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ONEOK has completed its $4.425B acquisition of Brazos Midstream’s natural gas gathering and processing assets in the Midland Basin.

ONEOK expands Midland Basin capacity with $4.425 billion deal

ONEOK has completed its $4.425 billion acquisition of Brazos Midstream’s natural gas gathering and processing assets in the Midland Basin, according to Rigzone’s October 8 report. The purchased network includes approximately 700 miles of gathering pipelines and 1.1 billion cubic feet per day of processing capacity, counting facilities under construction.

The deal brings ONEOK’s Midland Basin processing capacity to about 2.3 billion cubic feet per day, more than twice its previous level when projects under construction are included. The Cassidy 2 processing plant is expected to be finished in the third quarter of 2027. Long-term fixed-fee contracts cover 600,000 dedicated acres, with more than 12 years remaining on average.

The acquisition was supported by Apollo Global Management’s $9 billion investment. ONEOK said the transaction advances its adjusted EBITDA growth objectives for the next five to seven years and strengthens flexibility for potential dividend increases and share repurchases. Management also linked the combined transactions to reaching a debt-to-EBITDA ratio of 3.25 times.

Source: Rigzone
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DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Barnett-Woodford holds 3 billion barrels of recoverable oil across 6,400+ Midland Basin drilling locations, per EIR.

Barnett-Woodford expands Midland Basin oil development options

Enverus Intelligence Research (EIR) has identified more than 6,400 potential drilling sites in the Barnett-Woodford, representing roughly 3 billion barrels of recoverable oil awaiting development in the Midland Basin. According to Oil & Gas 360, these formations rank first among the basin’s interval groups for remaining undeveloped oil.

Average Barnett-Woodford well performance has exceeded the Midland Basin baseline by more than 30% since 2025. Assuming well costs of $800 per foot, EIR estimates a breakeven oil price near $41 per barrel, comparable with recent Midland and Delaware Basin averages. Encouraging results have supported broader operator programs, following limited inclusion in development models approximately 18 months earlier.

After adjusting for development maturity, well density and timing, EIR ranked Ector, Crane and northwestern Upton counties as the leading area, with recent wells averaging estimated breakevens around $42 per barrel. Southeastern Andrews, southwestern Martin and western Midland counties followed at about $46 per barrel. EIR describes the play as the largest Lower 48 expansion opportunity for oil-focused drilling.

Source: Oil & Gas 360
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
BLM announces Nov. 18 oil and gas lease sale offering 30 parcels totaling 8,071 acres in New Mexico, Oklahoma, Texas, and Kansas.

BLM to auction 30 oil and gas lease parcels in November 2026

The Bureau of Land Management has scheduled a November 18, 2026, auction for 30 oil and gas lease parcels spanning 8,071 acres in New Mexico, Oklahoma, Kansas and Texas. Announced on September 18, the sale will take place online through Efficient Markets. Parcel details and information about upcoming auctions are available through the agency’s National Fluids Lease Sale System.

BLM completed scoping in June 2026 and concluded public comments on the parcels and their environmental review in August. An additional public protest period closes on October 19. Maps, parcel information and protest submission instructions are available on the agency’s ePlanning pages for the Carlsbad, Farmington and Oklahoma field offices.

For operators, oil and gas leasing begins the federal resource development process. Operators must then outline proposed development in a drilling permit application before work can begin. The agency assesses these plans, publishes the applications for public input, examines environmental effects and works with state partners and other interested parties. Parcels offered in federal lease sales carry conditions designed to protect natural resources.

Source: Bureau of Land Management
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Matador completes $1.255B Paloma Permian deal, adding 16,500 acres and 156+ drilling locations in New Mexico.

Matador expands Delaware Basin holdings with Paloma deal

Matador Resources has completed its $1.255 billion purchase of Paloma Permian LLC from EnCap Investments, World Oil reported on October 1. The transaction adds about 16,500 net acres in New Mexico’s Eddy and Lea counties, with most of the land held by production. The company identified more than 156 net drilling locations, measured on a two-mile lateral basis, across at least nine potential target intervals, plus 59 approved drilling permits.

Matador intends to start drilling up to 25 wells on the acquired acreage by the end of 2027. Since June 1, 2026, the properties’ production has been approximately 10% higher than the estimates used to evaluate the acquisition, mainly because of newer Eddy County wells. Management sees opportunities to improve development efficiency and increase use of its existing midstream systems.

