[{"_1":2,"_112":-5,"_113":-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",[32,76,88,100],{"_33":34,"_35":36,"_37":38,"_39":40,"_41":42,"_43":44,"_45":46,"_47":48,"_49":50,"_51":52,"_53":54,"_55":56,"_57":58,"_59":60,"_61":62,"_63":64,"_65":66,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},"mediaId",6393325,"mediaKeyId","2107595-c476dd8b9441b8b6cfafb4bb369f2c69","parentId",2107595,"title","North Dakota transmission authority warns EPA rules could threaten grid reliability, urges support for baseload and resilience grants","audioSeconds",1367,"startMs",175000,"endMs",1542000,"viewUrl","/Search/View?dp=1&key=2107595-c476dd8b9441b8b6cfafb4bb369f2c69&start=175&end=1542","thumbnailUrl","https://assets.pipeline.soar.com/2107595-c476dd8b9441b8b6cfafb4bb369f2c69/thumbnail_175000.jpg","articleUrl","/articles/6393325/North-Dakota/North-Dakota-transmission-authority-warns-EPA-rules-could-threaten-grid-reliability-urges-support-for-baseload-and-resilience-grants","mediaUrl","https://secure.pipeline.soar.com/6393325-2db7164fa7eaf03148304419fc3fda39/orig.mp4?Expires=1771023122&Signature=QRd4jlntmm5nkJI-TWnN07AlFAtVaVLo-gsllxtapf-CqEvYtQ2YgidSH18vpGb5CWMUmau3eFveW82W9tu~05OYYdD8tBLTyHcE--c0l2i8ZHs7Ihsyp5WW~WH0v1dlLQo~ak27aaKCt2B16p6LxAxRuDke8oCHv4IGilzLTTv9UmUlUepimaBFZ5thst8MEmRlTp16vwLeG0G1CXzYgGYTX1mihAMcAHdwIAKlQvSI8q35-DCrRXg6jZDpPktXzvd2abtR07mHuXwIq66hOktqNh5fJULJEyzum3KUz3gWETf7fYu2ub4WVLVyo-aGFvEAhHoN4cSKK~o3KdxmKw__&Key-Pair-Id=KUT5TJCACFTXG","author","House Energy and Natural Resources, ND","date","2025-01-09T00:00:00Z","article","Jordan Connehion, deputy director at the North Dakota Industrial Commission, told the joint House and Senate Natural Resources and Energy Committee on Jan. 22 that studies produced by the North Dakota Transmission Authority (NDTA) show proposed federal air and greenhouse‑gas rules could reduce available generation and threaten the ability of the region’s grids to meet peak demand.

The Transmission Authority, Connehion said, produced engineering studies that the state is using in litigation and in planning discussions with regional transmission organizations. “The EPA rule seeks to cut the allowable mercury content by 10 times. It would decimate the coal industry,” Connehion said, adding that related modeling showed the Midcontinent Independent System Operator (MISO) could be unable to meet peak demand by 2029 under that rule.

Why it matters: North Dakota sits in two regional transmission organizations—MISO and the Southwest Power Pool (SPP)—and Connehion said both organizations are raising concerns about declining accredited capacity as more intermittent renewables replace conventional baseload units. Declining accredited capacity, he and other presenters told the committee, can reduce resource adequacy and make the grid less resilient to high‑impact, low‑frequency events such as extreme winter weather.

Connehion outlined NDTA activities that include producing studies to support state litigation and to inform RTO planning, commissioning an annual grid‑resilience report required by statute, and participating in capacity and congestion studies. He said a capacity study, produced in collaboration with the Energy Research Center (ERC) and paid for with litigation funds, was due for release in August and would identify congestion areas and capacity constraints relevant to large new loads such as data centers.

On the greenhouse‑gas side, Connehion said a second NDTA study modeled potential constraints on gas‑fired generators and found that, if the proposed rules took effect as written, MISO and SPP could face difficulty meeting peak demand by 2028–2030. “Three to five years from now, these are startling things to contemplate,” he said.

