Case History - Steam Injection Monitoring with Optical Fiber Distributed Temperature Sensing
- Marcelo A. Pavanelli Batocchio (Halliburton Servicos Ltda) | Adriana Lucia Cerri Triques (PETROBRAS) | Hardy Leonardo Pinto (PETROBRAS) | Luiz otavio Lima (PETROBRAS) | Carlos Sales Souza (PETROBRAS) | Ronaldo Goncalves Izetti (PETROBRAS)
- Document ID
- Society of Petroleum Engineers
- SPE Intelligent Energy Conference and Exhibition, 23-25 March, Utrecht, The Netherlands
- Publication Date
- Document Type
- Conference Paper
- 2010. Society of Petroleum Engineers
- 5.1.5 Geologic Modeling, 5.8.7 Carbonate Reservoir, 3.1.1 Beam and related pumping techniques, 5.4.6 Thermal Methods, 2.2.2 Perforating, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 5.6.11 Reservoir monitoring with permanent sensors, 2 Well Completion, 5.3.9 Steam Assisted Gravity Drainage, 2.4.5 Gravel pack design & evaluation, 1.6.9 Coring, Fishing, 3.3 Well & Reservoir Surveillance and Monitoring
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This paper describes a project initiated by Petrobras to map the steam-front progress in a heavy-oil, steam-assisted field. A new Distributed Temperature Sensing system (DTS) that was provided by a major service/engineering company to monitor the distributed temperature along the well has been deployed in a pilot program in a 4-well field that has three producers and one continuous steam-injection well. The project goals were to obtain:
- Proof of the performance capabilities of optical-fiber DTS in continuous injection wells for temperatures of approximately 300°C
- Mapping of the steam front in the reservoir to better understand the steam propagation so that injection efficiency can be increased
- Prediction and prevention of steam breakthrough.
The pilot forecasts selective injection in two zones using packers for isolation. Since there were no commercial packers available with feedthrough capabilities for deployment of hydraulic lines or optical fiber cables for steam injection, a new solution had to be devised to permit fiber installation at the injector.
Aspects considered for this project included the well selection for the pilot development, the performance capabilities of the system, and the solutions for fiber installation.
In a scenario of heavy oil and steam injection, companies are seeking accurate information that can help to provide more efficient driver mechanisms to move the crude to the wellbore. Consequently, accurate monitoring equipment and interpretative software tools are necessary keys to achieving production requirements, maintaining economic feasibility, and promoting safety. In this project, high-temperature (HT) conditions were also factors.
Optical-fiber-distributed temperature sensing (DTS) is a downhole monitoring technology that provides permanent and continuous well-temperature profiling (Carnahan, 1999; and Eriksson, 2001). This method allows real-time data collection that enables accurate, complete reservoir monitoring, whereas the traditional method of downhole monitoring during production only provides temperature at a fixed point for each reading. Alternatively, wireline temperature logs can be run, but this method does not offer continuous monitoring, and also, impacts production. With the DTS technique, the optical fiber is attached to the tubing and provides a complete log of the well temperature for each reading, allowing permanent and continuous monitoring without production interruption. Steam-front progress, which can provide better understanding of the reservoir geological model, steam breakthrough identification, and improved injection-efficiency can then be followed.
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