Wave 5: Robotics 🤖 (Loading…) Once AI is trained, powered, and connected — it needs a body. Physical deployment into warehouses, factories, logistics, and healthcare. This is the final and potentially the largest layer of the entire cycle. Hardware-software integration is still 12–24 months from full ignition. But the smart money is already laying the groundwork quietly. The pattern is simple: Each layer enables the one after it. → Semis built the brain → Memory gave it recall → Photonics gave it nerves → Power gives it fuel → Robotics gives it hands The investors winning this decade are not chasing yesterday’s leader. They are identifying tomorrow’s bottleneck — and positioning before the crowd arrives. The question is not which wave already ran. The question is: which wave are YOU in front of? $AAOI $COHR $LITE $POET $CIEN $FN $CEG $VST $OKLO $SMR $CCJ $VRT DOYR , bookmark this and retweet for others.

@thevalueistApr 11, 2026 · 7:20 PM

$CEG $VST $TLN $NRG RESEARCH NOTE - PJM Reliability Backstop: Hybrid Procurement Reorders the Merchant Power Opportunity https://t.co/FWkC9iVjQb Bottom Line: PJM's reliability backstop proposal is a clear admission that the existing capacity construct is no longer matching hyperscale-driven load growth with financeable dispatchable supply. The region is moving, at least temporarily, from a pure scarcity-price regime toward a hybrid system in which bilateral contracting and, if needed, central procurement are used to pair incremental large-load demand with incremental supply. That is supportive for merchant generation equities, but the payoff is not uniform: the best setups are companies that can monetize both sides of the transition, namely elevated near-term scarcity on existing fleets and longer-duration contracted growth through brownfield gas, nuclear uprates, direct-supply structures, or DR/DER-enabled BYOP solutions. The main refinement after fresh autoresearch is that the direct-supply/co-location pathway remains commercially unsettled, so near-term upside should still be underwritten more by scarcity and brownfield execution than by assuming a clean regulatory glide path for existing-fleet bilateral structures.

@investmentguru_Apr 9, 2026 · 10:42 AM

NUCLEAR ENERGY — Buying Opportunity Right Now? The setup is getting hard to ignore. Why Nuclear, Why Now - AI + data centers = massive, nonstop power demand - Policy tailwinds building (U.S. targeting major capacity expansion into 2050) - Global nuclear generation expected to hit new highs in 2026 - Energy security concerns (oil chokepoints, geopolitics) accelerating diversification - Big money calling it a “nuclear renaissance” The Watchlist $CEG - Largest U.S. nuclear operator - Long-term hyperscaler deals (AI demand locked in) $CCJ - Uranium leader + Westinghouse exposure - Strong contract book = revenue visibility - Best way to play uranium cycle $GEV - Massive backlog + global power footprint - SMR exposure + grid infrastructure play - Picks & shovels of nuclear buildout $OKLO - Next-gen SMR pure play - Big tech/data center pipeline - High risk, asymmetric upside $SMR - Large-scale SMR ambitions - Deep pullback (~80% off highs) - Long-duration, speculative bet $NEE - 30+ years of dividend growth - Nuclear + renewables balance - Safer compounder $VST - AI power demand leverage - Strong EBITDA growth trajectory - Undervalued vs forward potential $LEU - U.S. uranium enrichment leader - Strategic asset as supply chains shift - Direct geopolitical tailwind AI is creating a real energy crunch. Nuclear is one of the few scalable, reliable solutions. Pullbacks in this sector = opportunity across risk tiers. Not financial advice. Do your own research.

@kaizen_investorApr 7, 2026 · 5:06 PM

Q4 Energy transition update. I follow 7 big energy waves to keep track of the transition. Wind: $GEV, SIFG, ORSTED, $CDLR, PNE, NDX, VWS, Goldwind, Windey Green Hydrogen: $PLUG, $NEL, $ITM, TKA, LHYFE, $H2O, HYPRO, BLDP, CWR, FCEL Solar: $FSLR, $ENPH, $NXT, $TE, SMA Solar, Sunrun, Shoal, Longi, Jinko, Trina Energy Storage: $FLNC, STEM, $EOSE, NRGV, IES, $AMPX, $ENVX, CATL, LG, Gotion Nuclear: $BWXT, $SMR, $LEU, ASY, $CCO, Kazatomprom, $OKLO, NXE, UEC, DML LNG: $LNG, $VG, $EE, DLNG, GTT, CCEC, Kunlun, Petronet, ADNOC Mixed companies: $NEE, $VST, $CEG, $BE, $AES, $DUKE, $IBE, $RWE, $ENEL, $D Find out the details here 👇

@jasonl_capitalMar 30, 2026 · 3:26 PM

These stocks may be worth buying on future dips: AI Compute: $NVDA $AMD $AVGO AI Memory: $MU AI Infrastructure: $IREN $NBIS $VRT Networking: $MRVL $ANET $ALAB Photonics: $AAOI $LITE $COHR Power / Energy: $CEG $OKLO $VST $BE Robotics / Autonomy: $TSLA $AMZN Drones / Defense: $ONDS $KTOS $AVAV Satellites / Space: $ASTS $RKLB $LUNR $PL Digital Finance: $HOOD $CRCL $SOFI The market is giving you discounts on the next decade of growth. Take advantage.

