Northern Natural Gas Company’s Northern Lights 2025 Expansion Project is progressing as federal regulators assess its application. Designed to enhance natural gas transportation capacity in Minnesota and Wisconsin, the project recently hit a milestone with the Federal Energy Regulatory Commission (FERC) issuing an environmental assessment (EA).
The project involves 8.6 miles of pipeline extensions across four counties in Minnesota and Wisconsin, along with minor modifications to the La Crescent compressor station. Once completed, it will add 46,064 dekatherms per day of firm winter natural gas transportation capacity, addressing growing regional demand.
FERC was expected to issue a decision in December 2024, with an in-service target of November 1, 2025. However, the project remains under review, leaving the timeline uncertain.
Pipeline Route and Key Details
The planned pipeline expansions include:
- 3.0-mile extension of the 36-inch Lake Mills to Albert Lea E-line (MN)
- 2.43-mile extension of the 30-inch Elk River 3rd Branch Line (MN)
- 1.91-mile non-contiguous extension of the 30-inch Farmington to Hugo C-Line (MN)
- 1.28-mile extension of the 8-inch Tomah Branch Line Loop (WI)
Additional work will involve valve installations, pigging facilities, tie-in removals, and the abandonment of a 275-foot segment of the existing Elk River 3rd Branch Line.
The project requires 177.2 acres of land for construction and 47.9 acres for ongoing operations. Approximately 37.6 acres of workspace will overlap with existing pipeline rights-of-way. The company plans to use a 90-foot to 100-foot-wide construction right-of-way with trenching for pipeline installation.
FERC staff concluded in its Environmental Assessment that the project would not result in significant environmental impacts, strengthening its case for approval.
A Critical Investment in Energy Infrastructure
As U.S. natural gas infrastructure expands to meet rising consumption, the Northern Lights 2025 Expansion Project represents a strategic investment in reliability and capacity. By upgrading existing infrastructure, Northern Natural Gas aims to support regional energy needs while ensuring compliance with environmental and regulatory standards.
“Northern’s additional capacity could certainly benefit the region, but I fear the regulatory process may push the in-service date beyond 2025,” said Michael Reed, Editor-in-Chief of Pipeline & Gas Journal.
Northern Natural Gas: A Key Player in the Market
A Berkshire Hathaway Energy subsidiary, Northern Natural Gas operates a 14,300-mile pipeline network spanning multiple states. The system includes 55 compressor stations to maintain pressure and gas flow. In 2023, total deliveries reached 1.33 trillion cubic feet (Tcf), with a market area capacity of 6.4 billion cubic feet per day (Bcf/day) and a field area capacity of 1.7 Bcf/day.
The network serves over 2,400 receipt and delivery points, accommodating 300 shippers. Its underground storage capacity stands at 75.1 Bcf, utilizing one aquifer and two depleted oil/gas fields. Additionally, the company maintains 4 Bcf of liquefied natural gas (LNG) storage capacity across two cryogenic facilities, providing crucial peaking support.
As regulatory review continues, the industry is closely watching whether FERC will approve the project on schedule or if further delays could impact the region’s energy supply.