Video: Asphaltene Gradient Analysis by DFA Coupled with Geochemical Analysis by GC and GCxGC Indicate Connectivity in Agreement with One Year of Production in a Norwegian Oilfield
- Yngve Bolstad Johansen (AkerBP) | Joachim Rinna (AkerBP) | Soraya S. Betancourt (Schlumberger) | Julia C. Forsythe (Schlumberger) | Vladislav Achourov (Schlumberger) | Jesus A. Canas (Schlumberger) | Li Chen (Schlumberger) | Julian Y. Zuo (Schlumberger) | Oliver C. Mullins (Schlumberger)
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- Society of Petroleum Engineers
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- 2018. Copyright is retained by the author. This presentation is distributed by SPE with the permission of the author. Contact the author for permission to use material from this video.
- 6.5.5 Oil and Chemical Spills, 5.2 Reservoir Fluid Dynamics, 5.2.2 Fluid Modeling, Equations of State, 4.3.3 Aspaltenes, 5.6.2 Core Analysis, 5.5.2 Core Analysis, 1.6 Drilling Operations, 5 Reservoir Desciption & Dynamics, 1.6.9 Coring, Fishing, 5.2 Fluid Characterization, 5.6 Formation Evaluation & Management
- Reservoir Connectivity, Downhole Fluid Analysis, GCxGC, FHZ EoS and Yen-Mullins Model, Asphaltene Gradients
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Asphaltene gradient analysis in many wells in a large field match the Flory-Huggins-Zuo Equation of State (FHZ EoS) indicating equilibrated asphaltenes, thus reservoir connectivity. This analysis is consistent with data from over one year of production to date. Reservoir fluid samples were acquired with use of focused sampling techniques providing contamination free samples. Pressure measurements and many fluid properties are used to validate fluid equilibrium, including GOR and composition analyzed by the Cubic EoS, and a variety of markers in the condensate range, black oil range and the biomarker region. All analyses indicate equilibrium with the exception that the only two outliers in the asphaltene gradient curve are shown to be of different thermal maturity by utilizing the preferred biomarkers, the hopanes Ts and Tm. Moreover, the asphaltene abumdance in differently charged fluids varies by a factor of 6 while the maturity ratio Ts/(Ts+Tm) varies by 6% showing the sensitivity of asphaltene gradients for connectivity analysis. The modest levels of biodegradation (Peters- Moldovan rank=1) are used to constrain the petroleum system context of this reservoir considering that current reservoir temperatures significantly exceed biodegradation thresholds. There is evidence both that mildly biodegraded oil spilled into this reservoir and that some further biodegradation occurred in reservoir. Different gas-oil contacts in the field are associated with charge direction and show the limits of Cubic EoS for connectivity analysis in contrast to the good capability of the asphaltene gradients and FHZ EoS for this purpose. Moreover, the FHZ EoS analysis indicates that the asphaltenes are dispersed as a true molecular solution for this light oil in accord with the Yen-Mullins model of asphaltenes. Results from detailed whole-core and petrophysical analyses supports connectivity analysis. Core analysis shows the lack of any asphaltene deposition in the reservoir as expected from the fluid and asphaltene evaluations.