@thevalueistMar 5, 2026 · 2:25 PM

One additional new great data set on BBG - grid-scale energy storage. $CEG $VST $TLN $NRG https://t.co/VbeaPkKWJn

@thevalueistMar 3, 2026 · 4:25 PM

Lone Pine likes the merchant power producers - Kelly Granat $CEG $VST $TLN $NRG

@thevalueistFeb 26, 2026 · 7:50 PM

$VST NUCLEAR UPRATES: COMPLETE CALLOUTS, CONTEXT, AND INVESTMENT ANALYSIS FROM VISTRA Q4 2025 EARNINGS CALL (02/26/26) SCOPE OF WHAT MANAGEMENT MEANT BY “UPRATES” AND “UPGRADES” The call used “upgrades,” “upgrade capacity,” and “uprate” as closely related concepts referring to incremental megawatts added to existing nuclear units through plant modifications and performance improvements. The primary uprate program discussed was the Meta-supported nuclear upgrade package across Vistra’s PJM nuclear fleet, explicitly quantified as 433 MW of “upgrade capacity.” A second, smaller uprate opportunity was referenced as approximately 200 MW at Comanche Peak (Texas), described as a potential future opportunity still under study rather than a committed project. In Q&A, management indicated that these 2 items effectively cover the uprate opportunity at existing plants discussed by the company at present, while separately noting ongoing interest in “new nuclear and other opportunities.” QUANTITATIVE UPRATE DISCLOSURES AND ASSET FOOTPRINT META PJM NUCLEAR UPRATES: 433 MW TOTAL The largest and most concrete uprate disclosure was tied to the 20-year Meta power purchase agreements. Management characterized this as “the largest nuclear upgrade supported by a corporate customer in the United States,” and specified the assets and magnitude as follows: “20-year agreements with Meta covering 2,176 megawatts of operating capacity and an additional 433 megawatts of upgrades at our PJM nuclear plants…” (Jim Burke) “The agreements… cover 2,176 megawatts of operating capacity from our Perry and Davis Bessie nuclear power plants and an additional 433 megawatts of upgrade capacity from our Perry, Davis Bessie, and Beaver Valley power plants.” (Jim Burke) Key content embedded in these statements: The uprate package is not a single-unit project; it is a portfolio program spanning 3 nuclear sites (Perry, Davis-Besse, Beaver Valley). The 433 MW is incremental capacity (“upgrade capacity”) distinct from the 2,176 MW of contracted existing output. The uplift is framed as corporate-supported, meaning the offtake structure is intended to underwrite the economics and bankability of the incremental MWs. COMANCHE PEAK POTENTIAL UPRATE: ~200 MW A second uprate opportunity was referenced at Comanche Peak, framed as part of remaining nuclear contracting “opportunity” rather than a committed capital plan: “We still see an opportunity to contract up to an additional 3.2 gigawatts of nuclear capacity across our Beaver Valley and Comanche Peak sites, including potential upgrades of approximately 200 megawatts at Comanche Peak.” (Jim Burke) In Q&A, that Comanche Peak upgrade was further clarified as not yet in execution: “The 200 megawatts, we still have some work to do on those and that’s a future opportunity.” (Jim Burke) TOTAL UPRATE OPPORTUNITY IMPLIED ON THE CALL: ~633 MW An analyst framed the company’s previously discussed uprate potential at “about 600,” explicitly tying the components together: “I think you’ve talked about potential in the neighborhood of about 600. You’ve identified the 400 and change with Meta and I think you talked about 200 today with Comanche…” (Scotiabank) Management’s response effectively affirmed that aggregation as the current uprate set: “No, I think that covers it… for uprates at the existing plants that covers it…” (Jim Burke) TIMING AND RAMP PROFILE OF UPRATE MWs The call made a clear distinction between near-dated delivery of operating capacity under the Meta PPAs and the much longer-dated delivery of the uprate MWs. META OPERATING CAPACITY VS. META UPRATE CAPACITY Operating capacity delivery dates were provided: “We expect delivery of the operating capacity of Perry to commence in December of 2026 in Davis Bessie in December 2027.” (Jim Burke) Uprate timing was explicitly pushed out: “Upgrade capacity remains longer-dated with Perry upgrades expected to be online in the fourth quarter of 2031 with each subsequent year seeing an additional upgrade online until all 4 upgrades are completed by the fourth quarter of 2034.” (Jim Burke) Implications of this timing profile: The uprate MWs are not a 2026–2027 earnings driver. They begin contributing starting 2031 and ramp through 2034. The program appears to be structured in 4 discrete tranches (“all 4 upgrades”), with 1 tranche per year from 2031 through 2034, rather than a single in-service date. CFO CONFIRMATION THAT UPRATES ARE LONG-DATED FOR FREE CASH FLOW The CFO explicitly called out the uprate contribution as long-dated relative to nearer-term cash flow modeling: “Other actions such as the PPA with Amazon and the uprate supported by contracts with Meta won’t contribute to our free cash flow until further into the future, but will be meaningful sources of increased contracted earnings.” (Kris Moldovan) This is a critical interpretive statement because it confirms: The uprate program is positioned as a long-duration earnings/cash flow durability lever rather than a near-term beat/raise catalyst. Management is intentionally separating the near-term “execution plan” (2026–2027 cash generation, buybacks, growth investments) from the longer-dated nuclear uplift. CAPITAL REQUIREMENTS, RETURNS, AND HOW UPRATES FIT INTO THE CAPITAL ALLOCATION FRAMEWORK The call provided specific directional guidance on capex requirements and return thresholds for the uprate program, while leaving out explicit dollar