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AAPG Bulletin

Abstract

DOI: 10.1306/05051413192

Determination of the stable isotope composition and total dissolved solids of Athabasca oil sands reservoir porewater: Part 1. A new tool for aqueous fluid characterization in oil sands reservoirs

Benjamin R. Cowie,1 Bruce James,2 Michael Nightingale,3 and Bernhard Mayer4

1University of Calgary, Department of Geoscience, 2500 University Drive NW, Calgary, Alberta, Canada T2N 1N4; present address: Harvard University, Department of Earth and Planetary Sciences, 20 Oxford Street, Cambridge, Massachusetts, 02138; [email protected]
2Suncor Energy Inc. 150 6 Ave SW, Calgary, Alberta, Canada T2P 3Y7; [email protected]
3University of Calgary, Department of Geoscience, 2500 University Drive NW, Calgary, Alberta, Canada T2N 1N4; [email protected]
4University of Calgary, Department of Geoscience, 2500 University Drive NW, Calgary, Alberta, Canada T2N 1N4; [email protected]

ABSTRACT

We present a new method to determine the total dissolved solids (TDS) concentration and the stable isotope composition of drill-core-derived Porewater in oil sands reservoirs of northeastern Alberta, Canada. The technique described here uses two end-member mixing relationships between the stable isotope compositions of drilling fluids and formation waters from mechanically extracted porewater samples to calculate the formation water TDS, BLTN13192eq1, and BLTN13192eq2 values. Analysis of water samples extracted directly from McMurray Formation drill core provides an inexpensive and robust advance in the ability to characterize the properties of reservoir pore waters that can be widely deployed because of the ubiquity of drill-core sampling. Porewater data from three oil sands wells from different locations within the Athabasca region are presented in this study. Water derived from these wells had TDS values of 860 to 45,000 mg/L, BLTN13192eq3 values of −172 to −149‰, and BLTN13192eq4 values of −22.4 to −19.3‰. These values are consistent with regional trends in formation water salinity and stable isotope compositions, and illustrate the wide range of TDS values that can be found in McMurray Formation waters. The ability to characterize aqueous fluids within bitumen-saturated reservoirs is a new development that enables measurement of aqueous fluid properties that is not easily obtained by other sampling means. This methodology provides a tool to understand the origin and movement of reservoir water related to natural groundwater flow, or to anthropogenic influence by steam injection. Novel in situ extraction technologies that use electromagnetic heating systems may also benefit from detailed characterization of aqueous reservoir fluids to accurately determine the properties of the reservoir porewater.

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