In some embodiments, a method operates a heat pump that uses a ground loop to perform heating or cooling in a site. During the operating of the heat pump over a time period: the method measures a first series of measurements of a ground loop water flow rate by the heat pump; a second series of measurements of a ground loop fluid temperature for the heat pump; and measures a third series of measurements of a local soil or deep earth temperature. The first measurement, the second measurement, and the third measurement are outputted where a ground loop thermal resistance value is calculated for the heat pump based on the first measurement, the second measurement, and the third measurement.

In some embodiments, a method operates a heat pump that uses a ground loop to perform heating or cooling in a site. During the operating of the heat pump over a time period: the method measures a first series of measurements of a ground loop water flow rate by the heat pump; a second series of measurements of a ground loop fluid temperature for the heat pump; and measures a third series of measurements of a local soil or deep earth temperature. The first measurement, the second measurement, and the third measurement are outputted where a ground loop thermal resistance value is calculated for the heat pump based on the first measurement, the second measurement, and the third measurement.

This invention relates to the oil and gas production industry and can be used in geophysical surveys of horizontal and deviated (including vertical) wells for their injectivity profiling and assessment of total fluid loss into the lower zone of a target interval, inaccessible for survey, and below the bottom hole. The proposed technology can be used in the presence of both behind-casing and wellbore cross-flows.

This invention relates to the oil and gas production industry and can be used in geophysical surveys of horizontal and deviated (including vertical) wells for their injectivity profiling and assessment of total fluid loss into the lower zone of a target interval, inaccessible for survey, and below the bottom hole. The proposed technology can be used in the presence of both behind-casing and wellbore cross-flows.

An integrated and rigless method of determining the location and the type of damage in casing or tubing of a wellbore that involves recording a thickness profile of the casing or tubing, a temperature log, and a noise log along the depth of the wellbore, followed by locating the damage from the thickness profile, and determining the type of damage from the temperature log and the noise log.

A partially dissolvable plug is to be deployed in a position in a wellbore formed in a subsurface formation. The partially dissolvable plug comprises a first portion comprising a dissolvable material that is to dissolve over time after exposure to a downhole ambient environment in the wellbore and a second portion comprising a non-dissolvable material that is to create a flow restriction as the flow of fluid passes through the partially dissolvable plug. The first portion is to prevent a flow of fluid from downhole to a surface of the wellbore until at least a portion of the dissolvable material is dissolved. A flow rate is to be determined based on a detected change in a downhole attribute that is to change in response to the flow of fluid passing through the partially dissolvable plug after at least a portion of the partially dissolvable plug is dissolved.

A partially dissolvable plug is to be deployed in a position in a wellbore formed in a subsurface formation. The partially dissolvable plug comprises a first portion comprising a dissolvable material that is to dissolve over time after exposure to a downhole ambient environment in the wellbore and a second portion comprising a non-dissolvable material that is to create a flow restriction as the flow of fluid passes through the partially dissolvable plug. The first portion is to prevent a flow of fluid from downhole to a surface of the wellbore until at least a portion of the dissolvable material is dissolved. A flow rate is to be determined based on a detected change in a downhole attribute that is to change in response to the flow of fluid passing through the partially dissolvable plug after at least a portion of the partially dissolvable plug is dissolved.

Apparatus for use in sensing temperature in a wellbore, comprising: tubing comprising a plurality of temperature sensor modules provided at locations along the inside of the tubing, said temperature sensor modules comprising temperature sensors provided at least in part by at least one semiconductor element having electrical properties that vary with temperature; an electrical network configured to electrically connect to the semiconductor elements to in use allow measuring of the respective electrical properties of the semiconductor elements to infer a thermal characteristic of the semiconductor element; and at least one control module electrically connected to multiple temperature sensor modules, via the electrical network, and configured to receive and process an electrical signal associated with the temperature sensor modules to enable inference of the temperature of the semiconductor elements and the environment to which the tubing is exposed at the location of that semiconductor element.

A method for controlling downhole fluid flow in multi-lateral solution mining may include forming a solution mining production well with a plurality of horizontal laterals drilled from a surface to connect and intersect with a horizontal or vertical injection well; and installing a downhole flow control device at the intersection of the horizontal injection well and each of the horizontal laterals. The downhole flow control device may be capable of being adjusted to distribute injection flow as desired through the horizontal laterals. The downhole flow control device may be a sliding sleeve capable of ranging from fully open to full closed to control flow from the injection well into multiple locations within the mineralized zone.

Provided are methods and systems for monitoring and modifying stimulation operations in a reservoir. In particular, the methods and systems utilize a downhole telemetry system, such as a network of sensors and downhole wireless communication nodes, to monitor various stimulation operations.