Abstract: A diverter injection system is disclosed herein along with systems and methods relating thereto. In an embodiment, the diverter injection system includes a system inlet and a system outlet. In addition, the diverter injection system includes a canister including an internal volume configured to retain diverter therein. Further, the diverter injection system includes a first flow path extending between the system inlet and the system outlet that bypasses the canister, and a second flow path that extends from the system inlet, through the canister, and then to the system outlet. Still further, the diverter injection system includes a plurality of valves, wherein actuation of the plurality of valves is configured to selectively switch between the first flow path and the second flow path.

Abstract: A pumping system for performing a hydraulic fracturing operation includes a first fluid conduit having a central axis, a fluid pump including an outlet configured to be inserted into the first fluid conduit, and a connector assembly including an engagement member having a first position configured to lock the outlet within the first fluid conduit and a second position configured to unlock the outlet from the first fluid conduit.

Abstract: An intake for a downhole pump includes an outer tubular member having a central axis. In addition, the intake includes an inner tubular member disposed within the outer tubular member. The inner tubular member is radially spaced from the outer tubular member to form an outer annular flow path radially positioned between the inner tubular member and the outer tubular member. Further, the intake includes a central shaft rotatably disposed within the inner tubular member. The central shaft is radially spaced from the inner tubular member to form an inner annular flow path radially positioned between the central shaft and the inner tubular member. Still further, the intake includes a plurality of inlet apertures extending radially through the outer tubular member and in fluid communication with the outer annular flow path. Each of the plurality of inlet apertures has a circumferential width W between 5% and 50% of a total circumference of the outer tubular member.

Abstract: A method for determining a hydrocarbon-bearing reservoir quality prior to a hydraulic fracture treatment based on completions index is disclosed. The method comprises a step performing a test determining a hydraulic pressure at which a hydrocarbon-bearing reservoir will begin to fracture by pumping a fluid in a wellbore, wherein the wellbore extends from a surface to the reservoir and the wellbore has one or more perforations in communication with reservoir; a step generating a pressure transient in the wellbore, the pressure transient travels from the surface to the reservoir through the perforations and reflects back the surface after contacting the reservoir; a step measuring response of the pressure transient at sufficiently high sampling frequency; a step determining fracture hydraulic parameters of the perforations and the reservoir using the measured response; and optimizing a stimulation treatment to the reservoir based on the determined fracture hydraulic parameters.

Abstract: A method for determining a hydrocarbon-bearing reservoir quality prior to a hydraulic fracture treatment based on completions index is disclosed. The method comprises a step performing a test determining a hydraulic pressure at which a hydrocarbon-bearing reservoir will begin to fracture by pumping a fluid in a wellbore, wherein the wellbore extends from a surface to the reservoir and the wellbore has one or more perforations in communication with reservoir; a step generating a pressure transient in the wellbore, the pressure transient travels from the surface to the reservoir through the perforations and reflects back the surface after contacting the reservoir; a step measuring response of the pressure transient at sufficiently high sampling frequency; a step determining fracture hydraulic parameters of the perforations and the reservoir using the measured response; and optimizing a stimulation treatment to the reservoir based on the determined fracture hydraulic parameters.

Abstract: A method for cementing a tubular member within a subterranean wellbore extending from a surface into a subterranean formation and through a hydrocarbon reservoir includes (a) injecting a gas from the surface into an annulus surrounding the tubular member within the wellbore. In addition, the method includes (b) flowing cement through a throughbore of the tubular member. Further, the method includes (c) displacing the cement from the throughbore of the tubular member into the annulus. Still further, the method includes (d) reducing a pressure of the gas in the annulus during (c).

Abstract: A load measurement sub for measuring a load transferred between the sub and an inner surface of a tubing string includes a housing. The housing includes a central axis, an internal cavity, and a radially outermost surface. In addition, the load measurement sub includes a first load measurement assembly at least partially disposed within a first port extending from the radially outermost surface to the internal cavity. The first load measurement assembly includes a first button extending radially from the first port and the radially outermost surface of the housing. The first load measurement assembly also includes a first load cell. Further, the load measurement sub includes a first biasing member disposed between the first button and the first load cell. The first biasing member is configured to bias the first button away from the first load cell.

Abstract: A frac plug includes a body having an outer surface, a first pocket in the outer surface, and a second pocket in the outer surface. In addition, the frac plug includes a first sensor removably disposed in the first pocket. The first sensor is configured to measure and record a plurality of pressures. The frac plug also includes a second sensor removably disposed in the second pocket. The second sensor is configured to measure and record a plurality of pressures. Further, the frac plug includes a first cap releasably coupled to the body and closing the first pocket. Moreover, the frac plug includes a second cap releasably coupled to the body and closing the second pocket. The first cap includes a port and the second cap includes a port.

Abstract: A plunger piston assembly for a plunger lift system used to remove fluids from a subterranean wellbore includes a sealing sleeve having a central axis, an upper end, a lower end, and a throughbore extending axially from the upper end of the sealing sleeve to the lower end of the sealing sleeve. The throughbore of the sealing sleeve defines a receptacle extending axially from the lower end of the sealing sleeve. In addition, the plunger piston assembly includes an intermediate sleeve having a central axis, an upper end, a lower end, and a throughbore extending axially from the upper end of the intermediate sleeve to the lower end of the intermediate sleeve. The throughbore of the intermediate sleeve defines a receptacle extending axially from the lower end of the intermediate sleeve. The upper end of the intermediate sleeve is configured to be removably seated in the receptacle of the sealing sleeve.

