Abstract: A natural gas system includes a pneumatic controller configured to discharge vent gas, an expansion vessel configured to discharge an expanded pilot gas, wherein the expansion vessel includes an internal volume configured to expand the vent gas discharged from the pneumatic controller whereby the expanded pilot gas discharged from the outlet port falls within a predefined discharge pressure range, a vent gas flowpath extending from the pneumatic controller to the expansion vessel, a burner assembly coupled to the expansion vessel and configured to ignite the expanded pilot gas discharged by the expansion vessel, and a pilot gas flowpath extending from the expansion vessel to the burner assembly.

Abstract: A production inlet assembly for use within a subterranean wellbore, the wellbore including a central axis and the production inlet assembly including a landing sub that affixable within the wellbore, a sand catcher including a chamber that is configured to receive particulates separated from formation fluids that enter the production inlet assembly, and a telescoping joint coupled between the landing sub and the sand catcher, wherein the telescoping joint is permitted to translate axially along the landing sub.

Abstract: In one embodiment, a method for preventing flaring at a facility, by a system, includes receiving a plurality of pressure measurements from a sensor disposed downstream of the facility. The method further includes comparing the plurality of pressure measurements to a threshold pressure, wherein the threshold pressure corresponds to mitigating a flaring event. In response to determining that at least one of the plurality of pressure measurements is greater than the threshold pressure, the method further includes analyzing injection response curves for a plurality of wells to determine a first well for adjusting a back pressure on a reservoir intersected by the first well. The method further includes transmitting an instruction to the first well to adjust the back pressure on the reservoir.

Abstract: Methods and systems for controlling a drilling operation in a subterranean formation are disclosed. The method includes generating a simulated well log based, at least in part, on a subset of an MWD log from a horizontal well, wherein the subset of the MWD log is for measured depths between a starting measured depth and an ending measured depth. The method further includes monitoring and/or controlling a drilling operation based, at least in part, on the simulated well log.

Abstract: A method for determining conditions in a wellbore extending through a subterranean formation includes deploying a plurality of sensor pods in the wellbore, wherein each sensor pod includes a housing and a plurality of sensors disposed in the housing. The method also includes measuring and recording a plurality of pressures and a plurality of temperatures with plurality of sensors of each sensor pod, dissolving the housings of the pods to release the plurality of sensors from the pods after measuring and recording the plurality of pressures and the plurality of temperatures, and lifting the sensors to the surface.

Abstract: A pumping system for performing a hydraulic fracturing operation includes an inlet conduit extending from a manifold, wherein a pair of inlet valves disposed along the inlet conduit, a fluid pump including an outlet configured to be inserted into the inlet conduit, and a connector assembly including an engagement member having a first position configured to lock the outlet within the inlet conduit and a second position configured to unlock the outlet from the inlet conduit. The pumping system additionally includes a pair of branch conduits extending from the inlet conduit, a pair of branch valves, wherein one of the pair of branch valves is disposed along each of the pair of branch conduits, and a dump conduit extending from the pair of branch conduits, wherein a dump valve is disposed along the dump conduit.

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: A cement wiper plug for deployment in casing with an inner radius has a central axis, a leading end, and a trailing end opposite the leading end. The wiper plug includes an elongate body. In addition, the wiper plug includes a first plurality of axially adjacent annular fins mounted to the body. Each fin extends radially outward from the body and each fin extends circumferentially about the body. The first plurality of fins includes a first fin and a second fin axially adjacent the first fin. The second fin is axially positioned between the first fin and the trailing end. The first fin and the second fin are configured to contact each other in the casing. The second fin is configured to bias the first fin radially outward and axially forward toward the leading end.

Abstract: A method for determining conditions in a wellbore extending through a subterranean formation includes: (a) deploying a plurality of sensor pods in the wellbore, wherein each sensor pod includes a housing and a plurality of sensors disposed in the housing; (b) measuring and recording a plurality of pressures and a plurality of temperatures with plurality of sensors of each sensor pod; (c) dissolving the housings of the pods to release the plurality of sensors from the pods after (b); and (d) lifting the sensors to the surface after (c).

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 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 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 cement wiper plug for deployment in casing with an inner radius has a central axis, a leading end, and a trailing end opposite the leading end. The wiper plug includes an elongate body. In addition, the wiper plug includes a first plurality of axially adjacent annular fins mounted to the body. Each fin extends radially outward from the body and each fin extends circumferentially about the body. The first plurality of fins includes a first fin and a second fin axially adjacent the first fin. The second fin is axially positioned between the first fin and the trailing end. The first fin and the second fin are configured to contact each other in the casing. The second fin is configured to bias the first fin radially outward and axially forward toward the leading end.

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 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 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.