Clay Stabilization in Low-Permeability Formations

Himes, R.E.; Vinson, E.F.; Simon, David E.

doi:10.2118/18881-ms

Cited by 15 publications

(12 citation statements)

References 11 publications

(1 reference statement)

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“…Furthermore, some other scientists reported that high molecular weight polyamines are found to block permeability (R.E. Himes, Vinson, and Simon 1991;Zhou, Gunter, and Jonasson 1995;Schlemmer et al 2003). According to Beihoffer et al, combination of quaternary amine with potassium chloride provides greater shale recoveries than with either component alone.…”

Section: Amine Fixationmentioning

confidence: 99%

An experimental investigation of the shale inhibition properties of a quaternary amine compound

Tas¹,

Gucuyener²,

Parlaktuna³

2013

19th International Petroleum and Natural Gas Congress and Exhibition of Turkey

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Depleting oil reserves and increased costs of the oil and gas recoveries have created the need to drill in challenging formations. When drilled through, shale formations in particular always generated a wide variety of problems if conventional water-based muds are used. Furthermore, the complexity and variations in shales have compounded the task of developing suitable drilling fluids. In light of these problems, the study of shale properties and their interactions with fluids will continue to be a muchneeded source of information in drilling industry.In this study a low molecular weight quaternary amine compound, which is provided by KarKim Drilling Fluids Inc., and its mixtures with sodium and potassium chloride is investigated in the aspects of capillary suction times, hot rolling recoveries, methylene blue capacities and one-dimensional free swelling properties in order to compare performances of salts and amine compound.For all test methods quaternary amine concentration from 1% to 6% by volume were studied and seen that less amount of quaternary amine compound is needed in order to obtain close shale recoveries and shale volume change potential if compared with sodium and potassium chloride. This prevents the usage of high concentration of chlorides and hence provides environmental sensitiveness. Furthermore, it was concluded that combining an amount of salt with quaternary amine compound gives the system enhanced shale inhibition properties.

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Section: Amine Fixationmentioning

confidence: 99%

An experimental investigation of the shale inhibition properties of a quaternary amine compound

Tas¹,

Gucuyener²,

Parlaktuna³

2013

19th International Petroleum and Natural Gas Congress and Exhibition of Turkey

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“…However, it has been shown that these stabilizers are less effective in low-permeability formations [64]. Most additives used are highmolecular-weight cationic organic polymers.…”

Section: Clay Stabilizersmentioning

confidence: 99%

Fracturing fluids

2015

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

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Hydraulic fracturing is a technique to stimulate the productivity of a well. A hydraulic fracture is a superimposed structure that remains undisturbed outside the fracture. Thus the effective permeability of a reservoir remains unchanged by this process. The increased productivity results from the increased wellbore radius, because in the course of hydraulic fracturing, a large contact surface between the well and the reservoir is created.The literature from 2004 to 2014, more than 100 references concerning waterbased fracturing fluids for fracturing ultralow-to moderate-permeability reservoirs has been reviewed [1].Guar-based polymers are still used in fracturing at temperatures less than 150 • C. To minimize the damage associated with this class of polymers, several approaches are known. These include the use of a lower polymer concentration in formulating these fluids and the use of different crosslinking agents. Higher viscosities with lower polymer loadings can be achieved. In addition, cleaner guar-based polymers are used now, because commercial guar contains some 5% of residues, which may cause a damage of proppant packs.It has been found that shear and pressure effects on the rheological behavior of borate crosslinked gels are important. Although these fluids recover their viscosity after shear, they have been observed to lose a significant portion of their viscosity under high pressures.When fracturing is done in deeper wells, i.e., in hotter reservoirs, a new class of thermally stable polymers became relevant. These are poly(acrylamide)-based polymers. These synthetic polymers show a sufficient viscosity at temperatures up to 230 • C [1]. Examples are 2-acrylamido-2-methylpropanesulfonic acid and copolymers of partially hydrolyzed acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, and vinyl phosphonate. High-density brines have been used to increase the hydrostatic pressure by 30% for high-pressure pumping.Also, new breaker materials emerged [1]. These breakers destroy the gel by a reaction with the crosslinking agent. They form ligands with the metallic crosslinking agents and displace them from the crosslinking moieties of the guar-based polymers. Examples of these breakers include poly(succinimide) derivates and lignosulfonate derivates.To minimize the environmental impact of using massive amounts of fresh water and to minimize costs associated with treating produced water, the use of produced water in hydraulic fracturing treatments has been reported. Petroleum Engineer's Guide to Oil Field Chemicals and Fluids. http://dx.567 568 CHAPTER 17 Fracturing fluids B HO 17.3 Types of hydraulic fracturing fluids 571 TYPES OF HYDRAULIC FRACTURING FLUIDSGenerally, a hydraulic fracturing treatment involves pumping a proppant-free viscous fluid, or pad, usually water with some fluid additives to generate high viscosity, into a well faster than the fluid can escape into the formation so that the pressure rises and the rock breaks, creating artificial fractures or enlarging existing fractures.After fracturing...

