An example system includes an electrode-based tool for deployment in a downhole environment, where the electrode-based tool having a plurality of current electrodes, at least one voltage monitoring electrode, at least one return electrode. The electrode-based tool also includes electronics to measure leakage current between at least one of the plurality of current electrodes and the at least one return electrode as current from at least one of the plurality of current electrodes is injected into the downhole environment and flows to the at least one return electrode. The system also includes at least one processor configured to derive a corrected downhole environment parameter based at least in part on the measured leakage current.

Inlet and outlet connections of a well manifold connect to integrated piping of a unitary vessel on a skid. The unitary vessel defines an interior separated into two chambers by a barrier. One chamber has a test inlet for well testing operation, and the other chamber has a production inlet for production operation. Each of the chambers is in communication with a gas outlet for gas, a water outlet for water, and a condensate outlet for condensate. Each of the chambers has a weir plate disposed in the chamber and separating the water outlet on a waterside of the weir plate from the condensate outlet on a condensate-side of the weir plate adjacent the barrier. During use, the second chamber can be isolated so well testing operation can be performed using the first chamber. Also, the first chamber can be isolated so production operation can be performed using the second chamber.

Systems and methods are provided for geosteering in directional drilling based on water detection. An exemplary method includes determining a signal-to-noise ratio (SNR) for an electromagnetic communication between devices on a bottom hole assembly, and determining a distance to water based, at least in part, on the SNR. Adjustments to geosteering vectors for the bottom hole assembly are determined based, at least in part, on the distance to water.

A testing system for a shaped charge of a perforating gun, the testing system including a housing; a casing assembly located inside the housing; a perforating gun having at least one shaped charge, the perforating gun being located within the casing assembly; a sample material located within the housing, and in direct contact with the casing assembly; a wellbore accumulator in direct contact with the casing assembly and configured to supply a first fluid, at a wellbore pressure, inside the casing assembly; and a formation accumulator in direct contact with the sample material and configured to supply a second fluid, at a formation pressure, on the sample material.

Methods and systems are provided for characterizing interfacial tension (IFT) of reservoir fluids, which involves obtaining fluid property data that represents fluid properties of a reservoir fluid sample measured downhole at reservoir conditions, and inputting the fluid property data to a computational model that determines a value of oil-water IFT of the reservoir fluid sample based on the fluid property data. In embodiments, the fluid property data represents single-phase fluid properties of the reservoir fluid sample, such as fluid density and viscosity of an oil phase of the reservoir fluid sample and fluid density of a water phase of the reservoir fluid sample. In embodiments, the computation model can be based on machine learning or analytics combined with a thermodynamics-based physics model.

Flow electrification sensors and methods relating thereto may be useful in characterizing fluids, especially the in situ characterization of fluids produced during oil and gas production operations. A system may include a flow path; a flow electrification sensor at least partially contained within the flow path, the flow electrification sensor comprising a static charge accumulator and an insulator arranged such that the static charge accumulator interacts with a fluid in the flow path; a reference sensor; and a signal processor communicably coupled to the flow electrification sensor and the reference sensor.

An analytical method that establishes a thermodynamic equilibrium or known dynamic relationship between the concentrations of gases, natural gas liquids and oils or pressures of gasses in an isolated zone of a shale, or group of distinct shale gas intervals, with the concentrations of fluids or pressures of gasses in a wellbore penetrating the shale interval or intervals. An analytical method for identifying the chemical composition of gas, natural gas liquids and oils and determining their origin in an isolated zone of a shale, or group of distinct shale gas intervals with the identification of chemical composition of gas, natural gas liquids and oils in a wellbore penetrating the shale interval or intervals. A surface measurement apparatus capable of performing the measurement ex-situ. A downhole measurement apparatus capable of reliably performing the measurement in-situ and a downhole straddle-packer assembly capable of isolating part of, or an entire shale interval.

In one possible implementation, a computer-readable tangible medium includes instructions that direct a processor to access one or more wellbore properties and a plurality of well fluid properties. Instructions are also present that direct the processor to access a distance between a proposed location of an inlet to a multiphase production logging tool and an emulsion generation location in a wellbore. Further instructions instruct the processor to predict a drop size distribution of emulsified water in the well fluid at the proposed location of the inlet to the multiphase production logging tool. Additional instructions instruct the processor to compute an estimated error in water holdup detected by the multiphase production logging tool based on the drop size distribution, and recommend deployment of a pulsed neutron logging tool in the wellbore when the estimated error in the water holdup is above a preset threshold.

A method may comprise obtaining a formation sample, scanning the formation sample to form a data packet, loading the data packet on an information handling machine, performing a digital porous plate experiment with the data packet, and determining geometry of a pore throat in the formation sample. A system may comprise a computer tomographic machine configured to scan a formation sample and create a data packet from the scan and an information handling system. The information handling system may be configured to configured to perform a digital porous plate experiment with the data packet and determine geometry of a pore throat in the formation sample.

A method includes collecting a first set of borehole gravity data at a first time step along a length of a first wellbore and collecting a second set of borehole gravity data at the first time step along a length of a second wellbore. The method also includes interpolating a third set of borehole gravity data at the first time step in an area between the first wellbore and the second wellbore using the first and the second sets of borehole gravity data. Further, the method includes determining a first fluid saturation and a fluid saturation change over time in a reservoir containing the first wellbore and the second wellbore using the first set, the second set, and the third set. Moreover, the method includes controlling wellbore production operations or wellbore injection operations at the first wellbore based on the fluid saturation change.