The company IREN was formally known as Iris Energy, yet changed its name to reflect the stock ticker last year. There are a few key things that separates IREN from other Bitcoin miners. The first is that IREN is still a Bitcoin miner whereas others have retrofitted their Bitcoin operations for the data center entirely or plan to very soon as the operations were not profitable. In contrast, IREN is able to turn a profit from Bitcoin mining and plans to use that cash to help fund its AI data center expansions. IREN is able to turn the profit due to selling the Bitcoin it mines yet also due to operational efficiencies that result in lower power costs. The last part is interesting, to say the least, given the company not only has 3GW of power yet has demonstrated they can offer a PUE of 1.1 to 1.2 on air cooled sites, and around 1.4 PUE for the incoming liquid cooled sites like Sweetwater.  

Secondly, IREN can offer a hybrid mix of both colocation and AI cloud services, which is essentially bare metal servers without a hypervisor or virtual layer. This is attractive to hyperscalers as virtualization can lead to performance loss. For the AI cloud, IREN functions similar to CoreWeave as the GPUs are leased “as a service.” For colocation, IREN provides the facility, power and cooling for customers to deploy and manage their own hardware. Although IREN is open to a mix of both colocation and cloud deals as it diversifies how they fund operations and raise capital, there’s no doubt that cloud deals are what could separate this stock from its Bitcoin mining peers. 

IREN Doubles GPU Fleet to 23K with $674M Nvidia and AMD GPU Purchase 

At the start of the week, IREN announced that it had purchased an additional ~12.4K GPUs for $674 million, more than doubling its GPU fleet to ~23K. This order included approximately 7.1K Nvidia B300s, 4.2K Nvidia B200s and 1.1K AMD MI350X GPUs, scheduled to be delivered over the coming months. Notably, this is the first time that IREN has purchased AMD’s GPUs, as it is currently focused primarily on buying Blackwell GPUs, which account for >85% of its fleet. 

This builds upon rapid expansion of its GPU fleet in late August, where IREN purchased ~4.2K B200s for $193 million, followed by the $168 million purchase of 1.2K air-cooled B300s and 1.2K liquid-cooled GB300s just three days later. 

Currently, IREN’s fleet includes: 

• 1.9k Nvidia H100s & H200s 

• 19.1k Nvidia B200s & B300s 

• 1.2k Nvidia GB300s  

• 1.1k AMD MI350Xs 

In total, IREN’s fleet cost ~$1.24 billion, including ancillary equipment such as InfiniBand, servers, cabling, and licensing costs. This puts the company’s all-in cost per GPU at just above $53,000, though notably the Blackwell Ultra generation carries a significant premium to the B200s. IREN’s recent 2.4K purchase of B300 and GB300s cost ~$70,000 per GPU ($60,000 for the B300 and $80,000 for the GB300), while its 4.2K B200 purchase cost just under $46,000 per GPU.  

Financing future GPU purchases will be paramount for IREN’s expansion plans, as the company has turned to high-single digit interest rate, 24 to 36 month lease financing for recent purchases. Depending on the how its latest $674 million purchase is financed, these leases already could add up to $100 million in quarterly expenses tied to these GPUs.  

With the latest purchase, IREN has likely maxed out its capacity at Prince George, which it has previously said can host >20K GPUs. Across its British Columbia data centers, IREN can support >60K GPUs, which would likely require an additional $3B+ in funding depending on GPU mix. Comments from management hint at expanding its GB300 fleet, which is currently the most expensive GPU with an average all-in cost of ~$80,000:  

“Construction is well underway on a new 10-megawatt liquid cooled data center at Prince George, designed to support more than 4,500 Blackwell GB300 GPUs. … Beyond Prince George, Mackenzie and Canal Flats. Our data center campuses in each of these locations create an even larger opportunity with powered shells, existing and designed to the same architecture as Prince George, these sites offer a straightforward and replicable pathway to more than 60,000 GB300s. Horizon 1 and our broader portfolio of data center sites in Texas opens up a further path to continued AI cloud growth.” 

At Horizon 1, IREN says that it can host ~19K GB300 GPUs at 50 MW IT load, which, based on prices calculated above, would cost the company upwards of $1.5 billion. Funding this and fully outfitting its British Columbia sites for 100% AI cloud capacity would likely cost $5 billion or more, or ~10x IREN’s most-recently reported cash holdings. This also does not account for its 2GW Sweetwater campus, which IREN says can support >600K GB300s. 

Analysts are expecting IREN to quickly scale its fleet through 2026, with Roth Capital projecting IREN to reach a ~112K GPU fleet by year-end 2026. This ~90K increase in GPU fleet could require IREN to take on more than $6 billion in debt, per Roth’s calculations. This would represent nearly 60% its current valuation and likely cost ~$600 million quarterly, which would not be covered by revenue nor cash flows.  

New AI Cloud ARR Guidance of >$500M 

In accordance with its doubled GPU fleet, IREN unveiled a new AI Cloud annualized revenue (ARR) guidance, now targeting >$500 million in ARR by Q1 2026, more than double its guidance from August for $200 million to $250 million by year-end 2025. The prior $200-$250 million guide was based on a fleet size of 10.9K GPUs, which management expects to be “progressively commissioned over the coming months.”  

This is a rather ambitious target, as this would represent nearly 20x growth from June’s $26 million annualized run rate, or quarterly revenue of just $7 million. July and August have also shown minimal growth in AI cloud ARR, at ~$28 million and ~$29 million, respectively, compared to $26 million in both May and June.  

Management says that they are observing demand for multi-thousand Blackwell GPU clusters, which should help revenue ramp quickly, yet the lack of a ramp suggests that clusters of that size have not yet been delivered. Additionally, the first B200 tranche “was immediately contracted on a multiyear basis” upon commissioning, highlighting that demand for the new generation remains high with customers ready to contract chips immediately once they are available. 

On a quarterly view, IREN is essentially targeting a strong ramp in the December quarter extending into the March quarter, considering July and August revenue mean Q3 is approximately flat QoQ assuming similar run rate in September.    

IREN also disclosed that the >$500 million ARR target is “an illustrative run-rate measure of potential revenue based on a ~23k GPU deployment and internal company assumptions regarding utilization and GPU pricing.” IREN warns that this figure “is not fully contracted, there can be no assurance that it will be achieved, and actual revenue may differ materially.” The ARR target also assumes on-time delivery and commissioning of GPUs, and any delays could quickly and easily derail this target, considering the pace of growth needed over the next six months. 

