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Continental-Resources-Profile-2022-vs-2023-Overview-with-2024-M-A-Moves

 

  • Continental Resources was acquired by Omega Acquisition, Inc., becoming a privately held company owned by the Hamm family, in a deal valued at approximately $4.3 billion.
  • In 2024, the company marks its 57th year of operation.  
  • As one of the top 10 independent oil companies in the U.S., Continental Resources has a significant presence in key oil regions including the Bakken field, Anadarko Basin, Powder River Basin, and Permian Basin.
  • Continental Resources invested $250 million in a large-scale project to capture and store CO2 in North Dakota.
  • The company expanded its operations by acquiring 400,000 acres in the Powder River Basin.
  • Continental focuses on enhancing oil recovery in the Bakken play through innovative well completion designs and the potential refracturing of existing wells.

 

What does Continental Resources do?

Continental Resources is actively involved in innovative energy projects to enhance oil production and environmental sustainability. The company has invested $250 million in the world's largest carbon capture and sequestration (CCS) project, a partnership with Summit Carbon Solutions. This project aims to capture CO2 from industrial sources in the Midwest and store it in North Dakota's Williston Basin, where Continental has significant experience and presence​​​​. 

In the Powder River Basin, Continental has expanded its operations by acquiring 400,000 acres. It is now the second-largest producer in this area, achieving high initial productivity from its Niobrara wells. The company aims to develop a competitive program across its portfolio, drawing on its successes in the Williston Basin​​. 

In the Williston Basin, known for its Bakken play, Continental is enhancing oil recovery through innovative well completion designs and exploring the potential of refracturing existing wells. These efforts are part of Continental's broader strategy to increase oil extraction efficiency and contribute to environmental sustainability. 

Where does Continental Resources operate?

Continental Resources stands among the top 10 independent oil companies in the U.S. and is at the forefront of the country's energy growth. Located in Oklahoma City, it holds the most leases and produces the most oil in the Bakken field, which spans North Dakota and Montana. Additionally, it's the top producer in Oklahoma's Anadarko Basin and holds significant leases in Wyoming's Powder River Basin and Texas's Permian Basin. Continental is focused on oil exploration and production, contributing significantly to the U.S.'s energy independence and leadership in the global oil market. 

Who did Continental Resources merge with?

In October 2022, Continental Resources, the company founded in the late 1960s by billionaire Harold Hamm, underwent a significant transition as it was acquired by Omega Acquisition, Inc., an entity wholly owned by Hamm. This acquisition was finalized following a merger agreement where Omega Acquisition agreed to purchase all outstanding shares of Continental Resources' common stock. The transaction was valued at approximately $4.3 billion, marking a pivotal moment for Continental Resources as it transitioned from a public company to a privately held entity, wholly owned by the Hamm family. 

How much is Continental Resources worth?

As of March 2024, Continental Resources has a market capitalization of $26.96 billion, ranking it as the TOP 10 oil producer in the U.S. and the 717th most valuable company globally. 

How many rigs does Continental Resources have?

2021:

Crude oil exploratory wells: 11 gross, 8.0 net

Natural gas exploratory wells: 2 gross, 1.9 net

Total exploratory wells: 13 gross, 9.9 net

Crude oil development wells: 376 gross, 144.6 net

Natural gas development wells: 38 gross, 20.3 net

Total development wells: 414 gross, 164.9 net

2022:

Crude oil exploratory wells: 17 gross, 12.1 net

Natural gas exploratory wells: 2 gross

Total exploratory wells: 20 gross, 13.1 net

Crude oil development wells: 407 gross, 153.6 net

Natural gas development wells: 65 gross, 28.8 net

Total development wells: 472 gross, 182.4 net

2023:

Crude oil exploratory wells: 33 gross, 25.9 net

Total exploratory wells: 33 gross, 25.9 net

Crude oil development wells: 548 gross, 259.0 net

Natural gas development wells: 27 gross, 7.6 net

Total development wells: 575 gross, 266.6 net

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  • Bakken Field

 

Saw a 26% Q4 year-over-year production increase, drilling 363 wells in 2023. This region accounted for 35% of Continental's total proved reserves and 49% of Q4 average daily production, with reserves at 647 MMBoe and 1,006 undeveloped drilling locations.

 

  • Anadarko Basin

 

Constituted 35% of total proved reserves and 32% of Q4 average daily production, with a slight decrease in production. The drilling activity involved 120 wells in 2023, totaling 653 MMBoe in reserves and 272 undeveloped drilling locations.