If its separate Ridge Runner Resources II purchase closes as expected in October, Matador anticipates a core Delaware Basin position of roughly 240,000 net acres during the fourth quarter. Together with acreage obtained in a May federal lease sale, these additions would represent nearly 20% growth from October 2025.

Source: World Oil
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
US energy firms added rigs for a third consecutive week, marking the first such streak since July, Baker Hughes said.

U.S. drilling rig count reaches 599 after third weekly gain

U.S. energy firms added four oil and gas rigs in the week ended September 25, bringing the total to 599, according to Baker Hughes data reported by BOE Report. It was the third consecutive weekly increase and the highest combined count since May 2024. The total stood 50 rigs, or 9%, above its level a year earlier. Oil rigs rose by three to 455, gas rigs increased by one to 135, and miscellaneous rigs held at nine.

In the Permian Basin of West Texas and eastern New Mexico, the count increased by one to 270, its highest since June 2025. Oklahoma also added one rig, reaching 52, its highest count since May 2025. Rig counts provide an early indication of drilling activity and potential future production.

The report also cited U.S. Energy Information Administration projections for 2026. Crude oil output is expected to reach 13.8 million barrels per day, compared with 13.7 million in 2025. Natural gas output is projected to rise from 107.6 billion to 111.7 billion cubic feet per day, with demand for electricity used by data centers and for liquefied natural gas exports contributing to the outlook.

Source: BOE Report

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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
The US EIA raised its forecasts for crude oil and lease condensate production in its September Short-Term Energy Outlook.

EIA sees U.S. crude oil output topping 14 million bpd in 2027

The U.S. Energy Information Administration raised its forecasts for crude oil and lease condensate production in its September Short-Term Energy Outlook. It now expects U.S. output to average 13.83 million barrels per day in 2026 and 14.26 million in 2027, compared with August forecasts of 13.80 million and 14.15 million, respectively. The September report also puts 2025 production at 13.66 million barrels per day, up from the figure used in August.

The forecast shows output rising from 13.88 million barrels per day in the third quarter of 2026 to 14.39 million in the final quarter of 2027. If the annual projection is realized, 2027 would be the first year U.S. crude production averages more than 14 million barrels per day. These figures are forecasts, while the 2025 figure reflects reported production.

The Lower 48 states outside the federal Gulf account for most of the projected output: 11.38 million barrels per day in 2026 and 11.87 million in 2027. The federal Gulf is projected to contribute 2.00 million and 1.89 million barrels per day in those years, while Alaska contributes 0.45 million and 0.50 million. Readers comparing national forecasts with individual wells can use Ranger’s guide to oil well production for context on daily production rates.

Source: Rigzone
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
EIA now forecasts a larger oil market crunch in 2026 and a bigger glut in 2027 than in its August short term energy outlook.

EIA raises 2026 oil supply gap outlook, sees 2027 surplus

The U.S. Energy Information Administration’s September Short-Term Energy Outlook projects global petroleum and other liquid fuels consumption at 102.59 million barrels per day in 2026, compared with production of 100.62 million barrels per day. That represents a 1.97 million-barrel-per-day supply gap, slightly wider than the agency’s August estimate of 1.91 million barrels per day. For 2027, the EIA expects consumption to average 104.98 million barrels per day while production reaches 109.88 million barrels per day, resulting in a 4.90 million-barrel-per-day surplus.

The EIA expects the 2026 supply gap to reach 2.96 million barrels per day in the third quarter before narrowing to 1.71 million barrels per day in the fourth quarter. Global oil inventories are estimated to have declined by about 400 million barrels so far this year. The agency now forecasts Brent crude to average around $90 per barrel during the second half of 2026, followed by an average of $74 per barrel in 2027 as production increases and inventories rebuild.

The outlook assumes Middle East oil exports will gradually increase as flows through the Strait of Hormuz and alternative routes improve, while some export limitations remain through the end of 2026. For mineral and royalty owners, these market developments provide useful context when reviewing factors affecting oil prices and how benchmark crude prices can influence wellhead pricing and oil and gas revenue.

Source: Rigzone

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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
A legislative committee will hear from the Texas Railroad Commission Tuesday as it updates rules for inactive oil and gas wells.

Texas reviews new rules for long-inactive oil and gas wells

Texas lawmakers are reviewing how the Railroad Commission of Texas will implement updated requirements for inactive oil and gas wells. The commission oversees nearly 160,000 inactive wells statewide, including at least 12,000 classified as orphaned. The issue is receiving renewed attention as regulators work to reduce the number of wells that remain inactive for extended periods and clarify operators’ responsibilities for plugging them. Ranger readers can find additional background on orphan well liability and mineral rights.

