| Resource Type | Report |
| Author / Source | Horowitz, Peterson, Coddington, Ding, Sigrin, Saleem, Baldwin, Lydic, Stanfield, Enbar, Coley, Sundararajan, Schroeder (NREL) |
| Publication Date | April 2019 |
| Location | United States |
| Initiative Type | Technology, Policy, Program |
| Project Complexity | Advanced |
| Recommended For | Staff |
Estimated reading time: 30+ minutes
Why This Matters for Rural Electric Co-ops
As member interest in rooftop solar, battery storage, and other distributed resources grows, co-ops need a clear-eyed understanding of what interconnection actually requires: technical, procedural, and financial. Poorly managed interconnection processes create real risks. Delayed applications strain member relationships, cost-allocation disputes can stall DER projects entirely, and inadequate cybersecurity practices expose the co-op's distribution system to new vulnerabilities.
This report gives co-op staff a comprehensive, utility-focused overview of where interconnection standards and practices currently stand and what steps co-ops can take now, even at low DER penetration levels, to stay ahead of rising member demand.
Key Takeaways
| › | Adopting the IEEE 1547-2018 standard early is one of the most cost-effective actions a co-op can take. Countries that delayed saw expensive retrofits when DER penetration grew rapidly, and co-ops that act now avoid that risk. |
| › | The conventional "cost-causer pays" interconnection model increasingly creates fairness problems and procedural delays as DER adoption grows. Emerging alternatives like group cost allocation, post-upgrade reimbursement, and preemptive upgrades offer co-ops more equitable and efficient options worth evaluating. |
| › | Advanced inverter functions (volt-var, volt-watt control) can expand DER hosting capacity on existing distribution infrastructure at low or no cost if configured at installation. Retrofits later are typically prohibitively expensive. |
| › | Battery storage can serve double duty as both a DER and a mitigation strategy for distribution system violations, potentially reducing the need for costly grid upgrades. Its use for violation mitigation must be explicitly planned and incentivized, or it will be displaced by other operating objectives. |
Implementation Considerations
- Regulatory or Governance Considerations: Cost allocation, storage, and cybersecurity rules vary significantly by state, and many states are still updating standards to reflect IEEE 1547-2018. Co-ops should monitor their state's regulatory posture and engage with statewide associations.
- Staffing or Technology Requirements: Online platforms, power-flow modeling, and DER forecasting require technical capacity most smaller co-ops won't have in-house. Regional collaboration or consultants will likely be needed. At low penetration levels, low-cost steps like application templates and a designated point of contact are practical starting points.
Notable Examples
- Lake Region Electric Cooperative (LREC), Minnesota: Cited for preferring manual interconnection processes due to the value placed on member relationships; illustrates that low-penetration co-ops have operational flexibility in how they phase improvements.
- Hawaiian Electric Companies (HECO): Extensive case study on managing high DER penetration, including storage interconnection, cost allocation approaches, and advanced inverter curtailment data.
- Pacific Gas & Electric (PG&E) and San Diego Gas & Electric (SDG&E): Early adopters of online application systems; both achieved significant cost savings with near-immediate payback, providing a benchmark for utilities considering the investment.
- National Grid (New York): Piloting preemptive upgrade cost-sharing and flexible interconnection capacity solutions (FICS) under New York's Reforming the Energy Vision (REV) initiative.
- Pepco Holdings Inc. (PHI): Demonstrated automated power-flow modeling for DPV screening, completing engineering studies within five minutes of application submission.
Estimated reading time: 30+ minutes
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