Application of a Novel Polymer System in Chemical Enhanced Oil Recovery (EOR)

Wang, Wei; Liu, Yuzhang; Gu, Yongan

doi:10.1007/s00396-003-0873-6

Cited by 88 publications

(57 citation statements)

References 6 publications

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“…In the PF process, water-soluble polymers added into the injection water can increase the viscosity of water phase, simultaneously improve the mobility ratio, and enlarge the swept volume, leading to higher oil recovery efficiencies [3][4][5].…”

Section: Introductionmentioning

confidence: 99%

“…Partially hydrolyzed polyacrylamide (HPAM) is the most widely used water-soluble polymer and has been successfully employed in tertiary oil recovery worldwide [4][5][6][7]. However, the main problem of HPAM in the oilfield application is its poor heat tolerance and salt resistance performance, which limit its applications in the high-temperature and high-salinity oil reservoirs [8], such as the Class III reserve of the Shengli Oilfield in China where the temperature is above 85 °C and the salinity (total dissolved solids, TDS) is higher than 30,000 mg•L −1 in which the total amount of Ca 2+ and Mg…”

Section: Introductionmentioning

confidence: 99%

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Aqueous Hybrids of Silica Nanoparticles and Hydrophobically Associating Hydrolyzed Polyacrylamide Used for EOR in High-Temperature and High-Salinity Reservoirs

et al. 2014

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Water-soluble polymers are known to be used in chemically enhanced oil recovery (EOR) processes, but their applications are limited in high-temperature and high-salinity oil reservoirs because of their inherent poor salt tolerance and weak thermal stability. Hydrophobic association of partially hydrolyzed polyacryamide (HAHPAM) complexed with silica nanoparticles to prepare nano-hybrids is reported in this work. The rheological and enhanced oil recovery (EOR) properties of such hybrids were studied in comparison with HAHPAM under simulated high-temperature and high-salinity oil reservoir conditions (T: 85 °C; total dissolved solids: 32,868 mg873 mg•L −1 ). It was found that the apparent viscosity and elastic modulus of HAHPAM solutions increased with addition of silica nanoparticles, and HAHPAM/silica hybrids exhibit better shear resistance and long-term thermal stability than HAHPAM in synthetic brine. Moreover, core flooding tests show that HAHPAM/silica hybrid has a higher oil recovery factor than HAHPAM solution.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Aqueous Hybrids of Silica Nanoparticles and Hydrophobically Associating Hydrolyzed Polyacrylamide Used for EOR in High-Temperature and High-Salinity Reservoirs

et al. 2014

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“…Also, PAM cannot emulsify the oil-water system, which limits its oil recovery capability. In order to reduce the oil-water interfacial tension and enhance the emulsification process to improve the displacement efficiency, the binary flooding systems of PAMsurfactant or PAM-surfactant-alkali tertiary combination were developed [1][2][3]. However, for these combined systems, the use of a large amount of surfactant leads to a high cost, and the presence of alkali causes problems such as the separation of oil from water and waste water treatment [4].…”

Section: Introductionmentioning

confidence: 98%

Solution properties of hydrophobically modified polyacrylamides and their potential use for polymer flooding application

Al-Sabagh

Kandile

El-Ghazawy

et al. 2016

Egyptian Journal of Petroleum

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We tested nine hydrophobically modified polyacrylamides with molecular weights situated between 1.58 and 0.89 Â 10 6 g/mol for enhanced oil recovery applications. Their solution properties were investigated in the distilled water, brine solution, formation water and sea water. Their critical association concentrations were determined from the relationship between their concentrations and the corresponding apparent viscosities (g app ) at 30°C at shear rate 6 s À1 . They were between 0.4 and 0.5 g/dl. The brine solutions of 0.5 g/dl of HM-PAMs were investigated at different conditions regarding their apparent viscosities. Such conditions were mono and divalent cations, temperature ranging from 30 to 90°C, the shear rate ranging from 6 to 30 s À1 and the aging time for 45 days. The surface and interfacial tensions for the HM-PAMs were measured for concentration range from 0.01 to 1 g/dl brine solutions at 30°C and their emulsification efficiencies were investigated for 7 days. The discrepancy in the properties and efficiencies of the tested copolymers was discussed in the light of their chemical structure. Ó 2015 The Authors. Production and hosting by Elsevier B.V. on behalf of Egyptian Petroleum Research Institute. This is an open access article under the CC BY-NC-ND license (http://creativecommons.org/ licenses/by-nc-nd/4.0/).

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“…Hydrogels as fracture-plugging and fluid diverting materials have been employed in conformance control (profile modification) and in the control of excess water production during EOR applications [Bai et al ( , 2007a[Bai et al ( , b, 2008; Zhang and Bai 2011;Vossoughi (2000); Wang et al (2001Wang et al ( , 2003]. Mechanistically, hydrogel is injected to seal high permeability and fracture zones, such that when injected fluids are injected, they will be forced or redirected to the low permeability, unswept oil-rich zones, sweeping out oil from them, leading to additional oil production.…”

Section: Introductionmentioning

confidence: 99%

A more superior preformed particle gel with potential application for conformance control in mature oilfields

Tongwa

Bai

2014

J Petrol Explor Prod Technol

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The present work presents a nanocomposite preformed particle gel for conformance control in mature oilfields. This product was observed to have a better performance than conventional hydrogels without nanomaterials. Preformed particle hydrogel was designed by the reaction of monomer, initiator, crosslinker, additives, and calcium montmorillonite nanomaterial, whereas conventional hydrogel is designed from just monomer, initiator, crosslinker and additives. The presence of nanomaterial in hydrogel design affords it tremendous improvement in nanocomposite gel properties and behavior compared to conventional hydrogels without any nanomaterial. Additionally, swelling performance, post-degraded gel viscosity, and long-term thermal resistance of nanocomposite gel increased by several orders of magnitude compared to hydrogels with no nanomaterial. Environmental Scanning Electron Microscopy (ESEM) revealed the presence of a very dense 3-D network compared to hydrogels with no nanomaterial. On incorporation of nanomaterial, increase in gel strength of up to 2,150 % was observed. Thus, they are potential replacements for existing preformed particle gels in mitigating permeability variations in mature reservoirs.

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Application of a Novel Polymer System in Chemical Enhanced Oil Recovery (EOR)

Cited by 88 publications

References 6 publications

Aqueous Hybrids of Silica Nanoparticles and Hydrophobically Associating Hydrolyzed Polyacrylamide Used for EOR in High-Temperature and High-Salinity Reservoirs

Aqueous Hybrids of Silica Nanoparticles and Hydrophobically Associating Hydrolyzed Polyacrylamide Used for EOR in High-Temperature and High-Salinity Reservoirs

Solution properties of hydrophobically modified polyacrylamides and their potential use for polymer flooding application

A more superior preformed particle gel with potential application for conformance control in mature oilfields

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