Case Study Fiber-Based Fracturing Technology Boosts Gas Production
FiberFRAC fluid delivers 7 times greater gas production for PEMEX well.
Proppant settling occurs during hydraulic fracturing operations when the fluid viscosity falls below the critical threshold required to suspend proppant. The settling can reduce the deliverability of the fracture, negatively impacting productivity.
In slickwater applications, the viscosity of the base fluid is inadequate to provide proppant transport. In tight gas applications with conventional crosslinked fluids, the fracturing fluid is designed to break shortly after pumping. The fracture remains open for hours, and a low-viscosity fluid remains that is unable to suspend the proppant.
FiberFRAC fiber-based fracturing fluid technology decouples proppant transport from fluid viscosity. The technology creates a fiber-based network within the fracturing fluid, providing a mechanical means to transport, suspend, and place the proppant. Because the proppant transport then no longer relies on fracturing fluid viscosities, it can be tailored to reservoir conditions to optimize fracture geometry. If fracture height growth is a concern, a low-viscosity fluid can be used, even at high temperatures, while still maintaining good proppant transport.
In addition to fracture height containment, the retained proppant-pack permeability can be significantly increased because of the lower polymer loading required. Laboratory testing has shown that decreasing the polymer loading by 40% can increase retained permeability by 24%. When less polymer is used, more of the propped fracture contributes to production, yielding a longer effective fracture half-length.
FiberFRAC technology can be applied in wells with 140 to 345 degF [60 to 174 degC]—a range that accounts for more than 80% of the tight gas wells in North America. Proven in both the laboratory and the field, the FiberFRAC technology enhances proppant distribution in hydraulically fractured wells for increased stimulation effectiveness and improved subsequent production.
Field tests have demonstrated that the fibers do not adversely affect retained proppant-pack permeability and hence fracture conductivity. Recent extensive field testing of fiber-based fracturing treatments in tight gas wells in North America has shown significant production improvements compared with production increases seen after conventional treatments in offset wells.
|FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications|
|FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications, FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications Connate water conditions||Max. total water hardness||20,000 mg/L|
|Max. magnesium||8,000 mg/L|
|FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications, FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications Temperature Range||Low-temperature fiber||140–200 degF|
|High-temperature fiber||200–345 degF|
|FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications, FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications Fracturing fluid compatibility||Low-temperature fiber||Borate cross-linked fluids, ClearFRAC family of polymer- free fracturing fluids, and zirconate cross-linked fluids|
|High-temperature fiber||Borate cross-linked fluids, ClearFRAC fluids, and zirconate cross-linked fluids|
|FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications Proppant compatibility||, All mesh sizes: sand, precured resin-coated proppant, intermediate-strength proppant, bauxite|
|FiberFRAC Fiber-Based Fracturing Fluid Technology Specifications Energized compatibility||, Nitrogen in all cases; CO2 based on fluid compatibility|