Abstract: An intake for a downhole pump includes an outer tubular member having a central axis. In addition, the intake includes an inner tubular member disposed within the outer tubular member. The inner tubular member is radially spaced from the outer tubular member to form an outer annular flow path radially positioned between the inner tubular member and the outer tubular member. Further, the intake includes a central shaft rotatably disposed within the inner tubular member. The central shaft is radially spaced from the inner tubular member to form an inner annular flow path radially positioned between the central shaft and the inner tubular member. Still further, the intake includes a plurality of inlet apertures extending radially through the outer tubular member and in fluid communication with the outer annular flow path. Each of the plurality of inlet apertures has a circumferential width W between 5% and 50% of a total circumference of the outer tubular member.

Abstract: A method for cementing a tubular member within a subterranean wellbore extending from a surface into a subterranean formation and through a hydrocarbon reservoir includes (a) injecting a gas from the surface into an annulus surrounding the tubular member within the wellbore. In addition, the method includes (b) flowing cement through a throughbore of the tubular member. Further, the method includes (c) displacing the cement from the throughbore of the tubular member into the annulus. Still further, the method includes (d) reducing a pressure of the gas in the annulus during (c).

Abstract: A plunger piston assembly for a plunger lift system used to remove fluids from a subterranean wellbore includes a sealing sleeve having a central axis, an upper end, a lower end, and a throughbore extending axially from the upper end of the sealing sleeve to the lower end of the sealing sleeve. The throughbore of the sealing sleeve defines a receptacle extending axially from the lower end of the sealing sleeve. In addition, the plunger piston assembly includes an intermediate sleeve having a central axis, an upper end, a lower end, and a throughbore extending axially from the upper end of the intermediate sleeve to the lower end of the intermediate sleeve. The throughbore of the intermediate sleeve defines a receptacle extending axially from the lower end of the intermediate sleeve. The upper end of the intermediate sleeve is configured to be removably seated in the receptacle of the sealing sleeve.

Abstract: A method for determining a hydrocarbon-bearing reservoir quality prior to a hydraulic fracture treatment based on completions index is disclosed. The method comprises a step performing a test determining a hydraulic pressure at which a hydrocarbon-bearing reservoir will begin to fracture by pumping a fluid in a wellbore, wherein the wellbore extends from a surface to the reservoir and the wellbore has one or more perforations in communication with reservoir; a step generating a pressure transient in the wellbore, the pressure transient travels from the surface to the reservoir through the perforations and reflects back the surface after contacting the reservoir; a step measuring response of the pressure transient at sufficiently high sampling frequency; a step determining fracture hydraulic parameters of the perforations and the reservoir using the measured response; and optimizing a stimulation treatment to the reservoir based on the determined fracture hydraulic parameters.

Abstract: A method for determining a hydrocarbon-bearing reservoir quality prior to a hydraulic fracture treatment based on completions index is disclosed. The method comprises a step performing a test determining a hydraulic pressure at which a hydrocarbon-bearing reservoir will begin to fracture by pumping a fluid in a wellbore, wherein the wellbore extends from a surface to the reservoir and the wellbore has one or more perforations in communication with reservoir; a step generating a pressure transient in the wellbore, the pressure transient travels from the surface to the reservoir through the perforations and reflects back the surface after contacting the reservoir; a step measuring response of the pressure transient at sufficiently high sampling frequency; a step determining fracture hydraulic parameters of the perforations and the reservoir using the measured response; and optimizing a stimulation treatment to the reservoir based on the determined fracture hydraulic parameters.

Abstract: A fracturing fluid that includes the combination of liquid ammonia and a proppant, and a method for fracturing an underground formation by pumping this fracturing fluid into a wellbore that extends to the formation. The process includes generating pressure in the wellbore, creating fractures in the formation using the liquid or gelled ammonia and proppant slurry, and releasing pressure from the wellbore. The ammonia released from the liquid or gelled ammonia helps stabilize clays in the formation and the proppant helps to maintain the fractures in the formation.

Abstract: A method for stimulating a hydrocarbon-containing formation that includes the steps of: introducing a heat source in the formation; heating a portion of liquid hydrocarbons in the formation to expand hydrocarbon volume, thereby rejuvenating fractures in the formation; passing at least some of the heated liquid hydrocarbons through the rejuvenated fractures; and producing at least a portion of the liquid hydrocarbons that passed through the rejuvenated fractures. The methods and processes provide for in-situ stimulation of hydrocarbon-containing formations using energy to expand in-situ liquid hydrocarbons, thus rejuvenating naturally occurring fractures. In some embodiments, the energy is supplied as heat from injection of an oxygen-containing fluid.

Abstract: The subject invention is directed to a method for the surface recovery of hydrocarbons from a subterranean reservoir. The reservoir can be a formation found in sandstone, carbonate, coal bed or other mineral deposit formations. The method includes drilling a well bore having a first substantially vertical portion and a first substantially horizontal portion, in which the first horizontal portion intersects the subterranean reservoir. A plurality of lateral well bores intersecting and extending from the first horizontal portion of the well bore are drilled. Thereafter, a drainage well bore is drilled below and substantially parallel to the first horizontal portion of the well bore, in which the drainage well bore intersects the first horizontal portion.

Abstract: The subject invention is directed to a method for the surface recovery of hydrocarbons from a subterranean reservoir. The reservoir can be a formation found in sandstone, carbonate, coal bed or other mineral deposit formations. The method includes drilling a well bore having a first substantially vertical portion and a first substantially horizontal portion, in which the first horizontal portion intersects the subterranean reservoir. A plurality of lateral well bores intersecting and extending from the first horizontal portion of the well bore are drilled. Thereafter, a drainage well bore is drilled below and substantially parallel to the first horizontal portion of the well bore, in which the drainage well bore intersects the first horizontal portion.