Who Pays for Colorado’s Power Boom? Inside Xcel’s High-Stakes Tariff Fight

Colorado is deciding who carries the financial risk of its next wave of electricity-intensive development. Xcel Energy’s proposed large-load tariff reached evidentiary hearings beginning October 21, bringing the costs of data centers and other major customers before the Public Utilities Commission in proceeding 26AL-0137E. The Colorado Sun’s October 21 report

The stakes extend from household electricity bills to the location of factories, the financing of solar and battery projects, and the feasibility of new data center campuses. A major customer can require new generation, transmission and substations. Those investments can remain on the utility’s books long after a developer changes its plans.

Xcel proposes placing substantial responsibility for that infrastructure on the customer creating the demand. Contract length, cost allocation, financial security and an expedited custom-contract process remain disputed. The case is still underway as of October 26; the proposed terms discussed here are subject to the commission’s decision.

The central development question is whether a project can secure reliable electricity on a workable schedule and carry the full cost of the commitment. That question now belongs near the beginning of a land search.

What is Xcel’s large-load tariff?

A large-load tariff sets the rates, service conditions and financial obligations for customers with unusually large electricity requirements. Xcel’s Colorado proposal generally covers new customers or incremental expansions of at least 50 MW, with some new customers between 20 and 50 MW potentially included. The PUC’s public summary identifies transmission lines, substations, interconnection upgrades and new generation among the costs those customers would cover. PUC proceeding summary

Xcel also proposes minimum monthly payments, long-term agreements, financial security and termination protection. These provisions are intended to keep infrastructure costs from shifting to existing customers if a project opens slowly, shrinks or fails. Xcel’s April 2 announcement

The proposal reaches beyond data centers. A sufficiently large new industrial customer or expansion could fall within its scope. Final eligibility language, including the treatment of related facilities and service arrangements, will determine how it applies to individual projects.

What are the parties fighting over?

They disagree about how much commitment a large customer should make and how much flexibility it should receive. The Colorado Sun reported proposed contract terms of 15 years from Xcel, 20 years from PUC staff and 10 years from the Data Center Coalition. It also described a dispute over confidential custom contracts and Xcel’s proposed 120-day review process. The Colorado Sun

The issues have concrete development consequences:

Longer terms can improve cost recovery while making a project harder to finance. Shorter terms can fit a tenant’s commitments while leaving more infrastructure risk to resolve. The commission has to evaluate those consequences together.

The custom-contract dispute deserves close attention. Xcel says flexibility is necessary for these customers and that its core commercial protections would remain. Consumer advocates question whether a compressed review and confidential information provide sufficient scrutiny. The Colorado Sun’s account of the testimony

Why can one development require so much grid investment?

A large facility needs both electricity supply and a network capable of delivering it under the required operating conditions. A shortage at either level can delay service.

The U.S. Energy Information Administration explains the delivery chain: generation produces electricity, transmission moves it over long distances, substations change voltage, and distribution carries power to many homes and businesses. Very large industrial customers may connect at transmission voltage.

For a development team, that chain creates several separate questions:

1. Generation: What resources supply the new energy demand and meet reliability requirements?
2. Transmission: Can the high-voltage network deliver the requested power, including during relevant equipment outages?
3. Substations and connection facilities: What transformers, switching equipment, protection systems and land are needed?
4. Distribution: For projects served through local circuits, can the feeders and local equipment accommodate the load?

The utility studies the proposed connection within a larger system. A nearby line’s voltage describes an electrical characteristic. The available service depends on network conditions, existing commitments, equipment and the project’s schedule.

That is why a map showing a 345-kV line beside a property cannot establish an energization date. LandmAIn’s infrastructure screening methodology records proximity as an early research input and identifies the provider evidence needed next.

Colorado’s upgrades create opportunities on different schedules

Several major projects are already changing the state’s electrical network. Their benefits and delivery dates need to be evaluated separately from the tariff proceeding.

Colorado’s Power Pathway is a roughly $1.7 billion transmission investment spanning 12 counties. Xcel’s current project page describes approximately 550 miles of new double-circuit line. Segments 1, 2 and 3 are in service, while segments 4 and 5 have 2027 in-service schedules. The project links Eastern Plains resources with the Front Range. Official Power Pathway project description

Denver Metro Transmission Upgrades address the existing metropolitan network. Xcel reports a January 2, 2026 certificate of public convenience and necessity and construction scheduled across 2026–2032. The program supports integration of new resources and system reliability across multiple metro counties. Xcel’s Denver Metro overview and schedule

High Plains Solar + Battery Energy Storage adds a generation-and-storage example. Xcel announced a $685 million Morgan County project with 250 MW of solar and 200 MW of battery capacity. Its June announcement targeted December 2027 operation and a connection to Canal Crossing Substation on Power Pathway. Xcel’s High Plains announcement

These projects make infrastructure timing a meaningful part of site selection. A location might benefit from a completed line while still depending on a future substation or a separate customer connection. Another project may be able to start with a smaller phase while later improvements proceed.