capex totals or $/kW economics. CAPEX IS REQUIRED AND IS CLASSIFIED AS “GROWTH CAPITAL” Management drew a line between operating capacity PPAs (no incremental spend) and the uprate program (requires growth capex): “From a capital perspective, the Comanche Peak agreement will not require significant incremental spend from Vistra and the [PJM] agreements for operating capacity won’t require any additional spend. The [PJM] nuclear upgrades will require growth capital over an 8-year period with the majority of the spend occurring after 2028.” (Jim Burke) The capex framing carries several implications: The uprate program is being treated as a discretionary growth investment subject to hurdle rates, not as maintenance capex. The “majority of the spend occurring after 2028” suggests near-term cash flow (2026–2028) is less burdened by uprate capex, with the heavier capital draw later in the decade. The 8-year spend horizon implies extended project execution, engineering, procurement, outage planning, and regulatory sequencing. EXPLICIT RETURN DISCIPLINE TIED TO UPRATES Management directly tied the uprate investments to return thresholds: “We believe these investments represent attractive growth opportunities given the higher capacity, expected improvement in reliability and the enhancements that will allow for an additional operational license extension, all while exceeding our mid-teens levered return requirements.” (Jim Burke) Key read-throughs: The uprate projects are positioned not only as capacity adders, but also as reliability and life-extension enabling investments. That matters because the value proposition is not solely the incremental MW revenue; it is also higher availability and extended asset life. “Exceeding… return requirements” signals that the company believes the contract structures (and/or market conditions) make the uprates economically attractive versus alternative uses of capital, including buybacks. UPRATES ARE INCLUDED IN THE COMPANY’S MULTI-YEAR CASH ALLOCATION DISCUSSION The CFO included “the [PJM] nuclear upgrade supported by PPAs with Meta” as part of the growth investment bucket: “After allocating… approximately $4 billion towards accretive growth investments, including… the [PJM] nuclear upgrade supported by PPAs with Meta…” (Kris Moldovan) Implication: The uprate program is a planned capital call within the 2026–2027 capital framework, even if the majority of spending is after 2028. The company is embedding this into its long-range plan, increasing confidence that it is not merely aspirational. CONTRACT STRUCTURE AND RISK ALLOCATION: WHAT WAS SAID (AND WHAT WAS IMPLIED) The call made several statements that, taken together, outline how Vistra views corporate-backed uprates as a way to convert long-dated nuclear optionality into contracted value. CORPORATE SUPPORT WAS EMPHASIZED AS A DIFFERENTIATOR “20-year agreements with Meta… an additional 433 megawatts of upgrades… the largest nuclear upgrade supported by a corporate customer in the United States.” (Jim Burke) This framing implies: The upgrade economics are being underwritten by a creditworthy corporate offtaker through long-duration contracts rather than being purely merchant investments. The size and “first-of-kind” nature (as framed by management) is intended to signal repeatability and to position Vistra as a preferred counterparty for future nuclear contracting and uprate monetization. UPRATES WERE LINKED TO LICENSE EXTENSION AND LONG-LIFE ASSET VALUE The call explicitly connected uprates/upgrades to extending nuclear plant operations: “The financial impact… is significant… and in the case of the [PJM] nuclear sites to apply for additional license renewals and extend site operations into the 2050s and 2060s.” (Jim Burke) “Enhancements that will allow for an additional operational license extension…” (Jim Burke) Implications: The uprate program is framed as part of a broader “life extension plus performance” strategy, not just incremental MWs. The ability to justify additional license renewals can materially increase terminal value by extending depreciation life and maintaining contracted cash flows over multiple decades. FULL-RAMP ACCRETION CLAIM INCLUDES UPRATES Management provided a consolidated view of nuclear PPA upside: “Upon achieving full ramp of all the nuclear agreements, we see a pathway to nearly 25% adjusted free cash flow before growth accretion on an annual basis.” (Jim Burke) Interpretation specifically for uprates: The 25% figure is not isolated to uprates; it aggregates Amazon + Meta operating capacity + Meta uprates and associated contract economics. Because the metric is “before growth,” it will, by definition, not subtract the growth capex required for the uprates. That is directionally useful for earnings power but can overstate distributable free cash flow in the capex-heavy years, particularly as spending ramps post-2028. COMANCHE PEAK UPRATE: SPECIFIC COMMENTS AND PRIORITIZATION SIGNALS The Comanche Peak uprate (~200 MW) was discussed with a noticeably different tone than the Meta PJM uprates, reflecting earlier-stage status and a focus on near-term execution of the Amazon on-site data center. COMANCHE PEAK UPRATE IS “UNDER STUDY” AND SUBORDINATE TO CURRENT EXECUTION “On the upgrade timing, we’re continuing to study that possible upgrade at Comanche Peak. But right now… we are very focused on executing for our customer… to make sure the data center on-site at Comanche Peak gets online on time. And that’s our number 1 focus… But certainly, the team continues to explore the upgrade in the back in the background.” (Stacey Dore) Implications: The Comanche Peak uprate is not being used to underpin near-term guidance or near-term