Fracking 2.0 Was a Financial Disaster, Will Fracking 3.0 Be Different?

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Two years ago, the U.S. fracking industry was trying to recover from the crash in the price of oil. Shale companies were promoting the idea that fracking was viable even at low oil prices (despite losing money when oil prices were high). At the time, no one was making money fracking with the business-as-usual approach, but then the Wall Street Journal published a story claiming all of this was about to change because the industry had a trump card โ€” and that was technology.

Today, frackers are again relying on technology as a financial savior, but this time, they are looking to Microsoft.

As ExxonMobil embarks on an ambitious move into fracking in the Permian oil fields of West Texas, it has announced a partnership with Microsoft to use cloud technology to analyze oil field data and optimize operations. Exxon claims the move could generate โ€œbillions in net cash flow.โ€

Time will tell if the Microsoft cloud will make Exxon rain profits in the Permian. 

Fracking 2.0

In March 2017, the Wall Street Journal ran an article with the headline, โ€œFracking 2.0: Shale Drillers Pioneer New Ways to Profit in Era of Cheap Oil,โ€ which detailed the ways the shale industry expected technology could help it finally deliver profits. The article mentioned โ€œlonger, supersize wellsโ€ and said, โ€œThe promise of this new phase is potentially as significant as the original revolution.โ€

The article highlighted EOG Resources (as in, Enron Oil and Gas), a company often touted as the โ€œApple of oil,โ€ and quoted the companyโ€™s chief information officer saying that technology advances allowed its employees to work at the โ€œspeed of thought.โ€

It also reported that Chesapeake Energy was betting on these new supersize wells as part of its โ€œturnaround strategy.โ€ Chesapeake needed to โ€œturnaroundโ€ from losing money and move in the direction of profits.

In June 2017, investment website Seeking Alpha trumpeted โ€œThe Arrival of Super-Lateralsโ€ as a technological accomplishment for the shale oil industry. (โ€œLateralsโ€ are the industry term for the horizontal wells used in the fracking of shale oil and gas). That article featured Chesapeake Energyโ€™s new achievements in drilling longer lateral wells.

But supersized wells werenโ€™t the only solution for keeping shale drillers from losing more money. Another was more wells per drilling pad. A year ago shale company Encana announced plans for โ€œcube development,โ€ in which it would drill 64 wells on one gargantuan drilling site in the Permian oil fields of West Texas.

The same thing was happening in the Marcellus Shale in Pennsylvania, where top natural gas producer EQT Corporation had plans for drilling 40 wells per pad. The company recalled the early days of fracking when drilling three wells per pad was seen as a significant breakthrough. As the Pittsburgh Post-Gazette reported at the time, the higher number of wells per pad required โ€œcreative geometry,โ€ which โ€œensures that the wells donโ€™t crowd each other underground.โ€


Oil and gas fracked well sites in Wyoming. Credit: Ecoflight

The Post-Gazette also quoted Dave Elkin, a senior vice president of asset optimization at EQT, touting the ever-increasing lengths of horizontal wells, as saying the โ€œeconomic and technological limitโ€ for those in the Marcellus Shale was 21,000 feet, or just shy of 4 miles.

With more advanced technology delivering longer horizontal wells and creative geometry packing them into smaller areas, profits seem like the next logical step.

But Fracking 2.0 was a financial disaster, and shale drillersโ€™ desperate attempts to make money any way they can is coming back to haunt them in a big way.

Frac Hits and Technological Limits

EQT did indeed drill the longest wells but also lost a lot of money in the process. According to the Wall Street Journal, โ€œThe decision to drill some of the longest horizontal wells ever in shale rocks turned into a costly misstep costing hundreds of millions of dollars.โ€

EQT started 2019 with a round of layoffs. Chesapeakeโ€™s supersized wells meant that in 2018 the company spent $600 million more than it made to produce oil and gas.

But that wasnโ€™t the really bad news for the fracking industry, which was learning that its โ€œcreative geometryโ€ was mostly creating losses. Encana โ€” the company with the super pad of 64 wells โ€” also announced layoffs. In a letter to the Texas Workforce Commission, Encana said, โ€œThe company intends to gradually separate employees between now and May 31, 2019,โ€ moving from creative geometry to creative ways of describing layoffs.