 

  • Powder River Basin

 

Represented 8% of total proved reserves and 6% of Q4 average daily production, decreasing production by 9% from the previous year. The 2023 drilling included 53 wells, increasing total reserves to 139 MMBoe and 136 undeveloped drilling locations.

2023 Continental's proved reserves

For crude oil, the proved developed producing reserves amount to 394,532 MBbls, with natural gas at 3,186,722 MMcf, a total of 925,653 MBoe. 

The proved developed non-producing reserves for crude oil stand at 7,319 MBbls and 34,844 MMcf for natural gas, resulting in 13,126 MBoe. 

Proved undeveloped reserves are substantial, with 512,183 MBbls of crude oil and 2,376,765 MMcf of natural gas, totaling 908,310 MBoe. 

Summing these categories, Continental Resources has a total of 914,034 MBbls of crude oil and 5,598,331 MMcf of natural gas reserves, combining for a grand total of 1,847,089 MBoe.

Region

Proved Developed Crude Oil (MBbls)

Proved Developed Natural Gas (MMcf)

Proved Developed Total (MBoe)

Proved Undeveloped Crude Oil (MBbls)

Proved Undeveloped Natural Gas (MMcf)

Proved Undeveloped Total (MBoe)

Bakken

187,125

916,570

339,887

201,766

630,987

306,931

Anadarko Basin

80,047

1,933,019

402,216

77,239

1,042,211

250,941

Powder River Basin

30,871

150,785

56,002

57,496

155,329

83,384

Permian Basin

82,261

220,725

119,049

175,682

548,238

267,054

All other

21,547

467

21,625

Total

401,851

3,221,566

938,779

512,183

2,376,765

908,310

Proved crude oil and natural gas reserves by region as the end of 2023

2021: Building Up

The year started with 1,103,762 MBoe in reserves. Positive adjustments (53,569 MBoe) and new discoveries (371,105 MBoe) showed the company was on the right track, finding more than it used. Even though 120,321 MBoe was produced, buying more resources (237,343 MBoe) helped end the year strong at 1,645,310 MBoe. 

2022: Keeping Steady

With a starting point of 1,645,310 MBoe, the year saw some downs due to adjustments (-133,061 MBoe) but stayed positive with new finds (395,490 MBoe). Production took away 146,657 MBoe, but smart buys (102,826 MBoe) kept the reserves healthy, ending at 1,863,764 MBoe. 

2023: Moving Forward

Beginning with 1,863,764 MBoe, the year had its challenges with a big dip from adjustments (-369,264 MBoe). Yet, new successes (438,367 MBoe) and smart purchases (90,476 MBoe) helped overcome the production loss (160,660 MBoe) and sales (-15,594 MBoe), closing the year at 1,847,089 MBoe. 

2023 Continental's Proved Undeveloped Reserves

At the start of 2023, the company had a lot of oil and gas waiting to be produced in the future, specifically 828,336 MBoe. This included 435,240 MBbls of crude oil and 2,358,578 MMcf of natural gas.

Continental had to revise their initial estimates, which led to a decrease of 298,945 MBoe. This happened for a few reasons:

  • They decided to wait to drill 39 MBoe of their reserves within five years because they found better places to invest their money and efforts.
  • Another 170 MBoe was revised down due to changing expectations about how much oil and gas they could get out of the ground, which was influenced by things like how close wells could be to each other and their performance.
  • The drop in oil and gas prices made them reduce their reserves by 25 MBoe since it might not be profitable to extract that oil and gas at those lower prices.
  • Lastly, 65 MBoe was reduced due to changes in who owns what, the cost of getting the oil and gas out, and how much they expect to produce.

On the bright side, Continental found and added 393,426 MBoe to their reserves thanks to new discoveries and other additions. They also bought more reserves, adding 84,088 MBoe, which more than made up for the small amount they sold (354 MBoe).

During the year, they moved 98,241 MBoe from being "undeveloped" to "developed," meaning they're closer to actually getting oil and gas out of those areas.

After all these changes, by the end of 2023, Continental Resources had 908,310 MBoe in Proved Undeveloped Reserves. This was made up of 512,183 MBbls of crude oil and 2,376,765 MMcf of natural gas. A part of these reserves, specifically 49 MBoe, were in wells they started drilling but hadn't finished setting up yet. 