IREN says it expects delivery of its most recent 12.4K order from Sept 22 to be also delivered over the coming months, and much of its target likely hinges on this tranche as it accounts for more than half of its total fleet. Any delays in delivery towards the start of 2026 could threaten this ARR guide. Management hinted that they are “pre-contracting ahead of delivery”, providing additional visibility into future growth, but that does not span across its entire order book, limiting a high degree of confidence in the near-term.  

IREN Offers Cheaper Energy than Industry Average 

If IREN can maintain lower power costs compared to other Miners, then that could potentially provide a leg up in terms of signed deals. For example, IREN sees a profit of about $50,000 per Bitcoin mined at current prices for a hardware gross margin of about 70%. The company has stated their Childress facility sees energy rates of $0.033 kWh. In the most recent earnings call, the company stated they saw $0.035 kWh in Q4. 

According to an analysis by Nlyte.com the industry average PUE is 1.58 with companies like Google reaching 1.10. The analysis also points toward rates of $0.0616/kWh in regions like Iowa up to $0.2496/kWh in regions like Rhode Island. This helps to illustrate how IREN stands apart as the company is seeing energy rates 50% lower than cheap regions. 

Regarding PUE, this fluctuates depending on air cooled versus liquid cooled, and may be impacted as power demands rise with new generations of GPUs. However, as of now, the company sees PUEs as low as 1.1 for air cooled and anticipates PUEs of 1.4 for its Sweetwater facility. All of the above is lower than the industry average. 

“So as you mentioned, across the BC sites, we're operating at a PUE of 1.1. That's on an air cooled basis. Once we install the liquid-cooled facilities there, we expect that to be operating on an average slightly higher than that, but still well under 1.2 PUE across the year. At Childress, the Horizon 1 liquid cooled installation, the number that you mentioned is much closer to a peak PUE number, although we actually expect it to be less than 1.4 and the average PUE over the year to be around 1.2.” 

IREN Mixes Colocation with Cloud for a Hybrid Approach 

There are pros and cons to colocation versus cloud deals for IREN. Quite a bit of time was spent going through how the company plans to approach its hybrid strategy, given it’s rare to see a Bitcoin miner offer GPUs-as-a-service. It makes sense to try for Cloud deals as they come with a 97% margin, yet analysts were detailed in their questions how successful a Miner will be in pivoting to operate as a neocloud is an unknown and is the only attempt, thus far (the obvious question being, if there’s demand for this, why wouldn’t all Miners pursue this route). 

As pointed out in the earnings call, the following are the major differences between the two from a funding standpoint: 

• Colocation offers longer-dated contracts. For IREN, the contracts would be between 5-20 years yet takes around 7 years to see the capital absorbed. It leads to lower cash flows. The benefits to colocation is the infrastructure costs are provided for, which are 2-3X higher than the GPU costs. 
• Cloud deals are shorter contracts with strong margins, yet not many companies are in a position to offer cloud deals. Most Bitcoin miners operate deep in the red whereas IREN has profitable mining operations and controls the infrastructure “end-to-end.” There was mention on the call of a 3-year payback on these deals: “As of today, we find a 3-year payback on data center and GPU infrastructure pretty compelling, particularly when Anthony is lining up 100% GPU financing at single-digit interest rates.” 

The takeaway from the earnings call is that IREN would, of course, prefer to do AI cloud deals yet it remains to be seen if this will be attractive to key customers. As of now, most hyperscalers and neocloud customers would prefer the colocation option.  

Should IREN be able to find a strong market for its AI cloud services, then the stock could do quite well. However, this is the first attempt (and perhaps only attempt) across the Miners to double up as a neocloud. Typically, pivots are difficult to pull off and colocation may be the more popular choice on the customer side (i.e., we can flip this and say … why would a hyperscaler or neocloud pay IREN a higher amount in three years on the cloud side if it can spread out a similar amount over seven years with a contract term of up to 20 years? What's the benefit to the customer to go cloud?) 

It’s my contention that CoreWeave is in a league of its own, offering early access to hundreds of thousands of Nvidia’s GPUs. The higher utilization rates that CRWV offers is an advantage whereas Bitcoin miners have not factored in FLOPs for training models, which can have a much larger impact on output than a simple metric like lower energy rates. As we covered in the past, CoreWeave’s specialty is in optimizing memory bandwidth, improving communication between GPUs, clearing data input bottlenecks, and other ways in which to fix batch size, enable faster data loading, and/or better ways to balance the compute. In other words, what CoreWeave does is not easily replicated. 

Therefore offering an AI cloud is one thing, yet it’s another matter entirely to offer enough software optimizations to justify recurring revenue that will result in 2X higher costs than colocation (if we assume cloud is a 3-year return on capital versus 7-years).  

Fluidstack and Poolside are the primary customers for IREN which indicates they simply want to move quickly and are willing to overpay. Should cloud contracts continue to accumulate, it would be important to understand if there is an exit clause. 

As a reminder, Fluidstack is the neocloud that Google put up a 50% guarantee for on the lease with Terawulf. This caused WULF’s stock to surge. Depending on how Fluidstack funds a specific lease, it can be viewed as an attractive customer. Here is what management stated on the call regarding their AI cloud offering: 

“Because we own and operate the full end-to-end stack, we are able to deliver superior customer service, tighter control over efficiency, uptime and service quality translating directly into a better customer experience for our customers. We are leading our service with a bare metal service because it gives sophisticated developers, cloud providers and hyperscalers what they want most, direct access to compute and the flexibility to bring their own orchestration.” 

Financials 

Top-Line Performance: Growth on Two Fronts 

IREN reported FY25 revenue of $501.0 million, up 168% year-over-year from $187.2 million, underscoring one of the fastest growth rates in the sector. This surge is driven by two different engines: the traditional Bitcoin mining business, which contributed $484.6M, and the emerging AI Cloud Segment, which posted $16.4 million, nearly five times its FY24 contribution. This represents IREN’s first full fiscal year with AI cloud as a meaningful contributor, validating management’s strategy of diversifying beyond the volatile crypto cycle into high-performance computing and AI hosting. 

