[{"_1":2,"_125":-5,"_126":-5},"loaderData",{"_3":4,"_26":27},"root",{"_5":6,"_17":10,"_18":19,"_20":21,"_22":10,"_23":-5,"_24":-5,"_25":10},"user",{"_7":8,"_9":10,"_11":10,"_12":-5,"_13":-5,"_14":15,"_16":-5},"roles",[],"isAuthenticated",false,"isPremium","planName","subscriptionStatus","featureFlags",{},"insightsBudget","isDevelopmentHost","userPreferences",{},"recaptchaSiteKey","6LcvOJcUAAAAAHsB-gPGfGktcRlKpH7OTIU_dMTD","isImpersonating","impersonation","affiliateStatus","isFreedomPortal","routes/v2/article/layout",{"_28":29,"_30":31},"notFound",true,"relatedArticles",[32,75,85,95,105,115],{"_33":34,"_35":36,"_37":38,"_39":40,"_41":42,"_43":44,"_45":46,"_47":48,"_49":50,"_51":52,"_53":-5,"_54":55,"_56":57,"_58":59,"_60":61,"_62":63,"_64":65,"_66":67,"_68":69,"_70":71,"_72":73,"_74":73},"mediaId",6142571,"mediaKeyId","5557028-4cbc41319f68f71f4cc3f965df5ca2bc","parentId",5557028,"title","PSC approves two Highland Crude pipeline permits in McKenzie County","audioSeconds",639,"startMs",2084000,"endMs",2723000,"viewUrl","/Search/View?dp=1&key=5557028-4cbc41319f68f71f4cc3f965df5ca2bc&start=2084&end=2723","thumbnailUrl","https://d352y6ypj4mjo3.cloudfront.net/AudioPlaceholder.png","articleUrl","/articles/6142571/North-Dakota/PSC-approves-two-Highland-Crude-pipeline-permits-in-McKenzie-County","mediaUrl","author","Public Service Commission","date","2025-08-07T00:00:00Z","article","The North Dakota Public Service Commission on Aug. 7 approved a pair of Highland Crude LLC applications for pipeline corridor compatibility and route permits in McKenzie County.
The commission approved the Gullickson Reroute Pipeline Project, an approximately 3.4‑mile, 8‑inch crude oil pipeline that will connect two existing Highland pipelines. Highland told the commission the project’s maximum operating pressure will be 1,440 psi, with a maximum design capacity of 80,000 barrels per day, an in‑service target of November 2025 and an estimated cost of about $9.5 million.
The commission also approved the Highland Express Spine Pipeline Project, a roughly 28.1‑mile, 10‑inch natural‑gas‑liquids pipeline with the same maximum operating pressure and design capacity, an anticipated in‑service date of March 2026 and an estimated cost of about $37.2 million.
Highland notified federal, state and local agencies including U.S. Fish and Wildlife Service, Army Corps of Engineers, North Dakota Game and Fish, State Historic Preservation Office (SHPO), Department of Water Resources and McKenzie County entities. Highland identified one state archaeological site within the corridors and coordinated with SHPO; Highland testified the project routes avoid crossing that site and no impacts are anticipated.
The company said it will use horizontal directional drilling for wetland and water‑body crossings, implement a weed control plan, stormwater pollution prevention, dust control and waste management plans, install leak‑detection systems and conduct regular monitoring, internal inspections and foot patrols as required by U.S. Department of Transportation pipeline safety regulations.
The commission found the projects will produce minimal adverse effects if Highland implements the proposed mitigation and monitoring measures and approved certificates and route permits for both projects with no recorded dissent.","mediaType","Audio","parentTitle","Public Service Commission Regular Meeting 08/07/2025 ","oneSentenceSummary","The commission granted permits and corridor certificates for Highland Crude’s Gullickson reroute (3.4 miles, 8‑inch crude line) and Highland Express Spine (28.1 miles, 10‑inch NGL line), finding minimal adverse effects with mitigation and monitoring conditions.","taxTitle","Public Service Commissioners, Officials, Organizations, Executive, North Dakota","taxId",68914,"location","North Dakota","headline","","shortSummary",{"_33":76,"_35":36,"_37":38,"_39":77,"_41":78,"_43":79,"_45":80,"_47":81,"_49":50,"_51":82,"_53":-5,"_54":55,"_56":57,"_58":83,"_60":61,"_62":63,"_64":84,"_66":67,"_68":69,"_70":71,"_72":73,"_74":73},6142576,"PSC approves Basin Electric’s Bison combined‑cycle plant for Williams County",414,1488000,1902000,"/Search/View?dp=1&key=5557028-4cbc41319f68f71f4cc3f965df5ca2bc&start=1488&end=1902","/articles/6142576/North-Dakota/PSC-approves-Basin-Electrics-Bison-combinedcycle-plant-for-Williams-County","The North Dakota Public Service Commission voted Aug. 7 to grant a certificate of site compatibility to Basin Electric Power Cooperative for the proposed Bison Generation Station in Williams County.
