Abstract: A method may include obtaining a plurality of historical drilling signals for a plurality of wells and generating a plurality of drilling parameters from the plurality of historical drilling signals of drilling activities of the plurality of wells into one real-time database of a computer processor. The method further includes applying Fourier Transform to decompose a plurality of functions into the plurality of drilling parameters and determining an optimum drilling parameter based on one or more optimized drilling parameters. The method further includes recomposing the plurality of functions to automate drilling activities for new wells by generating trends of the one or more optimized drilling parameters and using the trends in the drilling activities. The method further includes creating Key Performance Indexes (KPIs) for the plurality of optimized drilling parameters to evaluate performance and monitor the drilling activities in real time using machine learning algorithms.

Abstract: A portion of a wellbore is put into communication or is isolated by selectively applying an axial or rotational force downhole. The axial force moves a shifting sleeve and deployment sleeve from an initial position to an opening position causing a valve element to move into an open configuration and allowing communication to the portion of the wellbore. The shifting sleeve is returned to the initial position and separated from the deployment sleeve, which is anchored to a retraction sleeve adjacent the valve element. Threads on the shifting and retraction sleeves become engaged when the deployment sleeve is moved to the opening position. The retraction sleeve is rotated by rotating the shifting sleeve, threaded engagement with the rotating retraction sleeve draws the deployment sleeve away from the valve element, and allows the valve element to move to a closed configuration.

Abstract: A portion of a wellbore is put into communication or is isolated by selectively applying an axial or rotational force downhole. The axial force moves a shifting sleeve and deployment sleeve from an initial position to an opening position causing a valve element to move into an open configuration and allowing communication to the portion of the wellbore. The shifting sleeve is returned to the initial position and separated from the deployment sleeve, which is anchored to a retraction sleeve adjacent the valve element. Threads on the shifting and retraction sleeves become engaged when the deployment sleeve is moved to the opening position. The retraction sleeve is rotated by rotating the shifting sleeve, threaded engagement with the rotating retraction sleeve draws the deployment sleeve away from the valve element, and allows the valve element to move to a closed configuration.

Abstract: A downhole tubing joint assembly may have a first tubular and a second tubular axially movably disposed within the first tubular. The second tubular may have an initial position, a free-moving position, and a locked position. Additionally, at least one shear pin may be disposed between the first tubular and the second tubular. The shear pin may hold the second tubular in the initial position and is configured to shear upon application of a predetermined force. Further, a locking device may couple the first tubular and the second tubular together in the locked position. Furthermore, a cable may be connected to the first tubular. The cable may provide power to downhole tools. The cable is folded when the second tubular is in the initial position, and is extended when the second tubular is in the locked position.