Enhancing oil recovery from low-permeability reservoirs with a self-adaptive polymer: A proof-of-concept study

Zhang, Yan; Feng, Yujun; Li, Bo; Han, Peng

doi:10.1016/j.fuel.2019.04.034

Cited by 36 publications

(28 citation statements)

References 50 publications

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“…They concluded that the hydrophobically modified polymer had better properties for application in EOR. Similar studies were also performed by Zhang et al (2019), who noted that the injection of HMAP in porous media increased the oil recovery factor by 18.7% compared to PHPA injection. Abirov et al (2019) performed porous media tests with commercial PHPA and HMAP solutions simulating conditions of the Turgay Southern Basin reservoir in Kazakhstan, where severe salinity and temperature conditions prevail (92 000 ppm TDS and 82°C).…”

Section: Hydrophobically Modified Associative Polymers (Hmaps)supporting

confidence: 75%

“…In general, hydrophobically modified polymers have better thermal stability, salinity tolerance and oil recovery efficiency than unmodified polymers. Thus, they can be considered promising viscosifying agents for EOR in reservoirs with harsh conditions (high salinity and temperature) (El-Hoshoudy et al, 2017a;Liu et al, 2017a;Zhang et al, 2019). Table 1 shows the summary of the main scientific developments in this area and the evolution of the studies.…”

Section: Hydrophobically Modified Associative Polymers (Hmaps)mentioning

confidence: 99%

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Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Aguiar

Palermo

Mansur

2021

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Due to the growing demand for oil and the large number of mature oil fields, Enhanced Oil Recovery (EOR) techniques are increasingly used to increase the oil recovery factor. Among the chemical methods, the use of polymers stands out to increase the viscosity of the injection fluid and harmonize the advance of this fluid in the reservoir to provide greater sweep efficiency. Synthetic polymers based on acrylamide are widely used for EOR, with Partially Hydrolyzed Polyacrylamide (PHPA) being used the most. However, this polymer has low stability under harsh reservoir conditions (High Temperature and Salinity – HTHS). In order to improve the sweep efficiency of polymeric fluids under these conditions, Hydrophobically Modified Associative Polymers (HMAPs) and Thermo-Viscosifying Polymers (TVPs) are being developed. HMAPs contain small amounts of hydrophobic groups in their water-soluble polymeric chains, and above the Critical Association Concentration (CAC), form hydrophobic microdomains that increase the viscosity of the polymer solution. TVPs contain blocks or thermosensitive grafts that self-assemble and form microdomains, substantially increasing the solution’s viscosity. The performance of these systems is strongly influenced by the chemical group inserted in their structures, polymer concentration, salinity and temperature, among other factors. Furthermore, the application of nanoparticles is being investigated to improve the performance of injection polymers applied in EOR. In general, these systems have excellent thermal stability and salinity tolerance along with high viscosity, and therefore increase the oil recovery factor. Thus, these systems can be considered promising agents for enhanced oil recovery applications under harsh conditions, such as high salinity and temperature. Moreover, stands out the use of genetic programming and artificial intelligence to estimate important parameters for reservoir engineering, process improvement, and optimize polymer flooding in enhanced oil recovery.

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Section: Hydrophobically Modified Associative Polymers (Hmaps)supporting

confidence: 75%

Section: Hydrophobically Modified Associative Polymers (Hmaps)mentioning

confidence: 99%

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Aguiar

Palermo

Mansur

2021

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

View full text Add to dashboard Cite

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“…In the past, many scholars have studied and summarized the relationship between core injection capacity and relevant parameters such as pressure difference, resistance coefficient, and residual resistance coefficient through a large number of core displacement experiments. The injection capacity is judged from the stability degree of pressure, resistance coefficient, and residual resistance coefficient with the increase in injected PV number, and it is generally believed that the injection capacity of the displacement agent is poor when the injection pressure is high and good when the injection pressure is low, 47‐49 but these evaluation standards only analyze the injection situation from the total change trend, and there is no accurate range to specifically define the injection capacity for the actual displacement situation. According to these related research studies and combined with the main parameters such as injection pressure and produced fluid, 38 groups of experiments were carried out through laboratory experiments.…”

Section: Resultsmentioning

confidence: 99%

Experimental evaluation of ASP flooding to improve oil recovery in heterogeneous reservoirs by layered injection approach

Huang

et al. 2020

Energy Science & Engineering

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To improve the oil displacement effect of ASP (alkali/surfactant/polymer) solution in heterogeneous oil reservoirs, layered injection technology is proposed for the first time for Daqing Oilfield. The technology uses partial pressure tools to control the injection amount of ASP solution in high‐permeability oil layers and uses a partial quality tool in low‐permeability oil layers. To study the experimental effect of this layered injection technology, the relationships between the different permeability, molecular weight, and concentration of the ASP solution, as well as the resistance coefficient and residual resistance coefficient, are first established, and then, a layered injection experimental model is established to carry out experimental research on injection capacity and oil displacement capacity. The experimental results show that the smaller the range of the core permeability is, the larger the molecular weight and concentration of the ASP solution are, and the poorer the injection capacity of the ASP solution is. After the action of a partial pressure tool and a partial quality tool, the injection capacity of ASP solution is improved to different degrees, and the oil displacement effect of low‐permeability cores is significantly improved, while the total oil recovery is increased, and the total oil recovery of heterogeneous cores under different conditions is increased by 1.4%‐4.05%. This experiment is of great significance to the study of improving the oil recovery of heterogeneous reservoirs.

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“…Up to now, the most common evaluation methods used to measure polymers are SLS and viscometry. [ 38,39 ] In this study, static light scattering (SLS) was adopted to measure M W of CHPAM and HPAM. At the same time, the obtained other parameters, expected molecular weight, including second virial coefficient (A 2 ) and the radius of gyration ( R g ), could be utilized to evaluate the molecular diameter and flexibility of the polymer.…”

Section: Methodsmentioning

confidence: 99%

Preparation and structural analysis of a comb‐like polymer through functional monomer design

Zhao

Wang

Jiang

et al. 2021

Polymer Engineering & Sci

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Partially hydrolyzed polyacrylamide (HPAM) is the most extensively used polymer for enhanced oil recovery due to its accessibility and low cost. However, HPAM shows inadequacies in high mineralization and high‐temperature reservoirs. To solve this problem, a comb‐like polymer with superior salt‐resistance and stability named CHPAM was prepared via direct free‐radical copolymerization of acrylamide (AM) and acrylic acid (AA) with the self‐designed monomer (Acryloyl‐MPEG‐1000). The chemical structures of CHPAM and monomers were characterized by Fourier transform infrared spectroscopy (FT‐IR) and nuclear magnetic resonance spectroscopy (NMR). Static light scattering (SLS) was adopted to measure the molecular weights of CHPAM and HPAM. The solution properties of CHPAM and HPAM were comparatively studied. It was found that CHPAM showed better thermal‐salt stability and salt‐resistance than HPAM, especially in Ca2+ solution. This work paves a new way for the preparation of novel polymers.

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Enhancing oil recovery from low-permeability reservoirs with a self-adaptive polymer: A proof-of-concept study

Cited by 36 publications

References 50 publications

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Experimental evaluation of ASP flooding to improve oil recovery in heterogeneous reservoirs by layered injection approach

Preparation and structural analysis of a comb‐like polymer through functional monomer design

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