Optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model
Abstract Repeated hydraulic fracturing is essential for sustaining production in tight oil reservoirs due to rapid post-stimulation decline rates, yet optimizing its timing remains challenging. This study develops a two-phase (oil-water) flow model using finite difference methods to simulate fractur...
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Nature Portfolio
2025-07-01
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| Series: | Scientific Reports |
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| Online Access: | https://doi.org/10.1038/s41598-025-06341-x |
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| author | Qingan Zhou Rong Dai Liang Chen Chennan Wu Shunshe Luo |
| author_facet | Qingan Zhou Rong Dai Liang Chen Chennan Wu Shunshe Luo |
| author_sort | Qingan Zhou |
| collection | DOAJ |
| description | Abstract Repeated hydraulic fracturing is essential for sustaining production in tight oil reservoirs due to rapid post-stimulation decline rates, yet optimizing its timing remains challenging. This study develops a two-phase (oil-water) flow model using finite difference methods to simulate fracture-porous media. The governing equations are solved with the IMPES approach to predict flow and production. Validated with Well X data, the model closely matches actual trends (3.1% deviation in reservoir pressure). Comparing initial and repeated fracturing geometries reveals key production mechanisms: high-permeability fractures increase from 14 to 21 (33% density rise), boosting oil output but accelerating pressure depletion and shortening steady flow periods. Early re-fracturing maximizes cumulative output: simulations show re-stimulation at four years extends production by 18% versus delayed interventions. Gradual pressure decline requires proactive planning to avoid productivity loss. Field validation confirms the model’s accuracy, with repeated fracturing boosting oil production by 26% over five years. Results highlight the need to balance fracture-network expansion with pressure maintenance. The proposed two-phase flow model offers a transferable methodology for optimizing re-stimulation schedules based on reservoir dynamics. This work enhances recovery strategies in heterogeneous tight oil systems by linking fracture evolution and flow behavior. |
| format | Article |
| id | doaj-art-2b218b838cf34ba99c2a7f22da80b6f0 |
| institution | Kabale University |
| issn | 2045-2322 |
| language | English |
| publishDate | 2025-07-01 |
| publisher | Nature Portfolio |
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| series | Scientific Reports |
| spelling | doaj-art-2b218b838cf34ba99c2a7f22da80b6f02025-08-20T04:01:36ZengNature PortfolioScientific Reports2045-23222025-07-0115111710.1038/s41598-025-06341-xOptimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow modelQingan Zhou0Rong Dai1Liang Chen2Chennan Wu3Shunshe Luo4School of Geosciences, Yangtze UniversitySchool of Physics and Optoelectronic Engineering, Yangtze UniversityThe 7th Oil Production Plant of PetroChina Changqing Oilfield CompanyChangqing Engineering Design Co., LtdCooperative lnnovation Center of Unconventional Oil and Gas (Yangtze University)Abstract Repeated hydraulic fracturing is essential for sustaining production in tight oil reservoirs due to rapid post-stimulation decline rates, yet optimizing its timing remains challenging. This study develops a two-phase (oil-water) flow model using finite difference methods to simulate fracture-porous media. The governing equations are solved with the IMPES approach to predict flow and production. Validated with Well X data, the model closely matches actual trends (3.1% deviation in reservoir pressure). Comparing initial and repeated fracturing geometries reveals key production mechanisms: high-permeability fractures increase from 14 to 21 (33% density rise), boosting oil output but accelerating pressure depletion and shortening steady flow periods. Early re-fracturing maximizes cumulative output: simulations show re-stimulation at four years extends production by 18% versus delayed interventions. Gradual pressure decline requires proactive planning to avoid productivity loss. Field validation confirms the model’s accuracy, with repeated fracturing boosting oil production by 26% over five years. Results highlight the need to balance fracture-network expansion with pressure maintenance. The proposed two-phase flow model offers a transferable methodology for optimizing re-stimulation schedules based on reservoir dynamics. This work enhances recovery strategies in heterogeneous tight oil systems by linking fracture evolution and flow behavior.https://doi.org/10.1038/s41598-025-06341-xTight oil reservoirHorizontalRe-fracturingOil-water two-phase flowFinite differenceFracturing timing |
| spellingShingle | Qingan Zhou Rong Dai Liang Chen Chennan Wu Shunshe Luo Optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model Scientific Reports Tight oil reservoir Horizontal Re-fracturing Oil-water two-phase flow Finite difference Fracturing timing |
| title | Optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model |
| title_full | Optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model |
| title_fullStr | Optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model |
| title_full_unstemmed | Optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model |
| title_short | Optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model |
| title_sort | optimization of refracturing timing in tight oil reservoirs based on an oil water two phase flow model |
| topic | Tight oil reservoir Horizontal Re-fracturing Oil-water two-phase flow Finite difference Fracturing timing |
| url | https://doi.org/10.1038/s41598-025-06341-x |
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