This project drilled in Sin Phu Horm field. The main challenge in this field is the formation. The 8.5-in section is designed to drill through the hard and abrasive sandstone formation (known as Nam Phong formation) with unconfined compressive strength (UCS) between 6,000 and 24,000 psi and peak up to 55,000 psi. Multiple bit runs and heavy set of Polycrystalline Diamond Compact (PDC) bits were observed in the offset wells with slow rate of penetration (ROP) and short intervals, which resulted in a high drilling cost. In the offset runs, the average interval was observed between 200 and 300 meters and average on-bottom ROP ranged from 2 to 8 m/hr. Worn cutters were the main dull characteristic in the offset PDC bits and the bits were pulled out of hole due to slow ROP. Due to the challenging formation, the goal was to increase the interval per bit run and ROP which resulted to reduce the number of bit trips and drilling cost. Looking at the dull grading of the offset PDC bits, it was obvious that the slow ROP was caused by the cutters worn by the abrasive and hard Nam Phong formation. The fixed-cutter PDC bits were run in the offset wells and worn cutters were observed in the shoulder area. The worn portion of the cutter occurred only in the exposed side, while the portion in the cutter pocket remained intact. Utilizing the portion in the cutter pocket helps to prolong cutter life, increase the ROP, and bit life longevity. Thus, it can help to reduce undesired bit trips. Based on the worn cutter observation, the new design of the 8.5-in PDC bit equipped with innovative 360 rolling cutter (RC) bit was proposed. A comprehensive vibration simulation drilling parameters roadmap were provided to minimize shock and vibration. Two bits were run with rotary steerable BHA to drill Nam Phong formation in the field. The first bit drilled 431 meters at an average ROP of 6.8 m/hr and the second bit drilled 391 meters at an average ROP of 5.5 m/hr. Two runs using the 360 RC bits drilled 822 meters in total of 1,236 meters entire interval of Nam Phong formation, which was equivalent to 66%, achieving the operator's goal while saving 2.2 days solely from two runs of RC bit. This success increased the operator's confidence to run 360 RC bits in the subsequent wells to reduce the number of bit trips and increase the ROP. This paper will discuss the application and evolution of 360 RC bit, along with the result achieved by the bit fitted equipped with this cutter in Thailand onshore.

Oil and gas remote operations (RO) enabled by automation and digital solutions are reducing the number of people required to work in the wellsite; many subject matter experts can now complete their daily tasks from the safety of the office in town. We have been transitioning to these new ways of working for some time, and the progress has been greatly accelerated to help ensure business continuity for customers during COVID-19 restrictions, allowing high numbers of wellsite operatives the freedom to work from home. For the Oil & Gas companies that have experimented with more technology, the results have been incredible. Digital transformation has finally hit the industry and it’s taking off to meet sustainable goal of upstream companies, this transformation is one such measure by which these goals can be approached. Despite the global availability of technology to handle analytical task from a safe distance, substantial drilling activities have been carried out traditionally across globe. Such traditional drilling operations were carried out in Thailand where client and SLB work together in fast paced factory drilling environment where an oil well can drill and complete within 7 days for 2 strings (2-sections only) 2400-2600 m in onshore operation which requires experienced people to monitor and execute tasks. To support such operation from town i.e., remotely with systematic monitoring by skilled people, one requires to adapt digitization. This paper demonstrates the ability of SLB to adapt the digital environment by introducing "Remote Operation Center" setup enabling to help client achieve their sustainable goals within budget and provided an alternate solution to sustain operations in COVID-19 pandemic. Remote Operations is the ability to operate a system or a machine at a distance; one can handle multiple operations from a safe environment of office in town using technology. It unfolds analytical task & physical task; the former is handed over to Remote Operation Center and physical task is left at rig crew. The Remote Operation Center execute both Directional Drilling (DD) and Measurement & Logging While Drilling (MLWD) services at the well site, from town. Executing Directional Drilling Remote Operation was more challenging. RO moves industry towards future and pushes all other traditional players to work on sustainable goals while adapting to digital environment. On site presence of crew was reduced by 50% while maintaining same pace of operations with better data analysis.

Under the background of optimizing project costs and decreasing carbon footprint, CNOOC launched a campaign strategically to explore new offshore records. This paper records how the pilot project of this campaign achieved remarkable success to dramatically decrease operation cycle time and reduce drilling waste discharge with the help of technological innovation and advanced project management. The innovation to improve drilling efficiency starts from well designing phase. Wellbore geometry is optimized and downsized to smaller hole size to improve drilling rate and reduce drilling waste. A series of innovative modifications are made on both the rig operating equipment and the work process to reduce the operation time. Novel technologies are utilized to reduce drilling cycle time including industry's first definitive dynamic survey-while-drilling service, realtime drilling intelligence service, pulse neutron generator (PNG) enabled multi-function logging while drilling (LWD) platform, and so on. Bit and motor are both optimized to increase drilling speed. To reduce the waste discharge during drilling and completion, a fully closed zero discharge system is employed. Flawless project management also played vital role in the project success. Totally 23 wells are drilled for this pioneer project. 269.80 days are saved compared with plan and drilling efficiency is improved by more than 58%. Wellbore geometry optimization saves 111.63 days drilling cycle time and reduces 3189 tons waste. 25.94 days are saved by utilizing advanced measurement while drilling (MWD) tool and LWD technologies. More than 14 days are saved by innovative modification on the rig equipment. At least 7 days are saved through optimizing the work process. With the fully closed zero discharge system, 2414 cubic meters drilling fluid is reused and 7040 tons cutting are processed. This project breaks several drilling records in CNOOC. The novelty of this paper is to provide experiences of utilizing most up-to-date technologies and innovative systematic approach to reduce the drilling cycle and carbon and waste discharge.