capital commitments. The gating items are implied to be project sequencing and customer delivery milestones rather than a lack of strategic interest. POSSIBILITY OF EXPANDING THE ARRANGEMENT WITH THE SAME CUSTOMER “We have the opportunity potentially with the same customer to add that to the portfolio.” (Stacey Dore) Implication: The uprate may be structured as an expansion option with the existing offtaker rather than a standalone merchant decision, reinforcing the “contracted uprate” template. BROADER OPTIONALITY AT COMANCHE PEAK (NOT LIMITED TO UPRATES) While not an uprate per se, management contextualized Comanche Peak as a scalable energy hub: “We have a lot of land at Comanche Peak and we definitely could explore new generation at that site… in the past, the company had looked at Comanche Peak units 3 and 4… an early application in with the NRC… before we pulled it… around 2015…” (Stacey Dore) Implication: The Comanche Peak site is being positioned as a platform asset with multiple expansion vectors: on-site load, potential uprate, potential newbuild (including nuclear history), and potentially additional gas-enabled solutions. Q&A CLARIFICATION: MANAGEMENT VIEW ON “HOW MUCH MORE” UPRATE IS LEFT The most definitive “boundary” statement came in response to the question about whether the 433 MW + 200 MW “covers” uprate potential: Analyst: “Does that essentially cover the opportunity or do you see potential for more?” Management: “No, I think that covers it… for uprates at the existing plants that covers it… obviously, we’re continuing to look at new nuclear and other opportunities, but from the up-rate perspective, that I think you’ve got it covered.” (Jim Burke) Implication: Incremental uprates beyond the 433 MW (Meta PJM) and ~200 MW (Comanche Peak potential) were not flagged as a near-term strategic focus. The company is separating “uprates” (finite set, now largely identified) from “new nuclear” (ongoing option set). INVESTMENT AND FUNDAMENTAL IMPLICATIONS OF THE UPRATE DISCUSSION CASH FLOW DURATION IMPROVES, BUT THE VALUE IS BACK-END LOADED The uprate MWs, particularly under Meta, are explicitly long-dated (2031–2034). This increases long-duration earnings visibility and supports terminal value, but it does not materially change 2026–2027 reported EBITDA/cash flow other than through early capex planning and any preparatory spend. UPRATES ARE POSITIONED AS A CONTRACTED INFRASTRUCTURE INVESTMENT, NOT A MERCHANT BET Repeated emphasis on corporate support, long-term PPAs, and license extension ties the uprate decision to contracted economics. The risk profile shifts toward execution and regulatory approval rather than power price volatility. CAPITAL INTENSITY IS REAL AND DEFERRED, WHICH CAN MATTER FOR LEVERAGE AND SHAREHOLDER RETURN MIX POST-2028 Management stated that the majority of uprate capex occurs after 2028 over an 8-year period. This suggests a future window where capital allocation tradeoffs could become more binding, depending on prevailing forward curves, equity valuation, and M&A opportunities. The call’s framing implies confidence that cash generation will be sufficient to fund both buybacks and growth, but the uprate program is one of the principal long-dated calls on that cash. UPRATES ARE LINKED TO RELIABILITY AND LICENSE EXTENSION, WHICH CAN BE AS VALUABLE AS THE INCREMENTAL MWs Management explicitly cited “expected improvement in reliability” and “enhancements that will allow for an additional operational license extension.” This suggests the upgrade program includes broader plant modernization elements that protect availability and extend asset life, potentially reducing forced outage risk and sustaining long-term capacity value. COMPLETE LIST OF UPRATE/UPGRADE-RELATED STATEMENTS MADE ON THE CALL (AS PRESENTED IN THE TRANSCRIPT) “20-year agreements with Meta covering 2,176 megawatts of operating capacity and an additional 433 megawatts of upgrades at our PJM nuclear plants…” (Jim Burke) “The agreement [Amazon] also includes options to explore new nuclear development with a specific focus on possible upgrades and small modular reactors.” (Jim Burke) “The agreements [Meta]… cover… 2,176 megawatts of operating capacity… and an additional 433 megawatts of upgrade capacity from our Perry, Davis Bessie, and Beaver Valley power plants.” (Jim Burke) “Upgrade capacity remains longer-dated with Perry upgrades expected to be online in the fourth quarter of 2031… until all 4 upgrades are completed by the fourth quarter of 2034.” (Jim Burke) “The financial impact… is significant… to apply for additional license renewals and extend site operations into the 2050s and 2060s.” (Jim Burke) “Upon achieving full ramp… nearly 25% adjusted free cash flow before growth accretion…” (Jim Burke) “The [PJM] nuclear upgrades will require growth capital over an 8-year period with the majority of the spend occurring after 2028.” (Jim Burke) “These investments… exceeding our mid-teens levered return requirements.” (Jim Burke) “Opportunity… including potential upgrades of approximately 200 megawatts at Comanche Peak.” (Jim Burke) “Approximately $4 billion towards… growth investments, including… the [PJM] nuclear upgrade supported by PPAs with Meta…” (Kris Moldovan) “Other actions such as… the uprate supported by contracts with Meta won’t contribute to our free cash flow until further into the future…” (Kris Moldovan) “The 433 megawatts with Meta… are in process. The 200 megawatts… future opportunity… for uprates at the existing plants that covers it…” (Jim Burke, Q&A) “Continuing to study that possible upgrade at Comanche Peak… focused on executing… the data center… on time… team continues to explore the upgrade…” (Stacey Dore, Q&A)