The project is sited on about 240 acres one mile south of Highway 2 between Epping and Wheelock and would consist of two natural‑gas combined‑cycle generating units with expected capacity of up to 745 megawatts per unit (about 1,490 MW total). Basin Electric told the commission the first unit is planned for construction by October 2028 with commercial operation in February or March 2029; the second unit’s planned construction is November 2029 with commercial operation in March 2030. Basin Electric estimated total project cost at roughly $3.68 billion.
Commission staff and the applicant said Basin Electric conducted field surveys for wetlands, grasslands and protected habitat, consulted 35 federal, state and local agencies listed in North Dakota Administrative Code section 69‑06‑01‑05 and the Williams County Commission, submitted cultural and noise studies that SHPO accepted and proposed mitigation steps including stormwater and spill plans.
Commissioners said the application was thorough and noted the relatively quick turnaround from filing in March to approval in August. The commission found the project will produce minimal adverse environmental effects if mitigation measures are implemented, is compatible with environmental preservation and efficient use of resources, and will help meet reliability and energy needs.
Commissioners also said the project will be among the largest single plants in the state and described it as the first baseload combined‑cycle plant sited in decades. The commission voted to approve the certificate; no dissent was recorded.","Commission issued a certificate of site compatibility for Basin Electric’s proposed two‑unit natural gas combined‑cycle Bison Generation Station near Epping and Wheelock, a project the commission said will total about 1,490 megawatts and cost about $3.68 billion.",{"_33":86,"_35":36,"_37":38,"_39":87,"_41":88,"_43":89,"_45":90,"_47":91,"_49":50,"_51":92,"_53":-5,"_54":55,"_56":57,"_58":93,"_60":61,"_62":63,"_64":94,"_66":67,"_68":69,"_70":71,"_72":73,"_74":73},6142579,"PSC sets public hearing on Northern States Power Co. 2025 electric rate increase",157,1207000,1364000,"/Search/View?dp=1&key=5557028-4cbc41319f68f71f4cc3f965df5ca2bc&start=1207&end=1364","/articles/6142579/North-Dakota/PSC-sets-public-hearing-on-Northern-States-Power-Co-2025-electric-rate-increase","The North Dakota Public Service Commission voted Aug. 7 to issue a notice of public hearing on Northern States Power Company’s 2025 electric rate increase application.
Commissioner Sherry Haugenhofer moved the notice of hearing. The company proposes a $44,556,000 increase in annual North Dakota electric revenues, a 19.34% rise. The commission set a public hearing to begin Dec. 1, 2025, at 8:30 a.m. Central in the Commission Hearing Room and encouraged parties to file petitions to intervene by Oct. 15, 2025.
Haugenhofer summarized NSP’s stated drivers for the request as capital investments in generation, transmission and distribution, higher operation and maintenance expenses, and increased depreciation. The commission noted the magnitude of the proposal as one of the largest electric rate increases it has seen.
Commissioners discussed scheduling; the hearing could extend through the week depending on testimony and filings. The vote to issue the notice and set the hearing was approved unanimously with no recorded dissent.
