Compatibility evaluation of in-depth profile control agents in dominant channels of low-permeability reservoirs

Li, Junjian; Wang, Ze; Yang, Hanxu; Yang, Haitao; Wu, Tianjiang; Wu, Hui; Wang, Hao; Yu, Fuwei; Jiang, Hanqiao

doi:10.1016/j.petrol.2020.107529

Cited by 15 publications

(11 citation statements)

References 19 publications

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“…As the fluid injection volume of the studied microspheres increases, multiple microspheres are stacked and bridged, blocking the pore throats (Figure d). In general, when the particle size is larger than 1/3 of the pore throat diameter, the microsphere particles are trapped by the pore throat, producing an outer filter cake in the pore throat and blocking the pore channel . When the particle size is 1/3–1/7 times the pore throat diameter, the microsphere particles can enter the interior of the reservoir.…”

Section: Results and Discussionmentioning

confidence: 99%

“…In general, when the particle size is larger than 1/3 of the pore throat diameter, the microsphere particles are trapped by the pore throat, producing an outer filter cake in the pore throat and blocking the pore channel. 27 When the particle size is 1/3−1/7 times the pore throat diameter, the microsphere particles can enter the interior of the reservoir. The microspheres aggregate together, and bridge plugging occurs due to the mechanical trapping of the pore throats.…”

Section: Macroscopic Migration and Plugging Performancementioning

confidence: 99%

“…Reservoirs with low permeability in China have complex pore structures. − There are some problems such as severe water channeling and low oil recoveries during the water injection development. − Technologies of conventional plugging and profile control cannot meet the production demands of oilfields. − Polymer microspheres have attracted increasing attention in the area of depth profile control in recent years. − Polymer nano-microspheres have many advantages such as the small particle diameter, good elasticity, and deformation ability, making the microspheres easily reach the deep formation and selectively block the dominant channels of water flooding. − The permeability of the profound formation is changed, and the swept volume of the displacement fluid is enlarged due to the “migration-plugging-remigration-replunging” of microspheres. − …”

Section: Introductionmentioning

confidence: 99%

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Study on the Profile Control and Oil Displacement Mechanism of a Polymer Nano-microsphere for Oilfield

et al. 2023

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In this study, the mechanism of migration/plugging and the main performance of polymer nano-microspheres (HQ) were investigated using environmental scanning electron microscopy (ESEM), swelling hydration experiments, sand-filling pipe flooding experiments, and microscopic displacement experiments. Results show that the swelling ratio of HQ in salt solution first increases and then reaches equilibrium with the increase in swelling time. The expansion ratio of HQ increases rapidly at the initial stage of swelling and reaches its maximum value after swelling for 7 days. The maximum value of the expansion ratio was 15. In addition, the higher the salinity, the smaller the particle size of the studied microspheres. The particle size of the microspheres increases with increasing temperature. According to the visualized microscopic experiments, the migration and blocking mechanism of microspheres in the pore throat were discovered. When the particle size is 1/3–1/7 times the pore throat diameter, the microsphere particles can enter the interior of the pores. The microspheres aggregate together, and bridge plugging occurs due to the mechanical trapping of pore throats. In this case, the pore throats are blocked by the produced inner filter cake. The pressure at each point fluctuates up and down in a zigzag pattern during the displacement experiment, revealing the “migrated-plugged-breakthrough-replugged” mechanism for HQ. It can be seen from the oil displacement experiment that the final cumulative recovery and the enhanced oil recovery were 65.71 and 17.31%, respectively. Thus, the studied nano-microspheres have excellent oil displacement performance.

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Section: Results and Discussionmentioning

confidence: 99%

Section: Macroscopic Migration and Plugging Performancementioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Study on the Profile Control and Oil Displacement Mechanism of a Polymer Nano-microsphere for Oilfield

et al. 2023

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“…Considering the application effect of PCAs in low-permeability fractured reservoirs, study on the compatibility between PCAs and channel scale is particularly critical. Shown as Table 1 , microsphere suspension, poly(ethylene glycol) single-phase gel particle (PEG) and cross-linked bulk gel and swelling particle (CBG-SP) have been applied to more than 7000 wells in Changqing Oilfield from 2016 to 2018 [ 8 ]. Because of their substantial application results and favorable application prospects, they have attracted extensive attention in the domain of research and application of PCAs.…”

