Production Data Analysis in Complex Fracture Network Horizontal Wells with SRV Effects

2019 ◽  
Author(s):  
Zhiming Chen ◽  
Xuefeng Tang ◽  
Xinwei Liao ◽  
Junlei Wang ◽  
Xingjiao Zhang ◽  
...  
Keyword(s):  
Data Analysis ◽  
Horizontal Wells ◽  
Fracture Network ◽  
Production Data ◽  
Complex Fracture ◽  
Complex Fracture Network

Production-Decline Models Using Anomalous Diffusion Stemming From a Complex Fracture Network

SPE Journal ◽  
2019 ◽  
Vol 24 (06) ◽  
pp. 2609-2634 ◽  
Author(s):  
Shuai Liu ◽  
Peter P. Valkó
Keyword(s):  
Anomalous Diffusion ◽  
Time Derivative ◽  
Horizontal Wells ◽  
Fracture Network ◽  
Production Data ◽  
Fracture Networks ◽  
Type Curves ◽  
Complex Fracture ◽  
Complex Fracture Network ◽  
Fractional Time Derivative

Summary In this work, we develop a well–based fractional–production–decline model, which resorts to anomalous diffusion to characterize the heterogeneity of complex fracture networks and can be conveniently used to interpret the rate and cumulative data in the early and middle times of production from multifractured horizontal wells in unconventional reservoirs. We first develop a model (the fracture–based model) to be used in inverse problems by simplifying the fractional–time–derivative model using the traditional multiple–planar–fracture framework to essentially contain three parameters (α,Ar, and Ix). After performing tests with elaborate synthetic cases, the trace of anomalous diffusion is captured but the drawbacks of this model are also detected and analyzed. Then, by focusing on improving the fracture–based model, we consider an infinite–conductivity horizontal well draining a complex fracture network through a fractional–flux–related skin. The improved model (the well–based model) is bolstered with the corresponding type curves regarding production rate and cumulative production, which can be applied to interpret the single–phase production in the early and middle times and to mainly characterize the fracture–network–related heterogeneity reflected in the production data during this early–to–middle period. The well–based model is applied to two synthetic cases with explicitly modeled complex fracture networks and to the cases of multifracture horizontal wells in the Permian Basin. The results of all case studies display good matches between our model and the production data, which indicates the model's capability to accurately describe the transient regime of the flow in the extremely heterogeneous fracture networks on the basis of average values of the formation properties.

scholarly journals Study on Deliverability Evaluation of Staged Fractured Horizontal Wells in Tight Oil Reservoirs

Energies ◽  
2021 ◽  
Vol 14 (18) ◽  
pp. 5857
Author(s):  
Siyu Liu ◽  
Shengchun Xiong ◽  
Dingwei Weng ◽  
Peng Song ◽  
Rou Chen ◽  
...  
Keyword(s):  
Network Structure ◽  
Horizontal Wells ◽  
Fracture Network ◽  
Stress Sensitivity ◽  
Oil Reservoirs ◽  
Tight Oil ◽  
Complex Fracture ◽  
Complex Fracture Network ◽  
Tight Oil Reservoirs ◽  
Fractured Horizontal Wells

At present, the existing deliverability evaluation models mainly consider the impact of specific factors on production, and the description of the complex fracture network structure primarily remains at the stage of an ideal dual-pore medium with uniform distribution. However, this cannot reflect the actual fracture network structure and fluid flow law of fractured horizontal wells. Thus, in this paper, a non-uniform fracture network structure is proposed considering the influence of the threshold pressure gradient and stress sensitivity characteristics on the production performance of horizontal wells. The stress sensitivity and the fractal theory are combined to characterize the permeability of the complex fracture network, and a three-zone compound unsteady deliverability model for staged fractured horizontal wells in tight oil reservoirs is successfully developed. Laplace transformation, perturbation theory, and numerical inversion are applied to obtain the semi-analytical solution of the proposed deliverability model. The reliability and accuracy of the analytical solution are verified by the classical tri-linear flow model and an oil field example. The effects of related influential parameters on the production of horizontal wells are analyzed. The deliverability evaluation method proposed in this paper can provide a theoretical basis for formulating rational development technology policies for tight oil reservoirs.

