Methods for shut-in pressure escalation analysis
Methods for using shut-in pressures to determine uncertainties in a hydraulic fracturing process in a shale reservoir are described. Data commonly collected during multistage fracturing is used to calculate propped fracture height and induced stresses, as well as other variables, in the presence of horizontal stress anisotropy. These variables can then be incorporated into reservoir simulations to improve the fracturing monitoring, forecast hydrocarbon recoveries, or modify fracturing plans.
1. A method for fracturing a reservoir, comprising:
a. obtaining an instantaneous shut-in pressure (ISIP) in a well in a reservoir after each of n stages of a multistage fracturing plan in said well, each of said n stages having a known cluster number per stage (n cluster ) and stage spacing (s cluster ), thereby obtaining ISIP data for each of said n stages;
b. inputting said ISIP data into a spreadsheet software stored in a non-transitory memory of a computer;
c. comparing said ISIP data for each of said n stages with a two-parameter exponential recovery equation against type-curves to estimate hydraulic-fracture height and horizontal-stress anisotropy;
d. inputting each of the following into a reservoir model software: said estimated horizontal-stress anisotropy, said estimated fracture height, n, n cluster and s cluster ;
e. optimizing a reservoir fracturing plan using said reservoir model software to obtain an optimized reservoir fracturing plan;
f. implementing said optimized reservoir fracturing plan to fracture a next stage of said multistage fracturing plan or to fracture another well in said reservoir; and,
g. producing oil from said reservoir.
2. The method of claim 1 , wherein ISIP is a pressure value past an early rapid falloff as determined by extrapolating a slope at an end of a pressure pulse caused by shut-in.
3. The method of claim 1 , wherein fracture length, and fracture area are also estimated in step c) and inputted in step d).
4. The method of claim 1 , wherein said type-curves include load normalized stress plateau type curves, escalation type curves, and interference ratio type curves.
5. The method of claim 1 , wherein said shut-in pressure is measured at the surface, downhole, or both.
6. The method of claim 1 , wherein if a stress load is less than half a net-pressure at shut-in, fracture reorientation is limited, and said method may proceed, but if not, said method is discontinued.
7. The method of claim 1 , wherein said optimized fracturing plan uses one or more modified parameter(s) selected from the group consisting of: cluster number per stage, cluster spacing, stage spacing, fracturing pressure, fracturing fluid type, fracturing fluid volume, fracturing fluid viscosity, proppant type, proppant mass, proppant concentration, pumping rate, pumping schedule or combinations thereof.
8. A method for fracturing a reservoir, comprising:
a. obtaining an instantaneous shut-in pressure (ISIP) in a well in a reservoir after each of n stages of a diagnostic fracture injection test (DFIT), said DFIT comprising injecting a volume of fluid at a low rate through perforations in a cemented casing to create a small-scale hydraulic fracture, thereby obtaining ISIP data for each of said n stages of said DFIT;
b. inputting said ISIP data into a spreadsheet software stored in a non-transitory memory of a computer;
c. comparing said ISIP data for each of said n stages with a two-parameter exponential recovery equation against type-curves to estimate hydraulic-fracture height and horizontal-stress anisotropy;
d. inputting said estimated horizontal-stress anisotropy and said fracture height into a reservoir model software;
e. optimizing a reservoir fracturing plan using said reservoir model software to obtain an optimized reservoir fracturing plan;
f. implementing said optimized reservoir fracturing plan to fracture said well in said reservoir; and,
g. producing oil from said well.
9. The method of claim 8 , wherein ISIP is a pressure value past an early rapid falloff as determined by extrapolating a slope at an end of a pressure pulse caused by shut-in.
10. The method of claim 8 , wherein fracture length and fracture area are also estimated in step c) and inputted in step d).
11. The method of claim 8 , wherein said shut-in pressure is measured at the surface, downhole, or both.
12. The method of claim 8 , wherein if a stress load is less than half a net-pressure at shut-in, fracture reorientation is limited, and said method may proceed, but if not, said method is discontinued.
13. The method of claim 8 , wherein said optimized fracturing plan uses one or more modified parameter(s) selected from the group consisting of: cluster number per stage, cluster spacing, stage spacing, fracturing pressure, fracturing fluid type, fracturing fluid volume, fracturing fluid viscosity, proppant type, proppant mass, proppant concentration, pumping rate, pumping schedule or combinations thereof.
14. A method for fracturing a reservoir, comprising:
a. obtaining an instantaneous shut-in pressure (ISIP) in a well in a reservoir for n stages of a multistage fracturing process, each stage having a known cluster number per stage and a known stage spacing, thereby obtaining ISIP data for each of said n stages, and calculating a net pressure at shut-in;
b. inputting said ISIP data for each of said n stages into a spreadsheet software stored in a non-transitory memory of a computer;
c. matching the ISIP data for each of said n stages by varying an estimated stress plateau parameter and an estimated escalation number using a least squares regression method in said spreadsheet software;
d. extrapolating a stress interference (I) using one or more type-curves for said cluster number per stage and said estimated escalation number and said estimated stress plateau parameter;
e. calculating a stress load;
f. determining if a stress plateau is caused by overcoming an in-situ horizontal stress anisotropy by comparing said calculated stress load with said net pressure at shut-in, wherein said stress plateau is considered to be naturally occurring if the stress plateau is less than or equal to half of said net pressure at shut-in, wherein said stress plateau is considered to be caused by overcoming horizontal stress anisotropy if the stress plateau is more than the net pressure at shut-in, and wherein if said stress plateau is naturally occurring, a fracture height is calculated;
g. inputting said horizontal-stress anisotropy and said fracture height into a reservoir model software;
h. optimizing a reservoir fracturing plan using said reservoir model software; and,
i. implementing said optimized reservoir fracturing plan to fracture said reservoir and, fracturing a next stage of said well or another well in said reservoir.
15. The method of claim 14 , wherein ISIP is a pressure value past an early rapid falloff as determined by extrapolating a slope at an end of a pressure pulse caused by shut-in.
16. The method of claim 14 , wherein fracture length, and fracture area are also estimated in step c) and inputted in step g).
17. The method of claim 14 , wherein said type-curves include load normalized stress plateau type curves, escalation type curves, and interference ratio type curves.
18. The method of claim 14 , wherein said shut-in pressure is measured at the surface, downhole, or both.
19. The method of claim 14 , wherein if a stress load is less than half said net-pressure at shut-in, fracture reorientation is limited, and said method may proceed, but if not, said method is discontinued.
20. The method of claim 14 , wherein said optimized fracturing plan uses one or more modified parameter(s) selected from the group consisting of: cluster number per stage, cluster spacing, stage spacing, fracturing pressure, fracturing fluid type, fracturing fluid volume, fracturing fluid viscosity, proppant type, proppant mass, proppant concentration, pumping rate, pumping schedule or combinations thereof.