@thevalueistFeb 26, 2026 · 7:49 PM

$VST EXECUTIVE CALL SUMMARY: VISTRA CORP (02/26/26) Vistra reported a mixed quarter, characterized by an ongoing operations adjusted EBITDA outperformance versus consensus expectations but a year-over-year decline in profitability metrics and a market reaction that focused on reported misses in adjusted EPS and revenue (per Bloomberg). The quarter’s core message was not the quarter’s earnings power in isolation, but the company’s positioning for a structurally stronger demand environment, with a deliberate emphasis on dispatchable generation scale, long-duration nuclear contracting with hyperscalers, and a capital allocation framework anchored in significant buybacks while maintaining an investment-grade balance sheet. Fourth quarter ongoing operations adjusted EBITDA was $1.742 billion versus $1.983 billion in the prior-year quarter (-$241 million, -12.2% y/y), driven by weaker Texas and East results that more than offset a stronger retail quarter and improved West contribution. GAAP net income was $233 million versus $490 million (-$257 million, -52.4% y/y), while ongoing operations net income (excluding Asset Closure) was $375 million versus $545 million (-$170 million, -31.2% y/y), indicating a material drag from Asset Closure and other below-the-line items relative to the prior year. (Vistra Corp. Investor Relations) For full-year 2025, ongoing operations adjusted EBITDA was $5.912 billion, up modestly from $5.643 billion in 2024 (+$269 million, +4.8%), and ongoing operations adjusted free cash flow before growth (FCFbG) was $3.592 billion, described as meaningfully above the midpoint of original guidance. (Vistra Corp. Investor Relations) Reported GAAP net income for full-year 2025 declined sharply to $944 million from $2.812 billion in 2024, with management attributing the decline primarily to unrealized losses from commodity hedging transactions expected to settle in future years, including an unrealized pre-tax net loss from hedges of $808 million. (QuoteMedia) Forward guidance was reaffirmed rather than raised. 2026 guidance ranges were reiterated at $6.8 billion to $7.6 billion for ongoing operations adjusted EBITDA and $3.925 billion to $4.725 billion for ongoing operations adjusted FCFbG, explicitly excluding potential impact from the Cogentrix assets. (QuoteMedia) The 2027 midpoint opportunity for ongoing operations adjusted EBITDA was reiterated at $7.4 billion to $7.8 billion, and was described as unchanged and excluding Cogentrix and Meta impacts. (QuoteMedia) In Q&A, management stated that an incremental $700 million to $750 million of 2027 uplift could be inferred from disclosures related to Cogentrix and Meta, but indicated that formal updates to 2026 guidance and the 2027 midpoint opportunity would likely occur after Cogentrix closes (targeted for 2H 2026). (The Motley Fool) The most material incremental disclosure for equity valuation framing was the company’s longer-term adjusted FCFbG per share framework: $10.39 for 2025, $12.60 at the 2026 guidance midpoint, and a near-term potential of approximately $16 incorporating announced transactions and share repurchases under specified assumptions (including an assumed buyback price of $170.57). (InvestorRoom) This per-share disclosure increased transparency around the equity compounding path and clarified that buybacks remain a central tool, even as the share price level has risen substantially versus the program’s historical average repurchase cost. FINANCIAL PERFORMANCE AND EARNINGS QUALITY Fourth quarter performance showed a divergence between revenue expansion and profit compression. Operating revenues for full-year 2025 were $17.738 billion, and operating revenues for the 9 months ended 09/30/25 were $13.154 billion, implying 4Q25 operating revenues of approximately $4.584 billion. The comparable implied 4Q24 operating revenues were approximately $4.037 billion, implying roughly +13.5% y/y top-line growth in 4Q25. (SEC) The EBITDA profile moved in the opposite direction: ongoing operations adjusted EBITDA declined -12.2% y/y to $1.742 billion. (Vistra Corp. Investor Relations) This combination is consistent with lower realized gross margin per MWh and/or a mix shift to lower-margin retail volumes and purchased power, alongside operational headwinds. The quarter’s earnings quality must be assessed through the lens of Vistra’s hedging and non-GAAP framework. The company’s full-year GAAP net income decline versus 2024 was attributed primarily to unrealized hedge losses expected to settle in future years, with a disclosed $808 million pre-tax unrealized loss from hedges in 2025. (QuoteMedia) In commodity-linked generation portfolios, such unrealized hedge losses commonly coincide with higher forward price curves (and therefore higher embedded value in