Systems and methods to increase the durability of carbonate reservoir acidizing
Systems and methods for predicting and optimizing the effects of acidizing treatment of carbonate rock are disclosed. The disclosed methods predict the conflicting effects of increased production (i.e., wormhole creation) and reduced rock compressive strength due to acid rock reactions. The mechanical stability of stimulated wellbores, such as horizontal wellbores, can be determined under different acidizing conditions, such as acid type and volume. The acidizing conditions can be optimized to maximize short and long-term production.
1. A method of acidizing a formation traversed by a wellbore, the method comprising:
determining an optimized acidizing fluid, and
providing the optimized acidizing fluid to the formation, wherein
determining the optimized acidizing fluid comprises:
providing a set of acidizing parameters,
determining a distribution of reactive and non-reactive fluids along the wellbore during acidizing based on the set of acidizing treatment parameters,
determining a dissolution of the formation within a region of the wellbore based on the determined distribution of reactive and non-reactive fluids,
determining one or more mechanical parameters indicative of weakening of the formation within the region of the wellbore based on the determined dissolution,
predicting damage to the formation due to formation stress during hydrocarbon production based on the determined mechanical parameters,
predicting an amount of hydrocarbon produced during hydrocarbon production based, at least in part, on the predicted damage, and
adjusting the set of acidizing parameters to maximize the predicted amount of hydrocarbon produced during hydrocarbon production.
2. The method of claim 1 , wherein the set of acidizing parameters comprise one or more parameters selected from the group consisting of an acid strength, an acid concentration, an acid volume, and an acid injection rate.
3. The method of claim 1 , wherein determining a distribution of reactive and non-reactive fluids along the wellbore comprises determining a wellbore flow model of the formation based on an initial characterization of the formation and one or more multi-physics or multiscale simulations of the formation.
4. The method of claim 3 , wherein the initial characterization of the formation comprises one or more formation parameters selected from the group consisting of a type of hydrocarbon fluid in the formation, a configuration of the wellbore, a static fluid inside the wellbore, a distribution of rock properties along the wellbore, a completion type, and a production enhancement.
5. The method of claim 1 , wherein determining a distribution of reactive and non- reactive fluids along the wellbore during the acidizing treatment comprises determining wormhole penetration into the formation.
6. The method of claim 1 , wherein determining a dissolution of the formation within a region of the wellbore comprises determining a porosity profile of the formation within the region of the wellbore.
7. The method of claim 1 , wherein determining one or more mechanical parameters of the formation comprises determining one or more mechanical parameters selected from the group consisting of Young's modulus, bulk modulus, shear modulus, cohesion, internal friction angle, and pore-collapse pressure.
8. The method of claim 1 , wherein predicting damage to the formation during hydrocarbon production comprises determining one or more of shear failure and compressive failure within the formation.
9. The method of claim 8 , wherein the one or more of shear failure and compressive failure within the formation is determined based on porosity of the formation.
10. The method of claim 8 , wherein predicting damage to the formation during hydrocarbon production comprises determining one or more of shear failure and compressive failure that extends beyond a wormhole penetration radius from the wellbore.
11. A method of optimizing an acidizing treatment of a formation traversed by a wellbore, the method comprising:
for an initial set of acidizing parameters, determining a distribution of reactive fluid along the wellbore,
using a finite element model to determine porosity evolution along the wellbore based on the determined distribution of reactive fluid,
determining one or more mechanical parameters indicative of weakening of the formation based on the determined porosity evolution,
determining a damage radius for formation damage due to formation stress along the wellbore based on the one or more mechanical properties,
predicting an amount of hydrocarbon produced from the formation during hydrocarbon production based on the determined damage radius, and
adjusting the initial set of acidizing parameters to maximize the predicted amount of hydrocarbon produced during hydrocarbon production.
12. The method of claim 11 , wherein the mechanical parameters of the formation comprise one or more parameters selected from the group consisting of Young's modulus, bulk modulus, shear modulus, cohesion, internal friction angle, and pore-collapse pressure.
13. The method of claim 11 , further comprising determining an extent of wormhole penetration into the wellbore.
14. The method of claim 13 , further comprising comparing the extent of wormhole penetration into the wellbore to the determined damage radius along the wellbore.
15. A non-transitory computer readable medium having instructions stored therein, which when executed by a computer cause the computer to perform operations comprising:
for an initial set of acidizing parameters, determining a distribution of reactive fluid along the wellbore,
determining a dissolution of the formation within a region of the wellbore based on the determined distribution of reactive and non-reactive fluids,
determining one or more mechanical parameters indicative of weakening of the formation within the region of the wellbore based on the determined dissolution,
predicting damage to the formation due to formation stress during hydrocarbon production based on the determined mechanical parameters,
predicting an amount of hydrocarbon produced during hydrocarbon production based, at least in part, on the predicted damage, and
adjusting the set of acidizing treatment parameters to maximize the predicted amount of hydrocarbon produced during hydrocarbon production.
16. The non-transitory computer readable medium of claim 15 , wherein the initial set of acidizing parameters comprise one or more parameters selected from the group consisting of an acid strength, an acid concentration, an acid volume, and an acid injection rate.
17. The non-transitory computer readable medium of claim 15 , wherein determining a distribution of reactive and non-reactive fluids along the wellbore during the acidizing treatment comprises determining wormhole penetration into the formation.
18. The non-transitory computer readable medium of claim 15 , wherein determining a dissolution of the formation within a region of the wellbore comprises determining a porosity profile of the formation within the region of the wellbore.
19. The non-transitory computer readable medium of claim 15 , wherein determining one or more mechanical parameters of the formation comprises determining one or more mechanical parameters selected from the group consisting of Young's modulus, bulk modulus, shear modulus, cohesion, internal friction angle, and pore-collapse pressure.
20. The non-transitory computer readable medium of claim 15 , wherein predicting damage to the formation during hydrocarbon production comprises determining one or more of shear failure and compressive failure that extends beyond a wormhole penetration radius from the wellbore.