Injection-induced fracture reactivation during hydraulic fracturing processes in shale gas development as well as coal bed methane(CBM)and other unconventional oil and gas recovery is widely investigated because of po...Injection-induced fracture reactivation during hydraulic fracturing processes in shale gas development as well as coal bed methane(CBM)and other unconventional oil and gas recovery is widely investigated because of potential permeability enhancement impacts.Less attention is paid to induced fracture reactivation during oil and gas production and its impacts on reservoir permeability,despite its relatively common occurrence.During production,a reservoir tends to shrink as effective stresses increase,and the deviatoric effective stresses also increase.These changes in the principal effective stresses may cause Coulomb fracture slip in existing natural fractures,depending on their strength,orientation,and initial stress conditions.In this work,an extended finite element model with contact constraints is used to investigate different fracture slip scenarios induced by general reservoir pressure depletion.The numerical experiments assess the effect of Young’s modulus,the crack orientation,and the frictional coefficient of the crack surface on the distribution of stress and displacement after some reservoir depletion.Results show that the crack orientation significantly affects the state of stress and displacement,particularly in the vicinity of the crack.Slip can only occur in permitted directions,as determined by the magnitudes of the principal stresses and the frictional coefficient.Lastly,a larger frictional coefficient(i.e.,a rougher natural fracture surface)makes the crack less prone to shear slip.展开更多
In the current research,a new approach constructed based on artificial intelligence concept is introduced to determine water/oil relative permeability at various conditions.To attain an effective tool,various artifici...In the current research,a new approach constructed based on artificial intelligence concept is introduced to determine water/oil relative permeability at various conditions.To attain an effective tool,various artificial intelligence approaches such as artificial neural network(ANN),hybrid of genetic algorithm and particle swarm optimization(HGAPSO)are examined.Intrinsic potential of feed-forward artificial neural network(ANN)optimized by different optimization algorithms are composed to estimate water/oil relative permeability.The optimization methods such as genetic algorithm,particle swarm optimization and hybrid approach of them are implemented to obtain optimal connection weights involved in the developed smart technique.The constructed intelligent models are evaluated by utilizing extensive experimental data reported in open literature.Results obtained from the proposed intelligent tools were compared with the corresponding experimental relative permeability data.The average absolute deviation between the model predictions and the relevant experimental data was found to be less than 0.1%for hybrid genetic algorithm and particle swarm optimization technique.It is expected that implication of HGAPSO-ANN in relative permeability of water/oil estimation leads to more reliable water/oil relative permeability predictions,resulting in design of more comprehensive simulation and further plans for reservoir production and management.展开更多
During fluid injection into a multilayered reservoir,a different pressure gradient is generated across the face of each permeable layer.This pressure gradient generates driving forces in the wellbore during well shut-...During fluid injection into a multilayered reservoir,a different pressure gradient is generated across the face of each permeable layer.This pressure gradient generates driving forces in the wellbore during well shut-in that causes the injected fluid moves from higher pressure layers to lower pressure layers,a phenomenon known as interwell cross-flow.Cross-flow behavior depends on the initial pressure in the permeable layers and may be referred to as natural cross-flow(identical or natural initial pressures)and forced cross-flow(different initial pressures because of exploitation).Cross-flow may induce sand production and liquefaction in the higher pressure layers as well as formation damage,filter cake build-up and permeability reduction in the lower pressure layers.Thus,understanding cross-flow during well shut-in is important from a production and reservoir engineering perspective,particularly in unconsolidated or poorly consolidated sandstone reservoirs.Natural and forced cross-flow is modeled for some injection wells in an oil reservoir located at North Sea.The solution uses a transient implicit finite difference approach for multiple sand layers with different permeabilities separated by impermeable shale layers.Natural and forced cross-flow rates for each reservoir layer during shut-in are calculated and compared with different production logging tool(PLT)measurements.It appears that forced cross-flow is usually more prolonged and subject to a higher flow rate when compared with natural cross-flow,and is thus worthy of more detailed analysis.展开更多
文摘Injection-induced fracture reactivation during hydraulic fracturing processes in shale gas development as well as coal bed methane(CBM)and other unconventional oil and gas recovery is widely investigated because of potential permeability enhancement impacts.Less attention is paid to induced fracture reactivation during oil and gas production and its impacts on reservoir permeability,despite its relatively common occurrence.During production,a reservoir tends to shrink as effective stresses increase,and the deviatoric effective stresses also increase.These changes in the principal effective stresses may cause Coulomb fracture slip in existing natural fractures,depending on their strength,orientation,and initial stress conditions.In this work,an extended finite element model with contact constraints is used to investigate different fracture slip scenarios induced by general reservoir pressure depletion.The numerical experiments assess the effect of Young’s modulus,the crack orientation,and the frictional coefficient of the crack surface on the distribution of stress and displacement after some reservoir depletion.Results show that the crack orientation significantly affects the state of stress and displacement,particularly in the vicinity of the crack.Slip can only occur in permitted directions,as determined by the magnitudes of the principal stresses and the frictional coefficient.Lastly,a larger frictional coefficient(i.e.,a rougher natural fracture surface)makes the crack less prone to shear slip.
文摘In the current research,a new approach constructed based on artificial intelligence concept is introduced to determine water/oil relative permeability at various conditions.To attain an effective tool,various artificial intelligence approaches such as artificial neural network(ANN),hybrid of genetic algorithm and particle swarm optimization(HGAPSO)are examined.Intrinsic potential of feed-forward artificial neural network(ANN)optimized by different optimization algorithms are composed to estimate water/oil relative permeability.The optimization methods such as genetic algorithm,particle swarm optimization and hybrid approach of them are implemented to obtain optimal connection weights involved in the developed smart technique.The constructed intelligent models are evaluated by utilizing extensive experimental data reported in open literature.Results obtained from the proposed intelligent tools were compared with the corresponding experimental relative permeability data.The average absolute deviation between the model predictions and the relevant experimental data was found to be less than 0.1%for hybrid genetic algorithm and particle swarm optimization technique.It is expected that implication of HGAPSO-ANN in relative permeability of water/oil estimation leads to more reliable water/oil relative permeability predictions,resulting in design of more comprehensive simulation and further plans for reservoir production and management.
文摘During fluid injection into a multilayered reservoir,a different pressure gradient is generated across the face of each permeable layer.This pressure gradient generates driving forces in the wellbore during well shut-in that causes the injected fluid moves from higher pressure layers to lower pressure layers,a phenomenon known as interwell cross-flow.Cross-flow behavior depends on the initial pressure in the permeable layers and may be referred to as natural cross-flow(identical or natural initial pressures)and forced cross-flow(different initial pressures because of exploitation).Cross-flow may induce sand production and liquefaction in the higher pressure layers as well as formation damage,filter cake build-up and permeability reduction in the lower pressure layers.Thus,understanding cross-flow during well shut-in is important from a production and reservoir engineering perspective,particularly in unconsolidated or poorly consolidated sandstone reservoirs.Natural and forced cross-flow is modeled for some injection wells in an oil reservoir located at North Sea.The solution uses a transient implicit finite difference approach for multiple sand layers with different permeabilities separated by impermeable shale layers.Natural and forced cross-flow rates for each reservoir layer during shut-in are calculated and compared with different production logging tool(PLT)measurements.It appears that forced cross-flow is usually more prolonged and subject to a higher flow rate when compared with natural cross-flow,and is thus worthy of more detailed analysis.