• FY25: $501.0M vs $187.2M in FY24 (+168% YoY). 
• Q4’25: $187.3M vs $56.8M in Q4 FY24 (+229% YoY) and $113.6M in Q3 FY25 (+65% QoQ) 

The fourth quarter alone delivered $187.3 million, up 229% from the $56.8 million earned in the year-ago period and up 65% sequentially from Q3’s $113.6 million. This kind of sequential growth is rarely seen outside of hypergrowth SaaS, let alone in a miner. The bulk of Q4 revenue came from Bitcoin at $180.3 million, with AI Cloud adding $7.0 million.

As seen in the charts above and below, analysts expect further continuation of this trend in significant top-line growth. Quarterly estimates remain strong through FY26 with all quarters exhibiting greater than 80% YoY growth. Annually, this equates to an FY26 growth rate of 109%, with an additional 49.3% growth in FY27 before pausing in FY28.  

Segment Breakdown: Still Bitcoin-Heavy, but AI Cloud Gains Relevance 

To be clear, Bitcoin mining still dominates the financials, accounting for 97% of FY25 revenue. Revenue rose 163% year-over-year as hash rate climbed to 50 EH/S, even as net electricity costs per coin mined rose to $25,642 post-halving (vs. $18,127 in the prior year). Favorable spot prices offset that inflation, keeping the economics attractive. 

The eye-catcher is AI Cloud. The segment remains small, at just 3% of total revenue, yet it is growing rapidly. FY25’s $16.4 million compares with $3.1 million last year, and Management is already telegraphing a path to $200 – $250 million annualized run-rate assuming 10,900 GPU’s are deployed by December 2025. Q4’s $7.0 million contribution shows that ramping is starting to appear in the reported numbers. This segment’s strategic importance outweighs its current financial contribution, as it diversifies revenue away from Bitcoin and positions IREN as a credible infrastructure partner for AI workloads. 

Top Line Growth Drives Margin Expansion  

Gross profit (excl. depreciation) for FY25 was $342.0 million, translating to a 68.3% margin, up nearly 15 percentage points from FY24’s 53.5%. Combining 167% top line growth with this 15 pp of margin expansion leads to Gross Profit increase of 241.7% YoY. This is the textbook definition of operational leverage. In Q4, the margin reached 71.8%, further reflecting benefits from scaling mining operations and disciplined power cost management. 

Operating Income turned positive in FY25 at $17.3 million or a 3.5% margin, a sharp swing from FY24’s ($25.2M) loss and (14.6%) margin. Q4 Operating Income was $20.6 million (11.0% margin), another milestone, as operating profit is now sustainable rather than a one-off. 

Adjusted EBITDA tells the operational efficiency story most clearly. For FY25, IREN delivered $269.7 million, a 54% margin, up nearly 5x from FY24’s $54.4m. In Q4 alone, adjusted EBITDA reached $123.0 million, or 65.7% of revenue. 

GAAP Net Income was strong but requires an asterisk. FY25 bottom line came in at $86.9 million, swinging from ($28.9) million loss last year with diluted EPS of $0.39. Q4’s $176.9 million profit, an absurd 94% margin) was artificially boosted by $775 million in unrealized gains on financial instruments and a $9.1 million gain on liability extinguishment. Strip those out and the true earnings power looks more like the $20M operating income figure. 

FY25 Key Metrics: 

• Gross Profit (ex-D&A): $342.0M, margin of 68.3%, up from 53.5% in FY25 
• Operating Income: $17.3M, margin of 3.5% vs. ($27.2M) or -14.6% in FY24. 
• Ad. EBITDA: $269.7M, margin of 54%, up 5x YoY from $54.4M, a 29% margin 
• Net Income: $86.9M vs ($28.9M) in FY24 

Q4’25 Key Metrics: 

• Gross Profit (ex D&A): $134.4M, margin of 71.8%, up from 71.0% in Q3’25. 
• Operating Income: $20.6M, margin of 11.0% vs. $29.1M or 20.1% in Q3’25. 
• Adj. EBITDA: $123.0m, margin of 65.7% margin 
• Net Income: $176.9M, a 94% margin  

Overall, it’s important to remember that IREN’s profitability is extremely sensitive to BItcoin’s current trading price. The profitabilty discussed above is due to operational efficiencies on the mining operations combined with Bitcoin trading above $100K and not from scaling the AI data center infrastructure  or cloud services (yet).  

EPS remains volatile due to GAAP mark-to-market gains 

EPS flipped positive in FY25, with diluted EPS of $0.39 versus a ($0.29) loss in FY24, marking the Company’s first full-year profit on a per-share basis. However, Management cautions that GAAP EPS is heavily influenced by fair-value accounting marks. Looking forward, analysts see GAAP profitability through FY26 as the Company expands its AI Cloud offerings efficiently at scale. 

Operating Cash Flow Turns Positive amidst GPU-fleet buildout 

Operating cash flow was a bright spot in FY25, at $245.9 million, up from just $52.2 million the prior year. That represents 48.9% of revenue flowing through to operating cash, a healthy conversion rate given the non-cash noise in reported earnings. 

Despite healthy operating cash flow trends, free cash flow was negative in FY25 as capex spend was immense. IREN spent $1.38 billion on PP&E, consisting mainly of GPUs and data center expansion, more than doubling FY24’s spend of $692 million. The result was free cash flow of ($1.13B), a -226% FCF margin. In other words, every dollar of operating cash flow generated was more than outspent on buildout. 

Financing flows more than filled this gap with $1.30 billion raised via converts, equity, and leases. Net-net, IREN ended FY25 with $160 million more cash than it started with, despite billion-dollar capex outlays. After year-end, the Company raised another $253.5 million via ATM equity sales and finalized a lease program that funds GPUs entirely, with fixed monthly payments of ~$2.8M and a buyout option at 18% of cost after 36 months. This strategy shifts capital intensity away from cash up front, preserving liquidity while enabling AI Cloud scaling.  

Key Metrics: 

• Cash and cash equivalents: $564.6M, up from $404.6M in FY24. 
• PP&E: $1.38B, mainly GPU purchases and data center buildouts. 
• Debt: $962.8M, convertible notes outstanding (non-current) 
• Equity: $1.82B, reflects retained earnings and capital raises.  
• Shares outstanding: 258.1M. 

Liquidity / Solvency Comparison vs. Peers 

At fiscal year-end, IREN held $564.6 million in cash against $962.8 million in convertible debt, equating to cash-to-debt ratio of .59x. Put differently, the Company had roughly 60 cents of cash for every dollar of debt outstanding.  

