As oil prices tick up to $40 a barrel following a pandemic-induced plunge, there’s a sense the shale industry is snapping back to life with Continental Resources Inc., EOG Resources Inc. and Parsley Energy Inc. all saying they’re restarting closed wells.
But top industry forecasters are painting a far darker picture. The reopenings, they say, will do little to bring new growth to an industry being increasingly starved of cash by Wall Street after a decade of excess. Even before the pandemic, investors were demanding companies spend no more than they earn. Now, that’s become a major barrier to future growth.
Looking out 18 months, U.S. output will still be around 16% below its peak in February, according to the average of five major forecasters surveyed by Bloomberg. It will probably be at least 2023 before the U.S. again hits its record close to 13 million barrels a day.
“Nothing is going to be in the money,” said Bernadette Johnson, vice president of strategic analytics at Enverus, a data and research firm. At current crude prices in New York, she added, “very few new wells are being brought on line.”
Some 80% of executives surveyed by the Dallas Federal Reserve expect U.S. drilling and fracking won’t return to pre-Covid levels until at least next year, according to a report published Wednesday. Another 16% don’t expect the industry to ever return to the same workload again.
Even so, OPEC and its allies should not rest easy.
The shale revolution that made the U.S. the world’s No. 1 producer of oil and gas still retains its disruptive potential. Forecasters say there’s a high chance that shale could rebound quicker than expected if futures continue climbing and settle in the $55 to $65 a barrel range for an extended period of time.
America’s shale industry has defied the doubters for 15 years in terms of sheer volume of oil produced. In that period, it has more than doubled output, adding about 8 million barrels a day to global markets. That’s more than if the U.S. had taken over Iraq and Kuwait after President George W. Bush’s invasion in 2003.
But that achievement came at a huge cost. Shale operators have burned through about $340 billion over the past 11 years, using borrowed money and equity raised from Wall Street, leaving little left over for investors. The end result: Energy stocks have fallen this year to less than 3% of the S&P 500 Index in terms of weighting by the companies market capitalization.
As soon as oil prices began tumbling in March, shale producers rapidly slashed everything from drill rigs to workers and private jets. About 1.75 million barrels a day worth of production was shut in as producers couldn’t find buyers.
The last month has shown signs of a comeback, but it may be short-lived.
West Texas Intermediate, the U.S. benchmark, has doubled to $40 a barrel since the beginning of May, providing some relief to the industry’s most indebted names and creating an incentive for producers including EOG, Continental and Parsley to turn some previously shuttered wells back on. This is the lowest-cost and easiest supply to resume.
Over the past week, production has ramped up to about 10.8 million barrels a day, a 7% increase from when output bottomed out from shut-ins, according to Randall Collum Jr, managing director of upstream analytics at Genscape. Revivals in the Permian, Bakken and Gulf of Mexico have been particularly strong, he said.
While this may stabilize U.S. production for a few months, it probably won’t be enough to prevent further declines later in the year, according to IHS Markit and Enverus. That’s because shale’s explosive growth over the past decade came with a significant handicap: Massive decline rates.
Fracked wells give an initial pop of high production, but drop off by 60% in the first year, meaning more and more new wells must be drilled to overcome the decline. That requires cash that’s in short supply. If no new wells are drilled, U.S. production would drop by 35% in just 12 months, about seven times the rate for the global oil industry, according to Enverus.
Evidence of the negative outlook for producers can be seen in their spending plans, which are down by almost half to about $54 billion this year. The country now has just 189 active drill rigs, a 72% drop since March and around the lowest level since 2009, when the shale revolution was in diapers.
Even at $40 a barrel, the outlook for new wells is not good. While costs for the best parts of the Permian Basin break even below this level, the bulk of U.S. shale does not. In any case, most shale producers are busy conserving cash to repay their debts.
The big unknown, of course, is the price of oil. If prices rise to $50 a barrel, producers may be encouraged to start adding rigs again and drilling new wells, according to IHS. At that point, output could gain quickly, but even Rystad, the most bullish forecaster, doesn’t see the U.S. returning to the February peak before 2023.
The next level would be the big one. At $60 to $65 a barrel, the U.S. still has the capacity to add 1 million barrels a day for “a very long time,” said Johnson at Enverus.
The big question is how shale producers win back the trust of Wall Street to provide them with the money to do so. “They have the firepower to grow again but not the financing,” said Raoul LeBlanc, an analyst at IHS. “That trust will take some time to win back.”