Exelon Backs Continuum to Cut Power Line Siting Bottlenecks as Data Centers Overheat the Grid

The Transmission Wall: Why America’s Largest Utility Is Automating Line Design

Power utilities in North America face an unprecedented dilemma. On one side, electric power demand is growing at rates unseen in half a century. Artificial intelligence data centers, new domestic chip foundries, and factory electrification are requesting gigawatts of new capacity on short notice. On the other side, the physical transmission lines needed to deliver that power take anywhere from seven to twelve years to plan, permit, and construct.

Traditional grid expansion runs on an obsolete process. Route engineers and environmental teams typically evaluate a handful of potential paths using manual surveys, static maps, and disconnected local zoning records. Evaluating a single 50-mile high-voltage corridor routinely requires 18 to 24 months of study, hundreds of consultant hours, and millions of dollars in pre-construction capital. When a proposed route runs into an unmapped wetland, an endangered habitat, or local municipal opposition late in the review cycle, engineers often have to scrap the design and start over from zero.

Exelon, the largest utility company in the United States by customer count, is attempting to break this logjam. Through its Climate Change Investment Initiative (2c2i), Exelon has invested in Continuum, a software company founded in 2018 that builds automated infrastructure planning tools. As part of the investment agreement, Exelon will deploy Continuum’s flagship software platform, Optioneer, across its operating companies in the PJM Interconnection region, which spans five mid-Atlantic states and Washington, D.C.

Optioneer acts as an automated search engine for power line corridors. Instead of testing two or three routes by hand, the platform ingests spatial, environmental, legal, and terrain data across vast geographies. It tests thousands of possible route paths in hours, highlighting which corridors run the lowest risk of environmental litigation, permitting rejections, and excessive construction costs.

The scale of the problem explains why a regulated utility giant is buying into early-stage software. In regions like Northern Virginia, new commercial power connection requests have overwhelmed regional transmission operators. Regional grid operator PJM Interconnection faces severe capacity deficits, while Texas operator ERCOT recently froze new data center interconnection applications to assess stability risks. Without digital systems that speed up the delivery of physical poles and wires, utilities will simply run out of available power to allocate to high-value industrial customers.

420,000 Miles Screened: Benchmarking Automated Siting Against Legacy Workflows

Planning an electrical transmission project has historically been one of the most labor-intensive tasks in the energy sector. A typical 100-mile 500 kV transmission line crosses hundreds of individual private land parcels, scores of public roads, multiple water bodies, and dozens of distinct municipal jurisdictions.

Continuum claims its Optioneer platform has already screened more than 420,000 miles of infrastructure alternatives for developers and utilities. By converting complex land-use rules, local zoning laws, slope data, and environmental maps into an algorithmic scoring engine, the software tests routes across vast landscapes to identify corridors that minimize both capital cost and legal friction.

To understand why this software matters to utility capital allocation, consider the raw differences between standard manual planning methods and modern digital routing workflows:

These numerical gains translate directly into project survival rates. In transmission construction, the most expensive mistake a utility can make is not spending extra money on steel towers; it is spending $30 million designing a line that gets permanently blocked by a state utility commission because of an unaddressed environmental conflict.

How Transmission Delays Directly Threaten Industrial Balance Sheets

Grid interconnection delays are no longer an internal concern for utility engineers. They have evolved into a primary financial and operational risk for commercial enterprises, institutional energy developers, and hyperscale technology firms. When transmission networks freeze, three distinct cost drivers threaten corporate balance sheets.

1. Capital Expenditure Waste and Pre-Construction Soft Costs

Before a utility digs a single hole or erects a single lattice tower, it pours capital into land options, environmental impact statements, legal retainers, and public relations campaigns. On a standard $500 million regional transmission line, pre-construction soft costs routinely eat up 8% to 15% of the total budget ($40 million to $75 million).

When a project is forced into redesign because a route cuts across an unrecorded protected wetland or tribal boundary, that pre-construction capital is largely wasted. By automating multi-layer risk analysis before land easements are negotiated, developers avoid sinking millions of dollars into doomed corridors.

2. Interconnection Lead Times and Stranded Capital

Commercial developers building large energy consumers—like data centers, battery storage facilities, and clean hydrogen plants—now face interconnection queues that stretch between four and seven years across PJM, MISO, and CAISO.

Every month of delay carries a direct financing cost. A $1 billion data center campus waiting for a grid tie-in bleeds cash in land carry costs, standby generator contracts, and delayed revenue generation. If a utility can compress the preliminary planning and permitting phase from three years down to one, commercial customers can bring revenue-generating assets online up to 24 months earlier.

3. Supply Stability and Grid Congestion Penalties

When utilities cannot build transmission lines fast enough, regional grids develop physical traffic jams, known as transmission congestion. To keep the grid balanced, system operators must turn off cheap power plants located behind the bottleneck and turn on expensive, inefficient peaker plants located closer to the load centers.