Committee members pressed for specifics. Representative Conmee asked which public policies were most threatening; Connehion answered that the EPA proposals he described were the “biggest ones.” Senator Enget and Representative Novak pressed on mitigation, and Connehion told them the state’s options are largely twofold: continue litigation to challenge or slow rules and accelerate new baseload generation in North Dakota, including combined‑cycle natural gas or other dispatchable resources.

Connehion also summarized NDTA recommendations to state policymakers: support retention of existing baseload generation, expedite development of new baseload capacity, and continue to participate in and support federal resiliency grant programs (including funds coming from the Infrastructure Investment and Jobs Act). He noted utilities in the state are modernizing infrastructure and advancing resilience planning, but said “public policy has risen to the top” of risks to reliability over the prior four years.

NDTA funding request: Connehion said the authority wants a larger internal budget so its executive director can commission studies without seeking outside funding. He described a request to increase NDTA’s budget from its current allocation (named in the presentation as $300,000) to a larger sum for in‑house studies; he did not provide a single unambiguous final figure in the committee presentation.

Grants and federal engagement: Connehion described NDTA participation in federal resiliency and grid modernization competitions and urged continued state support for the 15% state match required by certain federal formula grants. He said the NDTA’s reports have been shared with RTOs and the attorney general’s office; Phil Axe, North Dakota's solicitor general, was described as “deeply involved” in litigation that relies on NDTA studies.

What the committee heard about timing and scale: Presenters and committee members repeatedly emphasized that accredited capacity values for renewables are lower than nameplate capacity and that retirements of fossil and combined coal/gas units have been replaced largely by wind. Connehion and others warned this trend means accredited capacity may decline even while installed capacity rises.

Outlook and next steps: Connehion asked legislators to support policies that stabilize or grow baseload capacity and to continue state participation in federal resilience grant programs. He also offered to coordinate follow‑up briefings from the solicitor general’s office for members seeking litigation updates.

Ending: The committee moved on to question and answer after Connehion’s remarks; no formal votes or committee directives were taken at the hearing.

","mediaType","Video","parentTitle","House Energy and Natural Resources- Jan 9, 2025\t","oneSentenceSummary","Jordan Connehion, deputy director of the North Dakota Industrial Commission, told a joint Natural Resources and Energy Committee hearing on Jan. 22 that state studies show proposed EPA rules and a shift toward intermittent generation could put MISO and SPP at risk of failing to meet peak demand within several years.","taxTitle","Energy and Natural Resources, House of Representatives, Legislative, North Dakota","taxId",28890,"location","North Dakota","headline","","shortSummary",{"_33":77,"_35":36,"_37":38,"_39":78,"_41":79,"_43":80,"_45":81,"_47":82,"_49":83,"_51":84,"_53":85,"_55":56,"_57":58,"_59":86,"_61":62,"_63":64,"_65":87,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},6393312,"New DMR director outlines steady Bakken production, high gas capture and progress on critical‑minerals sampling",11715,11715000,-1,"/Search/View?dp=1&key=2107595-c476dd8b9441b8b6cfafb4bb369f2c69&start=11715&end=0","https://assets.pipeline.soar.com/2107595-c476dd8b9441b8b6cfafb4bb369f2c69/thumbnail_11715000.jpg","/articles/6393312/North-Dakota/New-DMR-director-outlines-steady-Bakken-production-high-gas-capture-and-progress-on-criticalminerals-sampling","https://secure.pipeline.soar.com/6393312-ca1c98a0772043265f58c6397a782db3/orig.mp4?Expires=1771023123&Signature=SHJ-LiaJDWcF~6uAQrfbxBzVK8RYuhfcQHe7xC2HoQdTmfm4LzjxmjcGUXqtEaNxZiDPKvGK2s2iJDvR9f0g4kcr5sFKVi0kAO3NTMeimRTzZsJMimkVQQBazWxeYhA4g3aPKMZWVZeDPBBo8hx989ToY0BldNKOwj~OFW7pWCTioTFlrFzt0weX3fj~YlEPYBLWGyjiZ-3Qs28ZRxr5GLf6-Y21fhpBVTLdAJF9gML2nZS2CUVzprREG90qp-pxEBtuwFByWSDFXJYdgfgE0tZiv7KZkY5azYjyF1IK6P2t-OMQJOPGSPcmdLlfk2T166~Bs0CWuVzHC5445MZz7w__&Key-Pair-Id=KUT5TJCACFTXG","Nathan Henderson, director of the North Dakota Department of Mineral Resources (DMR), and Ed Murphy, state geologist, presented the DMR’s latest oil and gas statistics, mapping work and a state survey of critical minerals in lignite at a joint Natural Resources and Energy Committee meeting on Jan. 22.

