Crude oil prices and, just as important, the availability of pipeline takeaway capacity, have supported continued production growth in the Bakken. Good news, right? Except, that’s led to sharply increased output of associated gas in a region that for years has been playing catch-up on the gas processing capacity front. As a result, gas-flaring volumes have soared this year, putting pressure on crude-focused producers to slow down their drilling-and-completion activity. Things are finally getting better, though — 670 MMcf/d of processing capacity has come online in western North Dakota since late July, and another 200 MMcf/d will start up next month. That gives Bakken producers some room to grow but also poses a problem for Western Canadian producers, namely that more pipeline gas out of the Bakken means less room for Alberta and British Columbia gas on pipes to the Midwest. Today, we begin a short blog series on incremental Bakken gas processing capacity and its impacts on producers — and natural gas prices — up in Canada.
After falling 23% from 1.16 MMb/d in December 2014 to 895 Mb/d in December 2016, crude oil production in the Bakken has rebounded with a vengeance over the past two years, rising to a record 1.46 MMb/d in October 2019, according to the most recent data from the North Dakota Oil & Gas Division (blue area in left graph in Figure 1). (Data from IHS Markit’s PointLogic Energy suggest production has remained at a similar level since then.) Higher oil prices through most of 2017-19 helped make that 63% increase since December 2016 possible, but so did the June 2017 startup of the Dakota Access Pipeline (DAPL), which freed producers from pipeline takeaway constraints that had dogged them since soon after Bakken production took off back in the early 2010s.
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