Integrated Geoscience and Reservoir Simulation Approach to Understanding Fluid Flow in Multi-Well Pad Shale Gas Reservoirs
- Patrick Kam (Encana Services Company Ltd) | Muhammad Nadeem (Encana Services Company Ltd) | Eseoghene Nene Omatsone (Sasol Canada Holdings Ltd) | Alex Novlesky (Computer Modelling Group Ltd.) | Anjani Kumar (Computer Modelling Group Ltd.)
- Document ID
- Society of Petroleum Engineers
- SPE/CSUR Unconventional Resources Conference – Canada, 30 September–2 October, Calgary, Alberta, Canada
- Publication Date
- Document Type
- Conference Paper
- 2014. Society of Petroleum Engineers
- Reservoir Simulation, Shale Reservoir, Geoscience, Hydraulic Fracturing, Multi-Well Pad
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- 358 since 2007
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This paper presents a systematic approach to integrate geoscience and dynamic reservoir modeling of two multi-well pads in the Horn River Basin, Canada. The Horn River shale gas play is a world-class unconventional gas resource and is being exploited using multi-stage fracturing along horizontal wells. The two well pads, Pad-1 and Pad-2, selected for this study are comprised of eight and seven wells respectively with 1 to 7 years of production history. Numerical modeling of shale reservoirs has historically been a problematic low-confidence exercise, because of the difficulties associated with inadequate characterization of the geologic framework of shale plays; the problems of estimating the properties of fracture networks; and the complexities of capturing multi-phase flow in fracture networks and wellbores during production, especially in the face of offset wells activity. The work presented in this paper provides useful insights into these issues.
The geoscience modeling activity begins with integrating information from cores, well logs, petrophysical analyses and seismic data into a 3D geocellular model. At first, this model was based upon a simple lithostratigraphic concept and this was the basis of the numerical flow modeling exercise of Pad-1. The 3D geocellular model was thereafter thoroughly reworked to incorporate a sequence stratigraphic perspective of the Horn River shale and to include geomechanical considerations based upon the stratigraphic positioning and landing depths of the subject horizontal wells. This reworked geocellular model had a profound impact on the dynamic modeling of the Pad-2. Also hydraulic conductivity of induced and natural fractures was measured on core plugs at reservoir conditions to assign conductivity values to primary, secondary and tertiary flow paths into dynamic reservoir modeling.
As a result of the integrated workflow, we have achieved a history match allowing us to further understand the hydraulic fracture behaviour and its impact on producing shale reservoirs within the Horn River Formation. Based on the findings we recommend completion strategy that can produce more than one compartmentalized reservoir to optimize production. Ultimately, the objective of any reservoir modelling project is to provide a range of reliable forecast of future performance that is grounded in representative geoscience interpretations and that takes operational constraints into account. The technical learnings described in this work will be helpful to further understand the hydraulic fracturing behavior and their impact on producing the Horn River shale reservoirs.
The Horn River Formation is middle to Late Devonian age stratigraphic unit of the Western Canadian Sedimentary Basin. This formation is composed of dark siliceous and calcareous shale and argillaceous limestone and is subdivided into three shale reservoir members; i.e. Muskwa, Otter Park and Evie. These members are being targeted for exploration and exploitation of shale gas by several operators in northeastern British Colombia. The Horn River Formation varies in thickness from 125m to 320m across the basin, with varying degrees of stratigraphic distinction between the sub-units and also with varying amounts of structural deformation resulting in variable localized in-situ stress regimes and structural features (Snelling et al., 2013).
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