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Abstract In a standard conventional oil & gas service, each specialized downhole drilling tool service requires dedicated personnel to execute the field operation. This includes but is not limited to measurement while drilling (MWD), logging while drilling (LWD), directional drilling (DD), casing while drilling (CWD), underreaming service, loss circulation management tool service, drill bit performance service, and many others. In a complex drilling bottom hole assembly (BHA) deployment, multiple skilled-personnel presences at the rig site are required which consequently increases the service cost, the personnel safety risk, and the drilling performance risk caused by multiple chains of communication. Additionally, smaller rigs with less person on board (POB) capacity might become a limitation for multiple services to be deployed. From the environmental sustainability perspective, more personnel cause higher carbon emissions from the drilling operation. The Multi-skilling approach for the downhole drilling tool services workforce is the solution for future Oil & Gas operation sustainability. The integration capability of the oilfield service company enables the workforce training matrix to be designed adapting the drilling challenges. The cross-training framework was made available in the forms of base-workshop training checklists, online web-based or virtual instructor-led training, offline courses, and on-the-job training. The multi-skill training pathway for each individual is also tracked and monitored, to ensure all downhole drilling service personnel are equipped with sufficient competency. The multi-skilling was successfully deployed in several projects in Indonesia. A land operation in East Kalimantan executed the DD & MWD operation with fewer personnel by having MWD cross-trained to DD to cover the night shift alone (supported by remote operation), contributing to 25% more personnel-efficient operation. An offshore project in East Kalimantan also completed the drill bit performance service - Directional Drilling – Logging While Drilling – Underreaming While Drilling – Loss Circulation management tool services in an integrated approach with personnel multi-skill, contributed to 42% personnel efficiency by deploying only 4 personnel instead of 7 persons in a conventional way.
- Asia > Indonesia > Kalimantan (0.45)
- Asia > Indonesia > East Kalimantan (0.45)
Hydraulic Workover Unit Utilization for New Well Openhole Drilling with Directional Motor and Logging-While-Drilling Bottom-Hole-Assembly in M Area
Rachman, Buna Rizal (Schlumberger) | Noviasta, Bonar (Schlumberger) | Wijayanto, Timora (Schlumberger) | Mardiana, Ramadhan Yoan (Schlumberger) | Taufik, Esa (Schlumberger) | Saputra, Rangga (PT. Pertamina Hulu Mahakam) | Styward, Boris (PT. Pertamina Hulu Mahakam)
Abstract Achieving a number of well targets in M Area is an important objective for MK, one of the oil and gas operators in Indonesia. An economic challenge is present due to marginal gas reservoirs in shallow zone. The conventional swamp rig unit requires significant costs for site preparation work and in some cases no longer fulfils the economic criteria. The objective was to drill the same one-phase well (OPW) architecture as the swamp rig normally drills, but at lower costs using a hydraulic workover unit (HWU). Drilling the 8½-in hole section OPW architecture using HWU was challenging, not only on the equipment rating and capability, but also on the deck space limitation part. The fit-for-purpose directional and logging-while-drilling (LWD) system was utilized in this project consisting of customized low-torque excellent hydraulics drill bit design, a positive displacement motor (PDM) with aggressive bend setting to achieve directional objective (with max 3.8°/30-m dogleg severity), annular-pressure-while-drilling (APWD) measurement to ensure equivalent circulating density (ECD) is maintained, and combined electromagnetic propagation resistivity and sonic slowness measurement coupled with high-speed telemetry measurement-while-drilling (MWD) tool to get an accurate and timely formation evaluation. The HWU deck space limitation was solved by implementing a single combined directional drilling (DD), MWD, mudlogging cabin, in addition to the remote operation control implementation to further reduce carbon footprint. Five wells were drilled safely and successfully in this campaign. Drilling efficiency improved with up to 109% ROP increase as compared to the first well, showing the progressive learning curve and excellent teamwork from all involved parties. The directional bottom hole assembly (BHA) was capable of delivering up to 4–5°/30-m dogleg, not only achieving the directional objective, but also penetrating the reservoir targets with tight tolerances. The drill bit delivered very good ROP, reaching 60.4 m/h (about 66% of average OPW ROP achieved by swamp rig). This campaign also successfully reduced the overall site preparation cost by up to 30%, enabling MK to drill wells that were initially not feasible to be drilled using swamp rig within the time frame and budget. Thanks to the success, this new method is currently under study for industrialization. The HWU drilling campaign provided a valuable learning experience, is considered as a proven drilling method, and served as a benchmark for other operators in Indonesia. HWU drilling has proven to be an efficient drilling method and capable of delivering the one-phase-well. This paper presents a unique case study of new well open hole drilling with the HWU and its applicability in M Area. Most studies in the past were HWU drilling in re-entry or sidetrack cases.
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drillstring Design > BHA design (1.00)
- (10 more...)