The commission did not act on the merits of the rate request at the meeting; the hearing and intervenor processes will determine evidence and final outcome.","The commission set a public hearing beginning Dec. 1 for NSP's proposal to raise North Dakota electric revenues by $44.556 million (19.34%); a petition-to-intervene deadline of Oct. 15 was suggested.",{"_33":96,"_35":36,"_37":38,"_39":97,"_41":98,"_43":99,"_45":100,"_47":101,"_49":50,"_51":102,"_53":-5,"_54":55,"_56":57,"_58":103,"_60":61,"_62":63,"_64":104,"_66":67,"_68":69,"_70":71,"_72":73,"_74":73},6142582,"PSC affirms notice of violation, orders $6,000 penalty for Westmoreland Beulah Mining LLC",279,697000,976000,"/Search/View?dp=1&key=5557028-4cbc41319f68f71f4cc3f965df5ca2bc&start=697&end=976","/articles/6142582/North-Dakota/PSC-affirms-notice-of-violation-orders-6000-penalty-for-Westmoreland-Beulah-Mining-LLC","The North Dakota Public Service Commission on Aug. 7 adopted an order affirming Notice of Violation 2501 against Westmoreland Beulah Mining LLC relating to topsoil protection at the Beulah mine and assessed a $6,000 civil penalty.
Commissioners heard that inspections on April 24 and May 7 followed a staff observation of spoil material mixed with topsoil on about 3.5 acres. Samples taken from six sites on the tract showed an estimated 1,100 cubic yards of affected topsoil. The notice required containment, removal of the apparent spoil material, quantification of contaminated topsoil and submission of a revegetation plan.
The commission’s reclamation division said Westmoreland complied with the remedial actions within required timelines. The PSC described three recent notices of violation for the operator within a three‑year window and applied the commission’s four‑factor civil penalty framework (history, seriousness, degree of fault, and good‑faith abatement) to determine the penalty.
The order proposed $2,500 for history, $2,000 for seriousness, and $1,500 for negligence, totaling $6,000. The commission voted to adopt the order and close the case upon payment of the penalty.
The commission record notes that Westmoreland had contacted the reclamation division on April 23 to discuss possible contaminated topsoil and had fenced the area and taken four samples prior to the PSC inspection. The PSC performed its own testing and also used drone photography during the follow‑up inspection to document the affected area.
The order directs payment of the civil penalty; no further timetable for payment or additional enforcement steps was stated in the public meeting remarks.","The commission affirmed a notice of violation for topsoil contamination at the Beulah mine, found 1,100 cubic yards affected on about 3.5 acres, and adopted a $6,000 civil penalty.",{"_33":106,"_35":36,"_37":38,"_39":107,"_41":108,"_43":109,"_45":110,"_47":111,"_49":50,"_51":112,"_53":-5,"_54":55,"_56":57,"_58":113,"_60":61,"_62":63,"_64":114,"_66":67,"_68":69,"_70":71,"_72":73,"_74":73},6142584,"PSC adopts revised revegetation standards allowing USDA RMA yield data",310,464000,774000,"/Search/View?dp=1&key=5557028-4cbc41319f68f71f4cc3f965df5ca2bc&start=464&end=774","/articles/6142584/North-Dakota/PSC-adopts-revised-revegetation-standards-allowing-USDA-RMA-yield-data","The North Dakota Public Service Commission voted Aug. 7 to adopt updates to the state’s revegetation success standards used to demonstrate reclamation success on surface coal mine lands.
Commissioner Randy Christman moved the order and commissioners voted unanimously to adopt changes proposed by the reclamation division. The revisions add the U.S. Department of Agriculture Risk Management Agency (RMA) county yield data as an alternative source for cropland, hayland and tame pasture yield comparisons where the North Dakota Agricultural Statistics Service data are unavailable.
Commission staff told the commission that Ag Statistics Service county yields historically depended on voluntary farmer reports, and that Mercer County and statewide data have been incomplete in recent years; in 2024 no statewide Ag Statistics Service data will be published due to lack of funding. The RMA data, the staff said, are collected in connection with crop insurance and are not voluntary in the same way.
