Distributed Capacity Procurement (DCP) emerged to solve a specific problem: utilities needed a way to add targeted, planning-grade capacity at the distribution level: faster than utility-scale projects, more reliable than demand response, and fully under utility operational control. That need hasn't changed. It's accelerating.
The grid was built for centralized generation and one-way power flow. Distribution infrastructure was designed to deliver electricity to customers — not to manage two-way flows, localized constraints, or the kind of load volatility that electrification and data center growth are now producing.
For most of utility history, when a distribution circuit got constrained, the answer was a capital upgrade: new transformers, new lines, expanded substations. Slow, expensive, and often more than the constraint actually required.
Demand response programs emerged as a lower-cost alternative — aggregating customer flexibility to shave peaks and defer upgrades. But demand response has limits. It depends on customer participation and delivers capacity that carries accreditation uncertainty — performing below committed levels when system stress is highest. For utilities under pressure to demonstrate hard capacity additions, it's a partial solution at best.
The question utilities were left with: how do you add reliable, accredited, distribution-level capacity — at the speed load growth actually requires?
That's the question DCP was built to answer.
Distributed Capacity Procurement is a utility-led model for deploying front-of-the-meter batteries and gensets as grid infrastructure. Assets are utility-owned, utility-dispatched, and control-room visible, typically 1-5 MW, sited at commercial, industrial, and nonprofit locations directly on the distribution grid.
DCP converts latent distribution capacity into commercially deliverable, utility-grade, transmission-accredited megawatts.
Each DCP follows a three-phase framework — Design, Deploy, and Dispatch — with first capacity available in 9-12 months and full program buildouts of 200-500+ MW achievable in 24-36 months. Sparkfund serves as a single deployment services partner managing site acquisition, permitting, engineering, construction, and vendor coordination under one contract, with 80%+ of every dollar competitively bid.
Load growth is outpacing what the grid was planned for. Electrification, EV charging infrastructure, and data center expansion are stressing distribution circuits on timelines that traditional capacity procurement wasn't designed to match. The interconnection queue is at historic highs. Utilities need capacity that can be deployed on a planning-cycle timeline. Not a decade-long capital project schedule.
The regulatory environment is catching up. State utility commissions increasingly recognize DCP as a distinct category of distribution infrastructure — not a demand response program, not a VPP, but a new class of utility-owned, utility-controlled capacity. The Minnesota Public Utilities Commission's unanimous approval of Xcel Energy's Capacity*Connect program is the clearest signal yet. The Commission's ruling acknowledged distributed capacity assets as utility-owned, utility-dispatched, and core grid infrastructure similar to substations and switchgear.
The economics work. DCP models deliver capacity at a cost below traditional third-party developer approaches, with 80%+ of every dollar competitively bid. At scale, they generate direct ratepayer benefits. For example, Xcel Energy's bill impact analysis for Capacity*Connect projects average residential savings of $0.13/month over 20 years, rising to $0.17/month with Google's $50 million investment factored in.
DCP isn't a hypothesis. Xcel Energy's Capacity*Connect, the first-in-the-nation, is the program that demonstrates what DCP looks like at full scale: up to 200 MW of front-of-the-meter distributed battery storage by 2028, $430 million in program investment, 80% of dollars flowing to local vendors and competitively bid, and a regulatory approval that gives other utilities a replicable pathway.
That regulatory pathway matters as much as the technology. As SEPA's distributed capacity procurement white paper concluded, DCP represents a structurally distinct model for utility capacity procurement, not a variant of existing DER programs.
The rise of DCP is not a future state. It's underway.
Utilities across the country are evaluating DCP as a least-regrets option for distribution capacity: one that deploys fast, delivers capacity, generates ratepayer benefits, and builds a portfolio that compounds in value over time.
The grid's capacity problem isn't going to slow down. The question for utilities isn't whether DCP has a role — it's how quickly they can move.
As Sparkfund CEO Pier LaFarge has said: "No different than transformers or substations or capacity banks. It's just the next type of distribution grid infrastructure." The resource is proven. The deployment model works. The regulatory pathway is open.