And while those are just three companies that tried to push the limits of fracking technology, the issue of packing too many wells on the same pad could greatly alter the economics of the fracking industry. As I wrote in August 2018, when oil and gas wells are too close to each other, the fracking process can damage nearby wells โ€” a process known as โ€œfrac hits.โ€ The result can cost drillers money and greatly reduce the amount of oil they can pump from these wells.

Two years after its Fracking 2.0 story, the Wall Street Journal published one titled, โ€œShale Companies, Adding Ever More Wells, Threaten Future of U.S. Oil Boom.โ€  The article details how packing too many wells on a drilling pad is โ€œturning out to be a bust.โ€

According to the Journal, this reality could lead to an โ€œindustrywide write-down if they are forced to downsize the estimates of drill sites they have touted to investors.โ€ For a highly leveraged industry on a decade-long money losing streak, that isnโ€™t good news.

Industry analysts at Wood MacKenzie started to warn about the limits of technologyโ€˜s ability to deliver more oil in the Permian in 2017. In the Wall Street Journal, Robert Clarke, research director at Wood Mackenzie, said, โ€œUnless there is a massive technological breakthrough, those child wells are going to be smaller.โ€ Child well is the industry term for the multiple wells drilled on a pad around the first โ€œparentโ€ well.

Once again, unless technology can change the financial equation, the fracking industry is in trouble.

Which brings us to Fracking 3.0 โ€ฆ

Fracking 3.0: Exxon Bets on Microsoft to Solve the Problem

Despite the past financial disasters and failure of new technology to deliver profits for frackers, the oil industryโ€™s biggest players are now getting in on the game in the prolific Permian oil fields. And the solution to frackingโ€™s profits problem โ€” according to the likes of ExxonMobil โ€” is Microsoft. Apparently cloud technology has been the missing ingredient in the Permian.

In the past week, Exxon and Chevron have both announced plans for major investments in the Permian Shale, which they promise will deliver large increases in both oil production and profits.

Much like in 2017, current headlines have been touting Exxonโ€™s plans and its partnership with Microsoft to use technology to finally figure out how to make money fracking in the Permian.

It appears to be an effective public relations push by Exxon โ€” which was much needed. A year ago Exxonโ€™s poor financial performance was linked to its failure to make a big move into fracking shale for oil. At the time, CNN wrote, โ€œExxonMobil missed the invitation to Americaโ€™s big oil party.โ€

While this latest promise of profits from fracking now has some of the worldโ€™s largest companies behind it, these plans are nothing more than a press release at this point. Which makes this a good time to revisit when Exxon made a big move into natural gas in 2010. Exxon bought natural gas producer XTO for $40 billion, and while the U.S. is producing record amounts of natural gas in 2019, this deal is viewed as one of the worst in the history of the energy industry.

โ€œThat was one of the worst acquisitions in the history of the energy business. It was exquisitely poorly timed,โ€ Pavel Molchanov, an energy analyst at Raymond James, told CNN in 2018.  โ€œโ€ฆIt was essentially $40 billion down the drain.โ€

Perhaps Exxonโ€™s big move into shale oil wonโ€™t repeat history, and the oil giant will finally unlock the secret to profits while fracking for shale oil with improved technology.

For some perspective, however, it helps to look at how EOG โ€” the โ€œApple of oilโ€ โ€” is doing these days.

For that, letโ€™s turn to Art Berman, a leading industry analyst with a strong track record on many aspects of fracking for oil and gas. In February he published an analysis showing that 2015 was the best year for EOGโ€™s well performance for its Eagle Ford wells in Texas and that 2018 might be the worst.

Technology apparently isnโ€™t delivering great results for the โ€œApple of oilโ€ โ€” but perhaps Microsoft has the answers.

Main image: Original photo Marcellus Shale Gas Well โ€“ Jackson Township/Butler County, PA by WCN 24/7 under license CC BYโ€“NC 2.0 adapted by Justin Mikulka, CC BYโ€“NC 2.0

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Justin Mikulka is a research fellow at New Consensus. Prior to joining New Consensus in October 2021, Justin reported for DeSmog, where he began in 2014. Justin has a degree in Civil and Environmental Engineering from Cornell University.

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