Production and capture: Henderson told the committee that North Dakota oil production in 2024 is expected to finish near 1.1–1.2 million barrels per year and that gas capture across the state has remained strong—about 95% capture in recent years, he said. He described the current rig count as stable and indicated he expects rig and frac‑crew levels to hold roughly steady in the near term. Henderson said industry production decisions are increasingly driven by investor expectations (shareholder returns) rather than only by production growth targets.

Bakken inventory and well technology: The DMR updated lawmakers on inventory in the Bakken/Three Forks: the agency estimates tens of thousands of remaining locations across three tiers of development (Tier 1 core acreage largely developed, Tier 2 more prospective acreage and Tier 3 fringe acreage). Henderson said recent trends toward longer laterals—3‑mile and now 4‑mile wells—are being used to access more distant reserves; the committee heard that the first four‑mile lateral in the state has been completed and is being put on production. Committee members discussed unconventional horizontal well shapes (U‑shaped laterals) and drilling technology; Henderson and members described agitators and mud systems as part of controls that make extended reaches possible.

Enhanced oil recovery (EOR) and pilot tests: Henderson summarized several state‑level EOR pilot projects and tests—some completed, some in testing phases—that are testing CO2, waterflood and other huff‑and‑puff techniques to improve recovery. He said that, if successful, EOR approaches could extend the productive inventory of the Bakken and bolster supply and jobs.

IIJA orphan‑well plugging grants: Henderson reported on two Infrastructure Investment and Jobs Act (IIJA) grants administered by the DMR. The agency used an earlier IIJA award (presented to the state in 2022) to plug 73 wells and reclaim 114 sites. A separate formula grant recently awarded to the agency (described in the presentation as requiring extended federal compliance conditions) will provide additional funds, but Henderson told the committee that federal historic‑preservation and endangered‑species requirements tied to the formula grant impose significant procedural work and may require additional staff or contractor capacity to administer effectively.

Geologic survey, landslide mapping and critical minerals in lignite: Ed Murphy presented work by the North Dakota Geological Survey. He said the survey has completed statewide landslide mapping in multiple phases and is now using two lidar passes to identify active movement; the team identified roughly 12,000 active landslides in the latest comparison in the energy‑area lidar coverage. Murphy also summarized the state’s critical‑minerals sampling program in lignite. He said the survey has collected more than 2,200 rock samples and that analyses have returned loci with rare‑earth element concentrations far above typical North American coal baselines. Murphy cited individual samples and cores with rare‑earth totals up to about 4,000 parts per million in discrete horizons; he said the U.S. Department of Energy uses a rough economic screening benchmark around 300 parts per million (DOE figure referenced in the presentation). Murphy said many of the enriched intervals are thin (often a few inches to a few feet) and that additional core drilling is planned to better map the enriched horizons and evaluate recovery options; he said the survey will seek additional funding to continue drilling and laboratory analysis.

Next steps and funding asks: Murphy said the geological survey will request additional appropriations to finish targeted drilling and analysis; Henderson and Murphy both encouraged continued support for research and for IIJA grant administration resources. Henderson also said the department will continue to monitor industry consolidation, capital‑allocation dynamics and potential policy or regulatory shifts that might affect state production and employment.

Ending: Committee members asked technical and policy questions about u‑shaped laterals, radiation and processing requirements for rare‑earths, and the DMR committed to provide follow‑up technical details and to coordinate with EERC and industry on pilot efforts. No formal committee votes or policy actions were taken at the session.