For context, this is a stronger liquidity position than many mining peers, who often carry higher net leverage and rely more heavily on dilutive equity raises. The ratio underscores that IREN is not currently overextended. Its sizeable cash cushion provides flexibility to meet near-term obligations, fund working capital, and invest in ongoing GPU deployments. 

However, the ratio also illustrates the reality of IREN’s capital intensity. With a $1.38 billion in FY25 Capex and another multi-billion-dollar investment cycle ahead, cash on hand can quickly become consumed unless offset by financing inflows. Management has already leaned on convertible notes, ATM equity, and hardware lease financing to balance the scales. 

The sustainability of IREN’s expansion will depend on a handful of factors worth tracking. To fund operations, IREN must keep it’s cash-to-debt ratio stable through disciplined liquidity management. Further, IREN must avoid excessive reliance on equity dilution, which could weaken per-share economics even if absolute liquidity remains healthy. Beyond liquidity concerns, the Company needs to execute a successful ramp AI Cloud revenues to justify the spend. If IREN can scale AI Cloud revenues and maintain current unit economics (~93+% gross margin), these cash flows would provide a healthy recurring buffer against heavy capex. 

In short, IREN’s 0.59x cash-to-debt ratio highlights both balance sheet strength and exposure. As discussed above, the Company has meaningful liquidity today, but the scale of its expansion means this ratio will be a key metric to monitor as it pursues GPU deployments and new data center builds through FY26. 

Conclusion: 

If IREN can prove they can pull off charging recurring revenue for its AI cloud services, then the stock is one to watch. We are at a critical juncture for cloud deals as analysts are expecting IREN’s revenue to decelerate in H2 2026. Therefore, any cloud deals that beef up current analyst expectations can help to strengthen this narrative.  

Right now, we prefer to stay as close to the hyperscaler deals as possible when evaluating Bitcoin Miners. The reason for this is that it solves the pain point of having a company with deep pockets back-stop the leases, which in turn, improves creditworthiness and credit terms. As many of you are aware, our ethos is to participate in the upside while protecting to the downside. We want the best of both worlds, and in a highly speculative momentum play like Bitcoin Miners pivoting to AI data center infrastructure, the primary goal is to reduce risk.  

We are watching IREN closely and would buy on a clear breakout only. If we were to buy, we’d closely adhere to all stops.

Damien Robbins, Equity Analyst at I/O Fund contributed to this analysis.

Every Thursday at 4:30 pm Eastern, the I/O Fund team holds a webinar for premium members to discuss how to navigate the broad market, as well as various stock and crypto entries and exits. Beth Kindig offers weekly deep dives including lesser-known cryptocurrencies and AI stocks, plus the team offers trade alerts. The I/O Fund team is one of the only audited portfolios available to individual investors. If you’d like to subscribe to the Advanced Market Signals plan, email us at premium@io-fund.compremium@io-fund.com.

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• Vistra is an independent power product (IPP) with 41 GW capacity, operating the second-largest fleet of nuclear plants in the United States. 
• Vistra has closed power purchase agreements (PPAs) to supply Amazon with 200 MW and Microsoft with 405 MW of renewable energy for their data centers in Texas and Illinois, respectively.
• The Company is in talks with two unnamed hyperscalers for natural gas plants co-located with their data centers.
• Co-location involves building data centers or power plants on-site to provide electricity directly to the data center, bypassing the electrical grid. This is known as "behind the meter."
• Regulations on co-location builds are materializing as hyperscalers await the precedent-setting decision on Talen Energy/Amazon co-location reliability solution vs FERC/AEP/Exelon push for cost equity as a major catalyst.
• Vistra has said they are in talks with hyperscalers and data center developers for nuclear power but hasn’t announced any deals yet.

Vistra Corp. (NYSE: VST) is the largest competitive power generation and retail electric company in the United States. It’s an integrated independent power producer (IPP) based out of Irving, Texas, serving five million customers across 20 states and Washington, D.C., with a power generation capacity of 41 GW (41,000 MW). It has the second-largest competitive nuclear fleet in the country, behind Constellation Energy. Texas is a hotspot for data centers and chip manufacturers. 

The company has power purchase agreements (PPA) with Amazon and Microsoft and is actively “speaking with all the major hyperscalers” and actively engaged with the major data center developers, according to Vistra CEO Jim Burke during their Q4 conference call. As of March 1, 2025, Vistra energy has 41 GW capacity, comprised of 27 GW for natural gas, 6.4 GW for nuclear, 6 GW for coal and 2 GW for renewable and battery/energy storage (1 GW), which includes solar assets with 350 MW already online.

The Energy Harbor Acquisition Bolstered Vistra’s Nuclear Footprint

On March 1, 2024, Vistra completed the acquisition of Energy Harbor Corp., adding an additional 4 GW of 24/7 nuclear generation and 1 million retail customers. The Company paid $3 billion in cash and a 15% equity stake in a new subsidiary comprised of all of its nuclear fleet (6.4GW) called Vistra Vision. The transaction closing followed receipt of all required regulatory approvals, including the from the Federal Energy Regulatory Commission (FERC) in February 2024.

In Q3 2024, the Company bought back the remaining 15% minority interest stake in Vistra Vision for approximately $3.248 billion from affiliates of Nuveen and Avenue Capital Management LLC. The buyback increased its nuclear ownership stake to the full 6.4GW capacity, not to be mistaken with adding any more capacity or increasing its licensed output (uprate). This results in keeping all the proceeds they were distributing to the minority stakeholders in Vistra Vision, which will result in a bump up in net income moving forward, however, they still have to pay $3.248 billion for it.

Vista expects to pay in five installments of $1.18 billion on December 31, 2024, $114 million on June 30, 2025, $1.0 billion on December 31, 2025, $54 million on June 30, 2026, and $900 million on December 31, 2026. The net present value of the purchase price as of December 31, 2024, discounted at a 6% interest rate, is $3.085 billion.

Complying with the Electrical Grid Operators and FERC

Here’s a quick summary of the many acronym organizations in the electricity market. As an IPP, Vistra actively deals with the electrical grid operators where they sell their electricity. Vistra sells wholesale electricity to markets managed by the PJM Interconnection (Pennsylvania, New Jersey, Maryland), which covers 13 states. PJM is an independent system operation (ISO) and regional transmission organization (RTO). They run the wholesale electricity markets for the regions, balancing the needs of market participants and ensuring grid reliability. They coordinate the flow of electricity from the power generators to local utilities.

