oil-gas
21 August 2024
Global Energy Infrastructureoil-gas
Aug 21, 2024Global Energy Infrastructure
UK Oil & Gas PLC is delighted to announce that, via its wholly owned subsidiary UK Energy Storage ("UKEn"), it has executed a heads of terms covering the 60-year lease of land and subsurface mineral rights for a second underground salt-cavern hydrogen storage facility in south Dorset. The land lies above the thickest onshore part of the Dorset Triassic salt deposit and is also in close proximity to SGN's planned H2 Connect hydrogen pipeline, linking the proposed storage caverns directly to the planned Solent Cluster and the wider southern UK hydrogen super-cluster (see RNS 27th June 2024).
Each UKEn hydrogen storage site aims to provide around 6.5-10 Terawatt-hours ("TWh") of working storage per annum, equating to around 10-20% of the UK's estimated 2050 hydrogen storage demand*. UKEn's aim of delivering these key strategic energy infrastructure elements is fully in step with the Government's ambitious target to decarbonise the UK power system by 2030.
UKEn will now proceed ahead to finalise the lease agreement, complete salt cavern design studies and commence other works necessary to submit a Nationally Significant Infrastructure Project planning application. The Company also aims to apply for government Revenue Support for at least one Dorset site (see RNS 29th May, 27th June, 2nd August 2024).
Stephen Sanderson the Company's Chief Executive commented:
"UKEn's new Dorset site is optimally placed to exploit the thickest part of the onshore Dorset Triassic salt deposit, permitting large underground caverns to be emplaced via a modest sized surface facility. Its proximity to SGN's H2 Connect pipeline is deliberate and will ensure storage can be directly linked to the planned Solent Cluster and wider Southern UK hydrogen networks.
We look forward to continued collaboration with government to develop these strategic UK energy infrastructure assets and to help make the 2030 UK power decarbonisation target a reality."
Note: * National Grid's July 2023 System Transformation Scenario and the Royal Society's September 2023 Large-Scale Electricity Storage Report estimate 2050 UK hydrogen storage demand at around 50 TWh and 60-100 TWh, respectively.
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Adnoc Drilling Awarded Five-Year Contract For Oilfield Services Worth Up To Us$800 MillionADNOC Drilling Company PJSC has announced the award of a contract valued at up to US$800 million by ADNOC Onshore for the provision of integrated hydraulic fracturing services for conventional and tight reservoirs. The five-year agreement is set to commence in 3Q25, marking another significant milestone in ADNOC Drilling’s evolution as a fully integrated technology-enabled energy services company.
This award further reinforces ADNOC Drilling’s leadership in high-tech oilfield services, combining next-generation equipment, artificial intelligence (AI) and real-time intelligence to deliver smarter, safer and more sustainable energy outcomes.
Commenting on the award, Abdulla Ateya Al Messabi, ADNOC Drilling CEO, said: “This significant contract is a powerful endorsement of ADNOC Drilling’s expanding capabilities and our trusted partnership with ADNOC Onshore. It reflects our ability to deliver high-impact, technologically advanced fracturing services that will help unlock the UAE’s energy potential. As we continue our transformation, we are proud to support the nation’s strategic energy goals and reinforce our position as a leader in integrated drilling and completion solutions.”
The contract’s scope of work supports ADNOC’s strategic goal to accelerate the development of conventional and tight reservoirs across the UAE and includes the design, execution and evaluation of multistage hydraulic fracturing treatments, which will be deployed across a wide range of assets in Abu Dhabi. Fracturing services for conventional and tight reservoirs are used to enhance the flow of oil or gas through existing natural pathways and optimise production by improving flow rates.
ADNOC Drilling will deploy advanced technologies throughout the project to maximize efficiency and performance. Proprietary fracturing simulation software will be used to optimise every stage of the operation, increasing flow rates and overall hydrocarbon recovery. Intelligent fluid systems will adapt dynamically in real-time to reservoir conditions, improving fracture efficiency and reducing environmental impact. Automated pumping units and blending systems will enhance safety, streamline operations and reduce the need for on-site manpower.
This marks the fifth contract in just over two months, including a US$1.63 billion five-year contract for Integrated Drilling Services (IDS), a US$806 million contract for three island rigs and a US$1.15 billion 15-year contract for two jack-up rigs, all awarded by ADNOC Offshore, and a US$400m backlog of ADNOC Drilling’s signed acquisition in Oman and Kuwait.
