Automated Sand Influx Mitigation Workflow Using Geomechanical Analysis and Minimum Tubing-Head Pressure Estimation

Abstract Sand production is a major challenge for oil and gas companies worldwide. We describe an automated workflow that helps mitigate sanding caused by excessive drawdown by determining the minimum tubing-head pressure (THP). The automated workflow is designed to autocalibrate, analyze, and recommend actionable measures to control THP to prevent sand ingression. This enables oil and gas operators to control sand production, resulting in production enhancement and fewer workover jobs. The operating philosophy consists of four components: 1D geomechanical analysis, sand ingression analysis, wellbore modeling and automated calibration, and automated minimum THP estimation. A 1D Mechanical Earth Model (1D MEM) calibrated with drilling events and caliper data was used as an input to the sand prediction model. The sand prediction model evaluates critical drawdown pressure (CDDP) and establishes a sand-free envelope. A calibrated digital twin is created using well test parameters. The automated sand mitigation workflow uses CDDP values and well models. The minimum flowing bottomhole pressure estimated from CDDP is translated into minimum THP for regular monitoring and sand control by the production team. In this work, we examined the scale, complexity, technology, and advantages of using the digital oil and gas field workflow. Self-flow gas wells were considered as potential candidate wells for the study. The excellent results obtained from this study in terms of production enhancement can set a benchmark for projects concerning efficiency and output gains. Detailed analysis helped classify wells where production gain can be realized without any sand production. Through the study, it was observed that in two wells, THP reduction in steps can potentially lead to sand-free production, with a possible cumulative incremental gas production increase over 100%. Such analysis reiterated the significance of maintaining the minimum THP estimated by the workflow and resulted in a significant shift towards the adoption of digital and integrated workflows for problem solving, ultimately leading to improved operational efficiency and profitability. The integration of state-of-the-art geomechanical analysis and automated workflows produced outstanding results in terms of production gain and reduced analysis time, thereby leading to extended well deliverability, delayed sand production and reduced workover frequencies. This approach provided efficient management and control of minimum THP values without relying on downhole pressure gauges, thus empowering the production team to make informed decisions and optimize production, ultimately saving on well maintenance costs.