Mubadala Petroleum conducts a fast-paced drilling program in the Gulf of Thailand, where rapid response resolutions are often required. This paper demonstrates the Remote Operation (RO) approach, which is an integrated approach comprised of people, software, network, and technology to transform operations, and moves analytical activities to safer office-based environments (Figure 1). The approach provides a high level of performance, leveraging global domain expertise, real-time collaboration, data visualization techniques, and intelligent planning within the restrictive context of the COVID-19 pandemic. Figure 1 Remote Operation relevant function RO is the ability to operate a system at a distance. This is an adopted innovation and technology in the oil and gas industry, which is a completely new way of working. The principal concept for introducing the RO approach was to reduce the Personnel on Board (POB) and the HSE exposure, which was particularly relevant during the outbreak of the COVID-19 pandemic. The approach relied on leading-edge digital technology, as the RO was required to handle real-time directional drilling (DD), measurements, and logging while drilling (MLWD). During the implementation, the crew was trained in multi-skilling related to the DD/MLWD function, while working with the necessity of digital technology. Digital transformation is emerging as a driver of sweeping change in the world around us. Today, the Oil and Gas industry has redefined its boundaries through automation and digitalization. The potential benefits of going digital are clear, including increased productivity, safer operations, and significant cost savings. This exercise, it allowed us to reduce the POB on-site by 40% while maintaining both drilling efficiency and service quality. The drilling data can be monitored in real-time. The Remote Operation Center (ROC) has the capacity to execution and montor directional drilling, formation evaluation, programming, and dumping data from various tools. An experienced crew were assigned to the RO team ensuring competencies and familiarity with drilling operation in specific field characterization. This transformation supported our business continuity objectives by reducing the number of people traveling offshore during the COVID-19 pandemic while allowing us to achieve all our drilling performance objectives. In this new environment, following the turmoil of pandemics, this exercise indicates an opportunity to make fundamental improvements to the way business is conducted using the Remote Operations approach. RO takes a significant step towards the future for highly traditional industry. Preparing the industry toward the future may prove to be the most important outcome of the application of RO during the COVID-19 pandemic. The application of RO during the COVID pandemic has confirmed the possibility of more permanent improvements and increased resilience against future pandemics and other challenging events, as well as a new and more effective way of working during normal times.

Mid Nam Phong Formation in Thailand’s Sinphuhorm Field consists of hard and abrasive sandstone with unconfined compressive strengths (UCS) of 12,000–24,000 psi. Polycrystalline diamond compact (PDC) drill bits used for the 8.5-in. section through this formation were providing low rates of penetration (ROPs) and showing heavy wear, with just 50–180 meterage drilled per run. Multiple bit runs were raising drilling costs. A new drill-bit design to address these challenges is presented. Rolling cutter (RC) 616—an 8.5-in. drill bit with 16 mm cutters that rotate 360°—is holding the ROP record in offset wells, delivering 3.1 m/h compared with the average 2.15 m/h, a 44% improvement. Rolling elements use the entire circumference of the cutting edge to cut the formation, enabling them to stay sharper and longer. Conical diamond elements (CDE), which provide improved impact strength and greater resistance to abrasive wear, replaced some of the conventional cutters. Based on this result and lessons learned, a new and more robust bit design was proposed featuring 19 mm rolling cutters and conical diamond elements. To combat the damaging vibration observed in offset wells, which could further reduce ROP and increase the likelihood of premature drill-bit and downhole tool failure, a special bottom hole assembly that combined a rotary steerable system and a downhole motor was deployed to reduce stick/slip. Comprehensive simulations provided a detailed road map of drilling parameters that were used to minimize shock and vibration. The new 8.5in. drill bit and BHA drilled the entire section through the Mid Nam Phong Formation in one run and at a record ROP of 4.9 m/h—58% higher than the maximum rate achieved by the RC616 bit—saving 57.8 hours. The assembly also drilled an additional 179 meterage into the Lower Nam Phong Formation, eliminating the separate bit run that had been required in offset wells. The customer saved 2.9 days or USD 130,000 in total and a new standard of drilling performance was established. The new concept of PDC bit combining 19 mm rolling cutters and conical diamond elements expands the limit of PDC bit durability drilling hard and abrasive sandstone formation. This new type of bit can efficiently drill in those challenging geological condition reducing the drilling time and cost. This paper will discuss the application and evolution of rolling cutter bits, along with the results achieved by this bit.