Dehydration of polyacrylamide-based super-absorbent polymer swollen in different concentrations of brine under CO2 conditions

Sun, Xindi; Bai, Baojun

doi:10.1016/j.fuel.2017.08.047

Cited by 17 publications

(2 citation statements)

References 25 publications

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“…The size of PPGs range from micrometers (μm) to centimeters (cm) . They are developed to be applied to formations with high permeability channels or small fractures, not for treating matrix excessive water production problems. − These particles have hydrophilic groups, −COOH and −CONH 2 , so they can swell in the formation water within the range of a few to 200-times their original size, thereby plugging the water channels and improving the profile performance. − Thousands of oilfield PPG applications have been conducted in China. , One representative case is the Zhongyuan oilfield, China. This sandstone reservoir has an average permeability of 121 md, a high salinity of 150000 mg/L, and a formation temperature of 107 °C.…”

Section: Preformed Gelsmentioning

confidence: 99%

Polymer Gel Systems for Water Management in High-Temperature Petroleum Reservoirs: A Chemical Review

2017

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Polymer gel systems as water management materials have been widely used in recent years for enhanced oil recovery applications. However, most polymer gel systems are limited in their ability to withstand the harsh environments of high temperature and high salinity. Those polymer gel systems that can handle high-temperature excessive water treatments are reviewed in this paper and categorized into three major types: in situ cross-linked polymer gels, preformed gels, and foamed gels. Future directions for the development of polymer gel systems for high-temperature conditions are recommended. For excessive water management with temperatures from 80 to 120 °C, current polymer systems are substantially adequate. Polymer gel systems composed of partially hydrolyzed polyacrylamide (HPAM)/chromium can be combined with nanoparticle technology to elongate their gelation time and reduce the adsorption of chromium ions in the formation. Phenolic resin cross-linker systems have reasonable gelation times and gel strengths; however, more environmentally friendly cross-linkers should be developed to meet the increasingly stringent environmental requirements. For particle gels, the addition of functional monomer(s) can improve the antitemperature performance. When the applied temperatures reach 120 °C, inorganic cross-linker systems are no longer applicable, and the gelation time of organic cross-linking polymer gel systems and gel thermal stability will decrease significantly due to fast cross-linking reactions. During this period, retarders can be used to elongate the gelation time, and gel strength enhancers (e.g., cement, silica) can also be applied to improve the gel strength at such extremely high temperatures. Most importantly, novel polymers (e.g., ter- or tetrapolymers), functional monomers, and environmentally friendly cross-linkers need to be discovered and developed for polymer gel applications. Second cross-linking systems can be applied to further enhance the strength of the particle gels in harsh conditions. On the basis of these developments, foamed gels can be well-implemented in fractures and wormholes to save the amount of injected gels.

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Section: Preformed Gelsmentioning

confidence: 99%

Polymer Gel Systems for Water Management in High-Temperature Petroleum Reservoirs: A Chemical Review

2017

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“…The differential pressure across the fracture model might be responsible for this result. Under high differential pressure conditions, the swollen PPG experiences strong compressional force, 37 which will impair its water-holding capacity and then decrease its volume. However, the swelling ratio is not linearly correlated with the differential pressure, as demonstrated by Figure 6.…”

Section: Plugging Efficiency Undermentioning

confidence: 99%

Water Plugging Performance of Preformed Particle Gel in Partially Filled Fractures

Sun

Han

et al. 2019

Ind. Eng. Chem. Res.

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Preformed particle gel (PPG) treatment has been well-recognized as an efficient method to reduce excessive water production in fractured reservoirs. However, previous research on its plugging efficiency was mainly conducted in open fractures. In this paper, calcite-filled fracture models were designed to comprehensively investigate the water plugging performance of PPG in partially filled fractures which are extremely common in fractured reservoirs. Systematic plugging performance tests have proceeded under various calcite-filling conditions. The results show that the calcite particles can improve the breakthrough and retention of the PPG as well as the plugging efficiency. With increased size and concentration of the calcite particles, the PPG breakthrough pressure gradient increases, and the fracture permeability decreases. When the ratio of average calcite particle diameter to fracture width (RC) is small (0.15), the fracture permeability is difficult to be further reduced by increasing PPG concentration or PPG size. However, when the RC increases to 0.21, the plugging performance in fractures filled with more calcite particles or PPG particles, especially the latter, is better than that filled with larger calcite particles. This study provides new insight into the PPG treatment and will contribute to the water control in fractured reservoirs.

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Improved oil recovery by gel technology: Water shutoff and conformance control

2022

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Dehydration of polyacrylamide-based super-absorbent polymer swollen in different concentrations of brine under CO2 conditions

Cited by 17 publications

References 25 publications

Polymer Gel Systems for Water Management in High-Temperature Petroleum Reservoirs: A Chemical Review

Polymer Gel Systems for Water Management in High-Temperature Petroleum Reservoirs: A Chemical Review

Water Plugging Performance of Preformed Particle Gel in Partially Filled Fractures

Improved oil recovery by gel technology: Water shutoff and conformance control

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