Who Pays When the Hyperscaler Leaves
Your utility is planning a grid several times its current size to serve data centers. If that buildout gets socialized, your rate base absorbs decades of infrastructure you never asked for. Here is how to see it and press on it.
Who this is for
- ■Hospitals and health systems that cannot relocate around a rate change
- ■Industrial manufacturers where power is a material share of operating cost
- ■Universities and campus operators served by a utility with a large data center pipeline
- ■Multi-site retail and logistics operators exposed to a FERC-jurisdictional RTO
- ■Any C&I operator whose monthly bill runs five, six, or seven figures
Should you intervene in upcoming rate cases or IRP proceedings to prevent hyperscale buildout costs from landing on your bill, and when does that risk justify self-supply or relocation?
A utility incurs long-lived capital costs, generation, transmission, distribution, to serve a contracted large load. Those assets are recovered over 40 years or more. The large load signs a shorter contract, then downsizes, relocates, or fails. The remaining undepreciated cost does not disappear. It flows to whoever is left on the system.
If a hospital, a manufacturer, or a university cannot pick up and move, that is a direct rate exposure. Power Advisory frames the threshold as medium-to-long term, meaning greater than 10 years: if a load diminishes or disappears past that point, the residual cost flows to ratepayers who did not cause the expansion, or to the utility's shareholders.
32%of this guide, read. The rest of it is below.
- 02 The mechanism at scale What Makes This Moment Different
The scale of forecast large-load demand is unlike anything utility planners have modeled in recent decades. The International Energy Agency attributes 10% of global electricity demand growth to 2030 to data centers, and more than 20% of the growth in advanced countries.
Utility pipelines against current peakAEP Ohio is planning to serve demand more than three times its current peak. These are not theoretical numbers. Georgia Power's large-load pipeline, predominantly data centers, grew from 16 GW to more than 34 GW, roughly doubling in two years. IRPs being filed right now are built around these numbers, and those capital programs are what your rates absorb if cost allocation rules do not hold.
Power Advisory is direct about the two-way outcome. If new load driving grid-wide expansion is fully allocated the costs, existing customers face little impact. If the new load diminishes or disappears over the medium and long term, greater than 10 years, those costs flow to ratepayers who did not cause the expansion, or to utility shareholders.
Analytical forkThe two scenarios your rate case has to distinguish
Scenario ASpare capacity is being filled
Grid was overbuilt from a period of flat demand. Adding load spreads fixed costs over more units. Existing customers can see lower per-unit rates. No new large capital being committed.Scenario BNew buildout is being triggered
The IRP is adding generation and transmission line items beyond existing reserve margins, driven by the large-load pipeline. New capital committed against a contracted load that may or may not stay to pay it off.If the utility is in Scenario B and its tariff does not obligate the large load to cover the grid-wide costs, the exposure sits on remaining customers. In jurisdictions like Ontario, where many fixed generation costs are recovered through a mechanism allocated predominantly to small-volume customers, the stranded asset risk is even more severe.
- 03 What lands on you Where the Residual Cost Actually Goes
Power Advisory is direct about the two-way outcome. If new load driving grid-wide expansion is fully allocated the costs, existing customers face little impact. If the new load diminishes or disappears over the medium and long term, greater than 10 years, those costs flow to ratepayers who did not cause the expansion, or to utility shareholders.
Analytical forkThe two scenarios your rate case has to distinguish
Scenario ASpare capacity is being filled
Grid was overbuilt from a period of flat demand. Adding load spreads fixed costs over more units. Existing customers can see lower per-unit rates. No new large capital being committed.Scenario BNew buildout is being triggered
The IRP is adding generation and transmission line items beyond existing reserve margins, driven by the large-load pipeline. New capital committed against a contracted load that may or may not stay to pay it off.If the utility is in Scenario B and its tariff does not obligate the large load to cover the grid-wide costs, the exposure sits on remaining customers. In jurisdictions like Ontario, where many fixed generation costs are recovered through a mechanism allocated predominantly to small-volume customers, the stranded asset risk is even more severe.
RMI reviewed 65 tariffs state-level large load tariffs and identified five categories of protection. Every one of them has a design vulnerability. The utility can check every box and still leave you holding the cost.
How often each protection appearsCollateral is the most common protection; capacity reassignment is the least. Frequency is not effectiveness. Protection Benchmark on the page What to press on Minimum contract term Kentucky Power sets a floor of the length in the rail note for loads at or above the Kentucky Power load threshold. A term shorter than the asset recovery period leaves the back half of the capital unprotected. Minimum monthly billing demand Indiana Michigan Power: greater of the contracted floor share or the highest demand over the lookback period. A percentage floor on an underpriced demand charge does not close the cost recovery gap. Collateral Dominion GS-5: posted per MW of contracted capacity, reducible for creditworthy customers. Does the posted amount actually cover the incremental capital committed to serve that load? Exit fees AEP Ohio: fee equal to a fixed number of months of minimum charges, only after year five, with three years notice. Is the fee sized against uncommitted capital, or just against forward billed revenue? Capacity reassignment Appalachian and Wheeling Power: up to the reassignment share may be transferred without penalty. Assumes a replacement load exists and qualifies. Not automatic protection. - 04 The trap in the tariff Every Protection Has a Design Vulnerability
RMI reviewed 65 tariffs state-level large load tariffs and identified five categories of protection. Every one of them has a design vulnerability. The utility can check every box and still leave you holding the cost.