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“… 16 Himes pointed out that an organic cationic polymer clay stabilizer with high RMM could plug the pore throat within the low-permeability reservoir. 17 Wang pointed out that a cationic polymer clay stabilizer with high RMM may block the pore throat and reduce permeability by 70–80% when injected into low-permeability reservoirs. 18 Ma believed that although a cationic polymer clay stabilizer with high RMM can effectively inhibit the water-sensitivity damage for reservoirs with large clay content and low permeability, it would plug the pore throat and increase the plugging damage to reservoir permeability at the same time.…”

Section: Introductionmentioning

confidence: 99%

Study on the Relationship between the Relative Molecular Mass of a Polymer Clay Stabilizer and the Permeability of a Tight Reservoir

Ke-jian

Wei

et al. 2022

ACS Omega

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Water-sensitivity damage is inevitable during hydraulic fracturing for tight reservoir stimulation. A polymer clay stabilizer is the most effective and commonly used agent for reducing this kind of permeability damage. However, due to the small pore throat radii of tight reservoirs, polymers may be captured and detained, resulting in secondary permeability damage caused by polymer plugging. Therefore, it is necessary to clarify the matching relationship between the relative molecular mass of the clay stabilizer and the permeability of tight cores, which has not been reported yet. In response to this problem, the residual resistance factor and the permeability damage rate of PDMDAAC (poly dimethyl diallyl ammonium chloride, a kind of commonly used polymer clay stabilizer) to tight cores from Xinjiang Oilfield were investigated in cores with permeabilities of 0.10 × 10 –3 μm 2 (0.08–0.17 × 10 –3 μm 2 ), 0.05 × 10 –3 μm 2 (0.035–0.065 × 10 –3 μm 2 ), and 0.01 × 10 –3 μm 2 (0.007–0.020 × 10 –3 μm 2 ) through flow experiments. It was found that the relative molecular masses of PDMDAAC, which did not cause obvious core permeability damage, should be less than 10 000, 5000, and 2000, respectively. In addition, the bridging flocculation principle between the hydrodynamics radius of the clay stabilizer and the radius of the tight core pore throat can be used to explain the matching relationship between the relative molecular mass of the polymer clay stabilizer and the permeability of the tight reservoir. This study points out the direction for the optimization of the polymer clay stabilizer used in tight reservoir hydraulic fracturing and provides some references for the construction of hydraulic fracturing fluid systems for the efficient development of unconventional oil and gas resources.

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Clay Stabilization in Low-Permeability Formations

Cited by 15 publications

References 11 publications

An experimental investigation of the shale inhibition properties of a quaternary amine compound

An experimental investigation of the shale inhibition properties of a quaternary amine compound

Fracturing fluids

Study on the Relationship between the Relative Molecular Mass of a Polymer Clay Stabilizer and the Permeability of a Tight Reservoir

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