","New DMR director Nathan Henderson and State Geologist Ed Murphy told legislators that North Dakota’s oil output remains roughly 1.1–1.2 million barrels per year, gas capture stays near 95%, and a state sampling program has identified isolated lignite intervals with elevated rare‑earth concentrations that merit further drilling and economic study.",{"_33":89,"_35":36,"_37":38,"_39":90,"_41":91,"_43":92,"_45":93,"_47":94,"_49":95,"_51":96,"_53":97,"_55":56,"_57":58,"_59":98,"_61":62,"_63":64,"_65":99,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},6393317,"Garrison Diversion updates legislators on Red River Valley Water Supply: 18 miles built, federal funding push continues",4076,2934000,7010000,"/Search/View?dp=1&key=2107595-c476dd8b9441b8b6cfafb4bb369f2c69&start=2934&end=7010","https://assets.pipeline.soar.com/2107595-c476dd8b9441b8b6cfafb4bb369f2c69/thumbnail_2934000.jpg","/articles/6393317/North-Dakota/Garrison-Diversion-updates-legislators-on-Red-River-Valley-Water-Supply-18-miles-built-federal-funding-push-continues","https://secure.pipeline.soar.com/6393317-fba62569032d52fb2232b6a898fe50a1/orig.mp4?Expires=1771023123&Signature=iSX7aUcbJVlP3Hvc0omwZ8A8kcV~H9c0XeKQeiY3A1LjW9W12rlbO2wavfHBxGHPj5ETtwL21a0X~VZbUhGXO4q9sOiWYawzzZmJrAb0dQKqSXmlV49XsS4cf4klgqF5eeOIfFgDPy7hpwlPw7NVUyueba-L3lzaMcWYSYfsPoexAp6KALz7Qr7-BhQcgp-IG~I~tjnBzm5Ujy9thz1GunlT2kalHWGMV37QgGjSLF0Dvnd5XDplmbyzNc5aFapyH65EGMZi5gV9k9~wRx3sEsI419WxUBw024Aluy2GSFEMH8XN3UzwEhFHmg9XRyMngSl6YUYDCz9TXqBISra7xA__&Key-Pair-Id=KUT5TJCACFTXG","Duane de Kray, general manager of the Garrison Diversion Conservancy District, briefed the Natural Resources and Energy Committee on Jan. 22 about construction progress and federal funding needs for the Red River Valley Water Supply Project (RRVWSP), a regional pipeline and treatment plan designed to deliver Missouri River water to Central and Eastern North Dakota.

Project purpose and context: De Kray reviewed the project’s history and purpose: the Red River project is intended as a long‑term emergency and supplemental water supply to support municipal, industrial and agricultural needs in eastern North Dakota and to underpin economic development. He noted the project was originally conceived to address a long history of dry periods—“in a 30‑style drought, the Red River … had 0 flow for five months,” he said—and to provide a dependable supply for cities and industrial users.

Scope, status and technical details presented: De Kray told the committee the project design includes a 72‑inch (6‑foot) spiral‑welded steel pipeline about 125 miles long and a treatment plant sized to deliver up to 165 cubic feet per second, with minimum cover over the pipe of about 7 feet where constructed across irrigated farmland. As presented, the slide deck listed a total program cost of approximately $1,260,000,000 (speaker‑presented figure). De Kray said 18 miles of pipeline had been placed in the ground, multiple construction contracts were underway in the Carrington area, and the authority planned additional contracts in the coming construction season. He described specific completed and ongoing contracts (5b, 5c and 5d were discussed) and presented photographs of trenching and restoration work.

