Experimental study on spontaneous imbibition of recycled fracturing flow-back fluid to enhance oil recovery in low permeability sandstone reservoirs

You, Qing; Wang, Huan; Zhang, Yan; Liu, Yifei; You, Qing; Dai, Caili

doi:10.1016/j.petrol.2018.03.058

Cited by 163 publications

(72 citation statements)

References 25 publications

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“…The results (Figure 12) show the effect of conformance control. The oil recovery increased significantly by decreasing the water cut [51,52]. The conformance control increased the oil recovery by 29.4% based on the water flooding recovery of 32.2%.…”

Section: Eor Performancementioning

confidence: 96%

Study on a Novel Gelled Foam for Conformance Control in High Temperature and High Salinity Reservoirs

You

Jiao

et al. 2018

Energies

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A novel gelled foam for conformance control was investigated for its ability to enhance oil recovery (EOR) in high temperature and high salinity reservoirs. The formulation optimization, foaming performance, and core flooding performance of the gelled foam were systematically evaluated under harsh reservoir conditions. The gelled foam formulation was optimized with 0.4% polymer (hydrolyzed polyacrylamide; HPAM), 0.06% cross-linker (phenolic) and 0.2% foaming agent (sulphobetaine; SB). The addition of the gel improved the stability of the foam system by 3.8 times that of traditional foam. A stabilization mechanism in the gelled foam was proposed to describe the stabilization process of the foam film. The uniformly distributed three-dimensional network structure of the gel provided a thick protective layer for the foam system that maintained the stability of the foam and improved the strength and thickness of the liquid film. The gelled foam exhibited good formation adaptability, profile control, and EOR performance. The foam flowed into the high permeability layer, plugged the dominant channel, and increased the swept volume. Oil recovery was enhanced by 29.4% under harsh high -temperature and high salinity conditions.

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Section: Eor Performancementioning

confidence: 96%

Study on a Novel Gelled Foam for Conformance Control in High Temperature and High Salinity Reservoirs

You

Jiao

et al. 2018

Energies

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“…The recovery of unconventional reservoirs, including shale gas, coalbed methane, and so on, has drawn great attention in oil and gas industry 1‐5 . Hydraulic fracturing technology has been proven to be an effective technique to improve the recovery efficiency of unconventional reservoirs 6‐9 .…”

Section: Introductionmentioning

confidence: 99%

Viscoelastic surfactant fluids filtration in porous media: A pore‐scale study

Dai

et al. 2020

AIChE Journal

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We investigated the flow of viscoelastic surfactant (VES) solutions, an important type of fracturing fluids for unconventional hydrocarbon recovery, through a divergingconverging microfluidic channel that mimics realistic unit in porous media. Newtonian fluid and viscoelastic hydrolyzed polyacrylamide (HPAM) solution were used as control groups. We vary Deborah numbers (De) up to 61.2, and found that the flow patterns of HPAM and VES solutions become very different once De ≥ 6.12. This is attributed to different generation mechanisms of viscoelasticity, thus different responses to extensional rates at pore-throats, for HPAM and VES solutions. It results in significantly smaller pressure drop of VES solutions through the microchannel compared to HPAM solution. It interprets higher filtration loss of VES solution than HPAM in core experiments and in field observations. The set-up can be generalized as a prototype to effectively evaluate the filtration of fracturing fluids.

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“…It is certain that a large percentage of oil remains unrecovered in unswept zones after water flooding. It is estimated that only about 23%-35% of remaining oil is confined in water flooding zones and about 65%-77% of remaining oil is left in unswept zones [1][2][3]. Thus, it is crucial to sweep remaining oil from unswept zones to enhance oil recovery in heterogeneous reservoirs after water flooding.…”

Section: Introductionmentioning

confidence: 99%

“…The traditionally in situ polymer gel that is composed of polymer and cross linker was injected into the formation to form gel at reservoir condition. The disadvantages of in situ polymer gel are as follows [23][24][25]: (1) The effects of adsorption, dilution, and shear degradation on the cross-linking reaction; (2) it is hard to control the gelation time and gel strength; (3) possible damages on the low permeability unswept oil zone. To overcome the effect of adsorption, dilution, and shear degradation that usually occur in the in situ polymer gel, recently, the preformed particle gels have been widely studied and applied for conformance control.…”

Section: Introductionmentioning

confidence: 99%

Investigation of Injection Strategy of Branched-Preformed Particle Gel/Polymer/Surfactant for Enhanced Oil Recovery after Polymer Flooding in Heterogeneous Reservoirs

Hou

et al. 2018

Energies

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Abstract:The heterogeneous phase combination flooding (HPCF) system which is composed of a branched-preformed particle gel (B-PPG), polymer, and surfactant has been proposed to enhance oil recovery after polymer flooding in heterogeneous reservoirs by mobility control and reducing oil-water interfacial tension. However, the high cost of chemicals can make this process economically challenging in an era of low oil prices. Thus, in an era of low oil prices, it is becoming even more essential to optimize the heterogeneous phase combination flooding design. In order to optimize the HPCF process, the injection strategy has been designed such that the incremental oil recovery can be maximized using the corresponding combination of the B-PPG, polymer, and surfactant, thereby ensuring a more economically-viable recovery process. Different HPCF injection strategies including simultaneous injection and alternation injection were investigated by conducting parallel sand pack flooding experiments and large-scale plate sand pack flooding experiments. Results show that based on the flow rate ratio, the pressure rising area and the incremental oil recovery, no matter whether the injection strategy is simultaneous injection or alternation injection of HPCF, the HPCF can significantly block high permeability zone, increase the sweep efficiency and oil displacement efficiency, and effectively improve oil recovery. Compared with the simultaneous injection mode, the alternation injection of HPCF can show better sweep efficiency and oil displacement efficiency. Moreover, when the slug of HPCF and polymer/surfactant with the equivalent economical cost is injected by alternation injection mode, as the alternating cycle increases, the incremental oil recovery increases. The remaining oil distribution at different flooding stages investigated by conducting large-scale plate sand pack flooding experiments shows that alternation injection of HPCF can recover more remaining oil in the low permeability zone than simultaneous injection. Hence, these findings could provide the guidance for developing the injection strategy of HPCF to further enhance oil recovery after polymer flooding in heterogeneous reservoirs in the era of low oil prices.

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Experimental study on spontaneous imbibition of recycled fracturing flow-back fluid to enhance oil recovery in low permeability sandstone reservoirs

Cited by 163 publications

References 25 publications

Study on a Novel Gelled Foam for Conformance Control in High Temperature and High Salinity Reservoirs

Study on a Novel Gelled Foam for Conformance Control in High Temperature and High Salinity Reservoirs

Viscoelastic surfactant fluids filtration in porous media: A pore‐scale study

Investigation of Injection Strategy of Branched-Preformed Particle Gel/Polymer/Surfactant for Enhanced Oil Recovery after Polymer Flooding in Heterogeneous Reservoirs

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