ERCOT (Electric Reliability Council of Texas) performs the same ISO and RTO functions in Texas, managing high-voltage transmission grids. Texas is the only state that owns its power grid. ERCOT was the first ISO in the United States. Vistra also owns power plants and sells electricity to markets managed by ERCOT. The ISOs and RTOs are regulated by the Federal Energy Regulatory Commission (FERC).

Co-Location and BTM are Growth Drivers for Vistra

Front of the meter (FTM) refers to power produced by the power plants that flow to the electrical grid and then to the data center or customer. Behind the meter (BTM) refers to electricity that’s generated and directly delivered to the data center, bypassing the grid. Co-location deals where utilities like Vistra install gas power plants on-premise for the hyperscalers are BTM, as the power is generated on-site and delivered directly to the data center. Vistra can repurpose existing gas plants or construct new builds. BTM and co-location are Vistra’s AI hyperscaler growth strategy, but so far, there haven’t been any deals announced yet.

The time to power depends on the type of gas plant, whether it's repurposing an existing gas plant or constructing a new gas plant. Repurposing an existing gas plant can take six to 24 months, using spare capacity. New builds can take three to five years due to gas infrastructure, permits, construction and commissioning (IE, Building up to 860 MW of new gas plants in West Texas).

Vistra is a Nuclear Energy Powerhouse Primed for AI Data Centers

As of March 5, 2025, Vistra operates four active nuclear plants with a combined power capacity of over 6.4 GW, which is enough zero-carbon baseload capacity to power 3.2 million homes across PRJM and ERCOT markets. These include:

• Camanche Peak Nuclear Power Plant located in Texas, comprised of two units with 2,400 MW total capacity, with licenses extended to 2050 and 2053, approved by the Nuclear Regulatory Commission (NRC) in July 2024.
• Beaver Valley Nuclear Power Plant in Pennsylvania is comprised of two units with a 1,800 MW total capacity. NRC licenses expire in 2036 and 2047.
• Perry Nuclear Power Plant in Ohio is comprised of one unit with a 1,300 MW capacity. NRC license expires in 2046.
• Davis-Nesse Nuclear Power Plant in Ohio is comprised of one unit with 894 MW capacity. NRC license expires in 2037.

Beaver Valley, Perry and David-Neese Nuclear Plants were acquired from Energy Harbor for $3.4 billion in March 2024. The nuclear plants are operated under Vistra Vision, and the fossil fuel segment operates under Vistra Tradition. Nuclear energy comprises just over 15% of its total energy production. Vistra Energy’s nuclear fleet operates at 92% of its maximum capacity (aka capacity factor) in Q4.

Nuclear Energy and Gas Power Plants Talks with Hyperscalers

Vistra signed a 200 MW power purchase agreement (PPA) with Amazon for a Texas solar facility in October 2024. Vistra signed a 405 MW PPA with Microsoft for a solar project in Illinois during Q3 2024. Incidentally, Vistra hasn’t announced any major nuclear power purchase agreements (PPA) with major hyperscalers yet. However, the Company is in early discussions with some hyperscalers about nuclear uprates and some new builds as well.

Co-location is the trend of building data centers or power plants near data centers to alleviate pressure on the electrical grid and reduce transmission loss to ensure maximum efficiency.

Vistra is in discussions with two unidentified hyperscalers to build new natural gas power plants co-located with data centers. During its Q3 2024 conference call, Vistra's Head of Strategy, Stacey Dore, said this.

“There's a lot of interest, obviously, in the nuclear side. However, we have ongoing conversations with several different development companies about a handful of our gas sites, both in PJM and in ERCOT. And we're in early discussions with some of the hyperscalers about nuclear uprates, and some new build as well as Jim mentioned. And then, finally, we're in discussions with two particular large companies about building new gas plants to support a data center project.”

Diore also cautioned that these talks aren’t an overnight decision, “As we've said before, the diligence process for these deals takes a long time. It's an intense effort because these are very long-term commitments to purchasing power.” The announcement if and when these two hyperscalers closed the deal should be a catalyst for the stock.

How Natural Gas is Used to Generate Electricity

Vistra generates 66% or 27 GW of its energy capacity from natural gas using gas-fired power plants. The primary method for large-scale natural gas generation (1MW or more) is combined-cycle gas turbines (CCGT), which connect a gas turbine with a steam turbine. The natural gas is burned in a combustion chamber with compressed air to spin the turbine connected to a generator producing electricity. The exhaust heat can climb up to 1,000 degrees Fahrenheit, which is used to boil water to generate steam, driving a second turbine to generation addition electricity.

Simple-cycle turbines operate with just the natural gas turbines, without the steam turbines. Natural gas combustion turbines generate 35% to 42% of direct electricity. The steam turbines add another 20% to 25%, yielding total thermal efficiencies between 55% to 67%, which is the energy output vs fuel input. As natural gas is delivered through pipelines, around 92% is actually delivered, as 8% energy loss is common. Coal plants yield around 33% thermal efficiency. Nuclear plants yield 33% to 37% thermal efficiency, similar to or slightly better than coal. The main difference is the carbon emissions, which are virtually none, making nuclear the cleanest option of the three.

On a smaller scale (325 KW), we wrote about how Bloom Energy Servers (BES) can reach 85% to 90% thermal efficiency through its non-combustion, electrochemical reaction method using solid oxide fuel cells and heat capture. 

“BES is designed to work with existing carbon capture utilization and storage (CCUS) and combined heat and power (CHP) technologies. CCUS mitigates emissions from natural gas as BES generates a pure stream of CO2 that can be used or sequestered. CHP allows the exhaust heat generated by BES (operating at a core temperature of 1,500 degrees Fahrenheit or 800 degrees Celsius) to be channeled and made available for use, further increasing the efficiency of the system.“

AI Applications are Driving AI Data Center Power Needs

AI applications require much more electricity to operate, depending on the applications. AI training and inferencing drive power demand, “Wells Fargo is projecting AI power demand to surge 550% by 2026, from 8 TWh in 2024 to 52 TWh, before rising another 1,150% to 652 TWh by 2030. This is a remarkable 8,050% growth from their 2024 projected level. AI training is expected to drive the bulk of this demand, at 40 TWh in 2026 and 402 TWh by 2030, with inference’s power demand accelerating at the end of the decade. In this model, the 652 TWh projection is more than 16% of the current total electricity demand in the US.”

