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Collaborating Authors
Production and Well Operations
Abstract Permanent downhole gauges are today routinely part of completion design and the data can be quickly analyzed to accelerate the decision making, with in particular the development of integrated surveillance platforms. However, this classical permanent monitoring is limited, at best, to only few points of measurement, which is, in some cases, not enough to fulfill the monitoring requirements. Distributed sensing becomes a firm favourite item within all Oil and Gas operators to improve well and reservoir monitoring. Optical technologies provide a distributed measurement all along the well trajectory. A lot of in-well installations have been performed worldwide; however the added value of such monitoring technology still remains to be shared to become a standard or a base case for reservoir engineers in charge of field monitoring plans. Optical distributed sensing started in TOTAL E&P in 2001 with a first trial in Sincor field (Petrocedeño) (SPE paper). Following this success, TOTAL E&P deployed different DTS or optical sensing systems in different areas and for different reservoir monitoring objectives: well clean up control well performance monitoring in well flow profiling ... This paper partly describes he background and current activity of TOTAL E&P in distributed sensing systems and provides some feedbacks from routine monitoring, details from recent pilots, field trials. Capitalizing the experience acquired from the various installations and applications, including treatment and interpretation capabilities, proved to be valuable to promote the deployment of in-well optical distributed sensing technologies with respect to monitoring requirements.
- South America > Venezuela > Orinoco Oil Belt (0.24)
- Europe > United Kingdom > North Sea > Central North Sea (0.24)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Well performance, inflow performance (0.87)
E-Field Real Time Well Temperature Monitoring - Kharyaga Field Case
Semenov, Andrey (Total) | Renaud, Antoine (Total) | Allanic, Christophe (Total)
Abstract Kharyaga field is a complex karstified carbonate reservoir located in a harsh arctic environment of Timan Pechora region on the North of Russia. The main Kharyaga reservoir, still under development, is subdivided on several layers and is characterized by an important heterogeneity (spacial distribution, fractures, karstified areas, etc …) leading to a very complex flow distribution in the reservoir (sweep efficiency) as well as in the well (water breakthrough, possibility of cross flow). In addition, the oil of this reservoir is waxy crude with high positive appearance pour point temperature. High dynamic data quality and adequate real time follow up is mandatory for proper reservoir behavior understanding and characterization in order to be able to take effective operational decisions in due time and then maximize production level. Estimation of each layer contribution to the overall production allows proactive reservoir management including real time follow up and well intervention planning. Fiber optic systems were installed as a part of the upper completion system below ESP in front of perforated interval. Each development pad is equipped with permanent DTS (Distributed Temperature System) to acquire temperature traces data in selected wells. An innovative system was implemented in order to ensure temperature traces acquisition, transfer and storage in real time to Moscow office, which allows reservoir engineer to interpret in real time and upon operational request any variation (well rate, watercut increase, Wax deposition evolution along the well, etc…) and take well-informed decision. This new procedure allowed to reduce drastically the time needed to integrate temperature information thanks to human interference reduction in the data transfer and data storage. Real time qualitative interpretation, thanks to real time data, allowed curative program and improving scrapping frequency leading to production gain. In this paper, interpretation and action plan taken will be described in various conditions, such as: –Determining the contribution of main contributing layer in a single phase flow well - 90% of inflow was produced only from first 20 m out of 45 m perforated height –Identified a primary water-flooded zone after rapid water breakthrough. This zone was isolated leading to a 50% watercut decrease –Detecting water cross flow from a shallower water bearing reservoir into Kharyaga reservoir. A cross flow rate was estimated based on acquired temperature data and help designing remedial work-over. Cross-flow was successfully eliminated and the well was put on stream as producer with pure oil thanks to adequate remedial work over design Obtained knowledge brings better understanding of the field behavior and revision of the object development strategy.
- Europe > Russia > Northwestern Federal District > Nenets Autonomous Okrug (0.63)
- Europe > Russia > Central Federal District > Moscow Oblast > Moscow (0.26)