Funding, the MR&I program and federal requests: De Kray explained that the Garrison Diversion Conservancy District is funded in part by one mill levied across member counties for general operations, and that many program costs are reimbursed or reimbursable by federal partners when work is performed on federal facilities. De Kray said the MR&I (Missouri River and Tributaries/Red River Mitigation and Restoration?) fund—created to compensate the state for prior federal decisions—was indexed to $200 million in earlier authorizations and that the program’s balance would be exhausted in 2025 absent additional federal appropriations. The district has a federal funding request in Congress; De Kray said the authority had sought roughly $454,000,000 in federal funds (presentation figure) and that Senator Hoeven was leading the effort. He said earlier committee progress had cleared some committee action but that at least two senators from other states raised objections; De Kray described the effort as continuing.

State appropriations and schedule: De Kray said the Legislature had provided $180,000,000 in the last biennium with local cost shares and that the state is following a multi‑biennium spend plan for a 10‑year build if the Legislature approves the requested amounts in future budgets. He noted the governor’s proposed budget included an amount the presenter quoted (discussants referred to a $172,000,000 figure in the governor’s recommendation) and said the district would seek $221,000,000 for the next phase under the ten‑year plan (presenter used the shorthand “2/21” for the next request; see clarifying details). He warned the committee that construction delays raise costs because of inflation and that slower legislative action would increase the total price.

Landowner, recreation and operations notes: De Kray described the project’s cooperative operations with local counties and the Department of Water Resources, listed recreation grants funded by the district (more than $9 million awarded historically), and noted that some irrigation development is already occurring on portions of the canal; the presenter said canal irrigation currently supports about 8,000 irrigated acres and that the canal had been underutilized for decades when the Bureau of Reclamation previously limited service to one‑year contracts.

Legal and river use context: De Kray traced the project’s federal history back to the Flood Control (Pick‑Sloan) Act of 1944 and North Dakota’s 1965 Garrison Diversion Act; he said the district worked to get a record of decision allowing the project to use existing canal infrastructure rather than a higher‑lift river intake, saving an estimated $300,000,000 in construction costs and lowering operational lifts and annual costs.

Ending and next steps: De Kray told lawmakers the district would continue construction where funding allowed and urged support for both continued state appropriations and federal funding. He asked for policy direction on whether certain intake infrastructure should be used for economic development or held as system redundancy; no formal legislative decision was taken at the hearing.

","Duane de Kray, general manager of the Garrison Diversion Conservancy District, told legislators on Jan. 22 that construction of the Red River Valley Water Supply Project is under way (18 miles of pipeline in the ground) and that the district is pursuing more federal funding while following a 10‑year construction plan if the Legislature continues appropriations.",{"_33":101,"_35":36,"_37":38,"_39":102,"_41":103,"_43":104,"_45":105,"_47":106,"_49":107,"_51":108,"_53":109,"_55":56,"_57":58,"_59":110,"_61":62,"_63":64,"_65":111,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},6393320,"Pipeline Authority outlines Bakken East gas pipeline, nonbinding open‑season and state backstop option",2621,2332000,4953000,"/Search/View?dp=1&key=2107595-c476dd8b9441b8b6cfafb4bb369f2c69&start=2332&end=4953","https://assets.pipeline.soar.com/2107595-c476dd8b9441b8b6cfafb4bb369f2c69/thumbnail_2332000.jpg","/articles/6393320/North-Dakota/Pipeline-Authority-outlines-Bakken-East-gas-pipeline-nonbinding-openseason-and-state-backstop-option","https://secure.pipeline.soar.com/6393320-8611e27cf8942c5154e03961d849b4b2/orig.mp4?Expires=1771023123&Signature=SwySqU4A0lMDx8I9bX-7bE73FcoUA6Q2DoMNYH7wXzW418SPezKMHuy44E8elTYA5rZ2sJu50cVylpGtEGrWJbLsQ5vKXv7Y9pQJHeDSYP7QP39gkTDpSDzfMvafzdcK2TTWP1EozaChF2Mzto3I-3xTkQVj3~CKeDEIF0hRSqxxmH1jM50Nv67vOGSIegc4GQCfh3PUVkqkb2Aq5oOr1JL1yrMnVj3St5S4YAeIUa1zKCuLJqsPtLnLWk46VQMtI6EJqGXoGBOP7kz8SybaeUDrpyrFH7DRG19A5VGWdntXlUq2J0J1QWXMRU4r1PbykESfnAu09x8ddYfW~GUxJg__&Key-Pair-Id=KUT5TJCACFTXG","Justin Kringstead, representing the North Dakota Pipeline Authority, told the Legislature’s energy committees that the state’s crude oil transmission system is generally adequate today but that natural‑gas takeaway capacity is the critical near‑term constraint for producers as wells get “gassier.”

