2018 Conference Highlights

EOC Recap


Knowledge is king in the oil patch and sweeping technological innovation has granted producers sovereignty.

“You have to know the rock and be able to innovate quickly,” Phil Webb, COO of Surge Energy, told attendees of Hart Energy’s Executive Oil Conference on Nov. 7.

Know these—viscosity, velocity and proppant size—and you have the advantage.

“The tools to steer wells are incredible today, and now the effort is to accurately quantify the subsurface volume,” said Allen Gilmer, co-founder and executive chairman of Drillinginfo Inc. The goal, said members of the afternoon “positive sum production” roundtable, is to wrest as many barrels of oil equivalent per day (boe/d) as possible per dollar invested.

Earlier in the day, Bill Wren of the University of Texas at Austin’s McDonald Observatory discussed how he works with the industry in the Permian Basin to keep the night skies dark to the benefit of both astronomers and operators.

Wren said that such collaboration entails the use of shielded lighting fixtures as well as aiming lights downward. Those suggestions benefit the industry as well because they reduce glare and enhance visibility, he said. Full cutoff fixtures, warmer color temperatures and improved management of flares are some of the actions the industry can take that work well for both industry and the observatory’s Hobby-Eberly Telescope, third-largest in the world.

Closer to the ground, a late-morning discussion concluded that the Permian is primed for a coming wave of consolidation. Panelists included Mike Marziani, executive vice president and CFO for Tall City Exploration III LLC; James Walter, Co-CEO of Colgate Energy LLC; and Chris Atherton, president of EnergyNet.

The panelists examined pricey tracts of land in the basin. Bids on the Bureau of Land Management’s 50,000 acres in New Mexico totaled $972 million. That’s partly the acres are in the prolific Delaware Basin and partly because the tracts are longer. Pricees for side-by-side parcels swung from $300 to $2,500 per acre based on the ability to accommodate 2-mile laterals.

Very large firms will be able to swallow a percentage of leaseholds with a low cost of capital, with the result that the big get much bigger, panelists said. As these companies consolidate, they will shed non-core assets down the chain.

For the smaller companies, the story is a bit different. Panelists said it’s likely that small to mid-sized Permian E&Ps can expect stock-heavy offers and a pittance of cash these days.

Earlier, the conference kicked off with a focus on the Permian, which for supermajor Shell Oil Co., is home, sweet home.

Shell views shales as a complement to its vast international and deepwater portfolio, Gretchen Watkins, the company’s executive vice president for upstream unconventionals, told attendees. Shell plans to grow its Permian production from the current average of 120,000 boe/d today to 200,000 boe/d by 2020.

“Reducing flaring is critical for the industry’s social license to operate,” Watkins said, adding that economic production was also key. Shell has stopped installing flare stacks on its new well pads in the Permian, she said.

The importance of the basin was underscored by Reed Olmstead, director of North American onshore research and business development for IHS Markit. The dramatic growth in U.S. crude oil supply—1.3 million barrels per day in 2018 alone—is propelled by strong Permian Basin production.

As takeaway constraints are relieved, Olmstead believes U.S. crude supply will grow another 1.5 million bbl/d in 2019, but pipeline bottlenecks will likely keep Midland and Cushing, Okla., hub differentials wide well into next year, with no easing expected until 2020, he said.