How often each protection appearsCollateral is the most common protection; capacity reassignment is the least. Frequency is not effectiveness. Protection Benchmark on the page What to press on Minimum contract term Kentucky Power sets a floor of the length in the rail note for loads at or above the Kentucky Power load threshold. A term shorter than the asset recovery period leaves the back half of the capital unprotected. Minimum monthly billing demand Indiana Michigan Power: greater of the contracted floor share or the highest demand over the lookback period. A percentage floor on an underpriced demand charge does not close the cost recovery gap. Collateral Dominion GS-5: posted per MW of contracted capacity, reducible for creditworthy customers. Does the posted amount actually cover the incremental capital committed to serve that load? Exit fees AEP Ohio: fee equal to a fixed number of months of minimum charges, only after year five, with three years notice. Is the fee sized against uncommitted capital, or just against forward billed revenue? Capacity reassignment Appalachian and Wheeling Power: up to the reassignment share may be transferred without penalty. Assumes a replacement load exists and qualifies. Not automatic protection. On June eighteenth, twenty twenty six, FERC issued 6 orders under Section 206 of the Federal Power Act, directing each of the six FERC-jurisdictional RTOs and ISOs to justify or reform their large load interconnection rules. The orders affect 200 million across more than 30 states and cover nearly two-thirds of jurisdictional load.
The window that matters21daysTo intervene on each order5categoriesReform categories in scope200millionAmericans affectedThis is the single most time-sensitive item in the guide. The record built here drives the next phase of reform.FERC preliminarily found existing tariffs unjust and unreasonable because they lack a pro forma cost recovery agreement, and stated that such an agreement should likely be based on the amount of jurisdictional transmission service in megawatts requested to serve the large load. That preliminary finding is the standing that lets intervenors press for stronger cost recovery.
- 1 Confirm whether your facility is in one of the six FERC-jurisdictional RTOs or ISOs covered by the June show cause orders.
- 2 Identify the docket for your region and note the intervention window in the order itself.
- 3 Have counsel or an industrial customer coalition file to intervene within that window, not after the RTO's initial compliance filing.
- 4 In the compliance record, press specifically on category two: preventing cost shifting through financial security and credit requirements, and transparency into transmission costs.
- 5 In parallel, review your utility's next rate case and IRP for the retail-side tariff provisions covered in Part Four.
- 05 Your leverage The FERC Window and What to Ask For
On June eighteenth, twenty twenty six, FERC issued 6 orders under Section 206 of the Federal Power Act, directing each of the six FERC-jurisdictional RTOs and ISOs to justify or reform their large load interconnection rules. The orders affect 200 million across more than 30 states and cover nearly two-thirds of jurisdictional load.
The window that matters21daysTo intervene on each order5categoriesReform categories in scope200millionAmericans affectedThis is the single most time-sensitive item in the guide. The record built here drives the next phase of reform.FERC preliminarily found existing tariffs unjust and unreasonable because they lack a pro forma cost recovery agreement, and stated that such an agreement should likely be based on the amount of jurisdictional transmission service in megawatts requested to serve the large load. That preliminary finding is the standing that lets intervenors press for stronger cost recovery.
- 1 Confirm whether your facility is in one of the six FERC-jurisdictional RTOs or ISOs covered by the June show cause orders.
- 2 Identify the docket for your region and note the intervention window in the order itself.
- 3 Have counsel or an industrial customer coalition file to intervene within that window, not after the RTO's initial compliance filing.
- 4 In the compliance record, press specifically on category two: preventing cost shifting through financial security and credit requirements, and transparency into transmission costs.
- 5 In parallel, review your utility's next rate case and IRP for the retail-side tariff provisions covered in Part Four.
When to engage, when to hold
✓ Intervene now- The IRP shows generation or transmission buildout beyond existing reserve margins, driven by a large-load pipeline.
- Large load contract terms in the tariff are materially shorter than the asset recovery periods for that buildout.
- Your facility sits in a FERC-jurisdictional RTO or ISO covered by the June show cause orders.
- The utility has no separate large load tariff, or its provisions lack collateral, exit fees, or a meaningful minimum billing demand.
- Electricity is a material share of your operating cost and a rate case is filed or expected.
✗ Hold and monitor- Collateral, exit fees, and contract terms together bound the residual risk to a level disclosed and manageable in the tariff filing.
- The utility is genuinely filling spare capacity and the IRP does not show new capital tied to the pipeline.
