Laboratory Investigation of the Injectivity of Sulfonated Polymer Solutions into Carbonate Reservoir Rocks

Han, Ming; Zhou, Xianmin; Fuseni, Alhasan; Al-Zahrani, Badr H.; AlSofi, Abdulkareem M.

doi:10.2118/155390-ms

Cited by 55 publications

(29 citation statements)

References 28 publications

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“…Injectivity is the measurement of the ease with which the fluid can be injected into the reservoir . The high pressure generated by the viscoelastic polymer solutions during EOR reduces the injectivity . The generated pressure is much higher than predicted from the shear rheology …”

Section: Introductionmentioning

confidence: 90%

“…[11] The high pressure generated by the viscoelastic polymer solutions during EOR reduces the injectivity. [6,10,[12][13][14][15][16][17] The generated pressure is much higher than predicted from the shear rheology. [8,9,[18][19] Partially hydrolyzed polyacrylamides (hereafter called HPAM) and hydrophobic associative polymers (hereafter called AP) are two commonly used high MW viscoelastic polymers for heavy oil recovery applications.…”

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confidence: 99%

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Understanding the flow behaviour of copolymer and associative polymers in porous media using extensional viscosity characterization: Effect of hydrophobic association

2018

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Associative polymer (AP) and hydrolyzed polyacrylamide (HPAM), the two commonly used polymers for heavy oil recovery, are reported to exhibit very different flow behaviour in porous media despite having similar shear viscosity. The kind of hydrophobic association (intramolecular or intermolecular) that AP exhibit is concentration dependent and will influence both shear and elongational flow in the porous media. To understand flow behaviour of these two polymers in porous media, the role of hydrophobic association on shear and extensional rheology and its effect on the resistance factor (RF) and residual resistance factor in porous media are investigated over a non‐associating HPAM polymer. The results suggest that shear rheology and the Deborah number cannot explain the porous media flow behaviour. However, direct measurements of extensional properties using a capillary breakup extensional rheometer have shown the marginal difference between two polymers at a lower concentration (1000 ppm) and the considerable difference at a higher concentration (2000 ppm), indicating an intramolecular and intermolecular association, respectively. These results are in accordance with porous media observations where both polymers have shown a similar RF at 1000 ppm. Whereas, at 2000 ppm AP showed a much higher RF at low/intermediate fluxes, and a similar RF at high flux, suggesting the transformation from intermolecular association to intramolecular association. The significant drop in the extensional viscosity at high strain rates after exhibiting the maxima explains this behaviour.

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Section: Introductionmentioning

confidence: 90%

mentioning

confidence: 99%

Understanding the flow behaviour of copolymer and associative polymers in porous media using extensional viscosity characterization: Effect of hydrophobic association

2018

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“…Often, the copolymer structure is assumed based on the synthesis technique (i.e., random comonomer distribution from free-radical polymerization, microblock structure from micellar polymerization, etc.) [26,77] or it is not mentioned at all [11,30,32,34,35,37,38,74]. Making assumptions based on synthesis technique is a good starting point (and is better than ignoring the microstructure altogether!…”

Section: Polymer Microstructurementioning

confidence: 99%

Evaluation of Polymeric Materials for Chemical Enhanced Oil Recovery

2020

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Polymer flooding is a promising enhanced oil recovery (EOR) technique; sweeping a reservoir with a dilute polymer solution can significantly improve the overall oil recovery. In this overview, polymeric materials for enhanced oil recovery are described in general terms, with specific emphasis on desirable characteristics for the application. Application-specific properties should be considered when selecting or developing polymers for enhanced oil recovery and should be carefully evaluated. Characterization techniques should be informed by current best practices; several are described herein. Evaluation of fundamental polymer properties (including polymer composition, microstructure, and molecular weight averages); resistance to shear/thermal/chemical degradation; and salinity/hardness compatibility are discussed. Finally, evaluation techniques to establish the polymer flooding performance of candidate EOR materials are described.

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“…3. Several investigations of laboratory evaluation of AM-AMPS copolymer for EOR applications 92,93 have been reported. Incorporation of the AMPS monomer in AM also improves the solubility of the polymer in the presence of divalent cations.…”

Section: Copolymer Of Acrylamide and 2-acrylamido-2-methylpropane Sulmentioning

confidence: 99%

Review on Polymer Flooding: Rheology, Adsorption, Stability, and Field Applications of Various Polymer Systems

Kamal¹,

Sultan²,

et al. 2015

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Polymer flooding is one of the most promising techniques for the recovery of remaining oil from light oil reservoirs. Water soluble polymers are used to enhance the viscosity of displacing fluid and to improve the sweep efficiency. In this paper, water soluble polymers used for chemical enhanced oil recovery are reviewed. Conventional and novel modified polymers are discussed along with their limitations. The review covers thermal stability, rheology, and adsorption behavior of various polymer systems in sandstone and carbonate reservoirs. Field and laboratory core flooding data of several polymers are covered. The review describes the polymer systems that are successfully applied in low-temperature and low-salinity reservoirs. Comprehensive review of current research activities aiming at extending polymer flooding to high-temperature and high-salinity reservoirs is performed. The review has identified current and future challenges of polymer flooding.

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Laboratory Investigation of the Injectivity of Sulfonated Polymer Solutions into Carbonate Reservoir Rocks

Abstract: The injectivity feasibility of th degree of 25 m carbonate core parameters, the quantitative me residual resistan a flow rate of after the polym solution. The r while residual permeability re ntroduction Water-soluble water. The prim The volumetric Chang, 1978; W EOR process, e

Cited by 55 publications

References 28 publications

Understanding the flow behaviour of copolymer and associative polymers in porous media using extensional viscosity characterization: Effect of hydrophobic association

Understanding the flow behaviour of copolymer and associative polymers in porous media using extensional viscosity characterization: Effect of hydrophobic association

Evaluation of Polymeric Materials for Chemical Enhanced Oil Recovery

Review on Polymer Flooding: Rheology, Adsorption, Stability, and Field Applications of Various Polymer Systems

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