Section: Introductionmentioning

confidence: 99%

Compatibility Evaluation of In-Depth Profile Control Agents for Low-Permeability Fractured Reservoirs

Wang

et al. 2022

Gels

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Under the background that the in-depth profile control technology is gradually applied in low-permeability fractured reservoirs, this paper regards block H of Changqing Oilfield as the research object, referring to the range of its physical parameters and field application data. Three common in-depth profile control agents (PCAs), nanosphere suspension, poly(ethylene glycol) single-phase gel particle (PEG) and cross-linked bulk gel and swelling particle (CBG-SP), are selected to investigate the compatibility between the fractured channels and the PCAs through a series of experiments. The experimental results show that the nanospheres with particle sizes of 100 nm and 300 nm have good injectivity and deep migration ability, which remains the overall core plugging rate at a high level. The residual resistance coefficient of 800 nm nanospheres decreases in a “cliff” manner along the injection direction due to the formation of blockage in the front section, resulting in a very low plugging rate in the rear section. The injection rate is an important parameter that affects the effect of PEG in the fractured channels. When the injection rate is lower than 0.1 mL/min, the plugging ability will be weakened, and if the injection rate is higher than 0.2 mL/min, the core plugging will occur. The appropriate injection rate will promote the better effect of PEG with the plugging rate > 90%. The average plugging rate of CBG-SP in fractured rock core is about 80%, and the overall control and displacement effect is good. Based on the experimental data of PCAs, the optimization criteria of slug configuration and pro-duction parameters are proposed. According to the principle “blocking, controlling and displacing”, references are provided for PCAs screening and parameters selection of field implementation.

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“…By analyzing the sealed coring well groups L76-60 and L88-40 located in Changqing Oilfield, Wang et al (2015) pointed out that during the process of injecting water with high pressure, when bottom hole pressure exceeds rock breakdown pressure and propagation pressure, the dynamic fracture will be generated and will change the seepage characteristics of water displacing in the ultra-low permeability reservoir (Takuya et al , 2019), which would lead to the reduction of profile producing degree. According to the research work by Gu et al (2019), Zhao et al (2020) and Li et al (2020), injecting water into the low permeability reservoir is difficult and the leakage along the cracks will adversely affect the efficiency of the development, which will result in nonideal development of the reservoir with low permeability.…”

Section: Introductionmentioning

confidence: 99%

Analysis of the channeling of water injection in low permeability reservoirs with interlayer considering the seepage–stress coupling

Vafai

et al. 2020

HFF

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Purpose This paper aims to establish a mathematical model for water-flooding considering the impact of fluid–solid coupling to describe the process of development for a low-permeability reservoir. The numerical simulation method was used to analyze the process of injected water channeling into the interlayer. Design/methodology/approach Some typical cores including the sandstone and the mudstone were selected to test the permeability and the stress sensitivity, and some curves of the permeability varying with the stress for the cores were obtained to demonstrate the sensitivity of the formation. Based on the experimental results and the software Eclipse and Abaqus, the main injection parameters to reduce the amount of the injected water in flowing into the interlayer were simulated. Findings The results indicate that the permeability of the mudstone is more sensitive to the stress than sandstone. The injection rate can be as high as possible on the condition that no crack is activated or a new fracture is created in the development. For the B82 block of Daqing oilfield, the suggested pressure of the production pressure should be around 1–3MPa, this pressure must be gradually reached to get a higher efficiency of water injection and avoid damaging the casing. Originality/value This work is beneficial to ensure stable production and provide technical support to the production of low permeability reservoirs containing an interlayer.

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Compatibility evaluation of in-depth profile control agents in dominant channels of low-permeability reservoirs

Cited by 15 publications

References 19 publications

Study on the Profile Control and Oil Displacement Mechanism of a Polymer Nano-microsphere for Oilfield

Study on the Profile Control and Oil Displacement Mechanism of a Polymer Nano-microsphere for Oilfield

Compatibility Evaluation of In-Depth Profile Control Agents for Low-Permeability Fractured Reservoirs

Analysis of the channeling of water injection in low permeability reservoirs with interlayer considering the seepage–stress coupling

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