The commission record shows the reclamation division solicited comments from industry and agencies, including the Office of Surface Mining, by formal notice on May 8 and received no comments during the 30‑day comment period ending June 9.
The revised policy updates four sections of the pre‑ and post‑mining vegetative assessments document and also updates ecological site and forage suitability group tables. The commission’s action allows mine operators to rely on RMA county yield data when Ag Statistics Service data are not available, which the reclamation division said will help operators demonstrate revegetation success for bond release.
Staff emphasized that mines may continue to use on‑site control or reference areas for comparisons if appropriate, and that use of RMA data is an alternative, not a mandatory replacement.
The commission adopted the order with no recorded dissent.","Commission adopted edits to the surface coal mine revegetation standards to permit use of USDA Risk Management Agency county yield data where North Dakota Ag Statistics Service data are unavailable.",{"_33":116,"_35":36,"_37":38,"_39":117,"_41":118,"_43":119,"_45":120,"_47":121,"_49":50,"_51":122,"_53":-5,"_54":55,"_56":57,"_58":123,"_60":61,"_62":63,"_64":124,"_66":67,"_68":69,"_70":71,"_72":73,"_74":73},6142585,"North Dakota PSC asks FERC to review MISO transmission planning for tranche 2.1",178,144000,322000,"/Search/View?dp=1&key=5557028-4cbc41319f68f71f4cc3f965df5ca2bc&start=144&end=322","/articles/6142585/North-Dakota/North-Dakota-PSC-asks-FERC-to-review-MISO-transmission-planning-for-tranche-21","The North Dakota Public Service Commission said Aug. 7 it has joined a multi-state complaint to the Federal Energy Regulatory Commission asking for an objective review of Midcontinent Independent System Operator (MISO) transmission project planning for the so-called tranche 2.1 portfolio.
Commissioner Jill Kringstedt told the commission that MISO’s most recent business case for 24 projects — with an estimated cost of $22 billion — uses benefit calculations that differ from those used in earlier rounds and that the commission believes overstate benefits to the detriment of North Dakota utility customers.
The complaint asks FERC to review whether the MISO planning process and the tariff treatment of the projects produce just and reasonable costs for North Dakota ratepayers. Kringstedt said the commission’s staff raised concerns during MISO’s stakeholder process that were not adequately addressed and noted that MISO’s independent market monitor had raised similar issues.
Commissioners Randy Christman and Sherry Haugenhofer expressed support for the filing. Haugenhofer thanked Adam, Victor and Rob from staff and Stacy for help preparing a press release and said the commission would provide more information as the matter proceeds.
The filing does not ask FERC to block construction; Kringstedt said she was not saying the projects “shouldn’t be built,” only that states and utilities that will benefit should bear the cost rather than North Dakota ratepayers. No formal motion or vote on the filing was recorded in the meeting minutes beyond the commissioners’ comments.
The commission did not present additional detail about the legal arguments or the specific relief requested from FERC during the public portion of the meeting.
The PSC said it will provide further updates to the public as the case proceeds through FERC.","Commissioners said North Dakota joined other states in filing a complaint at FERC, arguing MISO used changed benefit metrics that could shift costs of 24 tranche 2.1 transmission projects onto North Dakota ratepayers.","actionData","errors"]

Article not found

PSC approves two Highland Crude pipeline permits in McKenzie County

PSC approves Basin Electric’s Bison combined‑cycle plant for Williams County

PSC sets public hearing on Northern States Power Co. 2025 electric rate increase

PSC affirms notice of violation, orders $6,000 penalty for Westmoreland Beulah Mining LLC

PSC adopts revised revegetation standards allowing USDA RMA yield data

North Dakota PSC asks FERC to review MISO transmission planning for tranche 2.1