Read the article online at: https://www.oilfieldtechnology.com/drilling-and-production/02072025/adnoc-drilling-awarded-five-year-contract-for-oilfield-services-worth-up-to-us800-million/
The newly installed equipment and facilities are working well and continue to be fine-tuned to optimise production.
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Oilfield Technology
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02 July 20253 min readAdnoc Drilling Awarded Five-Year Contract For Oilfield Services Worth Up To Us$800 Million
Oilfield Technology
02 July 2025
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Dno Inks Gas Offtake Deal With Engie, Secures $500M Financing FacilityNorwegian oil and gas operator DNO has entered into an offtake agreement with France’s Engie for its Norwegian gas production and secured a related offtake financing facility with a major U.S. bank for up to $500 million.
The offtake agreement, secured through DNO’s Norway operating subsidiaries, covers the entirety of its Norwegian gas production post acquisition of Sval Energi, offers premium pricing and has a tenor of four years as from October 1, 2025.
Related to the agreement, DNO has entered into an offtake financing facility with a U.S. bank for up to $500 million.
Under the facility, DNO is paid, by the bank, the value of up to 270 days of scheduled gas production based on future gas sales receivables.
The all-in interest rate for drawn amounts under the facility is significantly below conventional reserve-based lending (RBL) terms available to DNO, with no charges for undrawn amounts. There are no financial covenants related to the facility.
Proceeds from the offtake financing facility will be used to replace Sval Energi’s similar existing facilities as well as for general corporate purposes.
In June, DNO completed the acquisition of Sval Energi from HitecVision, picking up 16 producing fields in Norway and quadrupling its North Sea production to 80,000 barrels of oil equivalent per day (boepd).
“We have received strong interest by buyers to prepurchase our enlarged North Sea production of 80,000 barrels of oil equivalent per day split about equally between oil and gas.
“These three-way transactions are made possible because buyers are eager to lock in secure supplies of Norwegian oil and gas and US banks, in particular, have significantly stepped up fossil fuel lending,” said DNO’s Executive Chairman Bijan Mossavar-Rahmani.
Given availability of attractive offtake financing terms, DNO has repaid and will not renew over $600 million in RBLs across its North Sea subsidiaries. In addition, the company has borrowed #300 million under a one-year bank bridge loan ‘to add more arrows to its quiver’, according to Mossavar-Rahmani.
Separately, DNO said it was in discussions to establish an offtake agreement and related financing facility on comparable terms for its North Sea oil production.
Offshore Engineer
oil-gas
02 July 20252 min readDno Inks Gas Offtake Deal With Engie, Secures $500M Financing Facility
Offshore Engineer
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Dno Strikes Deals For Gas Offtake And $500 Million Financing FacilityDNO ASA entered into an offtake agreement with France’s ENGIE SA for DNO’s Norwegian gas production and secured a related offtake financing facility with a major U.S. bank for up to $500 million.
The offtake agreement covers the entirety of DNO’s Norwegian gas production post acquisition of Sval Energi Group AS, offers premium pricing and has a tenor of four years as from 1 October 2025.
Related to the agreement, DNO has entered into an offtake financing facility with a U.S. bank for up to $500 million (USD). Under the facility, DNO is paid, by the bank, the value of up to 270 days of scheduled gas production based on future gas sales receivables. The all-in interest rate for drawn amounts under the facility is significantly below conventional reserve-based lending (RBL) terms available to DNO, with no charges for undrawn amounts. There are no financial covenants related to the facility.
Proceeds from the offtake financing facility will be used to replace Sval Energi’s similar existing facilities as well as for general corporate purposes.
“We have received strong interest by buyers to prepurchase our enlarged North Sea production of 80,000 boed split about equally between oil and gas,” said DNO’s Executive Chairman Bijan Mossavar-Rahmani. “These three-way transactions are made possible because buyers are eager to lock in secure supplies of Norwegian oil and gas and US banks, in particular, have significantly stepped up fossil fuel lending,” he explained.
Given availability of attractive offtake financing terms, DNO has repaid and will not renew over $600 million in RBLs across its North Sea subsidiaries. In addition, the Company has borrowed $300 million under a one-year bank bridge loan “to add more arrows to our quiver,” according to Mr. Mossavar-Rahmani.
Separately, DNO is in discussions to establish an offtake agreement and related financing facility on comparable terms for its North Sea oil production.
