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Hydraulic Fracturing Techbook 2018

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70 | August 2018 | hartenergy.com HYDRAULIC FRACTURING: LOGISTICS Through its pipeline, storage and disposal net- work, H 2 O Midstream provides produced-water gathering, disposal, transportation, reuse, storage/ banking, peak-shaving and forward sales. The com- pany said its system has the potential to remove more than 650,000 truckloads per year of produced water from Texas roads. "We now have seven customers on the system," said Jim Summers, CEO, "all served by pipe. The hub was designed for reliability and peak management, as well as reuse, and we have been pleasantly surprised at the level of local interest." The next step will be expanding the pipe connec- tions. That will be in every direction, but primarily north and west. "We expect volumes to increase, and can add new capacity," Summers said. "We are also looking actively at new facilities in other geographies. There will definitely be further growth in Howard County, and we needed the first year of operational experience. That has been invaluable as we are doing something new here, managing multiple operators on a commercial pipeline system." Big fracks get bigger Like many of his colleagues in water manage- ment, Summers has watched the issue of frack sand supply erupt into the industry's conscious- ness. "There are fundamentals driving demand for both sand and water," he said. "The shift from conventional to unconventional and from gel fracks to slick water, the longer laterals; all those are creating opportunities but also creat- ing new constraints." Summers spent some of his career in biomass, so he understands the different logistics for solids as opposed to fluids—gas and liquids. "Still water and sand are both commodities, with advantages in economies of scale. And the fundamentals are driving water infrastructure more and more." "We are very busy," said Michael Henry, global production enhancement operations manager at Halliburton, "activity is picking up this year." There is not really any mechanical or material limit to fracking pressure, he noted; the control is the return on costs for higher pressures, and volumes of sand and water. "We usually operate up to 15,000 psi, but can go to 20,000. Jobs in the Eagle Ford run 10,000 to 11,000 psi, while jobs in the Bakken run more to 7,000 psi." Thirty to 50 stages per well is not uncommon, Henry added, "and we are seeing more and more wells per pad. What counts as 'big frack' is getting to 600,000 pounds of sand per stage." Sand demand, then, becomes paramount. "Part of that is change in mesh sizes and percentages," said Henry. "There were also a lot of weather delays, as well A Stingray pressure pumping subsidiary crew is on site in Ohio. (Photo courtesy of Mammoth Energy Services)

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