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
- Downloads
- 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 MB | Number of Pages | 11 |
References
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