Thursday, 3 October 2013
Baker Hughes announces new guar-alternative fracturing fluid delivers cleaner fractures for improved recovery
Baker Hughes announced today the commercialization of its ClearStar™ fracturing fluid system, which improves reservoir performance and delivers superior fracturing in both conventional and unconventional reservoirs. The ClearStar fluid system provides better flowback for increased production and improved economic results compared to guar, guar-derivate, and borate systems.
The ClearStar system is a guar alternative that uses an efficient, refined cellulose derivative polymer to attain superior viscosity and achieve a low pH to reduce the potential for clay swelling that can restrict production flow. It delivers stable performance at temperatures up to 275°F (135°C).
With customizable delay times based on lateral length and pump rates, ClearStar fluids enhance sand transport through the wellbore during pumping operations to ensure proper placement within the fractures. The ClearStar system has a high molecular weight compared to other guar-alternative fracturing fluids, so it requires a smaller amount of polymer to achieve the desired viscosity. Lower polymer loading helps reduce a fracturing operation’s overall horsepower requirements and related fuel costs.
Used with the Baker Hughes EnZyme™ and HighPerm™ encapsulated breakers, ClearStar fluids minimize the risk of formation and proppant pack damage to ensure maximum flowback capacity and speed, and increase both initial and long-term hydrocarbon production.
"We are delighted to add the ClearStar system to our robust fracturing fluid portfolio," said David Gallagher, Baker Hughes Vice President of Production Enhancement. "This premium fluid can offer our customers superior flowback performance, and has been shown to significantly boost one year cumulative hydrocarbon production compared to conventional fracturing fluids."
In 32 separate treatments in Colorado’s Wattenberg field, the ClearStar fracturing fluid system produced an average 11% more cumulative oil over 350 days of production compared to wells stimulated using premium, guar-based fluids.