Why Power Availability Belongs on the Critical Path

Every infrastructure project begins with risk.

Project teams plan for permitting, labor, equipment lead times, weather, land access, supply chain disruptions, and construction uncertainty because each can affect cost, schedule, and operational readiness.

Power has not always received the same attention.

Historically, electricity was often treated as a utility coordination item. The site was selected, engineering progressed, equipment was ordered, and utility service was expected to arrive before commissioning.

That sequence depended on an assumption:

When the project was ready for power, power would be ready for the project.

Today, that assumption carries more risk.

U.S. electricity demand is growing again after years of relative stability. EIA expects demand to continue rising through 2027, creating the strongest four-year growth period since 2000. NERC’s 2025 assessment forecasts North American summer peak demand increasing by 224 GW over the next decade, 69 percent more growth than projected just one year earlier.

At the same time, utilities are managing larger service requests, aging infrastructure, equipment constraints, and projects that may require years of engineering and construction.

Power availability has therefore moved beyond electrical coordination.

It can influence where a project is built, how it is designed, when it can be commissioned, and when the asset begins creating value.

Power has become a project risk.

Power Risk Is Easy to Discover Too Late

Some risks are obvious.

A permit has not been approved. A supplier quotes a long lead time. A landowner has not granted access.

Power risk can hide behind assumptions that sound reassuring:

• A utility line is nearby.
• The utility says service should be possible.
• The project has a relatively small load.
• Utility power is already included in the design.
• A preliminary energization date appears on the schedule.

None of those conditions confirms that the necessary capacity has been studied, approved, designed, funded, constructed, and committed for the date the project needs it.

A nearby feeder may lack capacity. A transformer may require replacement. A line extension may need easements or road crossings. A substation upgrade may be required. The utility may still be waiting for final load information before completing its engineering.

The issue is not always that utility power cannot be provided.

The issue is that the project may advance farther than the power plan.

By the time the full scope becomes clear, engineering may be substantially complete, equipment ordered, and construction underway. The same problem that would have been a planning consideration six months earlier can become a critical-path delay.

“Available” Is Not the Same as “Ready”

For project teams, the word available needs more definition.

A utility may say service is feasible without having completed the study. Power may be available only after a transformer arrives. Capacity may exist for the initial phase but not future expansion. The connection may be technically possible but arrive after the project’s required start date.

These are very different stages:

• Service request submitted
• Feasibility confirmed
• Engineering study completed
• Required upgrades identified
• Costs and responsibilities established
• Equipment ordered
• Easements and permits secured
• Construction scheduled
• Energization date committed
• Site energized and tested

A project can report “utility coordination underway” while remaining several major steps away from dependable power.

That uncertainty belongs on the risk register just like any other project dependency.

Power Risk Spreads Across the Project

A delayed utility connection does not create only one problem.

It can affect multiple areas at once.

A site selected without understanding utility requirements may carry unexpected extension costs or schedule delays. A design based on utility service may need to change if the source, voltage, reliability, or availability changes. Alternative power equipment may then need to be engineered and procured late.

Commissioning is especially vulnerable.

A project may be mechanically complete but still be unable to establish communications, test controls, calibrate instrumentation, verify remote operation, or demonstrate full functionality.

That delay also carries cost.

Contractors may remain mobilized. Temporary generators require fuel and maintenance. Commissioning specialists may need to return. Work may occur out of sequence. Project-management and engineering support can continue well beyond the planned closeout date.

Waiting is not financially neutral.

The asset may be physically complete while still unable to perform the function it was built to provide.

Midstream Projects Have a Particular Exposure

Midstream infrastructure has an additional challenge because assets must be located according to the pipeline system, not according to the convenience of the electric grid.

Measurement facilities, block valve sites, communications nodes, gas analyzers, and remote monitoring equipment may sit far from practical utility infrastructure.

The electrical load may be small, but serving it may still require a transformer, line extension, easements, road or railway crossings, property access, and utility construction.

At the same time, the function supported by that small load can be significant.

A remote terminal unit may support control-room visibility. A flow computer may provide commercially important measurement data. Communications equipment may transmit alarms and operating information. A remote valve system may need dependable power when an operator issues a command.

PHMSA regulations specifically address SCADA systems used to remotely monitor and control gas and hazardous-liquid pipeline operations, underscoring the operational importance of maintaining communications and control capability.

For midstream, the appropriate question is not simply:

How much electricity does this site consume?

It is:

What happens to the operation if that electricity is not available?

