The recent decline in crude oil prices has created the potential for weaker crude oil production. EIA's Drilling Productivity Report (DPR) includes indicators that provide details on the effect low prices may have on tight oil production, which accounts for 56 percent of total U.S. oil production. Analyzing these indicators and the changes in oil production following the drop in crude oil prices during the 2008-09 recession may offer some insight into possible near-term oil production trends.
Source: North Dakota Department of Mineral Resources, Bloomberg
The price of West Texas Intermediate (WTI) crude oil delivered to Cushing, Okla. declined more than 31 percent from June to November 26 and another seven percent after the late November announcement of the Organization of the Petroleum Exporting Countries (OPEC) decision to maintain the current production level. At $60 per barrel, the current price of oil is likely approaching or already below the expected per-barrel costs of some of the most expensive U.S. tight oil projects.
Some of the most active production fields in the country are in North Dakota. Indicators tracked by the DPR and North Dakota's Department of Mineral Resources (DMR) cover much of the exploration and production process, from planning to production. These indicators include:
- Permits. Before drilling begins, producers must sign lease contracts and apply for permits to drill exploration and development wells.
- Rig movement. Drilling rigs must be secured and moved to permitted locations.
- Spuds. Spudding is the term for the ground-breaking process of a new drilling project. In North Dakota, the spud count is a count of new wells drilled.
Based on the most recent data released by North Dakota's DMR, drilling and production activities in the state have not slowed, despite the significant decline in domestic crude oil prices since July 2014. Oil production in September 2014—the latest data available—rose five percent from the prior month.
The number of permits issued in October 2014 was 28 percent above the September level, but it dropped 30 percent in November. However, when normalized based on the number of business days during those months, October is only 17 percent above September's level, and November is only 10% lower than October.
During the 2008-09 recession, monthly average WTI prices fell by 71% to $39.09 per barrel between June 2008 and February 2009. At the time, shale oil production in North Dakota was still in the testing phase and thus relatively expensive. Drilling and production continued to increase until November 2008, when WTI prices dropped below $57 per barrel. Below $57 per barrel, the number of projects that were interrupted increased significantly, with the number of permits declining 73 percent from December 2008 to July 2009, the number of rigs declining 62 percent from November 2008 to May 2009, and the number of spuds declining 55 percent from November 2008 to April 2009. However, the decline in production was not nearly as dramatic, falling only 13 percent from November 2008 to January 2009, after which time production began increasing.
Looking forward, EIA expects 2015 drilling activity to decline as a result of less-attractive economic returns in some areas of both emerging and mature oil production regions. Many companies will redirect investment away from marginal exploration and research drilling and into core areas of major tight oil plays. However, projected oil prices remain high enough to support development drilling activity in the Bakken, Eagle Ford, Niobrara, and Permian Basin, which contribute the majority of U.S. oil production growth.
EIA expects U.S. crude oil production to average 9.3 million barrels per day (bbl/d) in 2015, up 0.7 million bbl/d from 2014, but down from expected growth of 0.9 million bbl/d in last month's Short-Term Energy Outlook. However, all of the decrease in forecast production growth comes in the second half of 2015. EIA revised production growth downward by 140,000 bbl/d and 270,000 bbl/d in the third and fourth quarters, respectively, compared with the previous forecast. However, this forecast remains particularly sensitive to actual prices available at the wellhead and drilling economics that vary across regions and operators.