Summary A real-time method is presented to predict impending stuck pipe with sufficient warning to prevent it. The new method uses automated analysis of real-time modeling coupled with real-time data analysis. It can be applied to all well types for any well operation, including drilling, casing running, completion activities, and re-entries. The method uses leading indicators of stuck pipe that were identified by use of historical data sets of 36 stuck-pipe incidents in the Eagle Ford, Utica, and Permian and in the Gulf of Mexico. Two case histories show the utility of the new method in shale and carbonate horizontal wells for both drilling and off-bottom operations. The new method combines two types of analysis: use of hydraulics and torque-and-drag (T&D) software to determine deviation of real-time data from the real-time model, and trend analysis (i.e., rate of change) of real-time data. Parameters used are pump pressure, flow rate, torque, rotary speed, hookload and drag, and weight on bit (WOB), along with static inputs such as bottomhole-assembly (BHA) and drillstring configuration and directional surveys. Additional parameters, such as downhole equivalent circulating density (ECD), are used when available and improve the results. But the method is designed to monitor all well types and provide a stuck-pipe-risk log even by use of only basic instrumentation. A novel algorithm predicts the probability of stuck pipe, which is presented in a real-time log. Results demonstrate that there is no single leading indicator in all stuck-pipe incidents. Our early-detection method, called the stuck-pipe-risk (SPR) log, relies on multiple indicators to strengthen the likelihood of detecting impending stuck pipe while avoiding false alerts. A key element to automating the process is the use of filtering for rig activity. The first indicator is deviation of actual data from model predictions. A second indicator is trend analysis (specifically, rate-of-change calculations), which provides valuable insight into rapidly deteriorating wellbore conditions when deviation from model predictions does not respond quickly enough over a short depth or time interval. Results are presented that show the SPR-detection method successfully detected impending stuck pipe on four historical shale wells an average 38 minutes before sticking and on one historical carbonate well more than 2 hours before the event. No false alerts were recorded in these wells. These results were viewed as meeting the initial goal of providing relevant alerts with sufficient time to prevent the pipe from becoming stuck.

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This paper will present the evolution of a third-generation, point-the-bit rotary steerable system (RSS) and its successful application for air drilling of directional wells and lateral intervals.There are a number of applications for air drilling; the primary one is obviously to drill hydrostatically underbalanced where extremely low bottomhole formation pressures are encountered. In certain circumstances, the requirement to have a very small rig footprint makes drilling with air preferable to drilling with mud systems.The engineering requirements for drilling with air obviously differ from more conventional drilling fluids. Pressure integrity of the mechanical components of the RSS device has to be sufficiently robust to withstand more extreme differential pressures. This paper will describe the steps in the evolution of the RSS design to accommodate this requirement and other functionalities of the system.Transmission of downhole information drilling with dry air necessitates effective communication of data via electromagnetic (EM) wave in the absence of the medium for conventional mud pulse telemetry (MPT). The timeline over nine years to integrate basic EM with more high-end LWD and steering devices is illustrated (Fig. 1). Optimization of controllable constraints to extend the reach of acceptable EM transmission is addressed.Results of successful deployments on over twenty bit runs so far will be demonstrated, along with a step-change in tool reliability delivered. Performance improvements were achieved using the surface output of the existing rig fleet without modifications. Lateral reach capability was extended, largely due to improved hole quality over the air motor drilling system used previously. This delivered greater production footage from fewer wellbores as well as the increased ability to reach topographically constrained payzones.

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