Effect and mechanism of combined operation of profile modification and water shutoff with in-depth displacement in high-heterogeneity oil reservoirs

Bao, Cao; Xie, Kongliang; Lu, Xiaofeng; Cao, Weijia; He, Xin; Xiao, Zhong; Zhang, Yunbao; Wang, Xiaoyan; Su, Cheng

doi:10.1016/j.colsurfa.2021.127673

Cited by 23 publications

(15 citation statements)

References 49 publications

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“…The effect of different temperatures on the viscosity: The LHPAM solution with a concentration of 3% was prepared, and the viscosity of the LHPAM was measured at different temperatures (20,40,60,80, 100 C) for three consecutive days.…”

Section: Viscosity Analyzingmentioning

confidence: 99%

Synthesis of a low viscosity amphoteric polyacrylamide and its application in oilfield profile control

Tian

Hongzhou

2022

J of Applied Polymer Sci

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A low viscosity amphoteric polyacrylamide (LHPAM) was synthesized with Acrylamide and a Cationic etherifying agent. FTIR, SEM, and EDS all suggest that it successfully synthesized a new material. It can be demonstrated from TG and DSC that the temperature resistance of LHPAM is higher than that of partially hydrolyzed polyacrylamide (HPAM) and it can be found from ultraviolet–visible spectrophotometer that the flocculability of LHPAM is stronger than that of HPAM. The viscosity testing shows that the viscosity of LHPAM is greater than that of HPAM at the beginning, but the viscosity of LHPAM has been ultimately lower than that of HPAM after 1d. In addition, LHPAM reacts with Cr3+ to form a gel with an interpenetrating network structure, while HPAM is a gel with a comb‐shaped system, and the gelation time of LHPAM is longer than that of HPAM. However, the final gelation strength is the same. The final flow experiment shows that the plugging rates of LHPAM and HPAM are greater than 95%, but the resistance coefficient of LHPAM is smaller than that of HPAM. This study expands the application of HPAM in profile control and water shutoff, which is of great significance for enhanced oil recovery.

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Section: Viscosity Analyzingmentioning

confidence: 99%

Synthesis of a low viscosity amphoteric polyacrylamide and its application in oilfield profile control

Tian

Hongzhou

2022

J of Applied Polymer Sci

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“…In recent years, the technique of working with pressure has been thoroughly researched and widely used 21–23 . Currently, the commonly used temporary plugging technology with pressure operation can be mainly divided into: mechanical temporary plugging technology 24,25 and chemical temporary plugging technology 26–29 .…”

Section: Introductionmentioning

confidence: 99%

“…19,20 In recent years, the technique of working with pressure has been thoroughly researched and widely used. [21][22][23] Currently, the commonly used temporary plugging technology with pressure operation can be mainly divided into: mechanical temporary plugging technology 24,25 and chemical temporary plugging technology. [26][27][28][29] Chemical temporary plugging technology is widely used because of its good plugging effect, low cost, low risk, and other advantages.…”

Section: Introductionmentioning

confidence: 99%

Research and performance evaluation of modified nano‐silica gel plugging agent

Zheng

Luo

2023

J of Applied Polymer Sci

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Due to the difficulties in plugging high-pressure injection wells, the short period of plugging, and the use of modified nano-silica, a novel chemical gel plugging agent has been created. Modification of silica using silane coupling agents, and using the aqueous free radical polymerization method synthesized chemical plugging agent with AM, AA, and DMDAAC. The optimum synthesis conditions were screened by single-factor analysis: mass ratio m(AM):m (AA):m(DMDAAC) = 8:1.5:1, modified nano-silica concentration of 1.0%, total monomer mass concentration of 8.0%, initiator concentration of 0.3%, the cross-linker concentration of 0.4%, and coagulant concentration of 0.6%. The performance of the chemical plugging agent was evaluated under the target oil formation conditions. The experimental results showed that the chemical plugging agent exhibited good temperature resistance at 40-100 C, good salt resistance at mineralization (0.5-2.5) Â 10 4 mg/L, and the chemical plugging agent breaks through pressure gradients of 1.12, 15.42 and 90.15 MPa/m in the wellbore, fracture and core, respectively, compared with most gel plugging agents, this plugging agent is more suitable for sealing with pressure work. After adding the breakout agent, the fluid after breakout is fluid-like with low viscosity, which is convenient for reverse discharge and will not cause harm to the reservoir and ensure the subsequent normal construction operation.

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“…often preferentially forms a dominant channel in the high permeability formation. With the development of the oilfield, the low permeability reservoir is rarely developed [ 3 ]. To solve this problem, it is necessary to effectively block the high flow passage and force the displacement medium to turn to the reservoir with low permeability to increase the sweep efficiency of the displacement medium.…”

Section: Introductionmentioning

confidence: 99%

Preparation Method and Performance Evaluation of a Gel Based on AM/AMPS Copolymer

Ran

Zhang

Jiang

et al. 2022

Gels

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Polymer gels have been widely used in high water cut oilfields for profile control and water plugging. It is urgent to develop a gel suitable for the Tahe Oilfield (Temperature: 130 °C, salinity: 2.2 × 105 mg/L) in China. A stable gel was prepared by using an acrylamide (AM)/2-acrylamide-2-methyl propanesulfonic acid (AMPS) copolymer crosslinked with urotropin (HMTA), hydroquinone (HQ), thiourea and Nano-SiO2. This paper covers a step-by-step process for designing gels based on experience with preparing gels. A wide range of combinations between polymers and crosslinking agents with and without stabilizers were investigated, and the results indicated that there is an optimal value of AMPS content of AM/AMPS copolymers in the preparation of gels. Increasing the mass fraction of copolymer and using stabilizer enhanced the performance of gel, but an excessive amount of crosslinking agent was not conducive to the stability of gel. The work optimized the formula of plugging agent suitable for the high temperature and high salt (HTHS) condition in the Tahe Oilfield. The gelling solution had a long gelation time of 20 h. The gel had high strength (Sydansk’s gel-strength code of “G”) with storage modulus of 12.9 Pa and could be stable for half a year at 130 °C and 2.2 × 105 mg/L of salinity. The plate model that could be heated and pressurized was used to simulate the oil flooding and profile modification under the condition of the Tahe Oilfield for the first time. The experiment results showed that the oil recovery could be increased by 13.22% by subsequent water flooding under heterogeneous formation condition. Therefore, it was fully confirmed that the plugging performance of AM/AMPS phenolic gel prepared in the work was excellent. The information provided in the study could be used as a reference for the design and evaluation of polymer gels in other HTHS reservoirs.

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Effect and mechanism of combined operation of profile modification and water shutoff with in-depth displacement in high-heterogeneity oil reservoirs

Cited by 23 publications

References 49 publications

Synthesis of a low viscosity amphoteric polyacrylamide and its application in oilfield profile control

Synthesis of a low viscosity amphoteric polyacrylamide and its application in oilfield profile control

Research and performance evaluation of modified nano‐silica gel plugging agent

Preparation Method and Performance Evaluation of a Gel Based on AM/AMPS Copolymer

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