Water Shut-off Polymer Systems: Design and Efficiency Evaluation Based on Experimental Studies

Vega, Isabel; Morris, Walter D.; Robles, J.; Peacock, Horacio; Marin, Amaury

doi:10.2523/129940-ms

Cited by 5 publications

(4 citation statements)

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“…The mechanical methods are known to be most suitable for wellbore related problems but can also be utilized in combination with the chemical water shutoff methods depending on the complexity of the reservoir problem. About seven decades ago, the chemical methods have attracted more industrial acceptability and thus have greater application than the mechanical methods. Polymer gels are among the chemical methods used for water shutoff treatments in the petroleum industry.…”

Section: Introductionmentioning

confidence: 99%

Investigation into the viscoelastic response at various gelation performance, thermal stability and swelling kinetics of fly ash reinforced polymer gels for water control in mature oilfields

Adewunmi

Ismail

Sultan

2016

Asia-Pacific J Chem Eng

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The present crippling crude oil price worldwide demands a new strategy and cost‐effective technology that will promote additional oil recovery in mature oilfields. Herein, crosslinked polyacrylamide (PAM) gels reinforced with coal fly ash (CFA) were investigated for water reduction purpose during enhanced oil recovery. Polyethyleneimine (PEI) is chosen as the crosslinker. Neat PAM/PEI gel and PAM/PEI composite gels filled with various CFA concentrations (0.5 to 2 wt%) were developed and characterized by aging, gravimetric, hybrid rheometer, thermogravimetric analyzer (TGA), scanning electron microscopy (SEM), X‐ray diffraction (XRD) and Fourier transform infrared spectroscopy (FTIR) instruments. Gelation performance of these gels was conducted at 90 °C, and results show that increase in CFA in PAM/PEI gels causes a delay in the gelation time. This indicates that CFA can act as a retarder in polymer gels applied for water control in mature oilfields. Moreover, the PAM/PEI composite gels containing CFA displayed improved viscoelastic properties as compared to the neat PAM/PEI gel at various gelation behaviors that were tested. Additionally, TGA analysis revealed that PAM/PEI gels infused with different CFA amounts possessed high resistance to thermal decomposition. The presence of alumina and silica in high concentrations in CFA induced a strong bond within these polymer gels, which resulted in improved thermal stability. Further, owing to the fact that CFA only absorbed a small amount of water through the hydroxyl and amine groups, its presence decreased the swelling ability of these composite gels. Morphological and structural analysis demonstrated by these gels affirmed the consistency of viscoelastic, thermal and swelling kinetic results. Copyright © 2016 Curtin University of Technology and John Wiley & Sons, Ltd.

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Section: Introductionmentioning

confidence: 99%

Investigation into the viscoelastic response at various gelation performance, thermal stability and swelling kinetics of fly ash reinforced polymer gels for water control in mature oilfields

Adewunmi

Ismail

Sultan

2016

Asia-Pacific J Chem Eng

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“…• form strong hydrogel under reservoir conditions-with Sydansk's gel-strength code > G (bottle testing, Figure 3), elastic modulus (G'), and viscous modulus (G") ratio above 10 (G'/G" > 10) with G' and G" being independent of the oscillation frequency, and G' > 1 Pa. These blocking-ability parameters can be obtained by bottle tests and oscillatory rheological tests [9,20,42,56,86];…”

Section: Gelling Polymer System Screeningmentioning

confidence: 99%

Hydrogels Applied for Conformance-Improvement Treatment of Oil Reservoirs

Tessarolli¹,

Gomes²,

Mansur³

2018

Hydrogels

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This chapter aims at presenting a review of gelling polymer systems that are commercially available or under academic development with potential to control the anisotropic permeability profile of heterogeneous oil reservoirs. In these reservoirs, the oil recovery and sweep efficiency tend to be low, even after applying secondary and enhanced oil recovery methods, because the injected fluid flows preferably through the matrix's most permeable regions leaving behind part of the displaceable oil retained at the nonswept volume. For that, cross-linked polymers can be used to plug the high-permeability main paths by means of: (i) the formation of an in situ hydrogel or (ii) the adsorption or swelling of precross-linked hydrogel within the reservoir pores, thus causing the diversion of the subsequently injected fluid to low-permeability zones and/or preventing the channeling and early breakthrough of the injected fluid (water or gas) in production wells. The selection of the most suitable hydrogel for the reservoir conformance-improvement treatment should take into account the nature of the conformance problem, the reservoir's lithology, mineralogy, temperature, pH value, salinity, and hardness of the formation water, as well as the gelling system toxicity and cost.

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“…Many techniques extensively were developed to achieve this purpose in the last decade. [1,2] Crosslinked polymers are considered as one of the most commonly applied alternative because of their relatively low cost, ease of pumping and ability to penetrate into the reservoirs. [3] Polymer gels based on copolymer/crosslinker solution are turned from low viscosity liquid (gelant) into strong or weak gels depending on their formulations under a needed time.…”

Section: Introductionmentioning

confidence: 99%

Hydrogel swelling properties: comparison between conventional and nanocomposite hydrogels for water shutoff treatment

Mohammadi

Sefti

Salehi

et al. 2015

Asia-Pacific J Chem Eng

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One of the unique properties of hydrogels is the dramatically change in their volume and shape. In this research, conventional hydrogels (composed of sulfonated polyacrylamide and Cr(OAc) 3 as copolymer and crosslinker, respectively) were investigated versus nanocomposite (NC) hydrogels for the purpose of achieving suitable composition with ability of high amount of equilibrium swelling ratio and low amount of salt sensitivity factor (f). The results showed that high ratio of Cr(OAc) 3 /copolymer (>0.39) and high concentration of copolymer (>27 000 ppm) were suitable areas for conventional hydrogels because of minimum f factor with still low ability of gel swelling. However, the results of NC hydrogels with composition of copolymer concentrations of 23 750 to 30 000 ppm, Cr(OAc) 3 /copolymer ratio of 0.28 and nano Na-MMT concentrations of 500 to 800 ppm represented a significantly high amount of swelling and low amount of f factor. Coreflooding tests were applied to investigate the effect of polymer gel swelling in porous media for water shutoff treatment. The values of the residual resistance factor of water/oil for samples with high and low swelling ratio were 32.34 and 7.08, respectively, confirming the ability of the polymer gel with high swelling ratio in reducing the relative permeability of water/oil in porous media.

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Water Shut-off Polymer Systems: Design and Efficiency Evaluation Based on Experimental Studies

Cited by 5 publications

References 0 publications

Investigation into the viscoelastic response at various gelation performance, thermal stability and swelling kinetics of fly ash reinforced polymer gels for water control in mature oilfields

Investigation into the viscoelastic response at various gelation performance, thermal stability and swelling kinetics of fly ash reinforced polymer gels for water control in mature oilfields

Hydrogels Applied for Conformance-Improvement Treatment of Oil Reservoirs

Hydrogel swelling properties: comparison between conventional and nanocomposite hydrogels for water shutoff treatment

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