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Unconventional Yearbook 2018

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50 | January 2018 | hartenergy.com 2018 UNCONVENTIONAL YEARBOOK | KEY PLAYERS Basin averaged 11,750 boe/d, a 78% increase over second-quarter 2017 levels. During third-quarter 2017, Whiting com- pleted 58 gross operated wells at its D-J Basin/ Redtail area in Weld County, Colo., and 29 gross operated wells in its Bakken/Three Forks play in the Williston Basin, according to the report. Whit- ing plans to put 25 gross wells on production in its Redtail area and complete 32 gross wells in the Williston Basin in the fourth quarter. At year- end 2017 Whiting estimated it will have 39 drilled but uncompleted (DUC) wells at Redtail and 50 DUC wells waiting on completion in the Williston Basin, the report stated. WildHorse Resource Development Corp. ■ About 385,000 net acres in the Eagle Ford ■ Closed $594.4 million acquisition from Anadarko/KKR WildHorse Resource Development Corp. (WRD) has operations in the Eagle Ford Shale in East Texas and the overpressured Cotton Valley in North Lou- isiana. WRD has about 483,000 total net acres, with about 385,000 net acres in the Eagle Ford and about 98,000 net acres in North Louisiana. WRD enhanced its acreage position with the June 2017 acquisition of about 111,000 net acres in the Eagle Ford from Anadarko Petroleum Corp. and affiliates of Kohlberg Kravis Roberts & Co. LP for $594.4 million. This acquisition followed WRD's December 2016 acquisition of about 158,000 net acres from Clayton Williams as well as a series of smaller bolt-on acquisitions earlier in 2017. In 2017 WRD revitalized interest in the East Texas Eagle Ford with its Gen 3 completion design utilizing 3,700 lb of sand per foot in comparison to legacy Gen 1 designs with about 1,000 lb of sand per foot. The result of the higher intensity com- pletions has been a considerable uplift in EURs to WRD's 91 boe per foot type curve. As of Nov. 20, 2017, WRD had brought online 68 Gen 3 Eagle Ford wells through the third quar- ter of 2017 and plans to bring online another 30 to 35 gross Gen3 Eagle Ford wells, two gross Austin Chalk wells and six gross North Louisiana wells in fourth-quarter 2017. Third-quarter 2017 production was 36.6 Mboe/d (62% oil), compared to 14.0 Mboe/d (35% oil) for third-quarter 2016, according to WRD's website. WPX Energy Inc. ■ Oil production of 75,000 bbl/d as of Nov. 1 ■ 100,000 net acres in the Permian's Delaware Basin WPX Energy has operations in the Permian, Wil- liston and San Juan basins. The company has 100,000 net acres in the Permian's Delaware Basin and 85,000 net acres on the Fort Berthold Indian Reservation in North Dakota. In October 2017 WPX signed an agreement for the sale of its legacy natural gas position in the San Juan Basin for $169 million, according to the WPX's third-quarter 2017 report. The transaction included WPX's operated and non- operated gas properties in the basin. The par- ties expected to close the agreement prior to year-end 2017. WPX's oil operations in the San Juan Basin's Gallup oil play were not included in the sale. In June 2017 WPX agreed to form a 50:50 joint venture (JV) with Howard Energy Partners to develop oil gathering and natural gas processing infrastructure in the Stateline area of the Perm- ian's Delaware Basin, a company news release stated. The JV is designed to support WPX's drill- ing operations in the Stateline area, representing 50,000 net acres, or 37% of WPX's roughly 135,000 net acre position in the Delaware. Third-quarter 2017 oil production of 64,800 bbl/d increased 11% vs. the second quarter and was up 67% vs. the year prior, according to the WPX's third-quarter 2017 report. Oil production was reported at about 75,000 bbl/d as of Nov. 1. For fourth-quarter 2017 WPX expected oil pro- duction averaging about 75,000 bbl/d and equiv- alent production of about 125 Mboe/d to 135 Mboe/d, including the impact of the sale of WPX's dry gas assets in the San Juan Basin, according to the third-quarter 2017 report.

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