future physical generation margins), but they depress current-period GAAP earnings through mark-to-market accounting. The investment implication is that GAAP EPS volatility is structurally amplified by hedge accounting and curve movements, while management and many investors are being asked to underwrite a cash-flow-centric, adjusted EBITDA and adjusted FCFbG framework for valuation. Fourth quarter GAAP net income was $233 million, down -52.4% y/y, while ongoing operations net income was $375 million, down -31.2% y/y. (Vistra Corp. Investor Relations) The gap between GAAP net income and ongoing operations net income in the quarter (approximately $142 million) reflects losses in the Asset Closure segment, which includes items such as impairment and incident-related impacts, including a disclosed transfer of the Moss Landing 100 MW battery facility to Asset Closure in the quarter’s non-GAAP reconciliations. (QuoteMedia) This is an important point for long-only and hedge fund investors alike: a meaningful portion of quarter-to-quarter GAAP noise is being driven by items that management is isolating in Asset Closure or adjusting out, creating a persistent risk of earnings “misses” on GAAP or adjusted EPS even when adjusted EBITDA is stable. SEGMENT PERFORMANCE AND OPERATIONAL DRIVERS Fourth quarter ongoing operations adjusted EBITDA by segment highlights the source of the y/y decline: Retail adjusted EBITDA: $645 million versus $600 million (+$45 million, +7.5% y/y). Texas adjusted EBITDA: $418 million versus $598 million (-$180 million, -30.1% y/y). East adjusted EBITDA: $631 million versus $774 million (-$143 million, -18.5% y/y). West adjusted EBITDA: $70 million versus $42 million (+$28 million, +66.7% y/y). Corporate and Other adjusted EBITDA: -$22 million versus -$31 million (loss narrowed). Asset Closure adjusted EBITDA: -$16 million versus -$49 million (loss narrowed). (Vistra Corp. Investor Relations) The profit compression in Texas and East dominated the consolidated y/y decline, even with a solid retail quarter and improved West performance. This is consistent with the operational commentary that extended outages at Martin Lake Unit 1 and the Moss Landing battery facility were material offsets, partially counterbalanced by higher generation volumes, Lotus acquisition contribution, and strong retail counts and margin (per Melius Research via Bloomberg). The underlying message is that operational availability and incident management remain key near-term swing factors, even as the strategic narrative has shifted toward long-duration contracting and acquisition-led scaling. A notable nuance in 2025 results was the performance of retail and its sustainability. Management explicitly stated that retail delivered a record 2025 result partly due to “tailwinds that are not expected to repeat,” including supply cost benefits and gains related to the Energy Harbor acquisition, and characterized medium-term retail adjusted EBITDA as “in the neighborhood of approximately $1.4 billion.” This is a material normalization signal versus 2025 retail adjusted EBITDA of $1.622 billion and implies a non-trivial headwind embedded in forward segment expectations even if customer counts remain strong. (Vistra Corp. Investor Relations) For generation, the structural benefit is the breadth of the hedging program and the portfolio’s scale across markets, but the structural risk is the operational volatility inherent in a large thermal and nuclear fleet, especially under extreme weather events and in aging units. Management emphasized Winter Storm Fern performance in late January (post-quarter), stating that assets “delivered very strong performance” during the 9-day event and that thermal generation provided approximately 93% of grid-delivered power during tight hours. This messaging is strategically aligned with their thesis that dispatchable generation value is increasing as load grows, but it also highlights the embedded reliance on fleet reliability during stress periods. FULL-YEAR CONTEXT AND HISTORICAL COMPARISONS The quarter must be viewed in the context of a multi-year earnings step-up. Full-year ongoing operations adjusted EBITDA rose from $4.101 billion in 2023 to $5.643 billion in 2024 to $5.912 billion in 2025. (InvestorRoom) The y/y growth from 2024 to 2025 was modest (+4.8%), but it occurred despite meaningful headwinds from outages and despite a sharp decline in recognized transferable nuclear production tax credit (PTC) revenues, which were disclosed as $545 million in 2024 versus $220 million in 2025. (InvestorRoom) The PTC dynamic is particularly important for forward risk: the IRA nuclear PTC acts as a downside stabilizer (higher credit in lower price environments, lower credit in higher price environments), which reduces earnings volatility of the nuclear fleet