Abstract: Methods and systems for determining reservoir permeability of a subsurface formation and fracture surface area. The method includes creating a first hydraulic fracture and a second hydraulic fracture in a horizontal well, generating a pressure pulse at the first hydraulic fracture, monitoring, using a first pressure gauge the pressure at the first hydraulic fracture, monitoring, using a second pressure gauge, the pressure pulse at the second hydraulic fracture, repeating this test at different locations along the wellbore to evaluate heterogeneity in permeability and variations in fracture surface areas, analyzing pressure and rate data to determine either permeability or fracture surface area by using: analytical/numerical simulation models, or physics-based proxy models inputting pressure front/peak arrival time or peak pressure.

Abstract: Provided are methods of recovering oil from a reservoir using carbon dioxide foam flooding in which a carbon dioxide foam of increased strength is used.

Abstract: A method for determining SRV and EUR includes: monitoring an amount and a density of a hydrocarbon fluid produced from the production well; obtaining a cumulative amount of the fluid that has accumulated from a beginning of production; obtaining a relationship between the cumulative amount and a square root of the time; determining a deviation point where the relationship changes from linear to non-linear; determining a deviation amount of the fluid corresponding to the deviation point; determining a first density of the hydrocarbon fluid at the beginning of production, a second density at a pore pressure equal to a bottom hole pressure in the production well, a first porosity at the beginning of production, and a second porosity for a pore pressure equal to the bottom hole pressure; and determining SRV and the EUR based on the deviation amount, the first and second densities, and the first and second porosities.

Abstract: A system and method to determine effective fracture surface-area per cluster of hydraulic fractures of a hydraulically-fractured well by estimating total effective fracture-area associated with a wellbore and estimating relative distribution of effective fracture surface-area along the wellbore.

Abstract: A method for determining SRV and EUR includes: monitoring an amount and a density of a hydrocarbon fluid produced from the production well; obtaining a cumulative amount of the fluid that has accumulated from a beginning of production; obtaining a relationship between the cumulative amount and a square root of the time; determining a deviation point where the relationship changes from linear to non-linear; determining a deviation amount of the fluid corresponding to the deviation point; determining a first density of the hydrocarbon fluid at the beginning of production, a second density at a pore pressure equal to a bottom hole pressure in the production well, a first porosity at the beginning of production, and a second porosity for a pore pressure equal to the bottom hole pressure; and determining SRV and the EUR based on the deviation amount, the first and second densities, and the first and second porosities.

Abstract: A method for concurrent fluid injection and production of a reservoir fluid from a hydraulically fractured horizontal well comprising the steps of completing a well in a formation to create the hydraulically fractured horizontal well; designating an alpha group; designating a beta group, such that each segment is in either the alpha group or the beta group, wherein the number and location of the segments in each of the alpha group and the beta group are based on the production configuration; initiating a first mode of operation; operating the hydraulically fractured horizontal well in the first mode of operation for a first mode run time; stopping the first mode of operation; initiating the second mode of operation; operating the hydraulically fractured horizontal well in the second mode of operation for a second mode run time; and cycling between the first mode of operation and the second mode of operation.

Abstract: Methods and systems for determining reservoir permeability of a subsurface formation and fracture surface area. The method includes creating a first hydraulic fracture and a second hydraulic fracture in a horizontal well, generating a pressure pulse at the first hydraulic fracture, monitoring, using a first pressure gauge the pressure at the first hydraulic fracture, monitoring, using a second pressure gauge, the pressure pulse at the second hydraulic fracture, repeating this test at different locations along the wellbore to evaluate heterogeneity in permeability and variations in fracture surface areas, analyzing pressure and rate data to determine either permeability or fracture surface area by using: analytical/numerical simulation models, or physics-based proxy models inputting pressure front/peak arrival time or peak pressure.

Abstract: A method for concurrent fluid injection and production of a reservoir fluid from a hydraulically fractured horizontal well comprising the steps of completing a well in a formation to create the hydraulically fractured horizontal well; designating an alpha group; designating a beta group, such that each segment is in either the alpha group or the beta group, wherein the number and location of the segments in each of the alpha group and the beta group are based on the production configuration; initiating a first mode of operation; operating the hydraulically fractured horizontal well in the first mode of operation for a first mode run time; stopping the first mode of operation; initiating the second mode of operation; operating the hydraulically fractured horizontal well in the second mode of operation for a second mode run time; and cycling between the first mode of operation and the second mode of operation.

Abstract: Provided are methods of recovering oil from a reservoir using carbon dioxide foam flooding in which a carbon dioxide foam of increased strength is used.

Abstract: A system and method to determine effective fracture surface-area per cluster of hydraulic fractures of a hydraulically-fractured well by estimating total effective fracture-area associated with a wellbore and estimating relative distribution of effective fracture surface-area along the wellbore.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.