An Integrated Approach to Development Optimization in Seven Generations’ Kakwa Liquids Rich Montney Play

Schmitz, Ron; Nevokshonoff, Glen; Haysom, Steve

doi:10.15530/urtec-2014-1934952

Cited by 4 publications

(2 citation statements)

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“…The Montney Formation is a sedimentary wedge that was deposited during the Early Triassic in the Western Canadian Sedimentary Basin. The Montney depositional fairway stretched over approximately 55,000 square miles from north-east British Columbia to north-west Alberta (Schmitz, 2014). Resources in place in Alberta consists of 2,113 Tcf of natural gas, 28.9 billion bbl.…”

Section: Field Backgroundmentioning

confidence: 99%

“…Montney formation lies between Doig formation and the Belloy formation. The depth of Montney top to the surface ranges from 2800 m to 3500 m and average formation thickness is 200 m, which tilts from the North East to the South West (Schmitz, 2014). Reservoir porosity is about 5% and matrix permeability is around 1000 nanodarcy, which is 0.001 md.…”

Section: Field Backgroundmentioning

confidence: 99%

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Reservoir Flow Simulation Coupled Rock Mechanics for Modeling Shale Liquid Rich Gas Play

et al. 2015

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Multistage hydraulic fracturing technique now applied with horizontal wells and over large areas has enabled commercial production of oil and gas from low-permeability rock formations, changing the energy landscape in North America. In these reservoirs, tons of fracturing fluid and proppants are pumped into the reservoir matrix to create hydraulic fractures and it is important to understand the propagation mechanism of hydraulic fractures and further optimize their properties. In addition, natural fractures are often present in the shale and tight formations, which might be activated during the fracturing process and contribute to the after-stimulation well production rates.In this paper, reservoir simulation is coupled with rock mechanics to predict the well after-stimulation production performance. Firstly, a dual-permeability geological model is built based on field data collected from a well pad in Montney formation, Canada. Fracturing fluid flow in the formation coupled rock mechanics is employed to simulate dynamic hydraulic fracturing process. More specifically, as the continuous injection of fracturing flurry, the effective stress will decrease accordingly. When the effective stress reaches the rock failure criteria, hydraulic fractures will be generated, allowing the fracturing liquid to flow along the fractures. Based on the fracturing operational schedule, dynamic hydraulic fracturing simulation is conducted and results show that hydraulic fractures tend to propagate upward first until it connects the entire formation in the vertical direction. Early production history of the stimulated well is then matched to valid the simulated fracture geometries. Finally, the effects of natural fractures and well bottom-hole pressure on well production are studied. Results show that if natural fracture can be propped or partially propped by the proppants, the production will be increased significantly for shale liquid rich gas plays. This paper provides a significant insights on the fracture propagation and can be a reference for fracturing treatments in unconventional shale reservoirs.

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Section: Field Backgroundmentioning

confidence: 99%

Section: Field Backgroundmentioning

confidence: 99%