Stress evolution and fracture propagation of infill well after production and injection of parent well in a tight oil reservoir

Shi, Shengbao; Shi, Chong; Tang, Gang; Lin, Bor-Luh; Yu, Hui; Wei, Shiming; Wang, Zejia

doi:10.1007/s13202-022-01605-y

Cited by 3 publications

(1 citation statement)

References 34 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Some scholars carry out regression fitting based on limited experimental test data. Shi et al 23 deduced fracture conductivity based on the Kozeny formula and the theory of elasticity considering the influence of proppant strength, particle size, sand concentration, closing pressure, proppant embedding, crushing, and proppant and fracture wall deformation. Kainer et al 24 employed multiple linear regression to generate empirical correlations based on experimental data for different shale types.…”

Section: Introductionmentioning

confidence: 99%

Fracture Conductivity Prediction Based on Machine Learning

Wang,

Zhang,

et al. 2024

ACS Omega

View full text Add to dashboard Cite

Hydraulic fracturing technology is the main method to develop low-permeability reservoirs. Fracture conductivity is not only the basis of fracture optimization design but also one of the key parameters to determine the effect of hydraulic fracturing. However, current methods of calculating fracture conductivity require a lot of time and labor cost. This research proposes a fracture conductivity prediction model based on machine learning. The main controlling factors of fracture conductivity are determined using the Pearson coefficient method and gray correlation analysis. Example application shows that the R 2 values of the BP neural network model based on a genetic algorithm for predicting the fracture conductivity of block A and block B are 0.981 and 0.975, respectively, indicating that the machine learning model can accurately predict fracture conductivity.

show abstract

Section: Introductionmentioning

confidence: 99%

Fracture Conductivity Prediction Based on Machine Learning

Wang,

Zhang,

et al. 2024

ACS Omega

View full text Add to dashboard Cite

show abstract

Improving reservoir permeability by electric pulse controllable shock wave

Zhu

Feng

Cheng

2023

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

Controllable shock wave (CWS) parameters such as amplitude, operating area and number of operations are easy to control and have received extensive attention as a potential new technology for reservoir permeability enhancement. Based on the continuous-discontinuous element method (CDEM) and considering the coupling mechanism of reservoir deformation, failure, pore seepage and fracture flow, a multiphysical field coupling model of reservoir permeability enhancement under CWS is proposed. Under the fluid–solid coupling condition, the formation and development dynamic process of reservoir fractures are obtained, and the change of reservoir permeability is also obtained. The compression fracture zone, tensile fracture zone and undamaged zone are formed around the wellbore. After repeated impact, the number of fractures is more sensitive to tectonic stress, the fracture aperture is more sensitive to reservoir strength. Different from hydraulic fracturing, a large number of fractures in different directions will appear around the main fracture after repeated impact, forming a complex fracture network similar to spider web, which may be beneficial to improve reservoir permeability. The permeability of reservoirs with different tectonic stresses and strengths increases nonlinearly and monotonicly with repeated impacts. Based on CDEM, the change of reservoir permeability with tectonic stress, strength and impact times is obtained, which is a nonlinear monotonic three-dimensional relationship. Based on that relationship, the parameters of CWS can be controlled to predict the change of reservoir permeability, such as peak pressure, duration, impact times, etc. Therefore, it can optimize the reservoir fracturing scheme and improve the reservoir fracturing efficiency, which has considerable practical significance in engineering.

show abstract

Application of a Fully Coupled Fracture-Reservoir-Wellbore Model in Shale Gas Development: Perspectives on Inter-Well Fracture Interference

Yu,

Wang,

Zheng

et al. 2023

Day 2 Wed, November 15, 2023

View full text Add to dashboard Cite

In the unconventional oil and gas domain, shale gas development adheres to the technical concept of "tight well spacing and infill well." Infill wells, along with large-scale hydraulic fracturing, have become effective strategies for increasing shale gas production. Nevertheless, during hydraulic fracturing operations in the horizontal wells, there is often a risk of frac hits due to geological and engineering factors, which has a significant adverse impact on on-site operations, resulting in lower individual well production and posing challenges to the efficient development of shale gas. Managing frac hits is critical for the industry's growth rate in future. Therefore, based on the current state of hydraulic fracturing in the southern Sichuan shale gas, this study aims to clarify the mechanisms of frac hits and the influencing factors, and to propose effective methods for preventing frac hits, thereby improving the performance of gas wells. In this article, we employed a fully coupled reservoir-fracture-wellbore geomechanical simulation method originated from Zheng (2019a), combined with the establishment of shale gas diffusion properties, to establish a frac hits model. A detailed analysis of the mechanisms and influencing factors of frac hits between shale gas wells under different interference patterns were conducted, and the effectiveness of mitigation methods for each pattern was validated. The results indicate that in reservoirs with developed natural fractures, the fractures in stimulated wells tend to propagate easily along these natural fractures, affecting offset wells. To some extent, this impact can be mitigated by avoiding fracturing in the risky stages. Similarly, the depletion of offset wells leads to a rapid decrease in rock pressure around the fracture tip. Due to the influence of pore elastic effects, rocks undergo elastic deformation, resulting in low-stress zones. The fractures in stimulated wells are affected by this phenomenon and tend to propagate towards offset wells, causing frac hits. The application of pre-pressurization in offset wells can lower the occurrence rate of frac hits. The simulation of inter-well interference between offset wells and stimulated wells provides a theoretical foundation for understanding the frac-hit phenomenon in the southern Sichuan shale gas. This method can be used to predict or mitigate the risk and damage associated with frac hits.

show abstract

Stress evolution and fracture propagation of infill well after production and injection of parent well in a tight oil reservoir

Cited by 3 publications

References 34 publications

Fracture Conductivity Prediction Based on Machine Learning

Fracture Conductivity Prediction Based on Machine Learning

Improving reservoir permeability by electric pulse controllable shock wave

Application of a Fully Coupled Fracture-Reservoir-Wellbore Model in Shale Gas Development: Perspectives on Inter-Well Fracture Interference

Contact Info

Product

Resources

About