Fibre Optic Sensing For Improved Wellbore Production Surveillance
- Juun van der Horst (Shell Global Solutions International BV) | Hans Den Boer (Shell) | Peter In 't Panhuis (Royal Dutch/Shell Group) | Brendan Wyker (Shell) | Roel Kusters (Shell International E&P) | Daria Mustafina (Shell International E&P) | Lex Groen (Shell International E&P) | Nabil Bulushi (PDO) | Rifaat Mjeni (PDO) | Kamran Fahmeed Awan (Petroleum Development Oman) | Salma Mohammed Rajhi (Petroleum Development Oman) | Mathieu M Molenaar (Shell Canada Ltd.) | Alan Reynolds (Shell International E&P) | Rakesh Paleja (Shell Global Solutions UK) | David Randell (Shell Global Solutions UK) | Richard Bartlett (Optasense Ltd) | Kevyn Green (OptaSense Ltd)
- Document ID
- International Petroleum Technology Conference
- International Petroleum Technology Conference, 19-22 January, Doha, Qatar
- Publication Date
- Document Type
- Conference Paper
- 2014, International Petroleum Technology Conference
- 4.1.5 Processing Equipment, 5.3.2 Multiphase Flow, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 4.2 Pipelines, Flowlines and Risers, 6.5.2 Water use, produced water discharge and disposal, 4.3.4 Scale, 2.4.3 Sand/Solids Control, 5.1.6 Near-Well and Vertical Seismic Profiles, 3 Production and Well Operations, 3.3 Well & Reservoir Surveillance and Monitoring, 3.2.2 Downhole intervention and remediation (including wireline and coiled tubing), 2.2.2 Perforating, 5.4.7 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex), 5.6.11 Reservoir monitoring with permanent sensors, 2.3 Completion Monitoring Systems/Intelligent Wells, 3.3.1 Production Logging, 4.1.2 Separation and Treating, 5.2 Reservoir Fluid Dynamics
- fibre optic sensing, production monitoring, well and reservoir surveillance
- 10 in the last 30 days
- 752 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 7.00|
|SPE Non-Member Price:||USD 23.00|
Since our previous publication1 significant progress has been made to further mature the application of Fiber-Optic (FO) based Distributed Acoustic Sensing (DAS) for production and injection profiling. A considerable number of new field surveys were conducted to further improve the evaluation algorithms or workflows which convert the DAS noise recordings into flowrates from individual zones. For gas producing wells, a new graphical user-interface has been developed that allows the user to visualize and QC the data in real time. Additional flow and visualization software have been developed for single phase gas producers to enable the user to select and evaluate the data in a user-friendly manner using the most up-to-date evaluation algorithms.
There are still improvements to be made in enabling Distributed Sensing infrastructure, such as handling and evaluation of very large data volumes, seamless FO data transfer, the robustness & cost of the FO system installation, and the overall integration of FO surveillance into traditional workflows. It will take some time before all these issues are addressed but we believe that FO based applications will play a key role in future well and reservoir surveillance.
In this paper we present two recent examples of single-phase flow profiling using DAS. The first example is from a single-phase gas producer in one of the Unconventional plays in North America and the second example is from a long horizontal, smart polymer injector operated by Petroleum Development Oman (PDO).
In oil and gas field development there is often a lack of high quality Well and Reservoir Surveillance (WRS) data for quality decision making; leaving significant reservoir or well performance uncertainties potentially leading to suboptimal reservoir development. The need for frequent and good quality surveillance data is highest in complex reservoir developments such as Unconventional plays, waterflooded reservoirs, Thermal and Chemical Enhanced Oil Recovery (EOR) projects. One of the reasons that well surveillance data is not acquired in practice is that it often causes significant production deferment. Another reason is that often the data gathering surveys are expensive or create large operational risks associated when using conventional logging methods, particularly in high rate, highly deviated or long horizontal producer wells. In some cases, the small diameter production tubing limits access to the well with conventional logging tools.
|File Size||857 KB||Number of Pages||7|