Hydraulic Fracture Propagation Modeling for Well Performance Analysis: Eagle Ford Formation Case Study

Eker, Erdinc; Uzun, Ilkay; Kazemi, Hossein; Rutledge, J. M.

doi:10.2118/186087-ms

Cited by 3 publications

References 16 publications

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Assessment of Rate Transient Analysis Techniques for Multiphase Flow in Unconventional Reservoirs: Application to Eagle Ford Formation

Uzun

Eker

Cho

et al. 2017

SPE Western Regional Meeting

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In reservoir evaluation of unconventional reservoirs, engineers use rate transient analysis (RTA) to assess the performance of hydraulically fractured horizontal wells. This technique consists of plotting rate- normalized pressure drop at the well sandface versus square root of time (i.e., linear flow) to calculate the reservoir effective permeability. In this paper, we report on the use of an in-house multiphase numerical simulator applied to production data from several Eagle Ford wells to assess both single- and multi-phase production performance. Furthermore, a combination of numerical simulation and analytical solution techniques was used to validate the information obtained from the RTA in the Eagle Ford wells. This procedure further improved our insight into the flow behavior of unconventional reservoirs. The multi-phase effective permeability calculated from the RTA was within a few percent of the input data to the numerical model. Furthermore, the multi-phase RTA results produce more accurate than the conventional single-phase RTA approach; and the multi-phase analysis results were more in line with the well performance observations than with when using the single-phase analysis approach. Furthermore, the multiphase results were more consistent with the success or failure of the hydraulic fracturing process.

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Assessment of Rate Transient Analysis Techniques for Multiphase Flow in Unconventional Reservoirs: Application to Eagle Ford Formation

Uzun

Eker

Cho

et al. 2017

SPE Western Regional Meeting

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Phase Behavior Change Due to Rock Deformation in Shale Reservoirs: A Compositional Modeling Approach

Uzun

Eker

Kazemi

et al. 2017

Day 3 Wed, October 11, 2017

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Pore diameters for shale reservoirs are on the order of few nanometers which become even smaller during production because of rock deformation. This dynamic interaction between pore fluid pressure and rock stress affects the phase behavior in unconventional reservoirs. In this paper, a new mathematical formulation of fully-coupled geomechanics and compositional dual-porosity model was used to determine the impact of rock deformation and confinement on the nanopore fluids as well as their effect on the production performance of Eagle Ford formation. The formulation presented was derived from our multiphase poroelasticity model which was an extension to the single-phase, single-porosity Biot's linear poroelasticity theory allowing to characterize the rock deformation and pore diameter reduction using the bulk modulus of the matrix-fracture system. Changes in reservoir pore pressure and rock deformation that cause the pore diameter to reduce increases the capillary pressure in the pores which affects the bubble-point pressure suppression and significant shift in the phase envelope, favoring longer period of single-phase production. It was observed that not taking rock deformation into account will lead to over estimation of production, whereas ignoring the effect of pore confinement would underestimate the production forecast. In an example field study based on Eagle Ford reservoir, an increase of around eight percent in cumulative oil production was achieved when the effect of rock deformation and confinement was included in the compositional model compared to the case where only the rock deformation was included. On the other hand, if only pore confinement effect was included in the simulation runs, four percent of increase was achieved.

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Induced Casing Deformation in Hydraulically Fractured Shale Gas Wells: Risk Assessment, Early Warning, and Mitigation

Zhou,

Duan,

Sang

et al. 2024

Processes

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In recent years, casing deformation has become a key factor affecting the scale and efficiency of shale gas development. Consequently, a fast and efficient integrated prevention, control, and treatment technology for casing deformation is of great significance in terms of both theory and application. This paper combines a geological mechanics analysis and multi-cluster fracture propagation to investigate the risk evaluation, early warning and identification, and warning and identification technology relating to casing deformation and its application. It proposes a method for the dynamic and static evaluation of casing deformation risk levels and types, and establishes an index system incorporating stress, fracture, time, and space factors. This four-factor evaluation method is in greater alignment with field conditions. It also proposes a method for the early warning and identification of casing deformation based on fracture monitoring and an operation curve, and clarifies the dominant engineering factors around casing deformation. According to the findings, the total fluid volume per stage has a greater impact on casing deformation than a high pump rate. The prevention and control of casing deformation should preferably be realized by optimizing the fracturing parameters. Moreover, the paper reviews existing technologies for treating casing deformation, several of which are defined as major technologies: small-diameter bridge plug staged fracturing and small-size gun perforation, and long-stage multi-cluster asynchronous fracture initiation and composite temporary plugging and diversion. The study results provide support for a significant reduction in the casing deformation rate during fracturing, improving the effective stimulation degree in the casing deformation section in shale gas wells in the southern Sichuan Basin. These results could serve as references for subsequent research.

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Hydraulic Fracture Propagation Modeling for Well Performance Analysis: Eagle Ford Formation Case Study

Cited by 3 publications

References 16 publications

Assessment of Rate Transient Analysis Techniques for Multiphase Flow in Unconventional Reservoirs: Application to Eagle Ford Formation

Assessment of Rate Transient Analysis Techniques for Multiphase Flow in Unconventional Reservoirs: Application to Eagle Ford Formation

Phase Behavior Change Due to Rock Deformation in Shale Reservoirs: A Compositional Modeling Approach

Induced Casing Deformation in Hydraulically Fractured Shale Gas Wells: Risk Assessment, Early Warning, and Mitigation

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