Numerical Simulation Study of Pressure Transfer Based on the Integration of Fracturing, Shut-in and Production in Tight Reservoirs

Tuan Gu, Le Yan (), Tao Fan, Xiaochao Guo, Feng Fan and Yanjun Zhang
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Tuan Gu: Research Institute of Petroleum Exploration and Development, Liaohe Oilfield Company of Petro, Panjin 124000, China
Le Yan: Natural Gas Research Institute Branch of Shaanxi Yanchang Petroleum (Group) Co., Ltd., Xi’an 710065, China
Tao Fan: Research Institute of Petroleum Exploration and Development, Liaohe Oilfield Company of Petro, Panjin 124000, China
Xiaochao Guo: Research Institute of Petroleum Exploration and Development, Liaohe Oilfield Company of Petro, Panjin 124000, China
Feng Fan: Research Institute of Petroleum Exploration and Development, Liaohe Oilfield Company of Petro, Panjin 124000, China
Yanjun Zhang: College of Petroleum Engineering, Xi’an Shiyou University, Xi’an 710065, China

Sustainability, 2023, vol. 15, issue 16, 1-28

Abstract: As an important replacement resource for conventional oil and gas, tight oil and gas are quite abundant. Long horizontal wells and multi-stage fracturing have become key technologies for developing tight oil and gas, and reasonable shut-in measures can improve the utilization efficiency of fracturing fluid. Therefore, it is especially critical to master the pressure transfer law during the shut-in process in tight reservoirs to further improve the energy efficiency of fracturing fluid. However, many studies have mostly focused on the separate design of fracturing, shut-in and production, and have not yet revealed the pressure transfer law during shutting in well based on the integration of fracturing, shut-in and production, which makes it difficult to realize the efficient development of tight oil and gas. Taking the tight oil reservoir in Block M as an example, the geological model of the target block was established using an integrated fracturing development software platform, on which the simulation of fracture extension, well shut-in and production was carried out. The changes in the reservoir pressure field during shutting in well were analyzed, and the influence law of fracturing fluid volume, shut-in time, reservoir original formation pressure and fracture network complexity on the effect of well shut-in were studied to optimize the shut-in system. It was found that the retained fluid increases, the pore pressure of the near-fracture matrix increases, and the diffusion distance of fracturing fluid to the distant matrix increases. The tight oil production increased after shutting in well, and the optimal retained fluid volume of 9600 m 3 was actually preferred based on the model. The pore pressure of the near-fracture matrix decreases as the shut-in time increases, the diffusion distance of fracturing fluid to the distant matrix increases, and the pore pressure decreases with an increase in diffusion distance. The tight oil production increased after shutting in well, and the optimal shut-in time was actually preferred to be 90 days based on the model. The increase in formation pressure on abnormal low pressure formation is larger, and the production can be significantly improved after shutting in well. The more complex the fracture network is, the more obvious the non-uniform variation in matrix pore pressure during shutting in well. The research is of great significance for the optimal design of a shut-in system for tight reservoirs and the sustainable development of oil and gas resources in China.

Keywords: integration of fracturing; shut-in and production; tight reservoirs; sustainable development of resources; well shut-in after fracturing; pressure transfer; numerical simulation (search for similar items in EconPapers)
JEL-codes: O13 Q Q0 Q2 Q3 Q5 Q56 (search for similar items in EconPapers)
Date: 2023
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