Poor drilling performance can lead to increased costs when enhanced drilling performance and extended reach are the main goals for oil operators. Service companies, using the latest technology, can achieve these objectives. A rotary steerable system (RSS) with advanced motor technology provides significant performance improvements. In addition to the improved drilling performance, the advanced system enables extended reach drilling to wells that were previously beyond the limits of a project.This paper presents the advances in motorized RSS technology and bottom-hole assembly (BHA) design considerations that provide increased drilling performance, thereby enabling faster well delivery and extended drilling. In addition, the authors examine ongoing initiatives aimed at reducing drilling risk (vibration and torque) and optimizing well placement.The motorized RSS technology has been used in many applications, including open hole side tracking, whipstock drill-off, cement plug side tracking and horizontal section drilling. In most instances, the technology demonstrated the capacity to deliver better penetration rates and directional control that outperformed conventional directional drilling systems. Using a motorized RSS BHA to drill-off the whipstock saved rig time by eliminating one trip in each offshore oil lateral. In addition, the nearly 25.6% improved rate of penetration (ROP) was one

Drilling complex wells with minimum risk and optimizing well placement with the least possible cost are key goals that oil companies strive to achieve. Service companies and operators apply several pre-well planning processes and methods to enhance drilling operations effectively and attain objectives. One of these processes involves a thorough understanding and application of the geological structure, not only within the reservoir section, but also in the over-burden where typically most of the time efficiency gains can be achieved. This can be best accomplished by fostering intense and effective communication between all stakeholders. In this paper, the authors present the latest integrated pre-well planning (IPWP) process that defines a methodology for conducting a formal planning, a process incorporating all aspects of drilling, well design, formation evaluation, bit selection and bottom hole assembly proposal. It also lists key considerations required in planning, coordination, and successful implementation of these services on the customer’s well with a means to assess potential technical risks that may influence the success of the job. The paper also describes a complex water injection well drilled in a Middle East onshore field where the integrated pre-well-planning process played a significant part in successfully achieving the aim of this challenging job.

There are always challenges associated with drilling and therefore continuous improvement of drilling programs to be in accordance with proper geological and petroleum fluids conditions is critical. Failure to do so may cause unplanned operational time also known as Non-Productive Time (NPT). Time lost during drilling in the form of NPT is a great ordeal of oil companies causes of which include equipment failure, stuck pipe or even poor decision making to mention a few. Hence, study of NPT and making risk registers for individual wells and sections drilled in a particular reservoir or field can aid in future drilling operations by lowering the severity and also reducing the probability of those NPT incidents. The objective of this paper is to study and analyze the different drilling activities extracted from the Saudi Aramco Drilling Knowledge (SADK) database to identify the critical mistakes occurring during drilling so that they can be avoided in future drilling operations making the drilling program more enhanced and efficient. This was achieved by adopting an innovative way of benchmarking wells, creating drilling activity charts and risk registers. The paper is supported by an actual case study from fifteen wells in Manifa field drilled during the field development plan of Manifa oilfield. Manifa field is located offshore and many problems were faced during the drilling activities and most of those problems were unexpected. The results of analysis revealed that the major problems causing NPT are well control, stuck pipe and bottom-hole problems. The mitigation of such risks or problems is also presented in this paper.

Over the past 20 years in the Middle East Region, the performance of Underbalance Coiled Tubing Drilling (UBCTD) has significantly improved, with regular use in several areas. Improvements in application selection, drilling technologies & procedures have also helped to expand the scope of available reservoir targets. Widening the available choice of down hole tools is one main factor that has led to an improvement in drilling performance and one such technology is the 2 7/8" downhole turbine drive motor (turbine). Historically, the choice of turbines for UBCTD had been restricted to harder formations but for over a decade now, turbines have been used in these UBCTD applications in KSA – consistently producing steady drilling performance and meeting well objectives. In a recent bid to optimize drilling performance, a newly designed high-power 2-7/8" downhole turbine was introduced for KSA in 2018. This new turbine utilized in varying downhole environments, from hard and abrasive sandstone to the typically targeted carbonate reservoirs. Trials were performed in varying downhole temperatures to evaluate the performance improvement. Today this turbine has shown a visible improvement in both performance and reliability compared to the alternative turbine options. The new turbine design integrated with existing MWD technology in order to execute the drilling operation in UBCTD with higher drilling efficiency and better economic returns. In order to establish performance improvements, a set of success indicators was established: Power delivery efficiency. Performance in varying reservoirs Turbine and MWD tool Reliability Directional drilling performance Downhole tool vibration monitoring. These success indicators were closely monitored during 2018 and the results revealed a significant increase in overall footage drilled. BHA reliability also improved. From these two major factors, the utilization of 2 7/8" downhole turbines have significantly increased.