These congestion costs are passed directly to commercial and industrial rate payers through monthly utility bills. In the PJM region alone, annual congestion costs routinely climb into the hundreds of millions of dollars. By deploying routing software that identifies quick-to-permit transmission bypasses, Exelon can relieve localized bottlenecks faster, holding down delivery rates for retail and industrial consumers.

Software Siting vs. Hardware Upgrades: How Utilities Modernize the Grid

To meet rising power demands, utilities have traditionally relied on brute-force hardware investments: building larger substations, stringing thicker conductors, or constructing parallel lines. While these capital investments are still necessary, leading operators are discovering that modern digital tools and advanced conductors offer a far faster buffer against capacity crunches.

Leading power companies are pairing automated siting tools like Continuum with physical grid-enhancing technologies (GETs) to build an operational defense against delays:

• Dynamic Line Rating (DLR): Traditional transmission lines are assigned static power limits based on conservative assumptions about hot summer days. DLR systems use weather sensors mounted directly on power lines to monitor wind speed, air temperature, and line sag in real time. On windy or cool days, lines can carry 10% to 40% more electricity safely without any route redesign.
• Advanced Conductors (Re-conductoring): Instead of spending a decade acquiring new land rights, utilities replace older steel-core aluminum wires with modern carbon-fiber composite cores on existing towers. These lines carry up to twice as much power along existing paths. Continuum’s Optioneer complements this approach by screening the surrounding landscape to verify whether existing right-of-ways can handle additional substation expansions or terminal upgrades.
• Automated Permitting Documentation: Beyond simple route geometry, platforms like Optioneer automatically generate the complex environmental impact documentation required by state utility commissions and federal agencies. Standardizing these application packages prevents administrative rejections, allowing legal teams to defend route decisions with clear, algorithmic data.

Exelon’s deployment of Continuum across its PJM footprint serves as a real-world test of this hybrid strategy. By deploying automated software to vet greenfield routes while using digital monitoring to maximize existing assets, the utility seeks to avoid the long construction freezes now hitting other regional markets.

Market Outlook: How the Grid Siting Race Will Separate Winners from Losers

The surge in power demand over the next decade will reshape the utility landscape. Electric power systems are shifting from an era of flat demand and predictable capacity planning to an era of explosive growth, supply constraints, and intense public scrutiny. Companies that navigate this landscape successfully will manage risk across two distinct operational realities.

Legacy Operators Face Margin Compression and Stranded Demand

Utilities that continue to rely on manual route planning and fragmented engineering consulting firms will face severe financial strain:

• Unrealized Industrial Growth: Tech companies building AI campuses will not wait seven years for power interconnections. Developers are actively migrating projects to regions and utility service territories that can provide committed energization dates within three to four years. Utilities trapped in multi-year planning cycles will lose lucrative, steady industrial loads to more agile operators.
• Disallowed Pre-Development Capital: State public utility commissions are tightening oversight on capital expenditure recovery. When a utility spends tens of millions of dollars on a transmission corridor that is ultimately abandoned due to poor environmental planning, regulators are increasingly refusing to let the utility recover those costs from rate payers. Shareholders are forced to absorb the losses directly.
• Regulatory Penalties for Interconnection Queue Delays: Under new rules introduced by the Federal Energy Regulatory Commission (such as Order 2023), utilities and regional transmission operators face financial penalties for missing study deadlines. Slower, manual study processes directly expose utilities to recurring regulatory fines.

Three Rules for Winners in the Grid Modernization Era

To survive and grow as electricity demand accelerates, transmission operators and industrial developers must execute on three distinct capabilities:

• Rule 1: Adopt Algorithmic Routing Across All Pre-Capital Work: Software screening must become the standard first step for any project exceeding five miles of corridor length. Utilities must make spatial risk scoring, automated parcel-boundary mapping, and environmental constraint filtering mandatory before hiring outside field surveyors or purchasing land easements.
• Rule 2: Integrate Digital Siting with Regional Interconnection Queues: Transmission planning can no longer happen in isolated silos. Software engines like Optioneer must connect directly to regional load forecasts and cluster study data from regional operators like PJM and MISO. By forecasting where power demands will concentrate two to five years in advance, utilities can pre-screen corridors before queue filings occur.
• Rule 3: Build Defensible Data Packages to Preempt Court Challenges: The primary cause of transmission construction failure is legal opposition from local communities and environmental organizations. Winning utilities will use automated spatial platforms to create verifiable, objective records showing why a chosen route causes the least environmental harm compared to thousands of alternatives. Objective, data-backed filings hold up under judicial review, neutralizing the legal challenges that have kept the American power grid frozen in place for decades.