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  • Continental Resources acquired 87 leases in Midland County from an Occidental Petroleum subsidiary.
  • The newly acquired Midland and Ector assets produced 76,000 barrels of crude and 123.1 million cubic feet of gas in their first three months.
  • Since going private in 2022, Continental has continuously expanded in the Permian Basin.
  • A recent acquisition added 92,000 net acres in Texas's southern Delaware Basin to Continental's holdings.

 

“Our main focus is on the Delaware side, but we’re looking also on the Midland side, as well.”

 

  • Continental CEO Doug Lawler. 

 

Continental Resources is expanding its operations in the Midland Basin, including taking over some assets that used to belong to Occidental Petroleum. The company plans to use its expertise in exploration in this area.

Owned by Harold Hamm, a billionaire known for his pioneering work in horizontal drilling in the Bakken region, Continental is a leading oil producer there.

Despite being well-established, Continental surprised many industry analysts by entering the Permian Basin with a big move. In late 2021, the company acquired Pioneer Natural Resources' assets in the Delaware Basin for $3.25 billion.

Now, Continental is pushing further east into the Midland Basin. According to records from the Texas Railroad Commission, in November 2023, Continental took on operatorship of several new leases in Midland and Ector counties, Texas.

Continental Resources has taken over 87 leases in Midland County from an Occidental Petroleum subsidiary, as shown by records from the Texas Railroad Commission (RRC).

In addition, Continental has started managing a few leases from Occidental in Ector County, just west across the county line, starting in November.

From November 2023 to January 2024, these assets in Midland and Ector counties produced around 76,000 barrels of crude oil in their first three months under Continental's operation, per the latest data from the RRC. They also produced a total of 123.1 million cubic feet of gas during the same period.

Most of the active leases have legacy vertical wells that tap into the Dora Roberts Field.

Occidental recently reported in its annual report that it sold some non-core proved and unproved properties in the Permian Basin for $202 million, recording a $142 million gain from these sales.

Continental has been tight-lipped about the specifics of the lease transfers in Midland and Ector counties but indicated that it continues to explore mergers and acquisitions in the Permian.

"We prefer not to discuss any specific transactions in detail, but expect Continental to keep looking for more acquisition opportunities and bolt-ons in the basin," said a Continental spokesperson.

Meanwhile, Occidental is expanding its presence in the Midland Basin through a $12 billion acquisition of CrownRock LP, a private producer. However, this deal increases Occidental's debt load. The Houston-based company has plans to sell between $4.5 billion and $6 billion worth of non-core assets within 18 months of closing the CrownRock deal to cut down its debt, including selling off some of its Permian assets.

Delaware Basin

In the Delaware Basin, Continental Resources is among a few companies venturing into deeper drilling, particularly targeting the Woodford formation.

So far, Continental has submitted detailed production data to regulators for three of its Woodford wells—two located in Winkler County and one in Pecos County. These wells have been drilled to significant depths, ranging from 13,000 feet to nearly 16,000 feet.

The production from the two Woodford wells in Winkler County, which have lateral lengths of 8,621 feet and 9,714 feet respectively, has totaled 248,747 barrels since they began operations in March 2023.

In Pecos County, the Magnolia State Unit well, with a lateral of 9,760 feet, has produced 144,590 barrels since it came online in April 2023. However, production data for another Woodford well in Pecos County, the Trees Ranch 0807 #1A, is not yet available.

Historically, the Permian Basin hasn't been a focus for exploratory drilling as it offers numerous easily accessible drilling sites. However, according to Lawler, Continental sees considerable potential for future gains, especially from the Barnett and Woodford intervals.

Rising Permian Portfolio

Continental Resources, which became privately owned after a $4.3 billion buyout by the Hamm family in 2022, has been steadily expanding its holdings in the Permian Basin since it first entered the area about two years ago.

The initial acquisition from Pioneer Natural Resources gave Continental about 92,000 net acres primarily in the southern part of the Delaware Basin, spanning Reeves, Ward, Winkler, and Pecos counties in Texas.

By the end of 2023, Continental had grown its Permian holdings to 193,275 net acres, as revealed in a filing in late February. Despite being privately held and not required to, Continental continues to publicly share its earnings and production details through quarterly filings.

Today, Continental's holdings in the Permian exceed 200,000 net acres, according to Lawler, the company's spokesperson.

