The disclosure presents processes and methods for determining an overpull force for a stuck drill string in a borehole system. The fluid composition of a mud in the borehole at a specified depth can be broken down into a percentage of liquid and percentage of solids, as well as adjusting for material sag and settling factors. The fluid composition can be utilized to identify friction factors and drag in respective fluid composition zones. Each friction factor and drag can be summed to determine a total fluid drag on the drill string. In some aspects, the total fluid drag can be adjusted utilizing the relative positioning of casing collars and tool joints. The total fluid drag can be summed with the other force factors, such as a shear force and mechanical drag. The total drag can then be utilized as the overpull force applied to the stuck drill string.

Techniques for plugging at least one zone of a hydrocarbon well are disclosed herein. The techniques include methods for deploying a wellbore dart configured for plugging the at least one zone of the hydrocarbon well, receiving, by a first node, location information indicating a first location of the wellbore dart, receiving, by a second node, location information indicating a second location of the wellbore dart, and detecting, an arrival of the wellbore dart at an intended location for the dart to plug the zone of the hydrocarbon well. In some aspects, the method further includes sending a command to a firing module of the wellbore dart, the command effective to cause the wellbore dart to plug the zone of the hydrocarbon well. Systems and computer-readable media are also provided.

Techniques for plugging at least one zone of a hydrocarbon well are disclosed herein. The techniques include methods for deploying a wellbore dart configured for plugging the at least one zone of the hydrocarbon well, receiving, by a first node, location information indicating a first location of the wellbore dart, receiving, by a second node, location information indicating a second location of the wellbore dart, and detecting, an arrival of the wellbore dart at an intended location for the dart to plug the zone of the hydrocarbon well. In some aspects, the method further includes sending a command to a firing module of the wellbore dart, the command effective to cause the wellbore dart to plug the zone of the hydrocarbon well. Systems and computer-readable media are also provided.

A crossbore detection system. The system is located in a downhole tool proximate a drill bit. The system comprises circuitry sensitive to a subsurface environment and a sensor that detects changes in the circuitry. The sensor detects changes in the circuitry that indicates that the drill bit has struck an underground pipe. The sensor may detect a series of electromagnetic signals indicative of the strike or may detect changes to an impedance bridge at a capacitive sensor.

An apparatus and method for measuring position and magnitude of downhole mechanical friction. The apparatus comprises sensors that reside along, or in-line with, a section of equipment that is installed or removed from a wellbore. The sensing device is configured measure relative to the wellbore during a work-over or other well intervention procedures where said section of equipment (tubing, rods, drill pipe, etc.) is installed in, or removed from, the wellbore. Recorded measurements are then processed to correct for dynamic forces to provide a measure of friction through the portions of the wellbore where said equipment travels. The sensing can be done near the source of friction, or at some distance through a mechanical connection. A method for determining depth and magnitude of downhole friction is also provided. Additionally, a method for applying the map of wellbore friction to the design and analysis of a rod actuated pump is presented.

An apparatus and method for measuring position and magnitude of downhole mechanical friction. The apparatus comprises sensors that reside along, or in-line with, a section of equipment that is installed or removed from a wellbore. The sensing device is configured measure relative to the wellbore during a work-over or other well intervention procedures where said section of equipment (tubing, rods, drill pipe, etc.) is installed in, or removed from, the wellbore. Recorded measurements are then processed to correct for dynamic forces to provide a measure of friction through the portions of the wellbore where said equipment travels. The sensing can be done near the source of friction, or at some distance through a mechanical connection. A method for determining depth and magnitude of downhole friction is also provided. Additionally, a method for applying the map of wellbore friction to the design and analysis of a rod actuated pump is presented.

A measurement device for a core drilling tool, the measurement device comprising: one or more data acquisition portions, and a housing portion configured to receive the one or more data acquisition portions, wherein the measurement device is adapted for removable connection to the backend assembly of the core drilling tool.

A measurement device for a core drilling tool, the measurement device comprising: one or more data acquisition portions, and a housing portion configured to receive the one or more data acquisition portions, wherein the measurement device is adapted for removable connection to the backend assembly of the core drilling tool.

Methods determine a state of a well and comprise: receiving a set of well operations data comprising at least some measured well operations data; determining the occurrence of a well operations event based on the received data; evaluating one or more possible state transitions from a current well operations state to one or more possible new well operations states, the current state and the possible new states selected from a configurable plurality of well operations states, wherein evaluating the one or more possible state transitions is based on the current state, the determined event and the received data and wherein evaluating the one or more possible state transitions comprises determining a confidence level associated with each of the possible new states; and determining one of the possible new states to be a new predicted well operations state according to whichever possible new state has a highest confidence level.

A method may include obtaining first pressure data regarding a first pressure sensor upstream from a restricted orifice and second pressure data regarding a second pressure sensor downstream from the restricted orifice. The method may further include obtaining temperature data regarding a temperature sensor coupled to the restricted orifice. The method may further include obtaining various gas parameters regarding a predetermined gas flowing through the restricted orifice and various orifice parameters regarding the restricted orifice. The method may further include determining a first gas flow rate of the predetermined gas based on a gas flow model, the first pressure data, the second pressure data, the temperature data, the gas parameters, and the orifice parameters.