Логин:
Пароль:
Регистрация
Забыли свой пароль?

Flow rate retrieval on the basis of algorithms of the “virtual flowmeter” for wells testing

UDK: 681.518:622.276
DOI: 10.24887/0028-2448-2017-11-63-67
Key words: well testing, telemetry, virtual flowmeter
Authors: A.A. Pashali (Rosneft Oil Company, RF, Moscow), A.S. Topolnikov, V.G. Mikhaylov (RN-UfaNIPIneft LLC, RF, Ufa)

The current state of automation of artificial oil lift allows monitoring the operation of downhole equipment in on-line mode on a large well stock from a single monitoring center. This was due to the large-scale introduction of measuring sensors and the development of transmission and storage systems that took place in the last 3-5 years. It turned out that information collected in continuous mode from submersible pressure sensors, which are installed on the intake of the electric centrifugal pump (ESP), can in some cases help with the determination of reservoir parameters: reservoir pressure, permeability, skin factor, and others. Such studies, which do not require special manipulations with the well, were called "passive" or auto wells testing. In this paper, we propose approaches to the development of a "virtual flowmeter" for the purpose of conducting auto well testing. The description of the algorithms that formed the basis of the calculation method for determining the well production rate from indirect data, as well as the results of their testing at various well samples, are described. It is shown that even in the presence of a complete set of initial data, the error in calculating the production rate of the well is about 10% and cannot be significantly reduced because of the errors in the parameter measurements that serve to calculate the production rate.

References

1. Pashali A.A., Aleksandrov M.A., Kliment'ev A.G. et al., Automatization of collecting and preparation of telemetry data for well testing using ''virtual flowmeter'' (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 11, pp. 60–63.

2. Topol'nikov A.S., Intelligent processing data of virtual telemetric system for interpretation during auto-well testing (In Russ.), Inzhenernaya praktika, 2016, no. 10, pp. 54–59.

3. Anderson D.M. et al., Production data analysis – challenges, pitfalls, diagnostics, SPE 102048, god.

4. Camilleri L.A.P., Banciu T., Ditoiu G., First installation of 5 ESP’s Offshore Romania – A case study and lessons learned, SPE 127593, 2010.

5. Khoroshev E., Zolotarev I., Shevtsov D., Ivanovskiy V., Remote monitoring system – Novomet SmartNet (In Russ.), Arsenal neftedobychi, 2015, no. 1 (18), pp. 15–19.

6. Hasan A.R., Kabir C.S., Two-phase flow in vertical and inclined annuli, International Journal of Multiphase Flow, 1992, no. 18, pp.  279.

7. Brill J.P., Mukherjee H., Multiphase flow in wells, SPE Monograph, Henry L. Dogherty Series, Vol.17, 1999, 164 p.

The current state of automation of artificial oil lift allows monitoring the operation of downhole equipment in on-line mode on a large well stock from a single monitoring center. This was due to the large-scale introduction of measuring sensors and the development of transmission and storage systems that took place in the last 3-5 years. It turned out that information collected in continuous mode from submersible pressure sensors, which are installed on the intake of the electric centrifugal pump (ESP), can in some cases help with the determination of reservoir parameters: reservoir pressure, permeability, skin factor, and others. Such studies, which do not require special manipulations with the well, were called "passive" or auto wells testing. In this paper, we propose approaches to the development of a "virtual flowmeter" for the purpose of conducting auto well testing. The description of the algorithms that formed the basis of the calculation method for determining the well production rate from indirect data, as well as the results of their testing at various well samples, are described. It is shown that even in the presence of a complete set of initial data, the error in calculating the production rate of the well is about 10% and cannot be significantly reduced because of the errors in the parameter measurements that serve to calculate the production rate.

References

1. Pashali A.A., Aleksandrov M.A., Kliment'ev A.G. et al., Automatization of collecting and preparation of telemetry data for well testing using ''virtual flowmeter'' (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 11, pp. 60–63.

2. Topol'nikov A.S., Intelligent processing data of virtual telemetric system for interpretation during auto-well testing (In Russ.), Inzhenernaya praktika, 2016, no. 10, pp. 54–59.

3. Anderson D.M. et al., Production data analysis – challenges, pitfalls, diagnostics, SPE 102048, god.

4. Camilleri L.A.P., Banciu T., Ditoiu G., First installation of 5 ESP’s Offshore Romania – A case study and lessons learned, SPE 127593, 2010.

5. Khoroshev E., Zolotarev I., Shevtsov D., Ivanovskiy V., Remote monitoring system – Novomet SmartNet (In Russ.), Arsenal neftedobychi, 2015, no. 1 (18), pp. 15–19.

6. Hasan A.R., Kabir C.S., Two-phase flow in vertical and inclined annuli, International Journal of Multiphase Flow, 1992, no. 18, pp.  279.

7. Brill J.P., Mukherjee H., Multiphase flow in wells, SPE Monograph, Henry L. Dogherty Series, Vol.17, 1999, 164 p.



Attention!
To buy the complete text of article (a format - PDF) or to read the material which is in open access only the authorized visitors of the website can. .

Mobile applications

Read our magazine on mobile devices

Загрузить в Google play

Press Releases

21.10.2020
21.10.2020
19.10.2020