Most of Continental's expansion in the Permian has been through smaller, accretive bolt-on acquisitions rather than large-scale mergers and acquisitions that have been common among other operators in the region.

Continental has primarily focused on acquiring assets with significant undeveloped potential rather than those with high existing production. This strategy was evident in the acquisition of the Delaware assets from Pioneer, which at the time of the purchase had a relatively low output of about 35,000 barrels of oil per day (50,000 barrels of oil equivalent per day).

In 2022, oil production from Continental's Delaware assets averaged around 32,416 barrels per day, growing to 40,443 barrels per day in 2023.

Most of the new wells Continental drilled in the Delaware assets targeted the popular Wolfcamp and Bone Spring formations, as indicated by RRC records.

Additionally, Continental is leveraging its expertise to identify horizontal drilling sites aimed at deeper geological layers, specifically the Woodford and Barnett Shale intervals across its Permian operations.

RRC data reveals production details for two Barnett wells in Ector County. The first well, Gardendale 121 13B #1H, with a lateral length of 10,565 feet, produced 201,408 barrels in its first 16 months. It also yielded 1,718 barrels during a 24-hour production test in December. The second well, H.S. Ratliff 85-17A #1H, which came online in December 2022 with a 10,219-foot lateral, produced 194,725 barrels over 14 months and initially tested at 380 barrels per day.

Continental has recently drilled five more Barnett wells, though full production data for these wells is not yet available due to regulatory provisions that allow producers to withhold post-completion well results for six months. The latest four wells on the Ratliff Red 0904 lease, all drilled to depths exceeding 11,000 feet, started production in late December 2023.

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Oil and Gas: Diamondback and Endeavor's $26 Billion Merger Redefines Permian Basin

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Diamondback's buyout of Endeavor happened about four months after ExxonMobil and Chevron made huge deals, with Exxon buying Pioneer Natural Resources for $59 billion and Chevron getting Hess for $53 billion. Even though 2023 was a slow year for company buyouts and mergers, with the total deals at $3.2 trillion (the lowest since 2013 and 47% less than the $6 trillion peak in 2021), the energy sector was still active. Experts think this buzz in energy deals is because these companies made a lot of money in 2022.

Vital Energy Expands Permian Basin Footprint with New Working Interest Acquisitions

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Vital Energy, an independent energy firm, recently expanded its holdings in the Permian Basin by purchasing additional working interests in prime production assets for approximately $55 million. These newly acquired assets were originally part of a larger transaction involving Henry Energy, Moriah Henry Partners, and Henry Resources.

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Recently, the progress toward an energy transition is hitting a snag. Sales of electric vehicles are decelerating, and the growth in wind and solar power needs to be keeping pace with expectations. To make matters more challenging, electricity prices are climbing when they were expected to fall. Amidst these setbacks, the oil and gas sectors are proving resilient. According to BP's latest energy outlook, not only are these energy mainstays here to stay, but their demand is expected to remain relatively high even after reaching a peak. Interestingly, BP forecasts that oil demand will reach its zenith next year, marking a critical moment in energy consumption trends. This isn't the first time BP has projected a peak in oil demand. Back in 2019, their review anticipated a decline in demand growth, but the prediction fell flat. Instead, oil demand surged to unprecedented levels following the end of the global pandemic lockdowns, defying previous forecasts and underscoring the enduring dominance of traditional energy sources in the global market.

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Texas energy companies are picking up the pieces after Hurricane Beryl, an early Category 5 hurricane, hit the U.S. Gulf Coast earlier this week. However, it weakened to Category 1 by the time it made landfall in Texas. The hurricane brought heavy rainfall and sparked fears of storm surges, flooding, and tornadoes. As Hurricane Beryl neared, the natural gas supply to Freeport LNG’s export facility in Texas nearly stopped the day before the storm struck. Houston was particularly hard-hit, with the storm knocking out power for two million residents. CenterPoint Energy, a key power provider in the area, felt the brunt of the hurricane but aimed to have power restored to half the affected customers by the following day.

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The total number of drilling rigs actively exploring and producing oil and natural gas in the United States increased to 585 for the week ending July 5, up from 581 the previous week. Despite this recent uptick, the current count still falls short of last year's 680, indicating a slowdown in drilling activities. Analysts suggest that this reduction may reflect greater efficiency among shale producers, who now require fewer rigs. Nonetheless, concerns remain about whether some producers have enough viable drilling land

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