Abstract: A method and system for determining a flow rate of at least a phase or a component of a fluid produced from an oil and gas well are presented hereinafter. The fluid is one of a multiphase and of a multicomponent fluid. The method comprises, in a training phase, collecting primary measurements of pressure, temperature, and additional flow parameter of the produced fluid. The primary measurements are carried out at the wellhead by a set of sensors installed in a flow line for the produced fluid. In the training phase, the method also comprises collecting a flow rate of at least one of the phases or components of the produced fluid simultaneously measured by a reference multiphase flow meter installed in the flow line. It also includes establishing a relationship between the pressure, temperature, and the additional flow parameter and the flow rate of the at least one of the phases or components of the produced fluid.

Abstract: Conductivity probe fluid property measurement systems and related methods are disclosed herein. An example apparatus includes a flow meter and a fluid conduit to provide a flow path for a fluid relative to the flow meter. The example apparatus includes a conductivity probe coupled to the fluid conduit to generate brine conductivity data of the fluid during flow of the fluid through the fluid conduit. The example apparatus includes a processor to modify fluid flow data generated by the flow meter based on the brine conductivity data.

Abstract: Conductivity probe fluid property measurement systems and related methods are disclosed herein. An example apparatus includes a flow meter and a fluid conduit to provide a flow path for a fluid relative to the flow meter. The example apparatus includes a conductivity probe coupled to the fluid conduit to generate brine conductivity data of the fluid during flow of the fluid through the fluid conduit. The example apparatus includes a processor to modify fluid flow data generated by the flow meter based on the brine conductivity data.

Abstract: The present disclosure relates to a method comprising: receiving a resource model associated with a resource site and receiving one or more objective parameters, such that a first objective parameter comprised in the one or more objective parameters is a function of one or more parameter values of the resource model. The method comprises executing simulations to generate a first uncertainty value based on at least one of a first parameter value and a first uncertainty value of a first parameter of the resource model. The simulations may be executed to generate a first forecast uncertainty value for each scenario comprised in a plurality of scenarios. The method also identifies one service that minimizes an uncertainty value of the objective parameter based on the forecast uncertainty value. The method further includes generating a first visualization comprising the one identified service for viewing by a user via a user interface.

Abstract: The present disclosure relates to a system that is operable to receive an execution plan and execute a control operation on one or more equipment based operations within the execution plan. The one or more operations may include a data capturing operation associated with a resource site. In one embodiment, the system may be operable to execute at least a first operation in response to a success variable of the data capturing operation indicating a successful execution of the data capturing operation. The first operation may include a quality control operation that is executed by comparing at least one characteristic of the captured data to an expected characteristic to generate quality state data. The quality state data may have one of an acceptable status and an undesirable status. In response to the quality state data indicating an acceptable status for the quality control operation, executing at least a second operation.

Abstract: An apparatus for performing a well test operation includes a tubular member having a surge chamber and a valve that can control fluid flow from a well into the surge chamber during the well test operation. The apparatus can also include a flow control device, in addition to the valve, for further controlling fluid flow into the surge chamber from the well. Flow rate and pressure data can be measured during the well test operation and used to estimate reservoir properties. Various other systems, devices, and methods are also disclosed.

Abstract: A measurement device is configured in a shaped charge package to be utilized in a perforating gun section tool string. The measurement device may include for example thermal conductivity detectors (TCD) configured to measure fluid flow velocity and/or thermal characteristics of the flowing fluid. The measurement device may include for example a pair laterally spaced TCDs each having sensor faces positioned co-planar with a surface across which the fluid flows. The measurement device may include a recessed TCD, having a sensor face recessed below an opening in the exterior surface.

Abstract: Conductivity probe fluid property measurement systems and related methods are disclosed herein. An example apparatus includes a flow meter and a fluid conduit to provide a flow path for a fluid relative to the flow meter. The example apparatus includes a conductivity probe coupled to the fluid conduit to generate brine conductivity data of the fluid during flow of the fluid through the fluid conduit. The example apparatus includes a processor to modify fluid flow data generated by the flow meter based on the brine conductivity data.

Abstract: A first water injection into an injection well is carried out followed by a first shut-in of the injection well. A second water injection is carried out, a volume of the injected water exceeds several times a volume of water in the well in an intake interval. Then there is a second shut-in of the injection well, and during the second shut-in transient temperature profiles are registered within the intake interval by temperature sensors. Then a third water injection step is carried out and at an initial stage of the third injection transient temperature profiles in the intake interval are registered using the temperature sensors. The transient temperature profiles registered during the second shut-in period are analyzed and intake zone boundaries are determined. The transient temperature profiles registered at the initial stage of the third water injection are analyzed and a water intake profile is determined.