and supports hedging and guidance credibility, but it also means that reported PTC revenues will vary significantly with power prices and related statutory formulas. From a top-line perspective, full-year operating revenues increased to $17.738 billion in 2025 from $17.224 billion in 2024 (+3.0%), and were $14.779 billion in 2023, reflecting a materially larger revenue base over 2 years (+20.0% from 2023 to 2025). (QuoteMedia) The contrast between revenue growth and GAAP net income decline over the same period reinforces the centrality of hedge mark-to-market effects and non-cash items in reported earnings. GUIDANCE, PRIOR GUIDANCE COMPARISON, AND VISIBILITY A key takeaway of the quarter was that guidance was reaffirmed rather than increased despite multiple strategic announcements (Cogentrix acquisition agreement and Meta nuclear PPAs). The company reiterated 2026 ongoing operations adjusted EBITDA guidance of $6.8 billion to $7.6 billion and 2026 ongoing operations adjusted FCFbG guidance of $3.925 billion to $4.725 billion, excluding any potential impact from Cogentrix. (QuoteMedia) This guidance was initiated in the 3Q25 earnings release and was not changed in this quarter, suggesting that management is maintaining a conservative posture and/or that they are awaiting closing certainty and integration planning for Cogentrix before embedding incremental earnings. (SEC) The prior guidance comparison for 2025 is constructive and highlights conservative execution. In 3Q25, the company narrowed 2025 ongoing operations adjusted EBITDA guidance to $5.7 billion to $5.9 billion and raised/narrowed ongoing operations adjusted FCFbG guidance to $3.3 billion to $3.5 billion. (SEC) Actual 2025 results were $5.912 billion adjusted EBITDA and $3.592 billion adjusted FCFbG, exceeding the top end of the 3Q25 narrowed ranges and exceeding the midpoint of original guidance by approximately $112 million (adjusted EBITDA) and $292 million (adjusted FCFbG). (QuoteMedia) This pattern supports a view that guidance is intentionally structured with meaningful downside protection, which is consistent with management’s repeated emphasis on comprehensive hedging and on maintaining investment-grade leverage. For 2027, the company reiterated the previously communicated midpoint opportunity for ongoing operations adjusted EBITDA of $7.4 billion to $7.8 billion, described as unchanged and excluding Cogentrix and Meta impacts. (QuoteMedia) In Q&A, management stated that “with the disclosure we have put out, you could get to… an addition to 2027 from just those transactions of… $700,000,000 to $750,000,000,” while emphasizing that formal updates would wait until Cogentrix closes. (The Motley Fool) The implied magnitude is significant: $700 million to $750 million would represent roughly 9% to 10% of the midpoint of the 2027 EBITDA opportunity range, suggesting that the “unchanged” 2027 range may be more of a timing/definition issue than a fundamental earnings power issue. HEDGING POSITION AND THE IMPLICATIONS FOR EARNINGS SENSITIVITY The company’s hedging levels remain a central determinant of near-term earnings sensitivity and guidance credibility. As of 02/18/26, Vistra disclosed that it had hedged approximately 100% of expected generation volumes for 2026, approximately 84% for 2027, and approximately 58% for 2028. (QuoteMedia) This hedging posture implies: High near-term earnings and cash flow visibility through 2026, with limited upside/downside to near-term power price moves. Increasing open exposure beginning in 2027 and more materially in 2028, with a greater portion of equity value tied to forward curve evolution, load growth realization, and capacity market outcomes. An embedded timing mismatch between the market narrative (near-term AI/data center demand) and Vistra’s monetization of that narrative, given that much of the near-term generation output appears largely hedged. This is consistent with management’s emphasis on contracting and de-risking: “We continue to make meaningful progress in derisking our business, locking in higher levels of contracted revenue while at the same time growing our total earnings… We are not trading growth for stability. We are achieving both.” DEMAND OUTLOOK AND THE TIME PROFILE OF DATA CENTER IMPACT Management framed the macro environment as structurally improved demand growth with a measured time profile for data center impact. The call stated that “US electricity consumption reached an all-time peak of approximately 4,200 terawatt hours during 2025, up about 2.5% versus 2024,” and that 2026 and 2027 are expected to continue showing growth. This was positioned as the 1st 4-year period of sustained growth since the period ending 2007. The critical timing message was: “we continue to believe the impact of data centers on tightening supply-demand