Fluid Selection for Fracturing High-Permeability Formations

McGowen, J.M.; Vitthal, Sanjay; Parker, M.A.; Rahimi, Al; W.E., Martch

doi:10.2523/26559-ms

Cited by 21 publications

(13 citation statements)

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“…During fracturing an aqueous suspension of polymer deposits a filter-cake of concentrated polymer on the fracture wall. 6 The thickness of the filter-cake can reach almost 0.055" (1.4 mm), or more than one proppant grain diameter for 20/40 mesh proppant. 7 The ultimate thickness of the filter-cake depends on formation permeability, fluid efficiency, local shear rate causing erosion of the deposited cake, and many other factors.…”

Section: Filter-cake and Gel Residue Damagementioning

confidence: 99%

“…The overall final conductivity is computed from equation (8), where the values of k f and w f are first adjusted for the effects of closure stress, embedment, and spalling. Equation (6) gives an infinite-conductivity effective length of 377 feet, ignoring the impact of gel tip-plugging. The correction for gel plugging, from equation (7) (8) Note that most of the damage factors are dependent on the flow velocity in the fracture, and its influence on R ep .…”

Section: Field Application: Predicted Post-frac Performancementioning

confidence: 99%

“…For any value of FCD the infinite conductivity half-length can be determined from equation (6) or the plot in Figure 12. The equation presented here is based on data originally published by Prats and CincoLey.…”

Section: Gel Yield-point and Critical Fcdmentioning

confidence: 99%

“…When FCD drops below the critical FCD for clean-up, the remaining fracture length remains gel-plugged. The apparent producing fracture half-length, including the effect of gel plugging, is calculated from the effective infiniteconductivity fracture half-length given by equation (6). The final apparent producing half length, given by equation (7), is based on the assumption that an infinite conductivity fracture is represented by FCD=30.…”

Section: Gel Yield-point and Critical Fcdmentioning

confidence: 99%

See 3 more Smart Citations

Realistic Assessment of Proppant Pack Conductivity for Material Selection

Barree¹,

Cox

Barree³

et al. 2003

SPE Annual Technical Conference and Exhibition

128

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractProppant selection in hydraulic fracturing is a critical economic and technical decision that affects stimulation and field development economics. In many cases the selection is based on laboratory data from standardized API conductivity tests on clean packs at specified stress and temperature. These tests predict conductivities that are optimistic compared to observed field performance. Often a laboratory measured conductivity difference of only 5-10% is considered a significant variance when applied to the producing life of a well. The significance of these small differences, however, is often overwhelmed by other factors affecting fracture performance in the field.The selection of a particular proppant should be based on an identifiable difference in performance under field conditions. This requires an accurate assessment of all the damage mechanisms that can and do occur during fracturing and their impact on final conductivity. This paper outlines the primary damage mechanisms and their effect on conductivity, fracture cleanup and ultimate stimulation response. The expected variance in laboratory measurements of conductivity is also quantified.

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Section: Filter-cake and Gel Residue Damagementioning

confidence: 99%

Section: Field Application: Predicted Post-frac Performancementioning

confidence: 99%

Section: Gel Yield-point and Critical Fcdmentioning

confidence: 99%

Section: Gel Yield-point and Critical Fcdmentioning

confidence: 99%

See 2 more Smart Citations

Realistic Assessment of Proppant Pack Conductivity for Material Selection

Barree¹,

Cox

Barree³

et al. 2003

SPE Annual Technical Conference and Exhibition

128

View full text Add to dashboard Cite

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“…VES fluids have also been widely used for fracturing high-permeability formations; used as gravel-packing fluids and frac-packing fluids; they exhibit excellent rheological properties and maintain low formation damage characteristics compared with crosslinked-polymer fluids (McGowen et al, 1993;Mathis et al, 2002;Sullivan et al, 2006, Daren Journal of Petroleum Science and Engineering 78 (2011) 131-138 et al, 2008. The use of VES technology is now extended to other oilfield applications, such as filter cake removal and coiled tubing clean out (Parler et al, 1999).…”

Section: Introductionmentioning

confidence: 98%

Performance and application of new anionic D3F-AS05 viscoelastic fracturing fluid

Khair¹,

Zhang²,

Shan-bo³

et al. 2011

Journal of Petroleum Science and Engineering

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The Effect of Fracturing Fluid Leak-Off on the Productivity of High Permeability Oil Reservoirs

Gupta

Shah

Gadiyar

2000

Journal of Canadian Petroleum Technology

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During hydraulic fracturing of permeable reservoirs there is concern that fracturing fluid leak-off may cause a reduction in permeability. One important criterion of a successful fracturing treatment is limited formation damage. This study focused on investigating the alteration of permeability with distance from the fracture face, during fracturing fluid leak-off, and its subsequent recovery during production. Experiments were conducted in a 2-in. diameter and 12-in. long dynamic fluid loss core holder. Ten-in. long Berea sandstone core samples of varying permeabilities were used. Four different types of fracturing fluids were tested. Also, the effect of fluid loss additive on regain permeability was investigated. The movable oil phase in the core sample was either mineral or crude oil. The variation of return permeability with time and distance was determined along the length of the core sample. Effects of shut-in time, fluid loss additive, fracturing fluids, flow rates during flowback, and oil composition on regain permeability of oil reservoirs are presented in this paper. Introduction In recent years, tremendous interest has been developed in hydraulically fracturing high permeability formations(1–3). The objective is to improve production by creating propped fractures which aid in favorably altering the natural flow profiles. In order to optimize productivity, the fractures created should have a very high conductivity and the impairment in formation permeability due to fluid leak-off should be minimal. Fracturing fluids play a major role in the success of a fracturing treatment of high permeability formation. The fracturing fluid is expected to exhibit the following desirable properties:Cause minimum damage to formation permeability due to interaction of filtrate with the matrixGood proppant carrying capacityMinimum fracture conductivity damageFluid loss should be minimal In this paper, the emphasis is on the impact of fracturing fluid leak-off on the regain/return permeability of oil reservoirs. While fracturing a reservoir hydraulically, the fracturing fluid has a tendency to leak-off into the reservoir. The fluid which leaks off into the formation is generally called filtrate. The filtrate consists of polymer and/or particulates which can plug the pore throats, thereby reducing the near fracture face permeability. Usually, the leak-off is enormous in high permeability reservoirs, due to which there is a potential to drastically reduce the near fracture face permeability. This can lead to a reduction in productivity of the reservoir. Few researchers(4–6) have investigated the impairment in formation permeability caused by fracturing fluid leak-off in high permeability reservoirs. Further, all of the past studies were conducted in 100% brine saturated core samples. However, the formations that are hydraulically fractured contain movable oil and/or gas in addition to brine. It has been shown by Gadiyar et al.(7) that the presence of movable oil significantly alters the leak-off behavior of the fracturing fluids. Therefore, one would expect the return permeability and its recovery after leak-off in oil core to be different compared to that observed in 100% brine saturated core. The objective of this study is to investigate the effect of fracturing fluid leak-off on information permeability in the presence of movable oil saturation.

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Fluid Selection for Fracturing High-Permeability Formations

Cited by 21 publications

References 0 publications

Realistic Assessment of Proppant Pack Conductivity for Material Selection

Realistic Assessment of Proppant Pack Conductivity for Material Selection

Performance and application of new anionic D3F-AS05 viscoelastic fracturing fluid

The Effect of Fracturing Fluid Leak-Off on the Productivity of High Permeability Oil Reservoirs

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