Abstract: For determining a water cut of an oil-water mixture produced from an oil well at least one Venturi tube is placed in a well, through which an oil-water mixture, produced from a selected well segment, enters the borehole. During production process, pressure at a Venturi tube inlet and in a Venturi tube throat are measured, and flow temperature of the produced oil-water mixture at the Venturi tube inlet and the temperature of the Venturi tube wall in the Venturi tube throat are measured. Based on the results of the pressure and temperature measurements, the water cut of the oil-water mixture produced from the selected well segment is determined.

Abstract: Whiles moving a pipe string in a wellbore during tripping operations, pressure and temperature are measured. Based on the measured pressure and temperature, such parameters of a bottomhole and a near-bottomhole zone of the wellbore are calculated as skin factor, permeability, reservoir thickness, bottomhole pressure, and outflow or inflow from/to the zone under consideration.

Abstract: The method for orienting hydraulic fractures in a subterranean formation comprises injecting a first fluid into a first horizontal wellbore penetrating the subterranean formation and open to the formation in at least one specified segment and pressurizing the first fluid in the first wellbore to create a stress field around each specified segment of the first wellbore. A second pressurized fracturing particle-laden fluid is simultaneously injected into a second horizontal wellbore open to the formation in at least one specified segment and vertically spaced apart from the first wellbore for inducing fractures propagating from the specified segments of the second wellbore towards the specified pressurized segments of the first wellbore.

Abstract: A first water injection into an injection well is carried out followed by a first shut-in of the injection well. A second water injection is carried out, a volume of the injected water exceeds several times a volume of water in the well in an intake interval. Then there is a second shut-in of the injection well, and during the second shut-in transient temperature profiles are registered within the intake interval by temperature sensors. Then a third water injection step is carried out and at an initial stage of the third injection transient temperature profiles in the intake interval are registered using the temperature sensors. The transient temperature profiles registered during the second shut-in period are analyzed and intake zone boundaries are determined.

Abstract: An apparatus for performing a well test operation includes a tubular member having a surge chamber and a valve that can control fluid flow from a well into the surge chamber during the well test operation. The apparatus can also include a flow control device, in addition to the valve, for further controlling fluid flow into the surge chamber from the well. Flow rate and pressure data can be measured during the well test operation and used to estimate reservoir properties. Various other systems, devices, and methods are also disclosed.

Abstract: A pressure in a wellbore and a temperature at least at one point of the wellbore are measured during wellbore testing. Transient profiles of temperature along the wellbore are determined and changes in a density of a downhole fluid and in a length of atubing when the wellbore is shut in are calculated. The pressure measurement results are corrected on the basis of the calculated changes in the density of the downhole fluid and in the length of the tubing.

Abstract: Temperature is measured in a shut-in wellbore and rates of temperature change in depth intervals within productive layers and in depth intervals adjacent to the productive layers are determined. Areas are selected in the depth intervals within the productive layers wherein the rate of temperature change is significantly higher than the rate of change in the depth intervals adjacent to the productive layers. A numerical model of temperature change in the shut-in wellbore is created taking into account a filtration effect of a reservoir fluid on the rate of the temperature change in the shut-in wellbore. The measurement results are compared with the numerical modeling results, and their best match is used for determining a fluid filtration velocity in the selected areas in the depth intervals within the productive layers.

Abstract: Methods for determining an inflow profile of multilayer reservoir fluids in a wellbore are described herein. A bottom-hole zone is cooled before well perforation. Then, the wellbore is perforated, and a flow temperature is measured in the wellbore above each perforation zone. A production rate of each productive layer is determined taking into account thicknesses of the perforation zones and using results of temperature measurements acquired in a period between an end of an initial production stage characterized by strong impact of a volume of the wellbore and quick flow temperature changes in the wellbore, and a time when the bottom-hole zone cooling effect on the temperature measurements becomes insignificant.

Abstract: A measurement device is configured in a shaped charge package to be utilized in a perforating gun section tool string. The measurement device may include for example thermal conductivity detectors (TCD) configured to measure fluid flow velocity and/or thermal characteristics of the flowing fluid. The measurement device may include for example a pair laterally spaced TCDs each having sensor faces positioned co-planar with a surface across which the fluid flows. The measurement device may include a recessed TCD, having a sensor face recessed below an opening in the exterior surface.

Abstract: A method for determining the profile of fluids inflowing into multi-zone reservoirs provides for a temperature measurement in a wellbore during the return of the wellbore to thermal equilibrium after drilling and determining a temperature of the fluids inflowing into the wellbore from each pay zone after perforation at an initial stage of production. Specific flow rate for each pay zone is determined by a rate of change of the measured temperatures.

Abstract: Whiles moving a pipe string in a wellbore during tripping operations, pressure and temperature are measured. Based on the measured pressure and temperature, such parameters of a bottomhole and a near-bottomhole zone of the wellbore are calculated as skin factor, permeability, reservoir thickness, bottomhole pressure, and outflow or inflow from/to the zone under consideration.