As IO Fund pointed out, “The Electric Power Research Institute forecasts that data centers may see their electricity consumption more than double by 2030, reaching 9% of total electricity demand in the US. The IEA is projecting global electricity demand from AI, data centers and crypto to rise to 800 TWh in 2026 in its base case scenario, a nearly 75% increase from 460 TWh in 2022. The agency’s high case scenario calls for demand to more than double to 1,050 TWh.”

Vistra Leverages Clean Energy Tax Credits and Incentives

Vistra currently does and could leverage many forms of energy credits to help squeeze every bit of margin. Its customers can also benefit from tax credits under these programs. Here are some of the most lucrative credits:

• The Inflation Reduction Act (IRS) of 2022 introduced a Nuclear Production Tax Credit (PTC) of up to $25 per megawatt-hour (MWh), which runs for 10 years through 2032 for facilities in service prior to January 1, 2023. The PTC kicks in went prices are below set limits. Vistra recognized a $545 million benefit from the nuclear PTC in Q4 2024.
• The Investment Tax Credit (ITC) was extended by the IRA through to December 31, 2024, under section 48, offering a 30% credit for projects started prior to then with up to four years to go online. New projects starting on January 1, 2025, and after shifts to section 48E, the Clean Electricity Production Credit, which applies to zero-emission projects through 2033
• The Clean Electricity Production Tax Credit (PTC) under section 48E replaced the traditional PTC with technology-neutral clean electricity PTC, which offers up to 2.75 cents per kilowatt-hour (kWh). Projects that begin construction before 2033 and meet wage/apprenticeship rules can receive the credit. Vistra can receive PTC for any upgrades (capacity increases) or new builds after 2025. It could have the potential for up to $50 million annually in solar and scaling higher with new projects. Vistra’s solar projects with Amazon (200 MW PPA) and Microsoft (405 MW PPA) are likely claiming the ITC of 30%, which covers installation costs. It’s 600 MW planned battery story planned in Texas also qualifies. Nuclear uprates could also apply if started post-2025.
• The Energy Community Tax Credit Bonus adds a 10% tax credit (10% points) to the existing ITC for projects in energy communities and areas with close coal plants/mines. Vistra operates in many former coal mining regions in Ohio, Pennsylvania and Texas.

The Trump administration has mentioned it plans to rollback many IRA provisions, which could cap or limit tax credits and incentives moving forward.

Financials: MTM Caused a Non-Cash Surge to Financial Metrics

Note that Q3 2024 shows a surge in net income to $3.465 billion, up 159% YoY from $1.335 billion in Q3 2023, driven primarily by unrealized mark-to-market (MTM) gains on derivative positions and the addition of Energy Harbor. This jolted various metrics, including gross and operating margins, GAAP EPS and gross profits. Still, since most of it was a non-cash gain, the operating cash flow didn’t surge proportionally. The mark-to-market gains were non-cash, but the addition of Energy Harbor gains were cash and are here to stay moving forward. Vistra expected $700 million in contributions from the Energy Harbor business for 10 months. The adjusted EBITDA excludes the impact of unrealized gains or losses on derivatives, which makes for a better measure of operating performance. CFO Moldovan clarified this in the Q4 conference call.

“Including the nuclear production tax credit, our adjusted EBITDA was more than $850 million above the midpoint and more than $600 million above the top end. Notably, the 10-month contribution from Energy Harbor, including the nuclear PTC, exceeded our $700 million expectation by approximately $200 million.”

Revenue is Lumpy, But The Energy Harbor Acquisition is Accretive

Q4 revenue rose 31.16% YoY but fell (35.8%) QoQ to $4.04 billion, beating the single analyst estimate by 3.2% or $124 million, driven primarily by the inclusion of results from the Energy Harbor acquisition and an increase in revenues due to the estimated nuclear PTC recorded in the quarter. The negative QoQ was primarily due to the surge in Q3 "driven primarily by unrealized mark-to-market gains on derivative positions."

Adjusted EBITDA from Ongoing Operations: Bypassing the MTM Noise  

Due to the MTM unrealized gains on derivatives, the adjusted EBITDA from the ongoing operations metric provides a more accurate picture of the operations. Q4 adjusted EBITDA from ongoing operations was $1.985 billion, up 104.2% YoY and 37.85% YoY. This was an improvement from Q3 adjusted EBITDA of $1.44 billion, down (10.73%) YoY and up 1.84% QoQ.

Net income for the full year 2024 increased by $1.32 billion, driven primarily by unrealized MTM gains on derivative positions, the addition of Energy Harbor and an increase in revenues due to estimated nuclear PTC recorded in Q4. Ongoing adjusted EBITDA for the full year 2025 increased $1.516 billion YoY primarily due to the inclusion of results from the Energy Harbor acquisition and estimated nuclear PTC recorded in Q4 2024. Full year 2025 adjusted EBITDA from ongoing operations was $5.656 billion. Management guided full year 2025 ongoing operations adjusted EBITDA of $5.5 billion to $6.1 billion, with the midpoint of $5.8 billion. Management has "high confidence" in an adjusted EBITDA midpoint opportunity above $6 billion in the full year 2026, as its hedge ratio has increased from 64% to 80% since Q3. 

The hedge ratio is the percentage of future (2026) expected electricity generation in megawatt hours (MWh) that is already locked in at a fixed price (IE, 80% is locked in at a fixed price) through derivatives like futures, options or swaps. The unhedged portion (IE: 20%) is exposed to market prices, which may rise, thereby raising EBITDA or potential fall and sinking EBITDA.

Margins: MTM and PTC Surge Q4 Improvement by 348.7%

Q4 gross margin was 39.6%, up 348.7% YoY and down (28.14%) QoQ, largely due to the MTM unrealized gains on derivatives, as mentioned earlier. The large YoY surge was due to the near doubling of gross profit to $1.6 billion in Q4 2024 compared to $850 million in Q4 2023, partially driven by the $545 million nuclear production tax credit (PTC), which reflects the full-year credit and the inclusion of results from the Energy Harbor acquisition. However, the jump was primarily based on a non-cash event, which investors shouldn't mistake for organic growth.

