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Fluid Identification in Light Hydrocarbons With Use of NMR and Downhole Fluid Analyzers--A Case Study

Authors
Marie Van Steene (Schlumberger) | Mario Ardila (Schlumberger) | Richard Nelson (BP Egypt) | Amr Fekry (BP Egypt) | Adel Farghaly (RWE Dea)
DOI
https://doi.org/10.2118/150886-PA
Document ID
SPE-150886-PA
Publisher
Society of Petroleum Engineers
Source
SPE Reservoir Evaluation & Engineering
Volume
16
Issue
04
Publication Date
July 2013
Document Type
Journal Paper
Pages
401 - 411
Language
English
ISSN
1094-6470
Copyright
2013. Society of Petroleum Engineers
Disciplines
5.2.1 Phase behavior and PVT measurements, 5.6.1 Open hole/cased hole log analysis
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2 in the last 30 days
580 since 2007
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Summary

In hydrocarbon reservoirs, fluid types can often vary from dry gas tovolatile oil in the same column. Because of varying and unknown invasionpatterns and inexact clay-volume estimations, fluid-types differentiation onthe basis of conventional logs is not always conclusive. A case study ispresented by use of advanced nuclear-magnetic-resonance (NMR) techniques inconjunction with advanced downhole-fluid-analysis (DFA) measurements andfocused sampling from wireline formation testers (WFTs) to accurately assessthe hydrocarbon-type variations. The saturation-profiling data from an NMRdiffusion-based tool provides fluid-typing information in a continuous depthlog. This approach can be limited by invasion. On the other hand, formationtesters allow taking in-situ measurements of the virgin fluids beyond theinvaded zone, but at discrete depths only. Thus, the two measurements ideallycomplement each other. In this case study, NMR saturation profiling wasacquired over a series of channelized reservoirs. There is a transition from awater zone to an oil zone, and then to a rich-gas reservoir, indicated by boththe DFA and the NMR measurements. Above the rich gas, is a dry-gas intervalthat is conclusively in a separate compartment. Diffusion-based NMR identifiesthe fluid type in a series of thin reservoirs above this main section, in whichno samples were taken. NMR and DFA both detect compositional gradients,invisible to conventional logs. The work presented in this paper demonstrateshow the integration of measurements from various tools can lead to a betterunderstanding of fluid types and distribution.

File Size  2 MBNumber of Pages   11

References

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Ardila, M., Hegeman, P., Dong, C. et al. 2008. Applications of EnhancedDownhole Fluid Analyzer for the North Sea Operations. Paper presented at theSPWLA 49th Annual Logging Symposium, Edinburgh, Scotland, 25-28 May.

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Dong, C., Mullins, O.C., Hegeman, P.S. et al. 2002. In-Situ ContaminationMonitoring and GOR Measurement of Formation Fluid Samples. Paper SPE 77899presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition,Melbourne, Australia, 8-10 October. http://dx.doi.org/10.2118/77899-MS.

Godefroy, S., Zuo, J.Y., Fujisawa, G. et al. 2008. Discussion on FormationDensity Measurements and Their Applications. Paper SPE 114648 presented at theSPE Annual Technical Conference and Exhibition, Denver, Colorado. 21-24September. http://dx.doi.org/10.2118/114648-MS.

Heaton, N.J., Cao Minh, C., Kovats, J. et al. 2004. Saturation and ViscosityFrom Multidimensional Nuclear Magnetic Resonance Logging. Paper SPE 90564presented at the SPE Annual Technical Conference and Exhibition, Houston,Texas, 26-29 September. http://dx.doi.org/10.2118/90564-MS.

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Mullins, O.C., Fujisawa, G., Elshahawi, H. et al. 2005. Identification ofVertical Compartmentalization and Compositional Grading by Downhole FluidAnalysis; Toward a Continuous Downhole Fluid Log. Paper presented at the 46thSPWLA Annual Logging Symposium, New Orleans, Louisiana, 26-29 June.

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