Multiphase Flowmeter for Testing Heavy-Oil Wells in Offshore Brazil
- Pierre-David Maizeret (Schlumberger) | Paulo S. Rocha (Queiroz Galvão Exploração e Produção SA) | Marcelo Danemberg Marsili (Queiroz Galvão Exploração e Produção SA) | Igor de Almeida Ferreira (Queiroz Galvão Exploração e Produção SA) | Tatiana Lipovetsky (Schlumberger) | Ewaldo Schubert Junior (Schlumberger) | Bertrand Theuveny (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- August 2015
- Document Type
- Journal Paper
- 257 - 266
- 2015.Society of Petroleum Engineers
- Well testing, Multiphase flowmeter, Discharge coefficient, Heavy oil, Viscous oil
- 2 in the last 30 days
- 420 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 12.00|
|SPE Non-Member Price:||USD 35.00|
In the heavy-oil Atlanta field, well-test operations were planned initially with a multienergy gamma ray/Venturi multiphase flowmeter as a contingency. During the well-test operations, the foaming propensity of the produced oil made it almost impossible to distinguish an interface between liquid and gas in the separator or tank, rendering the standard equipment useless. Only in the second test were some tank measurements available. The measurement principle used in this multiphase flowmeter, however, is not sensitive to foam or emulsion because the meter responds to the atomic-level composition of the different components of the mixture independently of their arrangement, providing accurate flow-rate measurements. Therefore, it became the main flowmetering device for the operator.
We detail the behavior of the multiphase flowmeter during the well tests in the Atlanta field and the challenges caused by this highly viscous oil. In the case of standard oils, the measurements are not sensitive to the viscosity value. However, in the case of low Reynolds numbers, the viscosity value can dramatically affect the results. In this case, some solvents were injected during the well test to reduce the liquid viscosity, and we present the consequences for the multiphase flowmeter. Because it was not possible to measure the viscosity directly at the wellsite, we highlight the work flow that was followed to determine the proper viscosity value to use. The viscosity number was validated by comparing the multiphase-flowmeter measurements to the gas/oil ratio measured in the laboratory on downhole samples from the same reservoir, to the water cut measured manually during the operations and to the tank total-liquid-rate measurements. Finally, we present some recommendations on the use of multiphase flowmeters for heavy-oil well tests.
|File Size||2 MB||Number of Pages||10|
Alshmakhy, A. and Maini, B.B. 2012. Foamy-Oil-Viscosity Measurement. J Can Pet Technol 51 (1): 60–65. SPE-136665-PA. http://dx.doi.org/10.2118/136665-PA.
Atkinson, D.I., Berard, M., and Ségéral, G. 2000. Qualification of a Nonintrusive Multiphase Flow Meter in Viscous Flows. Presented at the SPE Annual Technical Conference and Exhibition, Dallas, 1–4 October. SPE-63118-MS. http://dx.doi.org/10.2118/63118-MS.
Fraga, A.K., Rezende, D.A., Santos, R.F. et al. 2011. Method to Evaluate Foaming in Petroleum. Brazilian Journal of Petroleum and Gas 5 (1): 25–33. http://www.portalabpg.org.br/bjpg/index.php/bjpg/article/view/161.
Hollingshead, C.L., Johnson, M.C., Barfuss, S.L. et al. 2011. Discharge Coefficient Performance of Venturi, Standard Concentric Orifice Plate, V-Cone and Wedge Flow Meters at Small Reynolds Numbers. Journal of Petroleum Science and Engineering 78 (3-4): 559–566. http://dx.doi.org/10.1016/j.petrol.2011.08.008.
Juliboni, M. 2011. Queiroz Galvão conclui aquisições na Bacia de Santos. (Queiroz Galvão completes acquisitions in the Santos Basin.) Exame. http://exame.abril.com.br/negocios/noticias/queiroz-galvao-conclui-aquisicoes-na-bacia-de-santos. (accessed 20 November 2014).
Kokal, S.K. 2005. Crude Oil Emulsions: A State-Of-The-Art Review. SPE Prod & Fac 20 (1): 5–13. SPE-77497-PA. http://dx.doi.org/10.2118/77497-PA.
Maini, B. 1996. Foamy Oil Flow In Heavy Oil Production. J Can Pet Technol 35 (6): 21–24. PETSOC-96-06-01. http://dx.doi.org/10.2118/96-06-01.
Marin, A.J., Bornia, O., and Pinguet, B.G. 2008. Case Study in Venezuela: Performance of Multiphase Meter in Extra Heavy Oil. Presented at the International Thermal Operations and Heavy Oil Symposium, Calgary, 20–23 October. SPE-117285-MS. http://dx.doi.org/10.2118/117285-MS.
Pinguet, B. 2010. Fundamentals of Multiphase Testing. Sugar Land, TX: Schlumberger.
Pinguet, B. 2012. More Than 10 years’ Experience with Multiphase Flowmeter in Heavy Oil with Either Cold or Thermal Production. Presented at the 2012 World Heavy Oil Congress, Aberdeen, 10–13 September. WHOC12-131.
QGEP. 2014. QGEP Anuncia Excelentes Resultados do Teste do Poço de Atlanta. (QGEP Announces Excellent Results of the Well Test in Atlanta). Queiroz Galvão. http://www.qgep.com.br/queirozgalvao/web/conteudo_pti.asp?idioma=0&tipo=33780&conta=45&id=187621 (last accessed 30 October 2014).
Schlumberger. 2014. Retention Time. Oilfield Glossary. http://www.glossary.oilfield.slb.com/en/Terms/r/retention_time.aspx (last accessed 27 June 2014).
Standing, M.B. and Katz, D.L. 1942. Density of Natural Gases. Trans. Am. Inst. Min. Metall. Pet. Eng. Soc. Min. Eng. AIME 146 (1): 140–146. SPE-942140-G. http://dx.doi.org/10.2118/942140-G.
Theuveny, B.C., Segeral, G., and Pinguet, B. 2001. Multiphase Flowmeters in Well Testing Applications. Presented at the SPE Annual Technical Conference and Exhibition, New Orleans, 30 September–3 October. SPE-71475-MS. http://dx.doi.org/10.2118/71475-MS.
This, H. 1993. Les Secrets de la Casserole. (Secrets of the Saucepan). France: Belin. Viana, F., Mehdizadeh, P., Owston, R.A. et al. 2013. Challenges of Multiphase Flow Metering in Heavy Oil Applications. Presented at the SPE Heavy Oil Conference: Canada, Calgary, 11–13 June. SPE-165427-MS. http://dx.doi.org/10.2118/165427-MS.