Cumulative-Gas-Production Distribution on the Nikanassin Tight Gas Formation, Alberta and British Columbia, Canada
- Nisael Solano (University of Calgary) | Liliana Zambrano (University of Calgary) | Roberto Aguilera (University of Calgary)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- June 2011
- Document Type
- Journal Paper
- 357 - 376
- 2011. Society of Petroleum Engineers
- 1.2.3 Rock properties, 5.5.2 Core Analysis, 5.5 Reservoir Simulation, 3 Production and Well Operations, 5.1.1 Exploration, Development, Structural Geology, 5.8.2 Shale Gas, 1.6.9 Coring, Fishing, 5.8.1 Tight Gas, 4.3.4 Scale, 5.1.5 Geologic Modeling, 4.1.2 Separation and Treating, 1.6 Drilling Operations, 4.6 Natural Gas, 5.6.1 Open hole/cased hole log analysis, 5.8.6 Naturally Fractured Reservoir, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 1.2.2 Geomechanics, 5.8.3 Coal Seam Gas, 5.2.1 Phase Behavior and PVT Measurements, 2 Well Completion, 4.1.5 Processing Equipment, 5.6.2 Core Analysis, 5.8.7 Carbonate Reservoir, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 6.5.3 Waste Management, 5.2 Reservoir Fluid Dynamics
- Tight gas, Western Canada sedimentary basin, Slot and fracture porosity, Nikanassin formation, Borehole breakouts
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271 wells producing exclusively from the Nikanassin and equivalent formations in a very large area of more than 15,000 km2 in the Western Canada Sedimentary basin (WCSB), Alberta and British Columbia, Canada, have been evaluated with a view to determine the distribution of cumulative gas production and the possibilities of intensive infill drilling.
The Upper Jurassic to Lower Cretaceous Nikanassin formation is generally characterized as a tight gas formation with low values of permeability (typically a fraction of millidarcy) and low porosities (usually less than 6%). It is likely that natural microfractures and slot pores dominate the productivity of the formation. The study area was divided into six smaller narrow areas (A through F) approximately parallel to the northwest/southeast-trending thrust belt of the Canadian Rocky Mountains. Area A is located to the west of the deformation edge, Area B is on the deformation edge, and Areas C through F are located to the east. Area C is the deepest and closest to the thrust belt, whereas Area F is the shallowest and farthest from the thrust belt.
Cumulative production characteristics within each area were evaluated with a variability distribution model (VDM) developed recently for naturally fractured reservoirs. The evaluation of each one of the six areas (271 wells) resulted in coefficients of determination, R2 greater than 0.99 in all cases. The results indicate that the gas cumulative production distribution per well is more homogeneous along the deformation edge (Area B), in which 80% of the wells contribute approximately 50% of the cumulative production. The highest heterogeneity was found in Area F (the shallowest), with 80% of the wells contributing only 25% of the cumulative gas production. Areas A, C, D, and E have more or less the same distribution with 80% of the wells contributing between 35 and 45% of the cumulative gas production. In preliminary terms, there is an association between the cumulative-production distribution and lateral variations of borehole breakouts in the Nikanassin formation on a transect perpendicular to the deformation belt of the WCSB.
Analysis of the distributions leads to the conclusion that the Nikanassin is a very heterogeneous formation and that there is significant potential for massive drilling to efficiently drain the formation. The possibilities of horizontal wells and multistage hydraulic-fracturing jobs are being investigated at this time.
|File Size||2 MB||Number of Pages||20|
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