A developer’s schedule should identify the particular facilities it needs. A regional completion date supplies only part of that answer.

How do new developments stress the grid?

Stress arises when demand, supply and delivery capability fail to align in place or time. Growth can increase energy consumption across the year, increase the highest demand the system must serve, and create concentrated pressure at individual network locations.

The Department of Energy’s 2026 draft National Transmission Needs Study identifies data centers, manufacturing, large industrial loads and electrification as drivers of additional transmission needs. It also emphasizes interregional connections and congestion relief. DOE’s July 2026 findings

The local consequences depend on the operating pattern. A continuous industrial process creates a different load profile from a fleet depot that charges many vehicles together. A cold-storage facility must manage refrigeration while preserving temperature limits. A housing development adds a different mix of heating, cooling and vehicle charging.

The same megawatt figure can therefore imply different annual energy use and different pressure during system peaks. For an illustrative 100 MW facility operating continuously at full demand, annual consumption is 876,000 MWh: 100 MW multiplied by 8,760 hours. A facility with the same peak but half that average demand uses 438,000 MWh. These are arithmetic examples, not forecasts for named projects.

Supply planning is already a live Colorado issue. In its summer newsletter, the PUC described Xcel’s separate 2027–2028 resource-adequacy application, covering measures such as demand response, accelerated generation, plant repairs, power purchases and a proposed extension of Comanche Unit 2 operations. The newsletter describes the requested measures at the application stage. PUC summary of proceeding 26A-0235E

What does this mean for data center developers?

Power economics can determine whether a site survives diligence. The relevant budget includes the cost of connection, the ongoing service obligation and the financial exposure if buildings or tenants arrive late.

Xcel’s investor summary of its Colorado proposal lists a 15-year minimum term, an 80% minimum demand-charge provision, credit requirements and notice requirements for reducing capacity or ending service. These are proposed terms. Xcel’s May 2026 investor presentation, page 51

Consider a simplified 100 MW commitment under an 80% billing-demand floor once fully applicable:

At a hypothetical demand rate of $10 per kW-month, 80 MW produces an $800,000 monthly demand charge. Actual billing depends on the approved tariff, contract, ramp provisions and other charges. The example excludes energy purchases, taxes and other bill components; $10 is an illustrative input, not a quoted Xcel rate.

The exposure is easy to miss when a site is marketed by its ultimate campus capacity. A project may need years to reach that demand. Its tenant leases, financing and utility commitments should reflect the same phased operating plan.

Our earlier Xcel tariff analysis explains load factor and contract utilization in more detail. For a new comparison, give every candidate the same load ramp, then evaluate the delivery schedule, required investment and contractual obligations at each location.

Vantage’s search for another Trident site makes the issue concrete. Moving a large project farther from homes also requires re-evaluating how electricity reaches the replacement property and when the resulting obligations begin.

How could other industries be affected?

Large industrial projects could face direct tariff obligations if they meet the final eligibility rules. Smaller businesses can be affected by the same network investment, connection schedules and cost-allocation decisions even when they fall outside the special tariff.

Manufacturers need to compare electric service with equipment commissioning and production contracts. A plant that commits to capacity before a production line is ready can face a mismatch between payments and operating revenue.

Cold-storage operators need to evaluate both continuous refrigeration and peak conditions. Fleet-charging developers need realistic vehicle schedules, charger utilization and simultaneous demand. Hospitals and research campuses need service quality and resilience suited to their operations.

For residential and mixed-use developers, local distribution capacity remains important. A subdivision’s electric heating and charging plans can change the required transformers and circuits. Those projects need a utility delivery plan even when their demand is well below the large-load threshold.

This broadens the land question. Parcels should be compared against the particular facility’s operating requirements. A site well suited to one type of industrial demand may require a different connection or substantial additional work for another.

Can solar and batteries ease the pressure?

Yes. Solar adds energy supply, and batteries can shift electricity to more useful hours or provide grid services. The value depends on where the resources connect, when they operate and how long stored energy lasts. EIA’s guide to electricity storage

Solar output varies with sunlight. Batteries need an energy source for charging and lose some energy in the storage cycle. A reliable supply plan must account for those characteristics alongside the customer’s operating requirements.

Battery power and battery energy measure different capabilities. MW describes output capability; MWh describes stored energy. In a simplified example, a 100 MW / 400 MWh battery can supply its rated output for four hours before accounting for operating limits and losses. A continuous 100 MW load uses 2,400 MWh over 24 hours. EIA’s explanation of battery ratings and duration

That creates substantial opportunities for storage developers while keeping the engineering question specific. A battery can help cover a defined peak, support a constrained connection under an approved arrangement, or shift solar generation into evening hours. The proposed charging schedule also needs review because charging itself draws power.

