Revolutionizing Field Deliverability: Enhancing Production Capacity and Performance Optimization in a High-Temperature Gas Field, Offshore East Malaysia through Integrated Asset Modelling and Risk Mitigation
Authors: Peter Brandon Joseph John , Berok Sylvia Mavis James , Shata Karim Ahmed , Bidin Lufti Abbas , Bahari Azmir Bakhtiar , Jou Vermie Lai Fan , Rosli Azlesham , Sapiee Zool Nasri , Sanam Zeno 
Published: October 2024

High-temperature high producer gas fields pose significant challenges in terms of production and operational efficiency. This study focuses on a gas field located offshore of Sarawak, which currently operates at a fixed 95% production system capacity due to limitations of facilities and wells. By employing a comprehensive evaluation and optimization approach, the study aims to increase the field's capacity to 97% through targeted improvements via well choke optimization initiatives to meet gas sales demand. Historical events and data reveals integrity issues in the field due to inferior design for high-temperature field management, specifically the wellhead and the flowline design, which necessitates a thorough risk assessment, surface and subsurface analysis to identify opportunities for enhanced production delivery without jeopardizing the wellhead and flowline integrity and ensure safe operation.

The methodology adopted in this study revolves around the utilization of an Integrated Asset Management (IAM) also known as Digital Oil Field (DOF) and the integration of subsurface and surface analysis. IAM enables the simulation of well choke optimization increments and their impact on the overall system operating envelope and flow assurance module. Three main areas of evaluation for choke optimization are considered: tubing assessment, wellhead assessment, and topside risk. Tubing assessment entails the evaluation of erosional constraints and well modelling using IAM workflows. The wellhead assessment investigates the possibility of wellhead seepage and assesses the response to thermal growth and limitations in sliplock-type wellheads. Additionally, topside adequacy is evaluated, with a focus on flowline risk erosion, WGM capability, piping vibration issues, and operational constraints on the choke system.

The analysis of tubing integrity, wellhead seepage, flowline erosion risk, and operational constraints provides valuable information for decision-making and optimization of the field's production system. Through targeted improvements via well choke optimization initiatives, we have increased this gas field production system capacity from the current fixed 95% to 97%. Following through the systematic approach of conducting a through risk analysis and robust monitoring program onsite, we are able to replicate similar strategies across our other wells at the field, increasing the Possibility of Success (POS) of following initiatives. These insights contribute to the overall success of the field and enhance its role in the Sarawak gas network.

The presented comprehensive evaluation and optimization approach for high-temperature gas fields demonstrates the modernization of perspectives on production optimization. By integrating disciplines from surface & subsurface and employing advanced methodologies such as IAM, the study expands the understanding of managing high-temperature fields and improving operational efficiency. The research findings, methodologies, and insights are of significant benefit to the petroleum industry, particularly in maximizing production capacity, addressing integrity issues, and optimizing operational efficiency in high-temperature gas fields in a safe manner.