World Oil
oil-gas
02 July 20252 min readDno Strikes Deals For Gas Offtake And $500 Million Financing Facility
World Oil
02 July 2025
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Qapqa To Support Building 300Km Gas Pipeline For AramcoQapqa, an automated pipeline welding technology company, has secured a contract with A-HAK Pijpleidingen Saudi for Package 9 of Saudi Aramco’s Master Gas System-3 (MGS-3) project.
As part of the agreement, Qapqa will deploy three fully equipped automatic welding spreads along with a team of highly experienced welding professionals to support the construction of more than 300 km of 56-inch X70 gas pipeline.
This pipeline forms a critical segment of one of the Middle East’s most ambitious energy infrastructure developments.
The contract highlights Qapqa’s growing presence in the region and reinforces its reputation for delivering field-proven welding automation technology and consistent operational excellence on high-specification pipeline projects.
With a strong track record in complex environments, Qapqa continues to be a trusted partner for large-scale energy infrastructure projects.
"We are honoured to be selected as the automatic welding partner for this strategic project," says Ralph, CEO at Qapqa.
"Our team is proud to support A-HAK Pijpleidingen Saudi and contribute to Saudi Aramco’s long-term vision for energy infrastructure expansion."
The MGS-3 project is a key component of Saudi Aramco’s broader initiative to enhance the capacity, reliability, and efficiency of the Kingdom’s natural gas network.
OGN News
oil-gas
01 July 20251 min readQapqa To Support Building 300Km Gas Pipeline For Aramco
OGN News
01 July 2025
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Equinor, Partners Greenlight $1.3B Johan Svedrup Oil Field ExtensionEquinor and its partners have approved the $1.29 billion (NOK 13 billion) investment in the third phase of Johan Sverdrup field, which entails the installation new subsea infrastructure to increase recovery by 40 - 50 million barrels of oil equivalent (boe).
The development includes two new subsea templates, in the Kvitsøy and Avaldsnes areas with six well slots each, totaling eight wells, including seven oil production wells and one water injection well.
The new subsea templates will be tied into existing templates and pipelines to the P2 platform for processing and export.
The investment will increase recoverable volumes from the field by 40 - 50 million boe, with production expected to start in the fourth quarter of 2027.
To ensure optimal resource utilization, the project leveraged artificial intelligence to analyze field layouts and well paths. This technology has enabled faster decision-making and resulted in cost savings of $13 million (NOK 130 million) for the phase 3 project, Equinor said.
The project also facilitates future value creation at Johan Sverdrup by adding extra well slots, and opportunities for connecting additional subsea templates.
For the phase 3 project, TechnipFMC has been awarded the contract for engineering, procurement, construction, and installation (EPCI) for the subsea development, with a contract value of approximately $525 million (NOK 5.3 billion). Additional contracts, including platform modifications and the drilling of eight wells, are planned to be awarded later in 2025.
Johan Sverdrup is located in the Utsira High area of the North Sea, 160 kilometers west of Stavanger, in water depths of 110–120 meters, covering an area of 200 square kilometers.
The expected recovery rate from Johan Sverdrup is already at 66%, and the phase 3 project aims to increase it to 75%, while the average for the Norwegian continental shelf (NCS) is 47%.
Equinor is the operator of the field, with 42.6267%, with partners Aker BP holding 31.5733%, Petoro 17.36%, and TotalEnergies EP Norge 8.44%.
The partnership has submitted a notification to the authorities in accordance with the existing plan for development and operation (PDO). The notification is subject to governmental approval.
“By building on the technologies, solutions, and infrastructure from phases 1 and 2 of Johan Sverdrup, we can carry out an efficient development with a rapid start-up of production.
“The project increases the recovery rate and value creation from Johan Sverdrup, one of the world’s most carbon-efficient oil and gas fields. At the same time, it contributes to stable energy supplies to Europe,” said Trond Bokn, senior vice president for project development in Equinor.
Offshore Engineer
oil-gas
01 July 20253 min readEquinor, Partners Greenlight $1.3B Johan Svedrup Oil Field Extension
Offshore Engineer
01 July 2025
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275-Mile Texas-To-Oklahoma Gas Pipeline Enters Open Season(P&GJ) — Producers Midstream II, LLC has launched a binding open season to gauge shipper demand for firm transportation on its proposed Palo Duro (PD) Pipeline, a 275-mile (about 443-km) natural-gas line that will link residue markets at Waha in the Permian Basin with Mid-Continent outlets in the Anadarko Basin.
