Massive Hydraulic Fracturing of High-Temperature Wells With Stable Frac Foams

Wendorff, C.L.; Ainley, B.R.

doi:10.2523/10257-ms

Proceedings of SPE Annual Technical Conference and Exhibition 1981

DOI: 10.2523/10257-ms

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Massive Hydraulic Fracturing of High-Temperature Wells With Stable Frac Foams

C.L. Wendorff¹,

B.R. Ainley²

Abstract: Recent studies under downhole conditions show the relationship between foam texture, i.e., bubble size and foam rheology. They also show that under the low shear conditions that exist in a fracture during treatment, foams behave as power law fluids. Dynamic fluid-loss testing indicates ·stabilized foams are some of the more efficient fracturing fluids available.Formation damage results help explain why foam-fractured wells clean up so well.As a result of our better understandi ng of the properties of foam unde… Show more

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Cited by 10 publications

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Foam Fracturing in the Uinta Basin — A Field Study of the Dakota and Wasatch Formations

Goelitz¹,

Evertz²

1982

SPE Rocky Mountain Regional Meeting

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The Dakota and Wasatch formations of the Uinta Basin in northeastern Utah and northwestern Colorado have been historically difficult to clean up following a fracturing treatment. Recovery of normal water-based fluids has been averaging 20 to 30%, with much rig time spent in swabbing before the wells were put on production. Because of low recovery and the potential for clay problems, a number of techniques and fluids were tried without any significant improvement. Since these formations were very low in permeability, .05 to .2 md, deeper penetration through fracturing remained a high priority for treatment success. To achieve this penetration, relatively large volumes of treating fluids were needed. Foam fracturing was then instituted as a means of controlling the amount of water put into the formation. The first treatments were relatively small and sand concentrations of two pounds per gallon were the maximum that could be achieved. The results were encouraging enough to warrant the continued use of foam as a fracturing fluid. With the advent of equipment to achieve higher concentrations of sand at the formation and better materials to stabilize the fluid itself, foam fracturing matured into a much more viable means of treating both formations. The immediate advantages of foam are obvious. There is 65 to 75% less water put into the formation that has to be recovered and the possibility of damage due to swelling or migrating clay is reduced. The reduced damage is the result of smaller volumes of water and easier handling, of clay control agents, KCl and/or chemicals. A very important aspect of this technique is a faster and improved cleanup, which can be attributed to less water, more energy and lower hydrostatic head.

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Foam Fracturing in the Uinta Basin — A Field Study of the Dakota and Wasatch Formations

Goelitz¹,

Evertz²

1982

SPE Rocky Mountain Regional Meeting

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A New Crosslinked Foamed Fracturing Fluid

Watkins¹,

Wendorff²,

Ainley³

1983

SPE Annual Technical Conference and Exhibition

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The technology of stabilizing foamed fracturing fluids has been extended to include the use of cross-linked gels as foam stabilizers. Gasified treating fluids prepared from these gels have unique properties which differentiate them from both traditional foams and gels. Traditional foams require that the gas/volume ratio be greater than 0.52 in order to obtain a stable foam structure. Such high gas ratios produce foams with low fluid densities and low proppant concentrations. Using crosslinked gelled fluid as the stabilizer for foams, very stable dispersions of gas in liquid can be prepared with almost any gas content. Stable foams having a gas/volume ratio (GVR) greater than 0.52 as well as stable energized fluids having a GVR of less than 0.52 can be prepared. Stable energized fluids containing less gas can have appreciably higher fluid densities and proppant concentrations. This paper describes the properties of foams stabilized with crosslinked gels, their broadened uses in stimulating wells and the results of treatments.

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Foamed Sand Provides Improved Stimulation Results from Devonian Shale

Strang

Norton

1983

SPE Eastern Regional Meeting

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Generally, water saturations in the Devonian Shale are low. Production records indicate minimal, if any, water in the areas produci ng gas or gas and oil. This low water saturation appears to be the key to stimulating the shale, especially in the oil-producing areas.The introduction of water in the stimulation fluid appears to reduce the permeability to oil, which is reflected in poorer production.The relative permeabil ity reduction seems to be more of a problem than particle migration or clay swell ing. and ~ould explain the good initial results froo stralght nltrogen treatments. However, the lack of a proppant, even with low closure stress, leads to very rapid declines.Water-base stimulation fluids appear to increase water saturation in the Devonian Shale. Use of 90+ quality foam with sand should provide a method of minimizing saturation changes while creating a propped fracture.Initial results indicate this technique provides better sustained production increases in the Devonian Shale.This paper defines areas of production, describes the geology and presents physical data of the Devonian Shale. It also compares results of several types of treatments that have been used in the Devonian Shale. These results indicate 90+ quality foam with sand should provide an improved stimulation technique for this formation. RESULTSThe 90+ quality foam treatments to date have been done in Monroe and Noble counties, Ohio, and Ritchie and Raleigh counties in West Virginia.

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Massive Hydraulic Fracturing of High-Temperature Wells With Stable Frac Foams

Cited by 10 publications

References 0 publications

Foam Fracturing in the Uinta Basin — A Field Study of the Dakota and Wasatch Formations

Foam Fracturing in the Uinta Basin — A Field Study of the Dakota and Wasatch Formations

A New Crosslinked Foamed Fracturing Fluid

Foamed Sand Provides Improved Stimulation Results from Devonian Shale

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