Led by the shale revolution and oil and gas industry's move toward horizontal drilling, water has become an increasingly important resource as well as a challenge.

Without it, horizontal drilling is difficult and hydraulic fracturing is not possible.

Generally as laterals get longer and proppant loading increases, water needs rise. Though water usage per well can vary from region to region, according to a 2015 report by the U.S. Geological Survey (USGS).

In its report, USGS collected data of injected water volumes used to frack more than 263,859 oil and gas wells between 2000 and 2014. On average, 17,350 cubic meters (cu. m) of water per well was used to frack individual horizontal wells during that time, the USGS said.

The highest average fracking water usage per well ranged from 10,000 cu. m to 36,620 cu. m. In addition, wells that used the most water were in U.S. watersheds generally correlated with shale gas areas vs. coalbed methane and tight oil or gas.

The USGS analysis also showed that many oil and gas resources within a given basin are developed using a mix of horizontal, vertical and some directional wells, explaining why large volume, fracking water usage is not widespread.

In 2014, about 58% of the wells drilled were horizontal that used water for fracking, the USGS said.

The variability in fracking water use is also directly related to the potential for environmental impacts such as water availability, water quality, wastewater disposal and possible wastewater injection-induced earthquakes.

In addition, the USGS noted that fracking varies in regions due to local regulatory requirements, laws on wastewater management and disposal practices, recycling and underground fluid injection.

Larry Prado, activity highlights, water management, shale, Eagle Ford, Permian, Marcellus, Utica, oil, natural gas, map

1. Concho Resources: 10/20/16

COG Operating Inc. completed two horizontal Bone Spring wells on the Carlsbad Shelf of the Permian Basin in Lea County, N.M., IHS Markit reported.

COG Operating is a subsidiary of Midland, Texas-based Concho Resources Inc. (NYSE: CXO).

The #1H Lychee BWS State Com was tested flowing 729 barrels (bbl) of crude, 1.022 million cubic feet (MMcf) of gas and 3.815 Mbbl of water per day from acid- and fracture-treated perforations at 10,650 feet and 17,420 feet. Flowing tubing pressure was gauged at 550 pounds per square inch (psi).

The Berry South Field well was drilled to 17,570 feet in Section 22-21s-34e. The horizontal leg bottomed more than one mile to the north in Section 15 and the true vertical depth is 10,607 feet.

Three miles to the north in irregular Section 4-21s-34e, COG’s #1H Sitka BSI State Com is flowing 373 bbl of oil, 252 Mcf of gas and 1.995 Mbbl of water. Tested on an unreported choke size, the flowing tubing pressure was 240 psi. Production is from acid- and fracture-stimulated perforations are at 10,914 feet and 15,249 feet.

The Grama Ridge North Field well was drilled to 15,446 feet, 10,784 feet true vertical, with horizontal lateral that bottomed about 1.5 miles to the north.

2. Cabot Oil & Gas: 9/23/16

A Briscoe Ranch Field completion was reported in Frio County (RRC Dist. 1) in South Texas by Houston-based Cabot Oil & Gas Corp. (NYSE: COG).

The horizontal well, #1H Spear Point 1H, was tested flowing 374 bbl of 30-degree-gravity crude, 104 Mcf of gas and 1.792 Mbbl of water per day. The well is located in A. Casillas Survey, A-1077.

Production is from acidized and fracture-treated Eagle Ford perforations at 8,192 feet and 18,305 feet. The well’s lateral bottomed about two miles to the northwest in TC RR Co. Survey, A-1409.

The well was drilled to 18,520 feet, 7,729 feet true vertical, IHS Markit said. The producing leg was kicked off at 7,272 feet after the original lateral was abandoned in early 2016. The initial hole was drilled to 12,155 feet with a true vertical depth of 7,862 feet.

3. Marathon Oil: 9/28/16

Four Eagle Ford Shale discoveries in Live Oak County (RRC Dist. 2), Texas, were announced by Houston’s Marathon Oil Corp. (NYSE: MRO).

The horizontal wells were drilled from offsetting surface locations on a 164-acre lease in Section 5, John Houlighan Survey, A-17, and the Eagleville Field wells bottomed about a mile to the southeast.

The #1H Guajillo Unit 12 South is producing 1.105 Mbbl of 45.6-degree-gravity crude, 1.037 MMcf of gas and 613 bbl of water per day through fracture-treated perforations at 11,558-16,062 feet. Tested on a 16/64-inch choke, the flowing tubing pressure was 3,440 psi. The well was drilled to 16,190 feet, 11,392 feet true vertical

The #2H Guajillo Unit 12 South is flowing 1.364 Mbbl of crude, 1.211 MMcf of gas and 472 bbl of water per day from perforations at 11,560 feet to 16,127 feet.

The #3H Guajillo Unit 12 South is flowing 1.455 Mbbl of crude, 1.294 MMcf of gas and 485 bbl of water per day from perforations at 11,535 feet to 16,197 feet.

The #4H Guajillo Unit 12 South is producing 1.639 Mbbl of crude per day from perforations at 11,680 feet to 16,338 feet.

4. EOG Resources: 7/8/16

EOG Resources Inc. (NYSE: EOG) has completed two Eagle Ford-Eagleville Field wells in Karnes County (RRC Dist. 2) in South Texas.

The discoveries by the Houston-based company are on a 204.18-acre Central Texas Coast lease in Coley Myers Survey, A-407, and both bottomed about one mile to the southeast in Colin Campbell Survey, A-395.

The #2H Josey Unit initially flowed 1.772 Mbbl of 42-degree-gravity crude, 1.325 MMcf of gas and 2.198 Mbbl of water per day. Production is from fracture-treated perforations at 11,048 feet to 15,857 feet. Gauged on a 42/64-inch choke, the flowing tubing pressure was 1,264 psi. The horizontal well was drilled to 15,958 feet, 11,127 feet true vertical.

The offsetting #3H Josey Unit flowed 2.813 Mbbl of 42-degree-gravity crude, 2.3 MMcf of gas and 1.56 Mbbl of water per day. Production is from fracture-treated perforations at 10,974 feet to 15,900 feet. The well was drilled to 16,010 feet, 11,122 feet true vertical.

5. EQT Corp.: 10/4/16

EQT Corp. (NYSE: EQT) announced results from a Utica Shale test in Wetzel County, W. Va.

The Pittsburgh-based company’s #513926 WV is producing 31.294 MMcf of gas with 1.85 Mbbl of water per day from perforations at 13,638 feet to 19,973 feet. The well was drilled to 19,998 feet, with a true vertical depth of 13,038 feet. Additional completion details are not available for the Hastings-Piney Fork Field well.

6. Rex Energy: 9/9/16

Rex Energy Corp. (NASDAQ: REXX) is underway at a Marcellus Shale test in Butler County, Pa.

The #2H Klever is in Section 1, East Butler 7.5 Quad, Concord Township. The Queen Junction Field well has a planned lateral length of about 10,000 feet and a planned depth of 16,139 feet, 5,582 feet true vertical.

Recently, State College, Pa.-based Rex secured funding to drill 12 wells in the development program.

The company completed its transition to a purely Appalachian Basin-focused producer, selling its assets in the Illinois Basin to Campbell Development Group. The divestiture closed Aug. 22.

Larry Prado, activity editor, can be reached at lprado@hartenergy.com.