The project will repurpose existing 16-inch pipe running from Nolan County, Texas, to Wheeler County, Texas, and lease capacity on the company’s gathering header into western Oklahoma. Because no new pipe construction is planned, the company will seek interstate authority from the Federal Energy Regulatory Commission under Section 7(c) of the Natural Gas Act, aiming for a first-quarter 2026 in-service date.
“This Open Season marks a key milestone for the Palo Duro Pipeline and underscores our commitment to delivering scalable, market-responsive infrastructure,” said Matt Flory, Producers Midstream’s chief executive officer. “The pipeline's unique interconnectivity and strategic positioning creates a much-needed additional outlet for constrained Permian gas, while also supporting the rapid growth of AI-driven power solutions and other emerging sources of demand.”
The north–south line will interconnect with up to seven interstate systems—Northern Natural Gas, Transwestern, NGPL, ANR, Panhandle Eastern, Enable Gas Transmission and Southern Star—giving shippers multiple downstream options. Producers Midstream said the route is designed to ease Permian takeaway bottlenecks while meeting rising industrial, petrochemical, power-generation and behind-the-meter loads.
The open season runs June 30–July 14. Full bidding procedures and technical details are available at Producers Midstream’s website. Interested parties can contact the company’s marketing team at marketing@producersmidstream.com or 214-238-5740.
Mary Holcomb is the Digital Editor & Operations Manager at Gulf Energy Information, overseeing the Pipeline & Gas Journal, World Oil, and Underground Infrastructure brands. With over 5 years of experience, she drives digital content strategy and operations for these industry-leading publications.
Pipeline Gas Journal
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30 June 20252 min read275-Mile Texas-To-Oklahoma Gas Pipeline Enters Open Season
Pipeline Gas Journal
30 June 2025
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Adnoc Drilling Awarded Five-Year Contract For Oilfield Services Worth Up To $800 MillionADNOC Drilling Company PJSC (“ADNOC Drilling” or the “Company”) (ADX symbol: ADNOCDRILL / ISIN: AEA007301012) announced today the award of a contract valued at up to $800 million by ADNOC Onshore for the provision of integrated hydraulic fracturing services for conventional and tight reservoirs. The five-year agreement is set to commence in 3Q 2025, marking another significant milestone in ADNOC Drilling’s evolution as a fully integrated technology-enabled energy services company.
This award further reinforces ADNOC Drilling’s leadership in high-tech oilfield services, combining next-generation equipment, artificial intelligence (AI) and real-time intelligence to deliver smarter, safer and more sustainable energy outcomes.
Commenting on the award, Abdulla Ateya Al Messabi, ADNOC Drilling CEO, said: “This significant contract is a powerful endorsement of ADNOC Drilling’s expanding capabilities and our trusted partnership with ADNOC Onshore. It reflects our ability to deliver high-impact, technologically advanced fracturing services that will help unlock the UAE’s energy potential. As we continue our transformation, we are proud to support the nation’s strategic energy goals and reinforce our position as a leader in integrated drilling and completion solutions.”
The contract’s scope of work supports ADNOC’s strategic goal to accelerate the development of conventional and tight reservoirs across the UAE and includes the design, execution and evaluation of multistage hydraulic fracturing treatments, which will be deployed across a wide range of assets in Abu Dhabi. Fracturing services for conventional and tight reservoirs are used to enhance the flow of oil or gas through existing natural pathways and optimize production by improving flow rates.
ADNOC Drilling will deploy advanced technologies throughout the project to maximize efficiency and performance. Proprietary fracturing simulation software will be used to optimize every stage of the operation, increasing flow rates and overall hydrocarbon recovery. Intelligent fluid systems will adapt dynamically in real-time to reservoir conditions, improving fracture efficiency and reducing environmental impact. Automated pumping units and blending systems will enhance safety, streamline operations and reduce the need for on-site manpower.
This marks the fifth contract in just over two months, including a $1.63 billion five-year contract for Integrated Drilling Services (IDS), a $806 million contract for three island rigs and a $1.15 billion 15-year contract for two jack-up rigs, all awarded by ADNOC Offshore, and a $400m backlog of ADNOC Drilling’s signed acquisition in Oman and Kuwait.
Gulf Oil and Gas
oil-gas
30 June 20252 min readAdnoc Drilling Awarded Five-Year Contract For Oilfield Services Worth Up To $800 Million
Gulf Oil and Gas
30 June 2025
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Medco Energi Acquires Stake In Repsol’S Indonesian Gas Operation For $425MIndonesian oil and gas operator Medco Energi Internasional has reached an agreement with Spanish energy company Repsol E&P to acquire a 24% stake in the Corridor Production Sharing Contract (Corridor PSC), indirectly held by Fortuna International, for $425m (Rp6.88trn).