Numerical Simulation of Complex Fracture Network Development by Hydraulic Fracturing in Naturally Fractured Ultratight Formations

2013 ◽  
Author(s):  
Hannes Hofmann ◽  
Tayfun Babadagli ◽  
Günter Zimmermann
Keyword(s):  
Fracture Network ◽  
Natural Fracture ◽  
Fracture Networks ◽  
Network Development ◽  
Complex Fracture ◽  
Fracture Patterns ◽  
Fracture Systems ◽  
Fracture Development ◽  
Complex Fracture Network ◽  
Treatment Designs

The creation of large complex fracture networks by hydraulic fracturing is imperative for enhanced oil recovery from tight sand or shale reservoirs, tight gas extraction, and Hot-Dry-Rock (HDR) geothermal systems to improve the contact area to the rock matrix. Although conventional fracturing treatments may result in bi-wing fractures, there is evidence by microseismic mapping that fracture networks can develop in many unconventional reservoirs, especially when natural fracture systems are present and the differences between the principle stresses are low. However, not much insight is gained about fracture development as well as fluid and proppant transport in naturally fractured tight formations. In order to clarify the relationship between rock and treatment parameters, and resulting fracture properties, numerical simulations were performed using a commercial Discrete Fracture Network (DFN) simulator. A comprehensive sensitivity analysis is presented to identify typical fracture network patterns resulting from massive water fracturing treatments in different geological conditions. It is shown how the treatment parameters influence the fracture development and what type of fracture patterns may result from different treatment designs. The focus of this study is on complex fracture network development in different natural fracture systems. Additionally, the applicability of the DFN simulator for modeling shale gas stimulation and HDR stimulation is critically discussed. The approach stated above gives an insight into the relationships between rock properties (specifically matrix properties and characteristics of natural fracture systems) and the properties of developed fracture networks. Various simulated scenarios show typical conditions under which different complex fracture patterns can develop and prescribe efficient treatment designs to generate these fracture systems. Hydraulic stimulation is essential for the production of oil, gas, or heat from ultratight formations like shales and basement rocks (mainly granite). If natural fracture systems are present, the fracturing process becomes more complex to simulate. Our simulation results reveal valuable information about main parameters influencing fracture network properties, major factors leading to complex fracture network development, and differences between HDR and shale gas/oil shale stimulations.

scholarly journals Performance-based fractal fracture model for complex fracture network simulation

2017 ◽  
Vol 15 (1) ◽  
pp. 126-134 ◽  
Author(s):  
Wen-Dong Wang ◽  
Yu-Liang Su ◽  
Qi Zhang ◽  
Gang Xiang ◽  
Shi-Ming Cui
Keyword(s):  
Network Simulation ◽  
Fracture Network ◽  
Fracture Model ◽  
Complex Fracture ◽  
Complex Fracture Network ◽  
Fractal Fracture

scholarly journals A New Approach for Automatic Optimization of Complex Fracture Network in Shale Reservoirs

Lithosphere ◽  
2021 ◽  
Vol 2021 (Special 1) ◽  
Author(s):  
Haibo Wang ◽  
Tong Zhou ◽  
Fengxia Li
Keyword(s):  
Shale Gas ◽  
Flow Model ◽  
Optimization Method ◽  
Fracture Network ◽  
Gas Reservoirs ◽  
Fracture Length ◽  
Complex Fracture ◽  
Shale Gas Reservoirs ◽  
Automatic Optimization ◽  
Complex Fracture Network

Abstract Shale gas reservoirs have gradually become the main source for oil and gas production. The automatic optimization technology of complex fracture network in fractured horizontal wells is the key technology to realize the efficient development of shale gas reservoirs. In this paper, based on the flow model of shale gas reservoirs, the porosity/permeability of the matrix system and natural fracture system is characterized. The fracture network morphology is finely characterized by the fracture network expansion calculation method, and the flow model was proposed and solved. On this basis, the influence of matrix permeability, matrix porosity, fracture permeability, fracture porosity, and fracture length on the production of shale gas reservoirs is studied. The optimal design of fracture length and fracture location was carried, and the automatic optimization method of complex fracture network parameters based on simultaneous perturbation stochastic approximation (SPSA) was proposed. The method was applied in a shale gas reservoir, and the results showed that the proposed automatic optimization method of the complex fracture network in shale gas reservoirs can automatically optimize the parameters such as fracture location and fracture length and obtain the optimal fracture network distribution matching with geological conditions.

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