That is the better measure of power risk.

Manage Power Like Any Other Critical Dependency

Earlier evaluation does not eliminate utility delays or equipment shortages.

It gives the project more time to respond.

A stronger power-risk process should establish three things early.

First, define what the site actually requires: operating load, startup demand, critical equipment, uptime, communications, environmental conditions, future expansion, and the required operational date.

Second, understand what the utility has formally committed to rather than relying only on preliminary conversations.

Third, establish a decision point for alternatives.

If the utility cannot provide a credible service date by a defined project milestone, the team should know when it will evaluate bridge power, phased operation, UPS support, hybrid power, or a permanent independent system.

That distinction between preferred power and required power is important.

Utility service may remain the preferred long-term source.

The project still needs a strategy that supports its required operational date.

Where Solarcraft Fits

Solarcraft supports projects when standard utility service does not align with the site’s location, schedule, reliability requirements, or economics.

That may mean permanent off-grid power for a remote location, UPS backup for a critical load, bridge power while utility work continues, or an integrated power and automation system designed around the application.

Solarcraft designs and integrates systems supporting PLCs, RTUs, SCADA, communications, measurement, gas analyzers, valve actuation, motors, and other critical oil and gas applications. Its capabilities include solar and UPS power, automation panels, controls, industrial enclosures, fabrication, integration, testing, commissioning, and field services.

For a midstream project, the value is not simply access to another source of electricity.

It is the ability to evaluate power as part of the complete operational system.

Solarcraft is not intended to replace utility service in every application. Utility power may still be the right long-term solution.

Solarcraft becomes valuable when waiting for that solution would prevent critical infrastructure from becoming operational, or when an independent power architecture better fits the site.

The goal is to move power from an assumption to an engineered project strategy.

Key Takeaways

• Power availability is becoming a project risk because utility timelines do not always align with commercial project schedules.
• A nearby utility line or preliminary conversation does not mean power is committed for the required operational date.
• Power delays can affect design, procurement, construction, commissioning, cost, and operational readiness.
• Midstream sites may have modest electrical loads while supporting critical communications, measurement, monitoring, and control functions.
• The operational consequence of losing power matters more than the size of the load.
• Power dependencies should have defined ownership, milestones, and contingency triggers.
• Early evaluation gives teams time to consider bridge power, UPS support, hybrid systems, or permanent remote-power alternatives.
• Solarcraft helps align the power system with the site’s actual function, location, reliability needs, and schedule.

Ready to Continue the Conversation?

Power availability is influencing more than electrical design. It is affecting schedules, commissioning, operational readiness, and the ability of critical midstream infrastructure to begin creating value.

Explore the rest of the Power Without Waiting series to learn how changing demand and grid constraints are reshaping the way project teams plan for power.

Sources

1. U.S. Energy Information Administration. “EIA Forecasts Strongest Four-Year Growth in U.S. Electricity Demand Since 2000, Fueled by Data Centers.” January 13, 2026. Supports the near-term demand outlook and return of sustained U.S. electricity growth.
2. North American Electric Reliability Corporation. “2025 Long-Term Reliability Assessment.” Supports the forecast for 224 GW of additional summer peak demand and the significant increase from the previous assessment.
3. U.S. Department of Energy, Office of Electricity. “Distribution Transformer Webinar Text Alternative.” Documents the 41 percent increase in distribution-transformer demand since 2019 and substantially longer procurement lead times.
4. Pipeline and Hazardous Materials Safety Administration. “Control Room Management.” Describes federal requirements for SCADA systems used to remotely monitor and control pipeline operations.
5. Pipeline and Hazardous Materials Safety Administration. “DOT Issues Much-Anticipated Rules to Enhance Pipeline Safety.” Describes the role of SCADA systems in displaying pipeline pressure, flow, and valve-position information.
6. Solarcraft Inc. “UPS & Solar Power Systems for RTU, PLC, SCADA, & DCS.” Describes Solarcraft’s integration of continuously powered automation, communications, flow computers, measurement devices, and valve systems.
7. Solarcraft Inc. “Solar Powered 480VAC Motor & Valve Actuator.” Describes Solarcraft’s power architectures for remote motors, valve actuators, RTUs, PLCs, communications, and instrumentation.
8. Solarcraft Inc. “CID2 & UL 508A Power Systems for Oil & Gas Applications.” Describes Solarcraft’s broader power, automation, measurement, analyzer, motor-control, UPS, and midstream integration capabilities.