Texas Flood - The Challenges Facing CO2-Based Enhanced Oil Recovery

The collapse in crude oil prices this year hit U.S. producers hard, and forced them to make big cuts in their capital budgets and drilling plans. But it also helped to prove their resilience. Throughout the Shale Era, and especially since the 2014-15 oil price crash, producers have been increasing their productivity and slashing their production costs, enabling most of them to survive even when prices slipped below $30 and $20/bbl for a while. Not all producers are alike, however — neither is all production. Even with oil prices rebounding to about $40/bbl in recent weeks, production based on enhanced oil recovery (EOR) through carbon-dioxide (CO2) “flooding” has become economically challenged, at least for some producers. Can EOR, with its high production costs, survive in a low-price environment? Today, we take a fresh look at EOR in an era of $40/bbl crude.

Our younger readers may not remember, but not long ago U.S. crude oil production was on the decline — a number of conventional oil plays in the U.S. were viewed as being pretty much tapped out, and the U.S. was becoming increasingly dependent on imported crude. What grabbed all the headlines, of course, was the combination of horizontal drilling and hydraulic fracturing, which in the past decade have freed amazing volumes of mostly light and super-light crude from shale and tight-oil plays like the Bakken, the Denver-Julesburg Basin, and — most important — the Permian. But even before the Shale Era started in earnest, there was a lot of hope that enhanced oil recovery would breathe new life into conventional production areas whose output had dwindled to a trickle.

EOR, like hydraulic fracturing, is a way to unlock trapped oil. Primary recovery of oil from a conventional well (through natural pressure and pumps) typically recovers only about 10% of a reservoir’s total oil and secondary recovery (mostly by injecting water to displace oil and drive it to a production wellbore) draws out another 20 to 40%, leaving as much as 70% of a reservoir’s original oil in place (OOIP). EOR — also known as tertiary recovery — can recover another 10 to 20% of the OOIP. As we said in an EOR blog series a few years ago, there are two primary EOR techniques: thermal and CO2-EOR. Thermal EOR involves injecting steam to increase the flow of heavy, viscous oil. (Yes, that’s what goes on in Alberta’s oil sands; it’s also used to a much lesser degree to produce oil in California.)

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