The tariff proceeding includes a Clean Transition Tariff proposal. In filed testimony, Rewiring America and the Southwest Energy Efficiency Project argue for broader eligibility for clean and demand-side resources, with measurable incremental system value and protections against double counting. That is a participant’s recommendation before the PUC. Hearing Exhibit 1100

For developers, the opportunity is to match a load with resources that deliver value at the required hours and location. A solar contract, storage installation and grid connection each need to be evaluated within that combined plan.

Flexible demand can make infrastructure go further

Customers that can adjust consumption may help the system manage constrained hours. The Department of Energy identifies efficiency, demand flexibility, generation, storage and grid improvements as complementary tools for serving growth. DOE’s resource overview

The practical limit is the customer’s operation. Some computing tasks can move in time or between locations; others have strict service requirements. A factory may shift selected processes while keeping essential equipment running. Fleet charging can sometimes be staggered around departure times.

A useful flexibility proposal states how many megawatts can be reduced, how much notice is needed, how long the reduction can last and how consumption returns afterward. The utility must be able to rely on the commitment when it assigns value to it.

Customers should evaluate flexibility before sizing the final service request. It may influence equipment choices, operating schedules and contractual options. Any assumed benefit needs confirmation in the applicable service arrangement.

Will the tariff protect household and small-business bills?

It could improve protection by assigning costs and enforceable obligations to the customers creating them. The outcome depends on the final rules, individual agreements and implementation.

The difficult cases involve shared infrastructure and uncertain forecasts. A new substation may serve both a major customer and later development. A generation addition may meet several system needs. Regulators need a defensible basis for deciding which costs belong to the large customer and which benefit the broader system.

Financial security matters when a project disappears after equipment has been ordered or construction has begun. Minimum payments matter when infrastructure is ready but customer demand develops slowly. Contract review matters when a negotiated agreement changes the standard terms.

Well-designed rules can also support development by making obligations more predictable. Developers can price the commitment earlier, utilities can plan around stronger evidence of demand, and communities can examine the expected benefits alongside infrastructure costs.

Existing customers should expect evidence of cost recovery and enforceable protections. A large customer’s projected tax contribution and its electricity obligations should each be evaluated on their own terms.

What should a project team establish before committing to land?

Establish the proposed operating load, the serving utility, the connection concept and the financial assumptions that could change the site decision. Keep each answer tied to its source and date.

The initial work should produce:

• A phased demand schedule: first service, building additions, peak demand and expected annual consumption.
• A delivery assessment: necessary studies, connection facilities, network upgrades and dependencies.
• A commercial comparison: deposits, security, minimum payments, contract term and potential exit exposure.
• A supply and flexibility plan: generation, storage or demand measures the utility can evaluate.
• A land-use review: jurisdiction, current eligibility, surrounding development, usable area and required easements.

The LandmAIn map and opportunity profiles provide starting points for infrastructure and land research. Our development intelligence services organize the property evidence and the questions requiring utility or engineering confirmation.

For data centers, industry and energy developers, the next useful comparison is a site-specific one: the same project requirements tested against different locations, delivery schedules and power obligations. Send LandmAIn your use, load, timing and preferred geography to scope that work.

Frequently asked questions

Has Colorado approved Xcel’s large-load tariff?

The proceeding remains underway as of October 26, 2026. The contract terms and other provisions discussed here are proposals. The final commission decision and approved tariff will establish the governing requirements.

Does the proposed tariff apply only to data centers?

The proposal concerns very large electricity customers, including other industries. Xcel identifies new or expanded loads of at least 50 MW and possible coverage for some new 20–50 MW customers. Final eligibility and the specific service arrangement control applicability.

Does a new transmission line guarantee power for a nearby project?

No. The utility must evaluate the requested load, connection, system conditions, required upgrades and timing. A regional transmission investment can improve the network while a specific property still needs substantial connection work.

Can a battery reduce a project’s utility requirements?

Potentially, if its size, duration, charging strategy and operating controls support a utility-approved service arrangement. The analysis must account for the project’s full operating schedule and the battery’s recharge requirements.

Can LandmAIn compare sites affected by Xcel’s tariff?

Yes. LandmAIn can organize infrastructure, jurisdiction and property evidence alongside documented utility responses and commercial assumptions. We identify gaps that need provider confirmation so candidates can be compared on a consistent basis.

Can LandmAIn help solar, battery and industrial developers?

Yes. We can scope land and infrastructure research around those uses. Generation export, battery charging and discharge, and industrial consumption require different screening criteria. Provide the proposed use and operating requirements when requesting a review.

Does LandmAIn confirm available electrical capacity?

LandmAIn researches infrastructure context and tracks available evidence. The serving utility establishes project-specific capacity, upgrade requirements and service terms through its studies and agreements. Our work helps focus that inquiry and preserve the answers in the site record.