An overview of modeling thermal fields in a well using fiber-optic temperature sensing tools

About the authors:

Maxim V. Zuev, manager, Tyumen Petroleum Research Center; mvzuev-tnk@rn-gir.rosneft.ru. ORCID - https://orcid.org/0009-0005-2884-4859

Konstantin M. Fedorov, Dr. Sci. (Phys.-Math.), Professor, Professor of the Department of Modeling of Physical Processes and Systems, School of Natural Sciences, University of Tyumen, Tyumen, Russia; k.m.fedorov@utmn.ru, https://orcid.org/0000-0003-0347-3930

Nadezhda A. Chikhareva, leading specialist, Tyumen Petroleum Research Center; NA_Chikhareva@rn-gir.rosneft.ru. ORCID - https://orcid.org/0009-0007-6720-4429

Iosif V. Sudi, leading specialist, Tyumen Petroleum Research Center; IV_Sudi2@rn-gir.rosneft.ru. ORCID - https://orcid.org/0009-0003-6625-0483

Abstract:

The Distributed Temperature Measurement (DTS) technology is based on the use of a fiber-optic cable for continuous measurement of temperature profile along a wellbore. The interpretation of measurement data is a source of valuable information, among which the ability to define flow profile in a well in real time is of particular interest. This information makes it possible to make operational decisions on the development management in real time, however, the complexity of data analysis limits the possibility of using the DTS technology as a tool for determining inflow profile.

The article describes current issues for the field development that can be solved using fiber-optic tools for measuring the temperature distribution in a wellbore. The solution is based on the flow modeling and the equation of heat inflow for real liquids and gases in well and bottom hole zone. Exactly these tools allow to reproduce temperature anomalies in a well. The second fundamental point of interpretation of the distributed temperature measurements is the development of algorithms for solving inverse thermo hydrodynamic tasks in directional wells that penetrate several reservoirs.

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