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Ashok Belani

PDSView

Osprey Drilling Software
   You are here: SLB.com > Products & Services > Stimulation > Tight Gas > High Temperature CO2 Fracturing Fluid


ThermaFOAM High Temperature CO2 Fracturing Fluid



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Representation of a conventional guar crosslinked polymer (left) and ThermaFOAM CO2 biopolymer (right) at a semimolecular scale. The ThermaFOAM CO2 chemical structure renders more viscous foams and enhanced proppant transport in high-temperature CO² environments.


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ThermaFOAM CO2 fracturing jobs have shown improvements in time to sales compared with conventional fracturing technology.

The future of high-temperature brownfield CO² fracturing

A truly innovative chemical solution
CO² foam fracturing is typically performed in depleted formations to enhance flowback of the fracturing fluid and to increase initial post-treatment production. It is also used to stimulate water-sensitive formations. A drawback of this fracturing method has been that no CO² foam fracturing fluid has been able to withstand higher-temperature environments while retaining high proppant pack conductivity. Until now.

The ThermaFOAM CO2 foam system for high-temperature wells is a new and unique chemical system specifically designed for fracture applications in wells with bottomhole static temperatures (BHSTs) between 200 and 300 degF [93 and 149 degC].

The innovative ThermaFOAM CO2 system chemistry enables Schlumberger to formulate noncrosslinked gels that deliver viscosity equal to or better than the industry-standard foams of low-pH guar, or derivatized-guar, crosslinked fracturing fluids. ThermaFOAM CO2 systems deliver those results at significantly lower polymer loadings and with a reduced number of additives.

Tailored solutions for high-temperature CO² treatments
In the past the most common method of facilitating high-temperature CO² fracturing was to increase polymer loading to provide additional stability. The ThermaFOAM CO2 system is a CO²-compatible product that uses the CO²-polymer interaction to create stable and robust foam systems that allow polymer-loading reductions of up to 50%.

The reduction in polymer loading, combined with improved well performance and the elimination of the need for a crosslinking gel, has resulted in a fluid system that maximizes cleanup of the proppant pack within the fracture.

Laboratory experiments have consistently demonstrated retained conductivity of more than 90% for ThermaFOAM CO2 systems. This is a dramatic improvement over competitive CO²-compatible fluid systems.

Shorter time to sales
Significant reductions in time to sales can typically be expected for wells fractured using the ThermaFOAM CO2 foam system compared with wells stimulated using conventional fracturing technology.


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