Casing running has historically been recognized as one of the most inefficient and dangerous processes on drilling rigs. Conventional methods carry with them a substantial equipment and personnel burden. This burden results in lengthy rig up/down times, a crowded rig floor and is often responsible for a variety of injuries and occasional fatalities. Recently, Casing Running Tools are being utilized that reduce equipment and personnel required on the rig, advancing the industry toward a safer, more efficient casing running process. Casing Running Tools greatly reduce the equipment needed to run casing by incorporating many functions into one tool. Less equipment utilizing more intuitive procedures reduces the amount of rig up and rig down time. Both hydraulic and mechanical tools are currently available to the industry. Hydraulically operated tools require a "Hydraulic Power Unit" (HPU) and an operator on the rig floor to control the CRT's operation. Mechanical tools are more compact, do not require HPU's and place complete control of the tool and the casing running in the hands of the onsite driller. For this reason, a mechanical tool was selected for this string. This paper will cover the results of the run in terms of tool efficiency, tool efficacy, safety, and TRS footprint. Tool efficiency will be compared between a mechanical casing running tool and conventional methods, in terms of rig-in times and run times. This will include considerations between efficiency at the beginning of a run and expected efficiency gains near the end of the run. Efficacy will be discussed in the context of the tool's ability to satisfy its desired function. This is less directly measured but will include input from rig personnel and measurable components such as connection reports. Arguably the most important benefit will be recognized in equipment and personnel requirements, and this paper will discuss the differences in conventional services and the use of a mechanical CRT using conventional services as the baseline for comparison. The discussion concludes with an outline of the benefits realized by the operator, service-company, and other rig personnel. This publication reviews the first application of a fully mechanical CRT in Kuwait to run a string of casing with premium threads. This is also the first 630-ton casing string run with a mechanical casing running tool in the Middle East Region. A newly developed wireless Torque Turn Sub that matches the hoist and torque capacity of the CRT was also used to monitor and record the torque on the premium threads.

Realtime Wellbore cleaning and stability Monitoring Service has been deployed in the field, where several side-track wells had been drilled due to stuck pipe and consequent lost in hole equipment. Traditional drilling practices were to drill highly deviated wells with inconsistent ROP without having sufficient information about the borehole condition and with the narrow pore pressure margin, which regularly resulted in sustained losses, even leading to differential sticking. In addition to these challenges, the well geometry made it necessary to constantly maintain sufficient ECD sensitive to borehole condition. The service consists of Advance cutting flowmeter measuring cumulative bulk solids recovery while drilling, along with sophisticated software application compensating for drilling fluid coating the cutting. The real-time delta between actual and expected cutting volumes in surface is therefore a direct indicator of borehole cleaning efficiency and thus compared with various drilling and hydraulics parameters to provide timely operational recommendation, optimizing drilling performance and pre-empt potential causes of NPT/ILT. The service is successfully determining the maximum allowable ROP in relation to cutting recovery, optimizing the number of drilling fluid pills, and supporting torque and drag analysis including cutting effects to give early indication of potential stuck pipe. This has reduced the on-bottom circulation cycles, reaming time and tripping intervals; thus allowing to drill longer deviated or horizontal sections avoiding tripping to clean the borehole. As a result, operator was able to drill the wells optimally; saving 3.5 days of rig time, and about 50% of the pill volume for each well. The total cost saving for 5 wells, with the service deployed mostly in 6" production section was USD – 1.075 Million. The solution has then deployed across multiple rigs, drilling similar challenging wells.