The transaction is expected to enhance Medco Energi’s portfolio, with completion anticipated in the third quarter of 2025 (Q3 2025).
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The Corridor PSC, situated onshore in South Sumatra, Indonesia, comprises seven producing gas fields and one oilfield.
The gas from these fields is sold under long-term contracts to buyers in Indonesia and Singapore, ensuring a stable revenue stream.
MedcoEnergi president director Hilmi Panigoro said: “This acquisition supports our strategy of owning and developing high-quality, cash-generative assets and reaffirms our commitment to national development where natural gas is a vital bridge to a lower-carbon future.”
Medco Energi reported EBITDA (earnings before interest, taxes, depreciation and amortisation) of $332m in Q1 2025, surpassing its figures from Q4 2024.
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This financial uptick is attributed to effective cost management strategies, although it has been partially offset by seasonal variations leading to reduced gas demand.
Repsol, with a presence in more than 20 countries, is focusing on its upstream business to prioritise more lucrative assets.
This divestment aligns with its strategy to concentrate on assets with higher profitability and cash generation capabilities.
The sale is expected to positively influence Repsol’s financials, with an estimated $70m boost to its annual income, reported Reuters.
Moreover, the transaction will contribute to a reduction in Repsol’s net debt of approximately $350m, underscoring the deal’s strategic financial benefits.
In December last year, GeoPark signed binding sales and purchase agreements to acquire Repsol’s upstream oil and gas assets in Colombia.
Offshore Technology
oil-gas
27 June 20252 min readMedco Energi Acquires Stake In Repsol’S Indonesian Gas Operation For $425M
Offshore Technology
27 June 2025
oil-gas
Abbott Unveils $105 Million Loan For New 122-Mw Gas Plant In Texas(Reuters) — Texas Governor Greg Abbott announced on June 26 that the first Texas Energy Fund (TEF) loan agreement will be used to fund a 122 megawatt (MW) natural gas power plant in Texas.
"Under the loan agreement, subject to customary financial closing procedures, total project costs are not to exceed $175 million, with the PUC providing a 20-year TEF loan of up to $105 million at a 3% interest rate," said a press release on Abbott's official website.
The governor's office added that the Kerrville Public Utility Board is the project's sponsor and will develop the facility, which is projected to begin operations by 2027.
The facility will interconnect to the South Load Zone adjacent to Houston Load Zone, one of the largest electricity demand centers in the state.
Pipeline Gas Journal
oil-gas
27 June 20251 min readAbbott Unveils $105 Million Loan For New 122-Mw Gas Plant In Texas
Pipeline Gas Journal
27 June 2025
oil-gas
Boem Proposes Oil, Gas Lease Sale For 80 Million Acres In Gulf(WO) — The Bureau of Ocean Energy Management (BOEM) has published a Proposed Notice of Sale (PNOS) for Lease Sale 262, the first of three offshore auctions in the Gulf of America under the 2024–29 Outer Continental Shelf Leasing Program.
The sale would offer about 15,000 unleased blocks—roughly 80 million acres—located 3 to 231 miles offshore in water depths from 9 ft to more than 11,100 ft.
“Offshore oil and gas play a vital role in our nation's energy portfolio, with the Gulf of America supplying 14 percent of domestically produced oil,” said Matt Giacona, BOEM’s principal deputy director. “This proposed lease sale demonstrates BOEM’s commitment to advancing American Energy Dominance and fostering the production of affordable, reliable energy resources for the nation.”
BOEM estimates the broader Gulf outer continental shelf holds about 48 billion barrels of undiscovered oil and 141 Tcf of natural gas. Leases awarded through Sale 262 would be limited to exploration and development; areas withdrawn by a 2020 presidential order, portions near the Eastern Gap and the Flower Garden Banks National Marine Sanctuary remain off-limits.
To encourage industry interest, the agency is proposing a 16 ⅔ percent royalty rate for both shallow- and deepwater tracts, the lowest deepwater rate since 2007. “To support robust industry participation, lower production costs, and unleash the full potential of the Gulf of America’s offshore energy reserves, BOEM is proposing a royalty rate of 16 ⅔ percent for both shallow and deepwater leases—the lowest rate for deepwater since 2007,” said Laura Robbins, acting regional director for the Gulf.