Under SB 1150, passed during the 2025 legislative session, operators generally must plug wells after 15 years of inactivity, although extensions may be available under specified circumstances. The Texas House Energy Resources Committee was scheduled to hear from the Railroad Commission about its plans for implementing the law. Industry representatives have supported efforts to reduce inactive well inventories while preserving opportunities to return economically viable wells to production.

The hearing also brings attention to financial assurance requirements intended to help cover future plugging obligations. Texas currently allows bonding amounts to be calculated either by well depth or the number of wells an operator controls. The commission’s rulemaking could therefore be relevant to operators, mineral owners and investors tracking regulatory responsibilities and long-term well management in the state. More background on the regulator is available in Ranger’s coverage of the Railroad Commission of Texas.

Source: The Texas Tribune

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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
U.S. natural gas production and consumption are projected to reach record highs in 2026 and 2027, driven by rising demand.

U.S. natural gas production and demand set for record growth

U.S. natural gas production and consumption are projected to reach new highs in both 2026 and 2027, according to the U.S. Energy Information Administration’s September Short-Term Energy Outlook. The agency expects dry gas production to increase from 107.6 billion cubic feet per day (Bcf/d) in 2025 to 111.7 Bcf/d in 2026 and 115.9 Bcf/d in 2027. Domestic consumption is forecast to rise from 91.9 Bcf/d in 2025 to 92.2 Bcf/d this year and 94.3 Bcf/d next year.

The latest outlook also raised the EIA’s 2026 estimates compared with its August forecast. Meanwhile, U.S. liquefied natural gas exports are expected to increase from 15.1 Bcf/d in 2025 to 17.4 Bcf/d in 2026 and 18.6 Bcf/d in 2027. Growing output from regions including the Permian Basin and Haynesville is expected to support supply, while inventories could enter the winter season about 5% above the five-year average.

For energy markets, the projections point to continued expansion in both domestic demand and export activity alongside rising supply. The outlook also provides useful context for mineral and royalty owners following broader natural gas production trends, particularly as U.S. LNG exports and major producing regions continue to grow.

Source: BOE Report
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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.
Shipping through the Strait remains severely disrupted amid repeated attacks and a U.S. naval blockade, keeping oil prices elevated.

Hormuz vessel strike puts focus on energy shipping and prices

A commercial vessel was struck by an unidentified projectile while traveling through the Strait of Hormuz, according to the United Kingdom Maritime Trade Operations Centre. The incident, reported late Saturday, September 12, led to a fire aboard the vessel and prompted local authorities to assist with the evacuation of crew members. The event came as direct negotiations between the United States and Iran remained inactive, while Iranian and Gulf officials were preparing discussions in Oman on proposed shipping arrangements through the strategically important waterway.

The incident adds another consideration for global energy markets as commercial traffic through Hormuz remains substantially reduced. CNBC reported that Brent crude settled Friday at $104.61 per barrel and West Texas Intermediate at $100.05, after both benchmarks reached higher levels during the week. Saudi Arabia also temporarily closed its East-West crude pipeline as a precaution after drone attacks, affecting an important route used to bypass Hormuz. For mineral and royalty owners, these developments illustrate how geopolitics and transportation constraints can be important factors affecting oil prices and, consequently, revenue associated with oil and gas royalties.

U.S. Central Command also said it had redirected 100 commercial vessels during the previous 60 days following the resumption of the U.S. naval blockade against Iran. With Hormuz serving as a major route for oil and other cargoes, shipping activity, regional security developments and diplomatic discussions remain closely watched by energy-market participants.

Source: CNBC

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Ranger Land & Minerals curates weekly insights from across the oil and gas industry to keep our readers informed. To receive news like this directly in your inbox, join our free newsletter. If you’d like to learn more about mineral rights and oil royalty opportunities, contact us to speak with a representative.
DISCLAIMER: The summary above is based on information from third-party sources believed to be reliable, but its accuracy and completeness cannot be guaranteed. It is provided for general informational purposes only and does not constitute investment, financial, tax, legal, or other professional advice, nor a recommendation or solicitation to buy or sell any security, commodity, or investment product. Markets, regulations, and circumstances can change, and the information may not reflect the most current developments. You should conduct your own research and consult a qualified financial advisor, CPA, or other professional before making decisions based on this content. The publisher and its affiliates disclaim any liability for losses or damages arising from reliance on the information provided above.