By Rachel Adams-Heard, David Wethe and Kevin Crowley
“When you shut in wells, especially for a long period of time, you have a lot of surprises,” Clay Bretches, an executive vice president at Apache Corp., said during a conference call with analysts on Thursday. “Some of them are good and some of them are bad.”
EOG Resources Inc., the world’s second-largest independent oil explorer by market value, is curtailing about one-fourth of its production and canceling almost 40% of new wells it had planned to bring online this year.
An in-house analysis of 11 wells that were idle for an average of 23 days found they had a spike in production upon reopening, a sign that the reservoir suffered no damage, Houston-based EOG said in a slide presentation.
Executives are careful about disclosing which wells are being curtailed — which involves squeezing back on the volume of crude flowing out of the well — versus those that are completely shut down. That’s because reversing a total shutdown presents a more challenging set of tasks and costs.
Noble Energy Inc. is curbing daily output this month by as much as 10,000 barrels, mostly by completely shutting wells rather than choking back a portion of production.
A portion of the company’s older wells may be difficult to reopen “but we should be able to restart most of the wells over time,” said Chief Operating Officer Brent Smolik. “You can almost think of them as storage, where we’re just storing it in the ground and then they’ll respond pretty quickly when we turn them back on.”
Company executives told analysts during a conference call Friday that they hope to be able to restart most of those wells “over time.”
Houston-based Apache has shut about 2,500 wells, and Bretches said the company is taking “great pains” to make sure they’re being preserved. That includes preventing corrosion and maintaining equipment that sits atop the well in remote fields.
Read: Shale Drillers Risk Relapse Into Rampant Oil Output at $30 Crude
WPX Energy Inc., which plans to shut in a total of about 45,000 barrels of oil a day this month and possibly next, said it could be as simple as remotely opening up valves or speeding up electric pumps installed at the bottom of some wells. But the company cautioned against the expectation that it could be done quickly.
“It wouldn’t be as simple as ‘just give us a couple days and we’ll be back up running at 100%,’” said WPX Chief Operating Officer Clay Gaspar. “Anybody who says that, they’re probably short-changing their field organization just a touch.”
That’s why deciding whether to shut a well involves more than just comparing operating costs and oil prices, according to Rystad. Producers also must weigh the cost and mechanical difficulty of restoring those wells back to pre-curtailed volumes.
“When you start back up from the level we’re at, we do expect to have some start-up capital,” said Jeff Alvarez, head of investor relations of Occidental Petroleum Corp., which is shutting down about 5% of its production next month. “It’s things like, just when I spend $1 today, I don’t get production for a couple of months from that.”
Cimarex Energy Co. said the obstacles to reopening wells mostly revolve around speed and costs, rather than any threats to the structural integrity of the rocks themselves. The Denver-based explorer held an internal technical session recently that looked at how its reservoirs would be affected by shut-ins, and the results showed that they were likely to be “just fine.”
“We think we’re in pretty good shape with our reservoirs to shut them in and bring them back when we need,” CEO Tom Jorden said during a conference call.
Oil companies aren’t the only ones who have to think about the long-term impacts of shuttered wells. Millions of miles of pipelines crisscross the continent to haul crude from the field to refineries and export terminals. As supplies drop, so does demand for pipeline capacity.
Pipeline operator Targa Resources Corp. was asked Thursday if the wells its system serves would ever ramp up to previous volumes.
“I think for the most part, we’d expect the shut-in volumes to come back and perform well,” Targa CEO Matt Meloy said. “Could there be some older, really low-rate vertical wells … which they shut-in and just don’t bring back? I think there could be some amount of those.”