Controlling Gelation Time and Microgel Size for Water Shutoff

Chauveteau, G.; Omari, Abdelaziz; Tabary, René; Renard, Maurice; Rose, Jérôme

doi:10.2118/59317-ms

Cited by 53 publications

(11 citation statements)

References 25 publications

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“…Although microgel systems were developed as RPMs to reduce water production (Chauveteau et al 2000(Chauveteau et al , 2001(Chauveteau et al , 2003(Chauveteau et al , 2004Feng et al 2003;Rousseau et al 2005;Zaitoun et al 2007;Cozic et al 2009), other systems involving suspensions with various chemical properties were developed for total water shutoff and deep modification of water-injection profiles. The following two subsections will provide an overview of two technologies.…”

Section: Microgels For Deep Modification Of Water-injection Profilesmentioning

confidence: 99%

Polymer Systems for Water Shutoff and Profile Modification: A Review Over the Last Decade

2013

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Unwanted water production is a serious issue in oil-and gas-producing wells. It causes corrosion, scale, and loss of productivity. One method of treating this problem is to chemically reduce unwanted water. This paper discusses the use of polymer systems for this purpose and presents a thorough review of available literature over the last decade. In this paper, field-application data for various polymer systems are summarized over the range of 40 to 150 C (104 to 302 F). These applications cover a wide range of permeabilities from 20 to 2,720 md in sandstone and carbonate reservoirs around the globe. Moreover, the review revealed that the last decade of developments can be categorized into two major types. The first type is polymer gels for total water shutoff in the near-wellbore region, in which a polymer is crosslinked with either an organic or an inorganic crosslinker. The second type is concerned with deep treatment of water-injection wells diverting fluids away from high-permeability zones (thief zones). These thief zones take most of the injected water, which results in a large amount of unrecovered oil. For the total-blocking gels, various systems were identified, such as polyurethane resins, chromium (Cr 3þ ) crosslinking terpolymers, Cr 3þ crosslinking foamed partially hydrolyzed polyacrylamide (PHPA), and nanoparticle polyelectrolyte complexes (PECs) sequestering Cr 3þ for elongation of its gelation time with PHPA. In addition, polyethylenimine (PEI) was identified to crosslink various polyacrylamide-(PAM-) based polymers. The Petróleos de Venezuela S.A. (PDVSA) Research and Development Center developed a PAM-based thermally stable polymer and an organic crosslinker. The system is applicable for a wide temperature range from 50 to 160 C (130 to 320 F).For the deep modification of water-injection profiles in waterinjection wells, two systems were identified: microspheres prepared from PAM monomers crosslinked with N,N 0 -methylenebisacrylamide and microspheres produced by crosslinking 2-acrylamido-2-methylpropane sulfonic acid (AMPS) with diacrylamides and methacrylamides of diamines (thermally activated microparticles known as Bright Water). This paper highlights all major developments in these areas. Important Factors for Successful CITsThe identification of the water source is a key factor for successful CITs. The characterization of water production can be performed

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Section: Microgels For Deep Modification Of Water-injection Profilesmentioning

confidence: 99%

Polymer Systems for Water Shutoff and Profile Modification: A Review Over the Last Decade

2013

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“…PPGs are a better selection than in situ gels from the point of controlling the particle sizes for different reservoir characterization. Presently, preformed gels contain preformed bulk gels, partially preformed gels, and particle gels (Chauveteau et al 2000(Chauveteau et al , 2001Bai et al 2007aBai et al , b, 2008.…”

Section: Introductionmentioning

confidence: 99%

“…Particle gels contain PPGs, microgels, swelling micrometersized polymers (Bright Water R ), and a pH-sensitive crosslinked polymer (Coste et al 2000;Chauveteau et al 2000Chauveteau et al , 2001Al-Anaza and Sharma 2002;Pritchett et al 2003;Frampton et al 2004;Huh et al 2005;Rousseau et al 2005;Bai et al 2007aBai et al , b, 2008Zaitoun et al 2007;Roussennac and Tosschi 2010;Zhang et al 2010;Jia et al 2011;Juntail et al 2011a, b). Table 1 displays different types of particle gels used in the oil industry, related studies and the researchers who developed these gels, particle size, and applications.…”

Section: Introductionmentioning

confidence: 99%

Influence of strong preformed particle gels on low permeable formations in mature reservoirs

Elsharafi

Bai

2016

Pet. Sci.

