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Hasanov, Zahid (BP) | Allahverdiyev, Parviz (BP) | Ibrahimov, Fuad (BP) | Mendoza, Alberto (LYTT Limited) | Thiruvenkatanathan, Pradyumna (LYTT Limited) | Noble, Lilia (LYTT Limited) | Stapley, Jonathan (LYTT Limited)
Abstract This paper discusses results from the first successful deployment of a predictive modelling technology that informs pressure optimization procedures to help minimize sand production and increase hydrocarbon production efficiency in sand prone oil wells. The technique takes variabilities in sand production observed through time across the reservoir section, inferred from downhole sand entry logs, alongside real-time sand transportation logs that monitor sand deposition in pipe as key inputs (both of which computed using a fiber optic Distributed Acoustic Sensor (DAS) based Downhole sand monitoring system). This data is then combined with other time series sensor inputs, like choke position, Down Hole Pressure (DHP) and surface flowline acoustic measurement (sand detector) to predict drawdown pressure envelopes to improve production efficiency. This paper details observations and initial field results from the first deployment of the capability in a highly deviated sand prone oil well completed with an open hole gravel pack (OHGP) completion in the BP-operated Azeri- Chirag- Gunashli (ACG) field located in the Azerbaijan sector of the Caspian Sea. The paper will detail observations and procedures used to increase oil production by over 25% and eliminate sanding risks using the technology. The proposed workflow is part of a comprehensive suite of downhole sand surveillance and management tools fueled by streaming analytics capabilities run on DAS data that have played a key role in managing sand production challenges in the ACG field. The technology has been applied numerous times for base protection, drawdown optimization and targeted remediation. In this instance, we discuss the use of the technology to (1) identify and inform the source of sand detected at surface e.g., formation or completion accumulation, (2) identify formation intervals at risk of sanding, and (3) design advisory operational procedures for production optimization.
Abstract Sand production remains a key technical challenge in the ACG (Azeri-Chirag-Gunashli) field as the target formation is comprised of weakly consolidated sandstone. Although sand control completions (such as open hole gravel pack) are used to limit sand entry into the well, water breakthrough, increased fines production, high flux across completed intervals amongst other factors may negatively impact on their effectiveness as well as stability of reservoir rocks, resulting in high sand production, consequently requiring choking back of wells. This, at times, leads to significant production deferrals, which are attributed to the impact on entire production system: completion, wellbore, chokes, flow lines and production vessels. Therefore, improving techniques and developing technologies for downhole diagnostic and remediation to restore production will be of value throughout the ACG field life. An effective remediation requires an understanding of the sand entry points. Over the last 24 months, BP has developed a new real-time technology solution that employs novel signal processing techniques using Distributed Acoustic Sensing (DAS) systems to detect sand entry points along the wellbore during production. The technology solution has been employed to the interpretation of over 30 conducted surveys to identify sand entry zones in real time. In some instances, the results have also been used to inform targeted remediation using expandable patches. This paper summarizes the results from some of the DAS sand detection surveillance data acquired (in integration with other relevant dataset) and its use in remediation of compromised completion intervals. The authors will also share examples of drawdown optimization and risk management of wells with sand production based on acquired DAS data. This paper will cover a few examples of DAS survey data acquired both for wells with pre-installed fibre (25 wells) and those without it where the technology was deployed via wireline intervention (5 wells). The application of DAS technology in ACG has provided substantial value to date (both in terms of production and safety) and has much more value to be realized as the technology continues to mature.