Effect of polymer on disproportionate permeability reduction to gas and water for fractured shales

Song, Zhaojie; Liu, Lingbo; Wei, Mingzhen; Bai, Baojun; Hou, Jirui; Li, Zhiping; Hu, Yunpeng

doi:10.1016/j.fuel.2014.11.037

Cited by 58 publications

(43 citation statements)

References 21 publications

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“…It is defined as the permeability reduction of the core caused by the gel treatment, and it equals the ratio of the water permeability of core before the gel treatment to the water permeability of core after the gel treatment at a same brine injection rate. 22 According to eq 2, the water residual resistance factor can be calculated by dividing the stable effective injection pressure …”

Section: Gelant and Gel Preparationmentioning

confidence: 99%

Effects of Fracture and Matrix on Propagation Behavior and Water Shut-off Performance of a Polymer Gel

et al. 2015

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The influence of reservoir parameters on water shut-off treatment in hydraulic or natural fractured reservoirs remains unclear. In the present study, effects of fracture width and matrix permeability on propagation behavior and water shutoff performance of a polymer gel have been investigated. Results show that the fracture width can greatly affect the injection pressure of the gelant, but the effect of the matrix permeability is relatively slight. During the gelant propagation in fracture, because of the concentration and pressure differences, the gelant loses itself from fracture into matrix to form a gelant filter cake on the fracture face. The smaller the fracture width is, the greater the gelant loses; moreover, a higher gelant loss degree occurs in relatively high permeable matrix. After the cross-linking reaction between polymer and chromium, the gelant filter cake becomes into a gel filter cake. The cementing strength of the gel filter cake and the strength of the gel inside fractures greatly affect the shut-off performance of the gel for fractures. Therefore, an appropriate loss degree of the gelant which improves the thickness and the rigidness of the gel filter cake can enhance the water shut-off performance. Moreover, due to that both the narrow fracture and the high permeable matrix contribute to the gelant loss, the polymer gel presents favorable water shut-off performance in cores with a small fracture width or high permeable matrix.

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Section: Gelant and Gel Preparationmentioning

confidence: 99%

Effects of Fracture and Matrix on Propagation Behavior and Water Shut-off Performance of a Polymer Gel

et al. 2015

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“…In Sichuan basin in China, the development of shale gas is in full swing and large amounts of DRA are required in the near future . Considering the great application prospect and economic market, more DRA powder candidates with good DR performance still need to be developed urgently.…”

Section: Introductionmentioning

confidence: 99%

Using water‐miscible nonionic hydrophobic monomer associating HPAM as drag reducing agent

Jing¹,

Liu²,

Li³

et al. 2019

J of Applied Polymer Sci

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A water‐miscible nonionic surfmer (AC‐TX100) was synthesized based on Triton X‐100 and acryloyl chloride. Then, a terpolymer P(AM/AA/AC‐TX100) was synthesized by free radical polymerization in aqueous solution and intended to be used as drag reducing agent (DRA). The DRA was defined to be P(AM87.32/AA12.46/AC‐TX1000.22) according to 1H NMR and elemental analysis, the molecular weight was 2.12 × 106 g/mol according to scattering method. DRA shows excellent performance in drag reduction (DR). The highest DR rate of 76% can be obtained when DRA concentration is 0.023% in fresh water; while in brine containing 3% NaCl, DR rate decreases, and it is necessary to increase the concentration to 0.05% to ensure that DR rate is higher than 70%. SEM and cryo‐TEM show that DRA forms a network structure in aqueous solution, and the tightness of this structure has a direct influence on DR performance. Specifically, DRA molecules stretch into the whirlpools generated by water at high flow rates, reducing the quantity and intensity of whirlpools, thereby lowering the energy loss and the friction. © 2019 Wiley Periodicals, Inc. J. Appl. Polym. Sci. 2019, 136, 48362.

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“…As a matter of fact, after being flowed back, there will be a large amount of PAM remaining in the micro‐fractures in the shale reservoirs which decreases the reservoir permeability. Many works have been designed to reduce reservoir permeability damage before the damage occurs . There is no report that focuses on how to resolve the reservoir damage.…”

Section: Introductionmentioning

confidence: 99%

“…Many works have been designed to reduce reservoir permeability damage before the damage occurs. 29,30 There is no report that focuses on how to resolve the reservoir damage. It is important to establish a method to assess the behavior of PAM in the micro-fractures of shale reservoirs and to obtain a way to eliminate the damage that has occurred.…”

Section: Introductionmentioning

confidence: 99%

Reduced adsorption of polyacrylamide‐based fracturing fluid on shale rock using urea

Yang

Wang

Guo

et al. 2018

Energy Science & Engineering

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Hydraulic fracturing is generally necessary to achieve economically viable production rates during exploitation of shale reservoirs. Polyacrylamide‐based fracturing fluid is commonly used in shale fracturing. Polyacrylamide (PAM) becomes adsorbed in the shale micro‐fractures, decreasing the permeability of the reservoir. For improving the production of shale after being stimulated, the adsorption behavior and adsorption mechanism between the PAM and shale are studied. An ultraviolet spectrophotometer is used to obtain the amount of adsorption. To observe the adsorption morphology, a scanning electron microscope is employed. The action force between the PAM and shale rock is analyzed through Fourier transform infrared spectroscopy, zeta potential instrument, and X‐ray photoelectron spectroscopy. The results indicate that hydrogen bonding is the key force between the PAM and shale. A kind of shale micro‐fractures model is designed to determine the recovery of permeability. Urea breaks the hydrogen bonding and keeps the molecular of HPG stretch which can decrease the amount of adsorption on the shale surface and effectively recover the permeability of shale micro‐fractures up to 72.46% after being damaged. In conclusion, it is believed that the competitive adsorption is a new approach for remediation of the permeability damage by PAM‐based fracturing fluid and has great potential in oil field application.

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Effect of polymer on disproportionate permeability reduction to gas and water for fractured shales

Cited by 58 publications

References 21 publications

Effects of Fracture and Matrix on Propagation Behavior and Water Shut-off Performance of a Polymer Gel

Effects of Fracture and Matrix on Propagation Behavior and Water Shut-off Performance of a Polymer Gel

Using water‐miscible nonionic hydrophobic monomer associating HPAM as drag reducing agent

Reduced adsorption of polyacrylamide‐based fracturing fluid on shale rock using urea

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