2.1. Input parameters

To comprehensively address the issue of pipe sticking caused by wellbore uncleanliness, it is essential to consider various input parameters that significantly influence drilling operations. Understanding these parameters and their interplay is critical for developing effective mitigation strategies [Table 2].

Selected parameters and their category.

The larger the outer diameter of a drill pipe, the more friction it may encounter while drilling, making movement or rotation more difficult. This increases the possibility of pipe sticking during drilling operations.

The diameter of the bit can also affect pipe sticking in oil drilling operations. A larger bit diameter can result in more cuttings, increasing the risk of blockages and pipe sticking. It can also increase the torque needed to rotate the drill string, making it more prone to becoming stuck [17].

A larger stabilizer diameter can cause more drag on the drill string, making rotation more difficult and increasing the possibility of becoming stuck. It may also increase the possibility of borehole deviation [13].

JJR is the ratio of the total area of the drill bit opening to the total area of the bit. A low junk slot ratio increases the likelihood of cuttings buildup and blockages, which can lead to pipe sticking [24]. A high junk slot ratio can help to avoid this problem.

A high initial cutting volume fraction can lead to cutting buildup and blockages, increasing the risk of pipe sticking which is reduced using proper drilling fluid management [9].

Cutting's internal friction angle is defined as the angle at which they can rest on top of each other without sliding. Cuttings may slide and pack together as a result of a low internal friction angle, resulting in blockages and pipe sticking [9].

The coefficient of friction between cuttings and the drill string is determined by comparing the amount of force needed to move a cutting along the string with the amount of force pressing the cutting against the string. The chance of pipe sticking is raised when cuttings adhere to the drill string due to a high frictional coefficient. This issue can be avoided with careful management of drilling fluids [37].

The frictional coefficient between cuttings and the wellbore, is the ratio of the force required to slide a cutting along the wellbore to the force pressing the cutting against the wellbore. A high frictional coefficient can cause cuttings to stick to the wellbore, increasing the likelihood of pipe sticking [28].

The density of cutting represents the mass per unit volume of cuttings. Cuttings with higher density can settle and accumulate at the bottom of the wellbore, increasing the risk of blockages and pipe sticking [37].

If the drilling fluid's density is too high, it can exert too much pressure on the formation, resulting information damage and stuck pipe. However, if the density of the drilling fluid is too low, it may be unable to suspend cuttings and other solids, resulting in cutting accumulation and the risk of blockages [17].

The angle of repose is the natural angle at which a pile of loose cuttings will come to rest. If the angle of repose is too high, the cuttings will be less stable and more prone to sliding or settling in the wellbore, potentially resulting in blockages and stuck pipes. To maintain a low angle of repose, cuttings must be properly managed [26].

The frictional factors of torque and drag can cause pipe sticking during drilling operations. The frictional factor is the resistance that the drill string encounters as it rotates and moves through the wellbore. If the frictional factor is too high, the torque and drag on the drill string will increase, increasing the risk of pipe sticking. Wellbore geometry, drilling fluid properties, drill string design, and operating conditions are all factors that can contribute to a high frictional factor. Proper torque and drag management is critical for minimizing frictional factors and lowering the risk of pipe sticking [16,17,35].