Downhole fluid sensing device is disclosed for determining heat capacity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the sensor package and the sampling space having a common longitudinal center axis. The elongate sensor package body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate sensor package body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices (located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

A downhole well fluid sensing device is disclosed for determining thermal conductivity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the elongate body and the sampling space having a common longitudinal center axis. The elongate body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

Systems, devices, and methods for tracking the efficiency of a drilling rig are provided. A sensor system on a drilling rig is provided. A controller in communication with the sensor system may be operable to generate measurable parameters relating to at least one Key Performance Indicators (KPIs). The measurable parameters may be compared with measurable parameters from a target to generate an Invisible Lost Time (ILT) period and an Invisible Saved Time (IST) period for the drilling rig. The KPIs, ILT period, and IST period may be displayed to a user.

A method of determining the coal-bearing system boundary includes the following steps: firstly, determining the high-level boundaries mainly including the tectonic boundary, ore-bearing stratum and geological body distribution boundary, mixed complex boundary, etc.; secondly, determining the major boundary mainly including a fault or fault zone, giant fold or fold assemblage zone, sedimentary boundary, stratigraphic and mineral occurrence boundary, natural geography and artificial boundary, etc.. The determination of each major boundary contains the definition of its interfaces or boundaries with specific meaning among 18 types of such interfaces or boundaries. The coal-bearing system boundary is determined based on the features of the boundaries with specific meaning as well as the boundary development, mineral assemblage and spatial distribution conditions of a specific region. Among these types of boundaries, some boundaries with specific meaning are the necessary conditions for determining the coal-bearing system boundary, while some boundaries are optional conditions.

A method of determining the coal-bearing system boundary includes the following steps: firstly, determining the high-level boundaries mainly including the tectonic boundary, ore-bearing stratum and geological body distribution boundary, mixed complex boundary, etc.; secondly, determining the major boundary mainly including a fault or fault zone, giant fold or fold assemblage zone, sedimentary boundary, stratigraphic and mineral occurrence boundary, natural geography and artificial boundary, etc.. The determination of each major boundary contains the definition of its interfaces or boundaries with specific meaning among 18 types of such interfaces or boundaries. The coal-bearing system boundary is determined based on the features of the boundaries with specific meaning as well as the boundary development, mineral assemblage and spatial distribution conditions of a specific region. Among these types of boundaries, some boundaries with specific meaning are the necessary conditions for determining the coal-bearing system boundary, while some boundaries are optional conditions.

An example system for operation in a borehole in a hydrocarbon-bearing rock formation includes a logging tool for detecting one or more conditions in the borehole. The logging tool includes a tool body and a 4D printed sensing element. The 4D printed sensing element includes a 3D printed shape-memory material configured to alter in at least one spatial dimension in response to one or more stimuli, thereby generating a data signal. The example system includes a data recording device in communication with the logging tool to receive and record one or more data signals transmitted from the logging tool.

Hydrocarbon wells and methods of interrogating fluid flow within hydrocarbon wells. The hydrocarbon wells include a wellbore and downhole tubing that defines a tubing conduit and extends within the wellbore. The hydrocarbon wells also include an interrogation device. The interrogation device is configured to indicate at least one property of fluid flow within the hydrocarbon wells. The hydrocarbon wells also include a downhole location at which the interrogation device is released into the tubing conduit and a detection structure configured to query the interrogation device to determine the at least one property of fluid flow within the hydrocarbon wells. The methods include releasing an interrogation device at a downhole location within a hydrocarbon well and flowing the interrogation device from the downhole location to a surface region. The methods also include querying the interrogation device to determine at least one property of fluid flow within the hydrocarbon well.

A method for determining an oil-gas-water interface based on the formation pressure equivalent density. The method comprising: determining working parameters of the wireline modular formation tester based on the acquired conventional logging data of a block to be studied; acquiring a series of formation pressure and corresponding depth data based on the working parameter; computing formation pressure equivalent densities at different depths based on the formation pressure and the corresponding depth data; drawing a crossplot of the formation pressure equivalent density and the depth according to the formation pressure equivalent density and the corresponding depth data at the different depths; and determining the oil-gas-water interface according to the position of breaking point of the formation pressure equivalent density on the crossplot of the formation pressure equivalent density and the depth.

A method for determining an oil-gas-water interface based on the formation pressure equivalent density. The method comprising: determining working parameters of the wireline modular formation tester based on the acquired conventional logging data of a block to be studied; acquiring a series of formation pressure and corresponding depth data based on the working parameter; computing formation pressure equivalent densities at different depths based on the formation pressure and the corresponding depth data; drawing a crossplot of the formation pressure equivalent density and the depth according to the formation pressure equivalent density and the corresponding depth data at the different depths; and determining the oil-gas-water interface according to the position of breaking point of the formation pressure equivalent density on the crossplot of the formation pressure equivalent density and the depth.

Methods, systems, and devices for characterizing an anomalous fluid body in an earth formation using measurements in a borehole intersecting the formation. Methods include galvanically exciting a transient electric field in the earth formation which interacts with an anomalous fluid body in the earth formation remote from the borehole; galvanically receiving a corresponding transient electromagnetic (TEM) signal; and using at least one processor to estimate a value of a parameter of the anomalous fluid body using the corresponding transient signal.