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In mature reservoirs, the success of preformed particle gel (PPG) treatment rests primarily on the ability of the PPG to reduce and/or plug the high permeable formations, but not damage the low permeable formations. Static test models (filtration test model and pressure test model) were used to determine the effect of PPG on low permeable formations. This work used a strong preformed particle gel, Daqing (DQ) gel made by a Chinese company. The particle gel sizes were ranged from 30 to 120 mesh for this work. PPGs are sized in a millimeter or micrometer, which can absorb over a hundred times their weight in liquids. The gel strength was approximately 6500 Pa for a completely swollen PPG with 1 % (weight percentage) NaCl solution (brine). 0.05 %, 1 %, and 10 % NaCl solutions were used in experiments. Sandstone core permeability was measured before and after PPG treatments. The relationship between cumulative filtration volumes versus filtration times was determined. The results indicate that DQ gels of a particle size of 30-80 mesh did not damage the cores of a low permeability of 3-25 mD. The DQ gels of a smaller particle size ranging from 100 to 120 mesh damaged the core and a cake was formed on the core surface. The results also indicate that more damage occurred when a high load pressure (400 psi) was applied on the high permeability cores (290-310 mD). The penetration of the particle gels into the low permeable formations can be decreased by the best selection of gel types, particle sizes, and brine concentrations.

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“…Several researchers (Bai et al 2007;Chauveteau et al 2000Chauveteau et al , 2001Chauveteau et al , 2003Coste et al 2000;Feng et al 2003) investigated the use of gel particles for plugging of pores for circumventing the problems associated with the high permeability of "thief zones" by conditioning and preparing such unfavorable formations for drilling operations.…”

Section: Introductionmentioning

confidence: 99%

“…Seright (1997Seright ( , 2000 studied the performance of gel behavior and placement in fractured formations and determined that preformed gel can penetrate deeper into a fracture than in-situ-formed gel and causes much less gel damage in oil-bearing formations or matrices. Chauveteau et al (2000Chauveteau et al ( , 2001Chauveteau et al ( , 2003 investigated the performance of preformed soft and size-controlled microgel particles, which can crosslink by the shear effect and are insensitive to the physicochemical conditions of reservoir formations. Preformed microgels were found to achieve an indepth permeability treatment by adsorbing over the pore surface.…”

Section: Introductionmentioning

confidence: 99%

Experimental Investigation and Correlation of Treatment in Weak and High-Permeability Formations by Use of Gel Particles

Al-Ibadi

Civan

2013

SPE Production &Amp; Operations

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Near-wellbore formation treatment by injection of suspensions of deformable gel particles is explored as a method of prevention of lost circulation of drilling fluids, handling of reservoir permeability heterogeneity, and controlling water production in mature waterflooded oil fields containing highly permeable and weak zones. Conditioning and plugging of such formations and the resulting permeability impairment occurring during injection of suspensions of deformable gel particles are investigated experimentally. The effect of concentration, flow rate, and gel-particle sizes of suspensions on the prevailing pore-plugging processes is inferred by flow tests conducted with 3,800-md 16-to 20-mesh sandpacks. Prevailing particle-entrapment and -permeabilityimpairment mechanisms are identified under various conditions by means of specially formulated diagnostic equations. Appropriate dimensionless groups are used to develop several empirical correlations of the experimental data, which can assist in choosing suitable gel-particle suspensions and proper application conditions required for effective near-wellbore-formation treatment. This reveals valuable insights and information about the functional trends of sandpack plugging by gel-particle suspensions, which can help in successful design and mitigation of formation-plugging treatments in the field.

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Controlling Gelation Time and Microgel Size for Water Shutoff

Cited by 53 publications

References 25 publications

Polymer Systems for Water Shutoff and Profile Modification: A Review Over the Last Decade

Polymer Systems for Water Shutoff and Profile Modification: A Review Over the Last Decade

Influence of strong preformed particle gels on low permeable formations in mature reservoirs

Experimental Investigation and Correlation of Treatment in Weak and High-Permeability Formations by Use of Gel Particles

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