Texas Shale Forces Big Oil Cost Revolution, Chevron CEO Says
For Mike Wirth, the future of Big Oil lies at home, under the dusty fields of West Texas.
As he celebrates his first year as CEO of Chevron Corp., Wirth sees the Permian Basin as a plentiful source of high-quality crude for years to come, but that’s not all. The low break-even costs to pump in the Permian are forcing Chevron to be more efficient everywhere, Wirth said, from the deepwater platforms in the Gulf of Mexico to its liquefied natural gas plants.
In a time of transition, when everyone from politicians to shareholder activists is bashing Big Oil, shale’s success is forging a new reality, Wirth said: Lower your costs, or die.
Shale “has forced us to get smarter about how we do everything else,” Wirth said in an interview in Houston. The cost of Gulf of Mexico projects is at “levels we would never have imagined a decade ago,” he added. Chevron isn’t becoming more efficient “because we were dumb then and we’re smart now. We’re doing it because we have to.”
If not, he said, the alternative is to put money into the Permian.
CEO of Chevron Corp., Mike Wirth (Spike Johnson/Bloomberg News)
As Wirth prepares to present his new strategy to investors in early March, his message is one of never-ending belt-tightening, always preparing for even lower energy prices and strong competition. It’s a lesson that came from his days rising through the oil refining ranks at Chevron: Bad margins one year could turn even worse the next.
“Let’s not bet on high prices,” Wirth said, sitting in a conference room in the company’s Houston offices, with pictures of old Chevron retail logos on the wood-paneled wall behind him. “You make your own margin. Some of that comes through innovation and cost discipline. That’s a philosophy I bring to my current role and a belief that just because prices go back up, we shouldn’t accept the fact that costs have to go up.”
It’s a popular theme with shareholders in the energy industry who saw many companies spending billions in megaprojects that never deliver the expected returns. In Chevron’s case, investors endured half a decade of intense capital spending on developments in the Gulf of Mexico and enormous LNG projects in Australia, only for the oil price to crater in 2014.
Famously, at one Australian venture, Gorgon, costs swelled by almost half to $54 billion.
“Everybody was investing in these kinds of things,” Wirth said. “[But] it’s unlikely we’d see that confluence of events come together again. I certainly don’t see that in the foreseeable future.”
Chevron’s stock has outperformed U.S. rival Exxon over the past three years but lags European major Royal Dutch Shell. Oil executives have talked about keeping costs low since the 2016 crash, but the last quarter was their first real test. Chevron, along with all five Western supermajors, beat expectations on earnings, producing strong cash flows in the period despite Brent crude’s 38% decline.
Wirth declined to specify capital expenditure plans after 2020, a concern for some analysts, but said investors should expect “continual disciplined capital allocation.” Chevron will announce long-term capital plans at its investor day in New York on March 5. Wirth delivered last year’s version barely a month into the job.
“We won’t fund everything,” Wirth said bluntly, describing two deepwater projects Chevron abandoned last year that, a few years ago, it would have invested in. Instead, Chevron is focusing on the Permian Basin of West Texas and New Mexico, the world’s biggest shale oil field where it inherited a region-leading 2.2 million-acre position as part of its merger with Texaco in 2001.
The area has been transformed from dusty cattle pasture to the supermajor’s biggest global growth project in just three years. Production has surged 84% in the 12 months and now accounts for more than one in every 10 barrels Chevron pumps worldwide. The Permian is on track to be cash flow positive by 2020, Wirth said.
Big Oil initially ignored shale oil, not just in the Permian but in North Dakota, Colorado and Oklahoma, with executives instead touting the majors’ ability to build megaprojects in distant countries. All that changed with the oil price collapse that started in 2014. Exxon paid $6.5 billion to expand in the Permian in 2017, and BP shelled out $10.5 billion to buy acreage there.
The advantages of the Permian are manifold: a cheap source of production in an oil-friendly jurisdiction, high growth rates, low technical risk and the ability to raise and lower output depending on crude prices.
Chevron is allocating the bulk of its upstream capital expenditure to the Permian this year, which means two-thirds of its annual spending will begin generating cash flow within two years. That’s almost unheard of, and an example of disruption in an industry that typically measures its capital spending and returns over decades.
It also is a protection mechanism against an evolving energy future. Short-term projects are less likely to be stranded if demand or policy changes wipe out investments. It’s a risk that weighs on Wirth, though he insists that oil and gas still have a strong future in scenarios laid out in the Paris Agreement on climate change.
“I’m not one who believes that even the world’s best strategic planners can tell the future,” Wirth said. “We can build a portfolio and an operating culture that’s resilient to change, that’s resilient to unforeseen developments. Let’s not bet on high prices, let’s not bet on a particular technology shift or a policy shift because we can’t control those things.”
As such, don’t expect Chevron to follow European rivals Royal Dutch Shell and Total SA in diversifying into the power utility business as a hedge against declining crude demand.
“Some oil and gas companies may choose to reduce their share of oil and gas production and sales over time,” Wirth said. “You’d like to believe those who are the most efficient, the most capable, the most environmentally responsible are the ones who will be the producers that increasingly the world relies on. That’s a core competency of ours.”