dynamics will not meaningfully begin until late 2027 or early 2028.” This view differs from more aggressive market forecasts and serves to temper near-term expectations for extreme tightening. The investment implication of this messaging is 2-sided: Positive: A measured pace reduces the risk of near-term grid and interconnection disruption that could trigger punitive regulatory interventions, reliability crises, or forced market redesigns that damage merchant economics. It also provides time for dispatchable owners to integrate acquisitions, execute uprates and conversions, and negotiate long-term contracting from a position of strength. Negative: If investor positioning in the sector is predicated on a near-term data center-induced price spike (2026-2027), management’s timing guidance is a caution that the steepening of power price curves and capacity scarcity may not accelerate as quickly as the most bullish narratives imply, especially in markets with time for supply response. On regional growth, management stated: “We maintain our view that annual peak load growth of at least 3% to 5% in ERCOT and low-single digit growth in PJM is achievable through 2030,” and emphasized that overall load growth is expected to outpace peak demand, implying higher utilization (capacity factors) rather than only short-duration peaks. This is a key analytic point: higher system utilization improves the economics of existing thermal fleets and combined cycles in particular, and supports Vistra’s strategy of expanding dispatchable gas capacity through acquisitions rather than relying solely on greenfield development. MANAGEMENT’S PER-SHARE CASH FLOW FRAMEWORK AND CAPITAL ALLOCATION SIGNALS The quarter’s most consequential disclosure for equity underwriting was the explicit adjusted FCFbG per share trajectory. The investor presentation disclosed adjusted FCFbG per share of $10.39 for 2025 and $12.60 at the 2026 guidance midpoint, and presented a “near-term potential” of approximately $16 incorporating: (1) share repurchases, (2) the Cogentrix acquisition, and (3) the Meta operating PPA contribution, under specific market curve and repurchase price assumptions (including an assumed average buyback price of $170.57). (InvestorRoom) Several implications follow: The 2026 guidance midpoint implies approximately +21% growth in adjusted FCFbG per share versus 2025 ($12.60 versus $10.39), reinforcing that guidance implies a substantial earnings step-up even before Cogentrix is included. The near-term potential of ~$16 implies a further +27% uplift versus the 2026 midpoint, emphasizing that the company views repurchases and announced transactions as meaningful incremental per-share compounding levers. The disclosure makes clear that the per-share story is partly a function of capital deployment choices and share price levels (repurchase price sensitivity is explicitly embedded in the framework). At higher share prices, buyback accretion declines unless cash flow expectations rise commensurately. The metric is “before growth,” and therefore excludes growth capex and acquisition spend. This can create a valuation gap between perceived “free cash flow yield” and actual distributable free cash flow after growth investments. The company’s framing attempts to bridge that gap by simultaneously presenting a capital allocation plan that includes both growth spending and shareholder distributions through 2027. On capital allocation, the call stated an expectation to generate “more than $10 billion of cash through year-end 2027,” and to allocate approximately $3 billion to equity holders (buybacks and dividends) in 2026 and 2027 and approximately $4 billion toward accretive growth investments (including Cogentrix, Permian gas units, and PJM nuclear upgrades), while still retaining more than $3 billion of additional capital available through year-end 2027 and achieving net debt to adjusted EBITDA of approximately 2.3x by year-end 2027. (Vistra Corp. Investor Relations) This is a high-confidence signal that buybacks are expected to remain substantial even while funding growth and maintaining credit metrics. On buybacks, management stated that approximately 167 million shares have been retired since November 2021 at an average cost of $36 per share, and the press release disclosed approximately $1.8 billion of repurchase authorization remaining (expected to cover the annual target through 2027). (QuoteMedia) The program is executed via a 10b5-1 plan designed to accelerate repurchases during share price weakness. The investment implication is that management is explicitly positioning buybacks as a volatility absorber and a per-share value transfer mechanism, although the absolute accretion rate is increasingly dependent on whether the share price meaningfully dislocates relative to intrinsic cash flow.