2023 Continental's Acreages 

Bakken Region: The company holds a total of 1,189,834 gross acres and 753,175 net acres, with 1,115,481 acres developed and 74,353 acres undeveloped.

Anadarko Basin: There are 875,620 gross acres and 502,421 net acres in total, with 636,070 developed and 239,550 undeveloped acres.

Powder River Basin: This region has 526,439 gross acres and 376,043 net acres, with 247,057 acres developed and 279,382 acres undeveloped.

Permian Basin: The holdings include 227,753 gross acres and 193,275 net acres, with 118,803 developed and 108,950 undeveloped acres.

All other Regions: This category covers 421,056 gross acres and 300,010 net acres, with 186,906 developed and 234,150 undeveloped acres.

In total, the company's land holdings amount to 3,240,702 gross acres and 2,124,924 net acres across all regions. This includes 2,304,317 acres that are developed and 936,385 acres that are undeveloped.

2024 M&A moves 

Continental Resources has been very busy in the private sector, including making $1 billion in M&A.

The company isn't shy about sharing its business, unlike some private companies. It willingly shares details about its production and finances, even though it doesn't have to.

Continental's February 2024 report shows some of the business deals it's been involved in. It also covers how much oil and gas it produced from places like the Bakken and Permian, Anadarko, and Powder River areas.

In 2023, Continental spent $681 million buying other companies, with $161 million for properties already producing oil or gas and $520 million for those not yet doing so. It also sold $390 million worth of assets.

In March 2023, Continental announced it bought oil and gas properties in Oklahoma's Anadarko area for $178 million. This included $84 million for properties already producing and $94 million for those not yet producing.

This means Continental spent about $500 million on other purchases throughout the year, likely in the Bakken and Permian areas.

By comparing the amount of land Continental had at the end of 2023 to the amount at the end of 2022, we get a rough idea of what they added. This doesn't include land trades or other deals not involving money.

Continental's land in the Anadarko area grew the most, by 6%, to 502,421 acres. They also added land in the expensive Bakken and ultra-expensive Permian areas.

The only place Continental reduced its land was the Powder River Basin, by a small 1,773 acres. They also reduced their "other" oil and gas properties by 43,516 acres.

The company saw its overall production grow thanks to strong performances in the Permian and Bakken regions. This growth helped balance out small decreases of 3% to 5% in production from its Anadarko, Powder River, and other areas.

In the last three months of 2023, the Bakken area produced an average of 220,428 boe/d, which is 26% more than the same period in 2022. Over the whole year, the daily average production from the Bakken went up by 18% compared to 2022.

Continental shared that in 2023, it worked on drilling and finishing 363 wells in the Bakken, which is more than the 266 wells it worked on in 2022. By the end of the year, Continental had 539 wells in the Bakken that were ready to be developed but hadn't been drilled yet.

The Permian area accounted for 21% of Continental's total proven reserves at the end of 2023 and 13% of its production for the last quarter. The Permian produced 58,601 boe/d in the last quarter of 2023, up 30% from the same period in 2022. Continental drilled and finished 66 wells in the Permian, up from 35 the year before.

The company also reported that its proven reserves in the Permian Basin reached 386 MMBoe by the end of 2023, which is 27% more than at the end of 2022. Continental had 459 wells in the Permian ready to be drilled by the end of the year.

In the Anadarko area, production was down 13% in the last quarter of 2023 compared to the same period in 2022, averaging 144,158 boe/d. Continental drilled and completed 43 wells there.

The Powder River Basin saw a 9% drop in production in the last quarter of 2023, with an average of 25,577 boe/d.

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Who's Next after Diamondback? Potential Takeover Targets in the Permian Basin

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The $26 billion purchase of Endeavor Energy Resources by Diamondback Energy, with its stock up 2.6%, is the newest big deal combining oil and gas production in the Permian Basin under a few big companies

Bakken's Tipping Point: Grayson Mill's Potential Fall After Chevron-Hess

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The Permian Basin, a big oil area, is not seeing as many deals as before because lots of companies have already joined together. Now, experts think these companies might start looking for new places to invest in the U.S. One area getting attention is the Bakken play. Chevron Corp. has just made a big step there by buying Hess Corp. for $60 billion. Another company, Grayson Mill Energy, which got some help from a Houston investment firm EnCap Investments LP, might also be up for sale soon, worth about $5 billion.

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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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