T The drilling process in the upstream oil and gas industry is a critical, dynamic, and high-risk operation. during drilling, the drill bit penetrates various geological formations with different rock characteristics and formation pressures at each depth. these conditions frequently lead to technical challenges in the field, one of the most significant being stuck pipe, a condition in which the entire drill string cannot be moved either axially or rotationally. this study specifically investigates a stuck pipe incident in bomber 4 well, field s, during the drilling of the 8.5-inch hole section at a depth of 1,744 mmd/1,661 mtvd. the objective of this study is to determine the mechanism responsible for the stuck pipe incident in bomber 4 well and to formulate effective technical mitigation measures. specifically, the study aims to identify the primary root cause of the stuck pipe event and to evaluate the most appropriate operational method for releasing the stuck drill string.the research employed an analytical evaluation using secondary data obtained from the daily mud report (dmr) and daily drilling report (ddr). the collected data included mud weight, viscosity, yield point, annular flow velocity, hole size, drill string outside diameter, and pump flow rate. these parameters were analyzed using three stuck pipe evaluation approaches. first, differential sticking was evaluated based on a pressure differential criterion of greater than 500 psi between hydrostatic pressure and formation pressure. second, well pack-off was assessed using the cutting carry index (cci), where an index value below 1 indicates inadequate hole cleaning. third, wellbore geometry was evaluated using well trajectory parameters to identify the presence of key seating.the results indicate that the stuck pipe incident in the 8.5-inch hole section of bomber 4 well at a depth of 1,744 mmd produced a pressure differential of 275.76 psi, which is below the 500 psi threshold, indicating that differential sticking did not occur. the cutting carry index ranged from 5.83 to 26.87, demonstrating that well pack-off was not the cause of the incident. further evaluation of the wellbore geometry revealed significant trajectory changes that resulted in the formation of a key seat. the primary cause was a mechanical failure of the measurement while drilling (mwd) tool, which generated incorrect and erratic directional data that deviated from the planned well trajectory. consequently, the drill string continuously rotated through a sharp dogleg, causing sustained contact between the tensioned drill pipe and the borehole wall. this continuous friction eroded the borehole wall and formed a narrow groove (key seat). during the trip-out operation, larger-diameter bottom-hole assembly components, particularly the drill collar (dc), became mechanically lodged within the groove, resulting in mechanical sticking.the mitigation strategy was implemented through several operational stages. the first stage focused on hole cleaning by circulating drilling fluid at a flow rate of 588 gpm (pump rate variation of 500–570 gpm with pump pressures ranging from 1,520 to 1,860 psi) while pumping three cycles of high-viscosity sweep (10 bbl and 30 bbl), followed by 41 upward jarring operations (jar up) and seven downward jarring operations (jar down) on the first day. the second stage involved circulating the primary kcl polymer drilling mud with a density of 9.2 ppg at a flow rate of 530 gpm and a pump pressure of 1,550 psi, followed by pumping 40 bbl of solids-free kcl brine spotting fluid into the annulus over a 100 m interval above the bottom of the hole. mechanical jarring operations were then continued until a cumulative total of 64 jar-up and 16 jar-down operations had been performed. the final stage consisted of pumping a lubricating spotting fluid composed of 4,300 l of diesel, 10 bbl of water, 65 sacks of barite, and two drums of pipe free to the bottom of the well. the drill string was subsequently soaked while applying a constant torque of 17,000 lb-ft, with periodic dynamic torque increases up to 18,651 lb-ft every 30 minutes. through the combination of lubricant soaking and high-torque working, the stuck drill string was successfully released and the operation was completed by performing a back-reaming procedure.