- Your facility is outside FERC-jurisdictional RTO territory and your state has already opened a large load proceeding you are tracking.
- Electricity is a small share of operating cost and modeled rate increases would not change your competitive position.
- Decision matrix
When to engage, when to hold
✓ Intervene now- The IRP shows generation or transmission buildout beyond existing reserve margins, driven by a large-load pipeline.
- Large load contract terms in the tariff are materially shorter than the asset recovery periods for that buildout.
- Your facility sits in a FERC-jurisdictional RTO or ISO covered by the June show cause orders.
- The utility has no separate large load tariff, or its provisions lack collateral, exit fees, or a meaningful minimum billing demand.
- Electricity is a material share of your operating cost and a rate case is filed or expected.
✗ Hold and monitor- Collateral, exit fees, and contract terms together bound the residual risk to a level disclosed and manageable in the tariff filing.
- The utility is genuinely filling spare capacity and the IRP does not show new capital tied to the pipeline.
- Your facility is outside FERC-jurisdictional RTO territory and your state has already opened a large load proceeding you are tracking.
- Electricity is a small share of operating cost and modeled rate increases would not change your competitive position.
Questions for your morning huddle- Does our utility's current IRP show generation or transmission buildout that exceeds existing reserve margins, and has anyone on our team read what is driving it?
- For the large loads our utility already serves, are the contract term, collateral, and exit fee sized against the actual infrastructure being committed, or do they leave a material residual gap?
- Are we in a FERC-jurisdictional RTO covered by the June show cause orders, and has anyone identified the docket where the cost allocation rules will be written?
- If our electricity cost is a material share of operating cost, at what rate increase does relocation or self-supply become worth modeling?
The one thing to rememberThe tariff protections are only as strong as the numbers behind them. Presence of a provision is not the same as coverage against the buildout being committed on your behalf.
This week, pull your utility's most recent IRP and its large load tariff, if one exists. Mark every provision from Part Four and write down the specific number behind it. Bring the gaps to your next operations or finance review.
Know if the numbers actually pencil out before you sign anything.
A written second opinion on the project in front of you, whether that is a rate change, new equipment, or a renewable installation.
- 01A short call, to figure out quickly whether we can actually be helpful. If we can't, we'll say so on the spot.
- 02We pull the data, your bills, your rate structure, vendor proposals, project specs.
- 03You get the verdict in writing: whether the payback will materialize, and the opportunities or risks nobody has raised.
Get a Blueprint at blueprint.tac-nrg.com Free for Indiana-based operations spending five figures or more a month on electricity. No obligation. You keep the write-up either way. - The one thing to remember
The tariff protections are only as strong as the numbers behind them. Presence of a provision is not the same as coverage against the buildout being committed on your behalf.
This week, pull your utility's most recent IRP and its large load tariff, if one exists. Mark every provision from Part Four and write down the specific number behind it. Bring the gaps to your next operations or finance review.
The Energy Decision BlueprintKnow if the numbers actually pencil out before you sign anything.
A written second opinion on the project in front of you, whether that is a rate change, new equipment, or a renewable installation.
- 01A short call, to figure out quickly whether we can actually be helpful. If we can't, we'll say so on the spot.
- 02We pull the data, your bills, your rate structure, vendor proposals, project specs.
- 03You get the verdict in writing: whether the payback will materialize, and the opportunities or risks nobody has raised.
Get a Blueprint at blueprint.tac-nrg.com Free for Indiana-based operations spending five figures or more a month on electricity. No obligation. You keep the write-up either way.- Sticky ratepayer
- A customer, typically a hospital, manufacturer or campus, who cannot relocate to escape a rate outcome and therefore absorbs residual system cost when a large load exits.
- Cross-subsidy
- The reallocation of costs incurred to serve one customer or class to a different customer or class, usually because the causing party is not paying the full cost of service.
- Stranded asset
- Grid capital that has been built to serve a specific load but is not fully recovered from that load, leaving the residual to be paid by remaining ratepayers or utility shareholders.
- IRP
- Integrated Resource Plan. The utility's forward-looking filing describing expected demand and the capital it plans to commit to meet that demand.
- Rate case
- A regulatory proceeding at a state public utility commission where the utility proposes rates and cost allocation and interested parties can intervene to contest them.
- RTO or ISO
- A Regional Transmission Organization or Independent System Operator. Runs the wholesale grid across multiple utilities and files rules with FERC under jurisdictional tariffs.
- Show cause order
- A directive from a regulator, here FERC under Section two hundred six, requiring a party to justify existing rules or file reforms. FERC issued a set targeting large load interconnection in June twenty twenty six.
- Minimum billing demand
- A tariff provision that sets a floor on the demand a customer is billed each month regardless of actual use, so a large load keeps paying if it consumes less than contracted.
- Pro forma cost recovery agreement
- A standard-form contract, referenced in FERC's show cause orders, that would allocate the cost of expansions based on the megawatts of jurisdictional transmission service the large load requests.