Abstract This paper will provide a description of the benefits of the remote operations alternatives developed over a decade in the North Sea. Substantial support from Hydro/Statoil, starting in 1999, with remote data monitoring, re-manning the rig site with remote support, and the transfer of rig-based work tasks to a remote operations centre has changed the way we operate today and will also influence how automation will be integrated in the future. Reduction in personnel-on-board (POB) and alternative remote operational models implemented resulted in measurable reductions in cost and HS&E exposure. The paper will give a thorough description of how continuous high operational performance and efficiency gains to operations at different levels has been achieved and documented in the North Sea and translated to the Brazil environment. Other key areas for discussion are: improved performance and reliability, decreased NPT, standardized work processes, 24/7 technical support, real-time drilling optimization, cross-training of personnel, real-time data processing, immediate access to experts. Current remote operations models will continue to evolve by further integrating several classic service deliveries, like directional drilling, measurement and logging-while-drilling (MWD/LWD), mud logging, drilling fluids, wireline logging and other services and job functions. This integration will occur because automated advisory systems will be available, delivering advice based on a wider range of surface and downhole data as well as historical databases and best practices, replacing individual judgment and assumptions. This will significantly contribute to improved HS&E performance as well as risk mitigation. Automated systems in close combination with new cross-trained functions in the operations centers and re-manning of rig sites with reduced POB therefore will become the next step in automation of the overall drilling process.
- South America > Brazil (0.87)
- Europe > United Kingdom > North Sea (0.82)
- Europe > Norway > North Sea (0.82)
- (3 more...)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block BM-C-7 > Peregrino Heavy Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block BM-C-47 > Peregrino Heavy Field (0.99)
- Europe > United Kingdom > North Sea (0.89)
- (3 more...)
- Well Drilling (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Management > Professionalism, Training, and Education > Communities of practice (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (1.00)
- Information Technology > Communications > Collaboration (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
Remote Operations and Digital Transformation: A Solution for Business Continuity During Covid-19 Pandemic
Tongkum, Tossapol (Mubadala Petroleum, Thailand Ltd.) | Siritheerasas, Khamawat (Mubadala Petroleum, Thailand Ltd.) | Jafar, Feras Abu (Mubadala Petroleum, Thailand Ltd.) | Yosakrai, Chulakorn (Schlumberger) | Abbasgholipour, Ali (Schlumberger)
Abstract 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.
- Health & Medicine > Therapeutic Area > Infections and Infectious Diseases (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Logging while drilling (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Management > Professionalism, Training, and Education > Personnel competence (0.87)
- Information Technology > Architecture > Real Time Systems (0.75)
- Information Technology > Communications > Collaboration (0.67)
This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 178873, “Remote Directional-Drilling and Logging-While-Drilling Operations in the Arctic,” by Crispin Chatar, SPE, Alexey Stepnov, Anton Mardyashov, and Juan Raul Elizondo Gonzalez, Schlumberger, prepared for the 2016 IADC/SPE Drilling Conference and Exhibition, Fort Worth, Texas, USA, 1–3 March. The paper has not been peer reviewed. Few locations present as many challenges for drilling as the Arctic. It is one of the most hostile environments in the world, with some of the most remote locations, the toughest logistics challenges, and the largest gaps in infrastructure on the planet. One solution to reduce risk to personnel and the environment and to optimize cost was to use directional drilling and to log the well remotely. Advances in data, communication, and transmission technology have made this possible. Challenges of Remote Operations Implementing remote operations is not simple and definitely cannot be accomplished without thorough planning. Three key elements are required: people, infrastructure, and processes. First, the right profiles and competency levels to staff both field crews and remote operations centers (ROCs) must be identified. Second, infrastructure must be considered. Every remotely operated rig and ROC should be equipped with a standard kit that provides a reliable fit-for-purpose communication channel, ensuring continuous remote control. Finally, processes must be determined, reviewed, and implemented. Developing global baselines that will be adopted and adapted by the business units will provide consistency. This includes hazard analysis and risk-control documents; responsible, accountable, consulted, and informed charts; escalation matrices; emergency response plans; remote-operation standards; and remote-operation implementation guidelines. Challenges of the Arctic Drilling at high latitudes presents unique challenges. First, some personnel are reluctant to work in such an extreme environment. Temperature is only one of the reasons these environments are seen as harsh. These environments also experience cyclic opportunities for operations. An example of this is seen in Alaska, where, in summer, there is less drilling at high latitudes because the required infrastructure changes when the ice roads melt, preventing machinery and equipment from being transported. The environment also is isolated from proper infrastructure, and it can take twice as many employees to perform a given task because most employees will work on rotation. This doubles the health, safety, and environment (HSE) risk. Other reasons make these locations less attractive from a business perspective. These include the cost of special equipment, the cost of transport, and the cost of infrastructure. All of these are challenges that every operator must consider before beginning operations in the Arctic. Other risks are the health and safety of employees and the environment.