The PNOS appears in the Federal Register on June 27, opening a 60-day comment period for Gulf-state governors and local governments. BOEM expects to issue a Final Notice of Sale at least 30 days before the scheduled bid reading, now targeted for Dec. 10, 2025, which will be livestreamed.
World Oil
oil-gas
26 June 20252 min readBoem Proposes Oil, Gas Lease Sale For 80 Million Acres In Gulf
World Oil
26 June 2025
oil-gas
Equinor, Partners Greenlight $2 Billion Investment In North Sea Oil And Gas ProjectEquinor and its Fram partners will invest more than $2 billion (NOK 21 billion) in a new subsea development. The plan for development and operation was today submitted to the Minister of Energy, Terje Aasland.
"Fram Sør will contribute to security of energy supply from the Norwegian continental shelf (NCS) to Europe," said Geir Tungesvik, Equinor's executive vice president, Projects, Drilling & Procurement. "The development will put new oil and gas resources on stream by connecting new infrastructure to existing facilities that provide good and robust profitability. With the host platform Troll C being powered from shore, the production from Fram Sør will have very low emissions. The project will generate activity for the Norwegian supply industry, with an estimated employment effect of 4,500 full-time equivalents (FTEs) during the development period,"
The Fram Sør project is a combined development of several discoveries that will export oil and gas via Troll C. Recoverable volumes are estimated at 116 MMboe, 75% of which is oil and 25% is gas. Production is scheduled to start at the end of 2029.
Equinor holds 45% interest in Fram, along with partners Vår Energi ASA (40% interest) and INPEX Idemitsu Norge AS (15% interest).
"We have done a thorough job maturing the new resources discovered in the Fram and Troll area in recent years," said Kjetil Hove, Equinor's executive vice president for Exploration & Production Norway. "Fram Sør shows the importance of area solutions and close collaboration between partners and authorities in order to realize the resource values on a mature NCS. We have a large portfolio of projects that will phase in discoveries to our producing fields. Equinor expects to put more than 50 such projects on stream by 2035."
In the autumn of 2019, Equinor and partners made a discovery of oil and gas in the Fram area of the North Sea. This discovery, called Echino South, supported the belief that more oil could be found, and contributed to nine discoveries made in the Troll-Fram area over a four-year period. In the spring of 2021, Equinor and partners made the Blasto discovery. Together with two smaller discoveries in previous years, Echino South and Blasto form the basis for Fram Sør.
The field development is also technologically groundbreaking, Equinor stated. As the first on the NCS, Fram Sør will use all-electric Christmas trees that eliminate the need for hydraulic fluid supplied from the platform and improve monitoring capabilities of the subsea equipment. It is an efficient and reliable system for operating subsea Christmas trees, as well as reducing the risk of environmental impact.
World Oil
oil-gas
26 June 20253 min readEquinor, Partners Greenlight $2 Billion Investment In North Sea Oil And Gas Project
World Oil
26 June 2025
oil-gas
Intensity, Rainbow Energy To Build 344-Mile Gas Pipeline Across North Dakota(P&GJ) — Intensity Infrastructure Partners and Rainbow Energy Center have announced a joint venture to build a new natural gas pipeline spanning from the Bakken region in western North Dakota to the eastern part of the state, a move aimed at boosting in-state resource use and reducing flaring.
The planned pipeline will increase takeaway capacity for associated natural gas in the Williston Basin, enabling greater in-state processing and delivery while supporting oil production growth and boosting state tax revenues.
RELATED: North Dakota’s Bakken Basin Set for Midstream Comeback, Experts Say
“This project represents a long-term investment in North Dakota’s energy future,” said Stacy Tschider, CEO of Rainbow Energy Center. “A pipeline of this size directly supports the state’s goals to grow all energy production responsibly while capturing greater economic value for our citizens.”
The 344-mile project will be constructed in two phases:
The target in-service date is July 2029, with potential acceleration based on market interest and permitting.
“We’re excited to work with Rainbow to enhance the state’s ability to monetize its natural gas resources locally,” said Joseph Griffin, CEO of Intensity. “The state has been seeking a project of this size with a customer like Rainbow for nearly a decade.”
Continental Resources Vice Chairman Jeff Hume added, “This marks a major milestone in strengthening North Dakota’s energy infrastructure.”
The pipeline will also reserve capacity for future, unannounced projects along its route, allowing for expansion as demand grows.
Pipeline Gas Journal
oil-gas
26 June 20252 min readIntensity, Rainbow Energy To Build 344-Mile Gas Pipeline Across North Dakota
Pipeline Gas Journal
26 June 2025
oil-gas