Nonbinding open season for Bakken East/Bakken Express: Kringstead described a proposed new project—referred to in the presentation as Bakken East (also discussed as Bakken Express and involving multiple developers)—that would add pipeline capacity out of western North Dakota. He said the project’s developer has opened a nonbinding open season for potential long‑term contracts and that the initial scope described in the presentation calls for roughly a 375‑mile pipeline sized at about 30 inches in the western segment tapering to 24 inches in the east. The developer’s schedule presented to the committee showed phased in‑service dates in 2026 for the western segment and a twin east segment in late 2029, subject to commitments from users.

Capacity and timing concerns: Kringstead said the state’s major transmission system, Northern Border, is now 80–90% utilized by Bakken gas and other volumes, and that, depending on assumptions about Canadian flows and other projects, the state could face pipeline capacity shortfalls in the 2027–2029 timeframe in a base scenario. He said a specific project under discussion—Bakken Express—would add roughly 300,000,000 cubic feet per day (as described in the presentation) of capacity from the Kurtz/Glen Ullin area by re‑using existing pipe and interconnecting to larger hubs.

State financial tools and participation: The Pipeline Authority explained that the state has existing authority and financing tools to take a capacity position in a project as a participant of “last resort.” Kringstead said the Legislature previously provided a financing backstop that the authority could use; he described a currently available program that supports up to $30,000,000 per year (the presentation referred to it as a $30,000,000‑per‑year line of credit through Bank of North Dakota and backstopped by state investment funds). Under that program, Kringstead said, the state could take capacity commitments and then lease or release that capacity to private users if private interest is insufficient. He cautioned that, if private demand falls short and the state must retain capacity, the state could be liable for committed transport charges for the contracted term.

Open‑season mechanics, economics and risks: Kringstead explained that large pipeline projects commonly require long‑term (often 20‑year) take‑or‑pay commitments from producers, marketers or major industrial consumers before construction can proceed. The presentation included rate examples in the neighborhood of $0.85–$0.90 per dekatherm as an illustrative transport rate noted by the developer; Kringstead emphasized that the pipeline’s final sizing and timing depend on the level of binding shipper commitments that emerge from the open season.

Other infrastructure and storage: Kringstead highlighted the region’s major existing transmission systems (Northern Border, Alliance) and called attention to the WBI underground natural gas storage field near the southwest corner of the state, noting that the storage asset “has a tremendous amount of additional space and capability” and could be an important regional asset for supply security and flexibility.

What the committee heard: Lawmakers asked how the state’s $30 million annual capacity tool works in practice. Kringstead said that, as currently designed, the tool is intended to fill a gap alongside private sector commitments rather than be the primary financier. If the open season shows a meaningful shortfall, Kringstead said the authority would evaluate options and may request a policy decision from the Legislature on whether to provide a larger commitment.

Ending: Kringstead closed by asking interested counties, utilities and potential users to engage in the open season and said the authority will report back after the open season closes to show whether private commitments suffice to move the project forward.

","Justin Kringstead of the North Dakota Pipeline Authority briefed lawmakers on current crude and natural‑gas transport, a newly announced Bakken East pipeline proposal in nonbinding open season, and options for state participation under a $30 million‑per‑year backstop program.","actionData","errors"]

Article not found

North Dakota transmission authority warns EPA rules could threaten grid reliability, urges support for baseload and resilience grants

New DMR director outlines steady Bakken production, high gas capture and progress on critical‑minerals sampling

Garrison Diversion updates legislators on Red River Valley Water Supply: 18 miles built, federal funding push continues

Pipeline Authority outlines Bakken East gas pipeline, nonbinding open‑season and state backstop option