Lumpy Cash Flow as Debt Reaches Highest Level of 2024

Q4 cash flow reached $1.353B as operating cash flow rose to its highest level of five quarters at 33.5%. However, cash flow has been lumpy, ranging from $312 million in Q1 to a peak of $1.702B in Q3. Free cash flow closed Q4 at $923 million but was just as lumpy at ($153 million) in Q1, peaking at $1.017 billion in Q3 2024. Vistra closed Q4 2024 with $1.19 billion in cash and cash equivalents. The debt reached its highest level in five quarters, closing the year at $17.49 billion. Net debt to adjusted EBITDA is 2.9X. The Company plans on executing $2 billion in stock buybacks in 2025 and 2026.

Conference Call: Potential 10% Nuclear Capacity Increase by 2030

CEO Jim Burke reviewed 2024 events, including acquiring three nuclear sites and 1 million retail customers. They also completed a 20-year license renewal for the Camanche Plant nuclear power plant and secured Amazon and Microsoft PPA agreements with its renewables pipeline. The pre-Q&A can be summed up with the following:

• Vista is in the early stages of the development of two natural gas peakers, power plants using natural gas during high demand periods, "peak times," totaling up to 860 MW of capacity. They are targeting mid-2028 for commercial operations.
• Vistra continues to execute its zero-carbon growth strategy by leveraging existing land and interconnections to develop solar and energy storage projects opportunistically. They brought two solar and energy storage facilities online at its Coffeen and Baldwin, Illinois, sites. These facilities are part of the Illinois coal-to-solar and energy storage initiative. Vistra has begun construction of its Oak Hill, Texas, site for its contract with Amazon and the Pulaski, Illinois, site for its contract with Microsoft. Once they go online, it will add more than 600 MW of renewable capacity to Vistra’s portfolio.
• Vistra has engineering studies in process with initial estimates indicating the potential uprates across their nuclear fleet of nearly 10%. Uprates increase a nuclear plant's power output without having to build new reactors. This can be performed with technology upgrades and improved turbines. It means they have the potential to add an extra 640 MW of additional capacity to their portfolio by the early 2030s when they expect to go online. This could equate to an extra $258 million a year at $50/MWh x 5.16 TWh, and even higher towards $361 million annually, with hyperscaler PPAs paying a premium of $70/MWh.
• Texas policymakers are concerned about grid reliability and the challenges of accommodating rapidly growing energy demand, particularly from AI data centers. Despite these concerns, market reforms to incentivize new generations have been limited, raising worries among both generators and large-load customers, including data centers. While it's unclear if data center customers will alter their decisions during ongoing legislative discussions, there are potential solutions.
• Vistra plans to spend $700 million on solar and energy storage products in 2025, which includes solar projects for Amazon and Microsoft.

Q&A: Gas Power Plants and Nuclear Plants for Data Centers

Analysts had tunnel vision during the Q&A; data centers. Right off the bat, Management was asked about the primary impediment to getting the deal done with the hyperscalers. CEO Burke responded that it’s not as easy as just signing a contract. The “flavor of the deal” matters.

Burke assured, “So you can assume that we're speaking to all the major hyperscalers and that we're actively engaged with them and the major data center developers. But there are flavors of complexity. So, the virtual PPA, which would be a front-ended leader, would be a relatively straightforward deal to execute. We have a number of discussions going on with those. Those do not offer, we think, the same margin potential as the more complicated deals, which do involve co-location, whether it's with existing assets or new assets.”

Burke further elaborated on co-location deals (colo-deals), which include risk-sharing for 10 to 20 years.

“And you've seen not many deals have been announced that have actually been co-location related. We think colo-deals offer a lot of benefits for not only the data center customer and our fleet but the market overall — the overall customer base because it not only provides speed to market for the customer but can also result in more transmission build-out that the grid absorbs today.”

Front-of-the-meter (FTM) power purchasing agreements (PPAs) with data centers are a lower-margin product. Burke elaborated that the highest margins come for co-lo deals offering speed to market using an existing resource. Burke noted that the sweet spot is understanding their value proposition.

The complexity of these deals has sparked elevated discussions in regulatory and policymaking circles, with FERC and Texas recently addressing co-location issues. As customers seek clarity on the rules, the timing of any announcements will depend on the resolution of these regulatory discussions in PJM and Texas. Although front-of-the-meter virtual PPAs are still a possibility, co-location deals—where the load and generation asset are close—remain the ideal. The company is actively engaging in these discussions and is optimistic about progress, though further clarity is needed before any deals are finalized. Burke said the Comanche Peak opportunity is considered the most attractive and fastest to execute in its portfolio.

Status of Gas Power Plants for Co-Located Data Centers 

Morgan Stanley analyst David Arcaro asked about the prospects of potential gas co-location. Vistra Head of Strategy Stacey Dore started by saying they are seeing interest in their existing gas sites from data center developers at this point. Since a grid connection is typically needed at a gas power plant, the regulatory approval process applies even for a front-of-the-meter interconnection, which adds more time and complexity, especially when adding batteries and other backup generators to replicate reliability. Their gas lines don’t have as much land associated with them as a nuclear site, so the challenge of where to build the data center exists but continued to say:

 “Having said that, we're progressing on a lot of those conversations on a handful of our sites in detail, working on agreements to bring those projects to fruition. And in addition to that, we are in a number of conversations about building new gas for data centers as well. So we have a number of conversations going on that are at the papering stage. And as Jim referenced earlier, those agreements can be complex, but we are optimistic about our ability to bring those projects to a close.”

CEO Burke believes a cap and floor and likely to be approved in the next two auctions. While some worry about the grid doubling by 2030, Vistra anticipates a more moderate peak demand growth in the 3% to 5% range rather than double-digit increases.

Talen/Amazon Deal will Set Tone for AI Data Centers and Colocation

The Talen and Amazon deal highlights the resource adequacy issue, sparking a conversation about whether co-location or transmission charges should be addressed. While co-location helps minimize strain on the electrical grid as electricity is funneled directly to the data center bypassing the grid, critics argue it actually deprives consumers of capacity while shifting transmission costs to them unfairly. American Electric Power (AEP) and Exelon made the case that Amazon was getting a “free ride” by co-locating adjacent to Talen’s Susquehanna Nuclear Power Plant and shifting up to $170 million in grid costs to their customers, while depriving them of electric capacity.

