Fast-running model for high-volume hydraulic fracturing

Peshcherenko, Aleksandra; Bekerov, Ilmir; Chuprakov, Dimitry; Abdrazakov, Dmitriy

doi:10.1016/j.petrol.2022.110430

Cited by 5 publications

(3 citation statements)

References 24 publications

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“…Simulation results showed that the optimal fracture placement is a spindle-like placement, which has a much higher NPV than the uniform fracture placement. Aleksandra Peshcherenko et al [23] built a hydraulic fracture development model to determine the best characteristics for fracture placement. Omar Al-Fatlawi et al [24] established an equivalent simplified homogeneous reservoir simulation model to optimize the number and half-length of the fractures with net present value (NPV) as the objective function.…”

Section: Introductionmentioning

confidence: 99%

A New Fracturing Method to Improve Stimulation Effect of Marl Tight Oil Reservoir in Sichuan Basin

Wang,

Fan,

et al. 2023

Processes

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China’s argillaceous limestone reservoir has a lot of oil and gas resources, and hydraulic fracturing of the argillaceous limestone reservoir faces many difficulties. The first problem is that the heterogeneity of the argillaceous limestone reservoir is strong, and it is difficult to optimize fracturing parameters. The second problem is that there are a lot of natural fractures in the argillaceous limestone reservoir, which leads to a lot of fracturing fluid loss. The third problem is that the closure pressure of the argillaceous limestone reservoir is high, and the conductivity of fractures decreases rapidly under high closure pressure. The last problem is that the fracture shape of the argillaceous limestone reservoir is complex, and the law of proppant migration is unclear. The main research methods in this paper include reservoir numerical simulation, fluid-loss-reducer performance evaluation, flow conductivity tests and proppant migration visualization. To solve the above problems, this paper establishes the fracturing productivity prediction model of complex lithology reservoirs and defines the optimal hydraulic fracturing parameters of the argillous limestone reservoir in the Sichuan Basin. The 70/140 mesh ceramide was selected as the fluid loss additive after an evaluation of the sealing properties of different mesh ceramides. At the same time, the hydraulic fracture conductivity test is carried out in this paper, and it is confirmed that the fracture conductivity of 70/140 mesh and 40/70 mesh composite particle-size ceramics mixed according to the mass ratio of 5:5 is the highest. When the closure pressure is 40 MPa, the conductivity of a mixture of 70/140 mesh ceramic and 40/70 mesh ceramic is 35.6% higher than that of a mixture of 70/140 mesh ceramic and 30/50 mesh ceramic. The proppant migration visualization device is used to evaluate the morphology of the sand dike formed by the ceramsite, and it is clear that the shape of the sand dike is the best when the mass ratio of 70/140 mesh ceramsite and 40/70 mesh ceramsite is 6:4. The research results achieved a good stimulation effect in the SC1 well. The daily oil production of the SC1 well is 20 t, and the monitoring results of the wide-area electromagnetic method show that the fracturing fracture length of the SC1 well is up to 129 m.

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Section: Introductionmentioning

confidence: 99%

A New Fracturing Method to Improve Stimulation Effect of Marl Tight Oil Reservoir in Sichuan Basin

Wang,

Fan,

et al. 2023

Processes

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“…He et al [29] proposed a semianalytical methodology for diagnosing the locations of underperforming hydraulic fractures and found that the total production contribution mainly comes from the fractures at both ends of the horizontal wellbore, so fractures occurred in the form of a spindle shape. Peshcherenko et al [30] built a hydraulic fracture development model for determining the best fracture placement characteristics. Deng et al [31] presented a new automatic integrated optimization algorithm with NPV as the objective function.…”

Section: Introductionmentioning

confidence: 99%

Study on the Optimal Volume Fracturing Design for Horizontal Wells in Tight Oil Reservoirs

et al. 2022

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The application of horizontal well volume fracturing technology is an important method for enhancing oil recovery in tight oil reservoirs. However, the influence mechanism of the fracture placement scheme (FPC) on postfracturing productivity is still unclear. Based on the theory of the black oil model, combined with the reservoir stimulation characteristics of horizontal well volume fracturing in tight oil reservoirs, this paper established a postfracturing reservoir production simulation model. History fitting was used to verify the accuracy of the production model simulations. A series of numerical simulations was carried out to study the influence mechanisms of the fracture parameters and FPC on productivity. The simulation results show that compared with the fracture conductivity, the fracture length and number are the main parameters affecting tight oil reservoir productivity. Selecting a reasonable fracture length and number can realize the economical and efficient production of tight oil reservoir volume fracturing. Compared with the traditional fracture equal-length scheme, an FPC with an uneven fracture length can increase the cumulative oil production of oil wells. Under the condition of the same total fracture length, the scheme with a staggered distribution of long fractures and short fractures has the largest cumulative oil production over five years. A reasonable well spacing can greatly reduce the impact of interwell interference on postfracturing dual branch horizontal well productivity. When dual branch horizontal well fractures are alternately distributed, the postfracturing productivity is higher. The production simulation model established in this paper provides a method to accurately evaluate the productivity of horizontal wells after volume fracturing, which can provide guidance for the optimization of hydraulic fracturing operation parameters.

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“…Fractured rocks are ubiquitous in the environment, and they play a major role in a wide range of geoscience issues, such as groundwater flow and contaminant transport (e.g., Medici et al., 2019; Neuman, 2005), hydraulic fracturing (e.g., Osiptsov, 2017; Peshcherenko et al., 2022), storage of CO 2 and nuclear waste (e.g., Bodvarsson et al., 1999; Ren et al., 2017; Wang & Hudson, 2015) and geothermal production (e.g., Murphy et al., 1981; Patterson et al., 2020). Geophysical methods offer a variety of tools to obtain information on subsurface structure and physical properties of fractured rocks.…”

Section: Introductionmentioning

confidence: 99%

A unified model for the permeability, electrical conductivity and streaming potential coupling coefficient in variably saturated fractured media

Thanh

Nghĩa

van

et al. 2022

Geophysical Prospecting

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We present a new unified model for the permeability, electrical conductivity, and streaming potential coupling coefficient in variably saturated fractured media. For those, we conceptualize the fractured medium as a partially saturated bundle of parallel capillary slits with varying sizes. We assume that the fracture size distribution of the corresponding medium follows a fractal scaling law, which allows us establish a pressure head-saturation relationship based on the Laplace equation. We first describe the flow rate, the conduction current, and the electrokinetic streaming current within a single fracture. Then, we upscale these properties at the scale of an equivalent fractured media partially saturated in order to obtain the relative permeability, the electrical conductivity and the streaming potential coupling coefficient. The newly proposed model explicitly depends on pore water chemistry, interface properties, microstructural parameters of fractured media, and water saturation. Model predictions are in good agreement with both experimental and simulated data and with another model from the literature. The results of this work constitute a useful framework to estimate hydraulic properties and monitor water flow in fractured media.

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Fast-running model for high-volume hydraulic fracturing

Cited by 5 publications

References 24 publications

A New Fracturing Method to Improve Stimulation Effect of Marl Tight Oil Reservoir in Sichuan Basin

A New Fracturing Method to Improve Stimulation Effect of Marl Tight Oil Reservoir in Sichuan Basin

Study on the Optimal Volume Fracturing Design for Horizontal Wells in Tight Oil Reservoirs

A unified model for the permeability, electrical conductivity and streaming potential coupling coefficient in variably saturated fractured media

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