Systems and methods for operating wells of a field using a multi-objective genetic algorithm are disclosed. In one embodiment, a method of operating a plurality of wells within a field includes determining an oil rate for each well of the plurality of wells by a multi-objective genetic algorithm. The multi-objective genetic algorithm is defined by a multi-objective fitness function including a first objective function that meets a target oil rate for the field and a second objective function that maximizes bottom-hole reservoir pressure, maximizes a distance of the wells to a crest line of the field, and minimizes a water cut of the field. The multi-objective genetic algorithm outputs the oil rate for each well that satisfies the multi-objective fitness function. The method further includes operating the plurality of wells at the oil rate for each well.

A method for performing a drill stem test (DST) is disclosed. The method includes performing underbalanced drilling (UBD) of exploration wells to penetrate a target interval in a subterranean formation, where UBD is performed when a wellbore fluid pressure is less than a formation fluid pressure to allow a fluid flow from the target interval to surface during a drilling phase of the UBD, determining, based on the UBD of the exploration wells, a measure of the fluid flow from the target interval to the surface, obtaining, based on the UBD of the exploration wells, open hole logs of the exploration wells, where the open hole logs represent a reservoir property of the target interval, and selectively performing, based at least on the measure of the fluid flow and the open hole logs, the DST of the exploration wells.

A method that includes deploying a casing with a multi-electrode configuration over a dielectric layer in a downhole environment. The method also includes collecting electromagnetic (EM) measurements using the multi-electrode configuration, and processing the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall. A related system includes a casing deployed downhole, the casing having a multi-electrode configuration and a dielectric layer between the casing and the multi-electrode configuration. The system also includes a controller for directing collection of EM measurements using the multi-electrode configuration, and a processor that processes the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall.

The downhole tool may include an electrical power source, a positive and a negative electrode, and at least one sensor. The positive and negative electrodes may be configured to generate an electric field between the positive and the negative electrode with an electrical charge from the electrical power source and discharge the electric charge through a downhole formation. The at least one sensor may be configured to detect quantum particles dislocated by at least one of the electric field and the discharged electrical charge to determine downhole information from at least one of a travel time of the quantum particles, a composition of the quantum particles, a quantity of the quantum particles, and a charge of the quantum particles.

A yield estimation device for a low-yield shale gas reservoir includes: a separation tank, a pulse gas detector, and a methane concentration detector; wherein a liquid inlet is provided at an upper portion of the separation tank; an exhaust pipe is provided on a top of the separation tank, and the pulse gas detector is installed at a middle section of the exhaust pipe; the methane concentration detector is installed at a tail end of the exhaust; a valve is installed in a liquid outlet; a float is arranged in the separation tank, which is connected to the valve through a telescopic float rod. A yield estimation method includes steps of: inputting flowback fluid into the separation tank through the liquid inlet; discharging the air in the separation tank; performing gas-liquid separation; detecting and displaying the shale gas in real time with the pulse gas detector.

Processes and systems for correlating well log data sets from well logging passes within a well bore. In some embodiments, a process for well log depth matching can include normalizing a first well log from a first logging pass obtained within a well bore and a second well log from a second logging pass obtained within the well bore, performing a pre-shift, performing feature picking to identify one or more features along the second well log, performing normalized cross-correlation based optimization between the first well log and the second well log to match the one or more features along the second well log to the same one or more features of the first well log and generating a shift table for depth shifting the one or more features of the second well log and the first well log.

A method may comprise plotting treatment data to form a plot of the treatment data, fitting a function to the plot of the treatment data, determining an intercept of the function, calculating one or more coefficients, plotting the one or more coefficients on a histogram, and identifying one or more active flowpath elements on the histogram. A system may comprise a fluid handling system and an information handling system. The fluid handling system may comprise a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface; pumping equipment, wherein the pumping equipment it attached to the fluid supply vessel and disposed on the surface; wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation; and a plurality of flowpath elements, wherein the flowpath elements fluidly couple the wellbore supply conduit to the formation.

A method of estimating reservoir properties is disclosed. The method includes obtaining downhole pressure data during a drill stem test in a wellbore penetrating a reservoir, computing a first linearity measure of a first diagnostic plot, wherein the first diagnostic plot represents a first dependency of the downhole pressure data on a linear-scale with respect to inverse time on a linear-scale, determining, based at least on the first linearity measure, data sufficiency of the drill stem test, and generating, from the downhole pressure data and based at least on the data sufficiency, an estimation of the reservoir properties.

The disclosure provides a pump system including a pump, a gas relief valve coupled to the pump, a motor configured to turn the pump, and a sensor configured to measure a parameter of at least one of a fluid or the pump system. The gas relief valve includes an actuator and a rotary disk system, and the rotary disk system includes a stationary disk and a rotary disk. The actuator is rotationally coupled to the rotary disk, and in a first position, the gas relief valve directs a flow of a fluid into a production tubing and in a second position, the gas relief valve directs the flow of the fluid into an annulus of a wellbore.

A method and system for performing a pressure test. The method may comprise inserting a formation testing tool into a wellbore to a first location within the wellbore, identifying one or more tool parameters of the formation testing tool, performing a first pre-test with the pressure transducer when the pressure has stabilized to identify formation parameters, inputting the formation parameters and the one or more tool parameters into a forward model, changing the one or more tool parameters to a second set of tool parameters; performing a second pre-test with the second set of tool parameters; and comparing the first pre-test to the second pre-test. A system may comprise at least one probe, a pump disposed within the formation testing tool, at least one stabilizer, a pressure transducer disposed at least partially in the at least one fluid passageway, and an information handling system.