Vistra supports efforts to require customers larger than 75 MW to shed load during critical peak hours, and the customers they’re talking to are preparing their designs for this. But when the talk of remote disconnect switches arises, it's unusual and only would exist for these customers, which gives them pause.

Are Microgrids and Off-Grid Energy Servers the Solution?

Shedding loads during critical peak hours could be done through micro-grids. As IO Fund wrote in Bloom Energy: Fuel Cells for the Booming AI Data Center Trend Bloom Energy: Fuel Cells for the Booming AI Data Center Trend in the Discovery Tier, Bloom energy servers (BES) can be stacked. “The 325 kW base blocks can be duplicated and scaled up to multiple MWs for any project. They can also be used as the primary power source. They can be used off-grid or parallel as a microgrid. BES has a high density of 100 MW per acre.” The ideal has gained traction as evidenced by the game changer deal made with Bloom Energy and American Electric Power (AEP) to procure up to 1GW of Bloom’s solid-oxide-fuel-cells (SOFCs) for their hyperscaler customers.

Customers Waiting on Transmission Charges

Burke insists customers need clarity on transmission charges, which was a big choking point with Amazon and Talen. Amazon claims they shouldn’t have to pay transmission fees since their data center is co-located adjacent to Talen Energy’s Susquehanna nuclear plant. The data center would be powered behind the meter directly from the nuclear plant, bypassing the grid. However, FERC rejected the amended interconnection service agreement (ISA) to increase to 480 MW with a potential up to 960 MW. American Electric Power (AEP) and Exelon argued that diverting that much power would reduce the electricity available to the 65 million residents in the regional PHM grid, which could destabilize the grid, and shift up to $140 million in costs onto other ratepayers, essentially giving Amazon a "free ride." The case could set a precedent with co-location agreements around the country. Burke said this:

“They just want to know, are they going to get something that's commensurate with the transmission and grid utilization. These are revisiting potentially of the four coincident peak methodology. That probably does need revisiting because some customers are able to either reduce their load or turn on back up and minimize their transmission exposure, which means those costs go to other customers, including potentially residential customers. And since we serve nearly 5 million customers, we're sensitive to that as well.”

Seaport analyst Angie Storozynski bluntly asked management why they hadn't heard of any gas deals. Dore stated the co-location deals with existing assets are waiting on regulatory clarity as well. Whether gas or nuclear, regulatory clarity is what customers are waiting on.

“I mean the same uncertainty that is applying to behind-the-meter or co-located deals in PJM, for example, with the FERC proceedings, would apply whether the asset is nuclear or gas. Because the question really that's being asked is, what is the transmission charge, if any, that has to be paid on those deals.”

Vistra Expects FERC Clarity in the Second Half of the Year

Dore explained that Vistra isn’t waiting for full clarity from FERC or Texas before announcing deals, but ongoing legal proceedings (Amazon/Talon) are raising questions around risks like changing laws. The company is continuing work on projects like Beaver Valley and Comanche Peak, progressing without pause despite regulatory complexities. Jim Burke added that while co-locating load with plants raises concerns about grid adequacy, the company believes that co-location can benefit the grid by reducing transmission build-out and enhancing efficiency. Customers want to be seen as contributors to economic development, and co-location offers a faster market entry.

Despite regulatory delays, the company remains committed to advancing these discussions. Dore further noted that FERC's recent order sets a positive timeline for co-location and recognizes that there is no resource adequacy difference between front-of-the-meter and behind-the-meter loads. The challenge lies in balancing the customers' desire for fast deployment with policymakers' concerns about grid stability. The company hopes for clarity from FERC within the next 5-6 months to move co-location projects forward.

Conclusion:

Vistra is technically a utility company. Historically, these stocks have been considered defensive income plays due to their stagnant growth and consistent dividend yields. The AI boom has triggered interest in utility company stocks on a convincing thesis that power consumption is the chokepoint with AI. Utility companies will make more money with the explosion of power consumption driven by AI driven by data centers.

For utility companies, there are a number of ways to grow: acquisition (IE: Energy Harbor), rising energy prices (rate hikes), increasing capacity (uprates), increasing customers (IE: Energy Harbor = one million new customers), regulatory incentives (PTC, ITC, CEPTC, ECTC), cost reductions and new service offerings (co-lo). Co-location is the highest margin option with hyperscalers, but they are waiting on the Amazon/Talen FERC ruling in 2H 2025 to set a precedent on transmission fees and whether co-located data centers have to pay their share for grid maintenance and upgrades even without using the grid.

Vistra confirmed they are in talks with hyperscalers for co-location and new builds. However, they haven’t announced any nuclear PPAs so far or named the two hyperscalers getting gas plants. Announcements with hyperscalers will be a catalyst for the stock. Despite the stock being up 87% on a trailing twelve-month basis, the P/E is reasonable at 15.56.

Vistra was just a normal utility company until its announced the completion of the Energy Harbor acquisition on March 1, 2024, adding three nuclear plants and one million additional customers, this sent the stock surging from the $54.69 level gaining momentum on the AI data center “halo” as the markets turned to power producers as the next growth segment. Vistra announced Q2 earnings on August 8, 2024, revealing the two long-term PPA with Amazon and Microsoft, which were the first major hyperscalers they contracted. This sent VST stock on an upward trajectory from $80.46 to a peak of $199.84 on Jan. 23, 2025, just before the Q4 2024 earnings results, which triggered the downward trajectory as the Company only has two hyperscaler under contract (AMZN, MSFT), but are in talks with two hyperscalers for co-located gas plants. Investors put the cart in front of the horse, but shares are pulling back in time for the reveal of some more hyperscaler PPA news.

Investors should see how the stock reacts to announcements with hyperscalers, as it will either put in a new floor on the stock price or trigger a sell the news reaction as the AI “halo” dissolves. For now, it’s a waiting game for announcements and regulatory decisions.

Welcome to the I/O Fund’s new Discovery Tier, where we cover a new stock idea on a weekly or bi-monthly basis. We are excited to bring you more coverage from the I/O Fund team geared toward new idea generation only.

Jea Yu, Equity Analyst at the I/O Fund, contributed to this article.

Please note: The I/O Fund conducts research and draws conclusions for the Fund’s positions. We then share that information with our readers. This is not a guarantee of a stock’s performance. Please consult your personal financial advisor before buying any stock in the companies mentioned in this analysis.

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