Canada’s unconventional resources continue to excite the imaginations of geoscientists, as Canadian companies – with operators and investors from North America, India and Southeast Asia – are doggedly working to unlock the country’s unconventional resource play potential.
Resource plays represent significant new opportunities to expand production across Canada:
Although not the first region to capture new reserves from the Devonian Bakken Formation, Canada is continuing to develop new technologies and concepts to maximize recovery from this huge and prolific resource play.
Production in January averaged 75,000 boepd from 1,776 wells in Saskatchewan, where test water-flood/pressure maintenance schemes have demonstrated increased hydrocarbon recoveries.
However, it is not only the Bakken that has captured the attention of small and large exploration companies – new resource plays are consistently being identified and exploited. To date, these include:
Shale gas exploitation in British Columbia’s Horn River Basin has been on-going for several years. Here, the Devonian Muskwa and Otter Park shales are the main targets.
This Devonian interval – if the Cordova Embayment and extensions into the Northwest Territories are included – is potentially the largest shale-gas resource in North America.
As in most shale gas plays, horizontal well completions along with multi-stage fracture stimulations are the key to effective recoveries, with typical completion costs topping $9 million (C), according to the Daily Oil Bulletin. Initial production rates can exceed 10 mmcf/d.
If land sale prices are any indication, interest remains high in Canadian shale gas resource plays despite depressed North American natural gas prices. In fact, in 2010 British Columbia recorded its fourth-highest annual land bonus ever. The record-setting bonus totaled $844.4 million (C) for 381,132 hectares – an average of $2,215 per hectare.
The 2010 bonus followed on the heels of a 2009 bonus of $892.9 million for 389,664 hectares – in this case, an average price of $2,291 per hectare. Top bids have exceeded $5,000 per hectare.
Many operators have indicated a reduction in drilling activity in the basin, however, as a result of low gas prices.
The Triassic Montney tight gas play of northeastern British Columbia and North central Alberta continues to be attractive due to its generally shallower depths and, in some areas, higher natural gas liquids (NGL) content.
This play varies, from traditional “shale-gas” along the Alberta/British Columbia border to tight calcareous siltsone and sandstone in central Alberta.
In Alberta, more than 400 horizontal wells, most with multi-stage hydraulic fracture stimulations, have been drilled since January 2008. As in the Horn River Basin shales, the Montney can be quite prolific, with initial production rates exceeding 10 mmcf/d.
Current production is 1.36 bcfe/d from 749 wells.
The Cretaceous Cardium tight-sand oil resource play in central Alberta has gained real momentum following some early miscues after numerous un-economic horizontal wells were drilled.
The majority of successes there have been along the flanks of Canada’s largest oil field at Pembina, with conventional reserves estimated at 7.8 billion barrels of oil-in-place.
Since the first well was drilled there in December 2009, over 370 wells have been rig-released on the field’s flanks. Production in November 2010 averaged 22,000 boepd from 213 wells.
“Efforts are under way in Alberta to update resource-appraisal and forecasting methods for both conventional and unconventional resources,” said AAPG member Fran Hein, chief geologist for the Energy Resources Conservation Board of Alberta, “and to move the regulatory framework to a play-based approach.”
Moving eastward, finding economically viable prospects means solving new challenges. And the exact combination of drilling and completion methods needed to yield economic oil and gas production from unconventional resource plays can be elusive – particularly completion methods that yield consistent replicable results.
Canada’s newest shale gas plays are found in the eastern Canadian provinces of Quebec, New Brunswick and Nova Scotia.
Early estimates of recoverable gas in place from the Utica Shale in Quebec bode well for the economic viability of this emerging resource play.
Challenges, however, remain. Since the January 2010 EXPLORER article by correspondent (and AAPG member) Susan Eaton on Quebec’s exciting Utica shale gas trend, Quebec has yet to implement environmental regulations.
Some advancement toward regulation was made at the end of August, when Quebec’s minister of Sustainable Development, Environment and Parks mandated BAPE (Bureau d’audiences publiques sur l’environnement – Public hearings on the Environment Board) to propose a new regulatory framework for shale gas exploration and development in the province.
The impact on industry activity was felt by mid-January, when Questerre Energy Corporation delayed its Utica shale gas development program in the St. Lawrence Lowlands of Quebec, pending receipt of the BAPE regulations.
Release of the regulations was anticipated by end of February.
Any offshore drilling and assessment of Quebec’s resource potential will likely be delayed even longer. At present, there is a moratorium on oil and gas exploration in the Gulf of St. Lawrence pending a federal government review.
Unconventional exploration targets call for unconventional learning environments – and the AAPG Geosciences Technology Workshops (GTWs) are a model for unconventional thinking and creative learning.
A Canada GTW, “Resource Plays in Tight Unconventional Reservoirs: Multi-Disciplinary Technological Challenges and Solutions,” will be held June 12-14 at the Banff Centre in Banff, Canada.
The 2-1/2 day intensive learning environment will provide expert presentations, case histories and global analogs. Small group, cross-disciplinary discussions among all GTW participants will facilitate knowledge sharing.
Early bird registration pricing is effective through May 1.
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