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The current low oil price environment has driven a renewed focus on managing costs while minimizing exposure to operational risk, and lightweight well intervention activities have not been exempt from this scrutiny. Electric line (E-line) and conventional slickline are important and frequently used tools for light well intervention operations, and are often used at different times during the same well intervention program, leading to multiple rig-ups and rig-downs of the equipment, as well as the requirement to transport both units to the platform. This paper presents a case study of the use of digital slickline technology to perform typical slickline and typical electric line operations with the same digital slickline unit, thus saving costs and reducing risk by eliminating some rig up/rig down activities, minimizing equipment handling, and downscaling crew size. Mubadala Petroleum performs rig less activities similar to other oil operators in the region. Both slickline and electric line equipment must be mobilized to the platform and rigged up separately. This creates inefficiency with logistics, operations, while increasing risk and results in higher overall operational costs. With the introduction of digital slickline to offshore operations, it has changed the way that Mubadala Petroleum performs rig less intervention. The digital slickline data plots shown in this paper are representative real examples of its application. Interventions executed using real time digital slickline have proven to be safer, improve efficiency and are a more cost-effective way to conduct operations by having full real-time control of downhole tool and sensors. It also reduces total foot print of equipment and personnel during simultaneous slickline and electric line operation by utilizing a single digital slickline unit to cover both downhole mechanicals, perforation and real-time logging work scope without switching back and forth between units. Depth accuracy and shot detection was achieved with lower operational risk while working with perforation guns and explosives. Material presented in the paper are from actual operations, with examples of perforation, depth correlation, pressure surveys, and pressure monitoring while perforating, and demonstrate the operational efficiencies and risk reduction being delivered.

The Well X in Nong Yao field, is an infill-well designed for the Gulf of Thailand which presented several interesting challenges due to its complexity, tortuosity, and potential collision risks with other wells. This paper demonstrates the application of a Real-time Advanced Survey Correction (RASC) with Multi Station Analysis (MSA) to correct the Measurement While Drilling (MWD)'s azimuth. The Well X is a 3D Complex design with a high drilling difficulty index (DDI) at 6.9, high tortuosity of 316 degree, and which has an aggressive build on inclination and azimuthal U-turning well path. The well also creates difficult doglegs severity (DLS) up to 5.5deg/100ft, which is near the limit of the flexibility required to achieve the horizontal landing point. The conventional MWD survey, with proximity scanning with the nearby Well A, demonstrates high risk with a calculated Oriented Separation Factor (OSF) of 1.01. The RASC-MSA method is applied with a clearly defined workflow during execution in real-time and provide significant improvement in calculated OSF. RASC-MSA is applied for every 1,000 ft interval drilling below the 9.625in casing shoe. The workflow ensures that the directional driller follows the corrected survey along the well path and especially in the last 300 ft before reaching the electrical submersible pump (ESP) tangent section. The result from RASC-MSA, indicated a 29 ft lateral shift on the left side of the MWD standard surveys. Without this technique, Well X has a high potential to collide with Well A and Well B (Figure 1) as the actual OSF may less than 1 while drilling. The final 3D Least Distance proximity scanning with Well A shows a minimum OSF = 1.35, which is a 30% improvement compared to the conventional MWD survey. Another nearby well, Well B, indicates a minimum OSF=1.66 and passed the anti-collision OSF rule. In consideration of the drilling efficiency, availability, cost effectiveness and time saving, the RASC-MSA analysis to correct the MWD's azimuth are applied and the separation factor can be improved by 30%. In conclusion, the collision risk management technique applied successfully met the complex challenges of Well X, which was successfully drilled and safely delivered. Figure 1 3D visualization to exhibit the collision issue between Well X and nearby existing Wells A and Well B.

In a global first, Mubadala Petroleum in Thailand has successfully completed a three-month trial of a new technology designed to improve the operational performance of the regular program of well maintenance workovers required for its Gulf of Thailand fields. The trial tested the use of an innovative modular Rigless Pulling Unit (RPU) in place of a conventional Hydraulic Workover Unit (HWU) in a program of workover operations. Historically, the RPU used by most operators worldwide for Plug and Abandon (P&A) type of operation. However, Mubadala Petroleum has pushed the technical limits for the RPU to perform ESP change out and running upper/lower completions (Re-completion) on existing wells that has ESP failures, or any recompletion opportunities. During the trial period, this new unit achieved similar operational efficiency to a HWU, while proving its capabilities to execute the most complicated tasks that are challenging even for the HWU, in terms of reducing rig time, well cost, and most importantly minimizing the HSE risks. This technology can be developed to be a "fit for purpose" intervention method for the future workover, recompletion and decommissioning activities. The utilization of RPU for a long well services campaign, for post-drilling completions, for slot recoveries and for a decommissioning campaign will have more potential of cost saving vs using the Rig or HWU. With this first worldwide successful trial of a RPU for well workover operations, we have opened the doors for new opportunities to perform workover activities other than with standard hydraulic workover rigs. The RPU technology offers many advantages and capabilities to perform more efficient complex workovers or recompletion operations. Material presented is from actual workover operations, including electrical submersible pumps (ESP) change outs and cycling lower completions, wellbore cleanout, etc. It will also display the operational efficiencies increase and risk reduction achieved.

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.