Shale was largely behind the glut of American oil that flooded the market more than four years ago, leading oil prices to fall to $30 a barrel from more than a $100 a barrel in late 2014.
U.S. shale production in 2018 grew faster than it did during the boom years of 2011 to 2014, the IEA said last year.
The U.S. last year surpassed Russia and Saudi Arabia to become the world’s largest producer of crude oil, with output currently hovering around 12 million barrels a day.
U.S. crude production is expected to rise to 13.7 million barrels a day by the end of its five-year forecast period, the IEA said Monday.
“Annual gains will boost the U.S. to levels never seen in any country, in excess of maximum capacity in both Russia and Saudi Arabia,” the report noted.
In the next five years, Chevron expects to more than double its production in the Permian Basin in Texas and New Mexico to 900,000 barrels of oil and gas a day, the company announced at an investor event Tuesday. That’s a nearly 40% increase from its previous forecast.
“The shale game has become a scale game,” Chevron Chief Executive Mike Wirth said in an interview. “The race doesn’t go to the one who gets out of the starting blocks the fastest. The race goes to the one who steadily builds the strongest machine.”
Not to be outdone, Exxon on Tuesday announced plans to increase its Permian output to 1 million barrels of oil and gas a day by as early as 2024, a day before it was expected to disclose growth at its own investor meeting Wednesday. BP PLC,Royal Dutch Shell PLC and Occidental Petroleum Corp. are also focusing on the region.
Five years ago, Exxon, Chevron, BP, Shell and Occidental collectively made up about 9% of crude production from modern fracking techniques in the Permian. In October, the latest period for which relevant figures are available, they made up about 16%, according to data on ShaleProfile, an industry analytics platform.
Meanwhile, the big companies are just getting started. Exxon is now the largest operator in the Permian, with almost 50 rigs. The company estimates its Permian wells can generate a 10% rate of return at an oil price of $35 a barrel. While many companies reduced fracking activity in the fourth quarter of last year, Exxon increased it significantly to over 80 wells, more than double the total in the fourth quarter of 2017, according to Rystad Energy.
Chevron is raising its production guidance to 900,000 barrels of oil and gas a day by 2023. Last year, it predicted 650,000 barrels a day by 2023. The company is boosting production without adding to its rig count, a testament to how size can lead to greater efficiencies.
Chevron employed what could be described as a tortoise-and-hare strategy in the Permian. While smaller companies at times paid more than $40,000 an acre to gain rights to prime drilling opportunities, Chevron held on to land it already owned in the region, which decades ago was one of the world’s biggest traditional oil fields, without having to join in the buying frenzy.
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Within hours of each other on Tuesday, the two largest energy companies in America announced they want to pump almost 2 million barrels a day combined in the Permian Basin of west Texas and New Mexico, a higher amount than most OPEC nations. Chevron plans to reach 900,000 barrels a day by 2023, while Exxon aims for 1 million by 2024.
“Our position in the Permian just continues to get better and underpins our resource base,” Chevron Chief Executive Officer Mike Wirth said in New York. The value of the company’s Permian position has doubled over the past two years with reserve additions, he said.
Good read on technology and science at play in the Permian. This is a reminder that a great deal of what is happening (in my estimation) is still experimental.
Known in the industry as the “parent-child” well problem, the issue is surfacing in shale hot spots across the U.S. as companies ramp up production. Most of the tens of thousands of planned new wells will be child wells—wells drilled close to an already producing well.
It is one of the primary reasons why thousands of shale wells drilled in the past five yearsare producing less oil and gas than companies forecast to investors, a Wall Street Journal examination of drilling data has found.
Shale producers across the country are finding “you can get a lot of interference, one well to the other,” said billionaire Harold Hamm, who founded shale driller Continental Resources Inc., in an interview last year. “Laying out a whole lot of wells can get you in trouble,” he said. Mr. Hamm was discussing other companies, not Continental.
Many of the largest shale producers, including Devon Energy Corp. , EOG Resources Inc.and Concho Resources Inc., have disclosed they are facing the problem. Some have begun drilling wells farther apart to get around it, which means they have fewer total wells to drill on their land.
This post is a bit off our normally beaten path but the parallels are interesting.
The university’s endowment manager, Harvard Management Co., was stealthily building a sizable grape-growing business on the Central Coast through entities including Brodiaea. With the land, it was acquiring rights to vast sources of water in a region where the earth’s warming is making the resource an ever-more-valuable asset.
In a warming planet, few resources will be more affected than water, as more-frequent droughts, storms and changes in evaporation alter a flow critical for drinking, farming and industry.
Even though there aren’t many ways to make financial investments in water, investors are starting to place bets. Buying arable land with access to it is one way. In California’s Central Coast, “the best property with the best water will sell for record-breaking prices,” says JoAnn Wall, a real-estate appraiser who specializes in vineyards, “and properties without adequate water will suffer in value.”
Oldy but goody here from 1998. The modern owner has to wonder if Bregman’s quote around a “creeping buyout” will hold true from here.
“People are going to become less interested in ‘concept’ stocks that sell at hope times greed times infinity,” says Mr. Shaefer, who is also editor of the Investor’s Edge newsletter, which has pushed Texas Pacific. Instead, investors will “be looking for real underlying asset value in the companies they own.”
Mr. Shaefer says his fund bought an undisclosed stake in Texas Pacific in January 1997 at $27.63 a share, and he doesn’t plan to sell until the stock reaches at least $80. By his calculations, the underlying assets are worth about $100 a share right now.
At its current rate, the trust is buying back stock more quickly than it’s selling land. Between 1980 and 1995, the trust reduced its number of outstanding shares by 34% but reduced its land inventory only 8%, from 1.2 million acres to 1.1 million acres.
Steven Bregman, president of Horizon Asset Management in New York, has researched Texas Pacific for his firm’s Contrarian Research Report and believes the stock is worth buying. “It’s cheap,” he says. “As long as you want to hold it for a decade, you put it away and forget about it and get rich slowly.”
The buybacks, says Mr. Bregman, are “like a creeping buyout. It’s a snowball effect.”
Some good stats and soundbites here on US onshore shale production.
Chevron’s output in the Permian Basin of Texas and New Mexico rose 80% for the year ended in September, eclipsing some of the small producers that spent years building up their fracking positions.
While many big oil companies were slow to fracking, bigger companies have tended to benefit as technology matures and drillers shift from exploration to large-scale production. That trend is most apparent in the Permian Basin. Large companies including Exxon, Chevron, BP, Shell and Occidental this year are set to produce an average of about 600,000 barrels a day of crude in the region, up 54% from last year. By 2021, their output there will exceed 1.1 million barrels a day, or about 20% of the area’s total shale-related output, according to consulting firm Rystad Energy.
Pipeline access is another area where bigger companies fared better. As U.S. oil production soared above 11 million barrels a day, growth exceeded existing pipelines, forcing smaller companies to sell their oil at a discount. Crude sold in the Permian Basin was discounted by an average of $14 a barrel during the third quarter, according to S&P Global Platts. That differential has since contracted to about $5.