An extraction well system is disclosed that allows for isolation of electrical cables from underground mine atmosphere. The extraction well system provides for a well casing that extends downwardly proximate to an existing mine cavity and an extension casing that extends downwardly below the mine roof. In one embodiment the extension casing is external to the well casing and is attached to the well casing mechanically such as with a dual thread reducer. The extension runs from above the mine roof to below the mine floor and is perforated in the area of the mine cavity to allow liquid to drain into the bottom of the extension well. In a second embodiment, the extension casing is interior to the well casing and is attached for example by an internal liner hanger. In this embodiment, the extension casing runs from above the mine roof to below the desired minimum liquid level and it is the well casing that extends downwardly in the extension well and which is perforated to allow liquids to flow into the well.

Embodiments of the present invention use radar technology to detect features or conditions in a well. A radar unit having an electronics subsystem and an antenna subsystem is positioned downhole in the well. The radar unit is coupled receive power from and communicate with to a surface system. The electronics subsystem generates RF signals which are provided to the antenna subsystem, generating radar wavefronts that are propagated toward areas of interest (e.g., farther downhole). The radar wavefronts may be electronically or mechanically steered in the desired direction. The antenna subsystem receives radar signals that are reflected back to the unit by features or conditions in the well. The received reflected signals are converted to electronic signals that are interpreted by the electronics subsystem of the radar unit or by the surface system to identify the features or conditions that caused the reflections.

Embodiments of the present invention use radar technology to detect features or conditions in a well. A radar unit having an electronics subsystem and an antenna subsystem is positioned downhole in the well. The radar unit is coupled receive power from and communicate with to a surface system. The electronics subsystem generates RF signals which are provided to the antenna subsystem, generating radar wavefronts that are propagated toward areas of interest (e.g., farther downhole). The radar wavefronts may be electronically or mechanically steered in the desired direction. The antenna subsystem receives radar signals that are reflected back to the unit by features or conditions in the well. The received reflected signals are converted to electronic signals that are interpreted by the electronics subsystem of the radar unit or by the surface system to identify the features or conditions that caused the reflections.

Method and system for developing reservoirs, such as hydrocarbon reservoirs or aquifers, including correcting pressure transient test data to account for variations of fluid density between a gauge depth and a mid-reservoir depth in a wellbore. Gauge depth pressure and temperature measurements, and density correlations are used to estimate mid-reservoir depth pressures, which can be used in a pressure transient analysis.

Method and system for developing reservoirs, such as hydrocarbon reservoirs or aquifers, including correcting pressure transient test data to account for variations of fluid density between a gauge depth and a mid-reservoir depth in a wellbore. Gauge depth pressure and temperature measurements, and density correlations are used to estimate mid-reservoir depth pressures, which can be used in a pressure transient analysis.

The present disclosure relates to a fluid level sensing system for sensing a fluid level in a well. The system has an upper housing in communication with a lower housing, with the lower housing having a first bore in communication with a fluid in the well, and a second bore isolated from the first bore and in communication with at least one of a vacuum gauge or an external vacuum source. The upper and lower housings house a first flexible bag and a second flexible bag, with the first bag housed within the second bag. A portion of the first bag communicates with the first bore and is responsive to a change in pressure within the first bore caused by a changing fluid level in the well. A portion of the second bag communicates with the second bore and exerts a reference pressure on the first bag. A sensing subsystem senses expanding and contracting movement of the bags and generates a signal indicative of a change in a level of the fluid in the well.

The present disclosure relates to a fluid level sensing system for sensing a fluid level in a well. The system has an upper housing in communication with a lower housing, with the lower housing having a first bore in communication with a fluid in the well, and a second bore isolated from the first bore and in communication with at least one of a vacuum gauge or an external vacuum source. The upper and lower housings house a first flexible bag and a second flexible bag, with the first bag housed within the second bag. A portion of the first bag communicates with the first bore and is responsive to a change in pressure within the first bore caused by a changing fluid level in the well. A portion of the second bag communicates with the second bore and exerts a reference pressure on the first bag. A sensing subsystem senses expanding and contracting movement of the bags and generates a signal indicative of a change in a level of the fluid in the well.

A system can identify a type of contamination for drilling fluid based on measured fluid properties of the drilling fluid and fluid properties of a reference drilling fluid. A system can measure a first plurality of fluid properties for a drilling fluid sample contaminated from a wellbore drilling operation. A system can select a predicted model in relation to one or more types of contamination by comparing the first plurality of fluid properties and a second plurality of fluid properties measured from a reference fluid sample. A system can analyze the first plurality of fluid properties and a third plurality of fluid properties generated from the predicted model to determine a first type of contamination in the drilling fluid sample.

Embodiments are directed to methods, systems and user interfaces for assessing reservoir management competency for a petroleum producing field. In one scenario, a computer system measures, using various hardware-based sensors positioned in a petroleum reservoir supplying the petroleum producing field, physical or geological characteristics of the petroleum reservoir. The computer system establishes a reservoir management competency scoring system that evaluates a specific set of objective criteria that reflect a level of reservoir management competency at the petroleum producing field, and automatically generates, according to the objective set of criteria of the reservoir management competency scoring system, a reservoir management rating for the petroleum reservoir based at least in part on data measured by the sensors placed in the petroleum reservoir. Then, based on the generated reservoir management rating, the computer system controls operation of production units configured to direct extraction operations at the petroleum producing field.

Embodiments are directed to methods, systems and user interfaces for assessing reservoir management competency for a petroleum producing field. In one scenario, a computer system measures, using various hardware-based sensors positioned in a petroleum reservoir supplying the petroleum producing field, physical or geological characteristics of the petroleum reservoir. The computer system establishes a reservoir management competency scoring system that evaluates a specific set of objective criteria that reflect a level of reservoir management competency at the petroleum producing field, and automatically generates, according to the objective set of criteria of the reservoir management competency scoring system, a reservoir management rating for the petroleum reservoir based at least in part on data measured by the sensors placed in the petroleum reservoir. Then, based on the generated reservoir management rating, the computer system controls operation of production units configured to direct extraction operations at the petroleum producing field.