Abstract Tunu North Field, part of the Mahakam Delta in East Kalimantan, is a mature and complex gas-producing field operated by PT Pertamina Hulu Mahakam. The field includes more than 400 wells, with a significant number operating intermittently due to declining reservoir pressure and liquid loading. These intermittent wells require frequent manual open-close operations, which are time-consuming and resource-intensive. The offshore and swampy environment adds further complexity, with limited access due to weather constraints and logistical challenges. Traditional manual operation has limited the production potential of these marginal wells and increased exposure to operational risk. To address these challenges, a digital automation initiative called AutoSIBU (Automatic Shut-In Build-Up) was developed and deployed. The system automates the cyclic operation of intermittent gas wells based on real-time pressure and flow data, using logic embedded within the Process Control System (PCS). AutoSIBU eliminates the need for constant manual intervention by enabling valves to open and close automatically when predefined pressure thresholds are met. The system architecture includes relocated pressure transmitters, modified solenoid control lines, and PLC-integrated logic that continuously monitors well conditions. Field trials began with TN-Nx36 and subsequently expanded to the GTS-Nx cluster. The results demonstrated substantial improvements in both production and operational efficiency. Wells with higher build-up rates, such as TN-Nx39, TN-Nx43, and TN-Nx57, cycled more frequently and delivered the greatest production uplift, increasing cumulative volumes by 2–25 MMSCF compared with pre-installation baselines. Across six pilot wells, AutoSIBU wells delivered more than 192 MMSCF in 12 months, approximately four times higher than comparable manually cycled wells. Intervention frequency was reduced by more than 80%, eliminating over 400 manual seatruck trips in ten months. This translated into estimated savings of 1,300 manhours annually and approximately 2.2 billion IDR in fuel costs. In addition, real-time automation minimized downtime by ensuring wells flowed immediately upon reaching maximum WHSIP. For TN-Nx43 alone, this optimization captured an additional ~24 MMSCF in ten months compared with manual operation. The implementation also brought operational benefits beyond production gains. By reducing manual tasks and field presence, AutoSIBU improved personnel safety and reduced transport-related risks and costs. Additionally, the integration into existing safety systems ensured that process integrity and emergency shutdown mechanisms remained fully functional. This paper outlines the system design, implementation steps, performance monitoring, and lessons learned from deploying AutoSIBU in the Tunu North Field. It highlights how real-time automation and smart control logic can unlock production from marginal assets, optimize field operations, and extend the economic life of aging infrastructure. The success of AutoSIBU provides a scalable and replicable model for other gas fields with similar intermittent well challenges. Recommendations for future development include expanding deployment, enhancing the pneumatic version, and integrating AutoSIBU with broader production planning and monitoring tools to support digital transformation across upstream operations.
Kusuma et al. (Mon,) studied this question.