Approximately 95 per cent of coalbed methane wells are being drilled in the Horseshoe Canyon formation between Calgary and Edmonton. Development in these areas is often less costly, in part due to the dry nature of the coals, which results in no water handling costs. Most of the other coalbed methane wells drilled are targeting the deeper Mannville coals, located in the central Alberta Plains. The deep coals (over 1,000 metres) tend to produce highly saline formation water, similar to conventional oil and gas wells at this depth.
As of December 31, 2009, Alberta had over 14,000 producing coalbed methane well connections. In 2009, coalbed methane gas production was 319 billion cubic feet (9 billion cubic metres). The first commercial coalbed methane project was announced in 2002.
No. Fire normally needs free oxygen which is not available at the depths being targeted for coalbed methane development. While lightning or other natural occurrences may ignite exposed coal seams, there is no evidence of coal fires being started either underground or on the surface through coalbed methane production in Alberta.
The Energy Resources Conservation Board regulates the production and disposition of saline water (in Alberta, defined as groundwater having greater than 4,000 milligrams per litre of total dissolved solids). Both Alberta Environment and the Energy Resources Conservation Board regulate varying aspects of the production of non-saline water (in Alberta, defined as groundwater with less than or equal to 4,000 milligrams per litre of total dissolved solids).
Fracturing, or ‘fracing’, (the opening up of fractures in the formation to make gas flow more freely) a well is done to increase or initiate commercial production and is conducted in a controlled manner. Fracturing is a standard technique to enhance hydrocarbon recovery that has been used in Alberta’s oil and gas industry for many years.
Royalty is the price that the owner of a natural resource (i.e. the Alberta government) charges for the right to develop the resource. On May 27, 2010, the Alberta government unveiled initiatives to accelerate the implementation of new technologies to encourage the development of the province’s vast unconventional gas resources. The Emerging Resources and Technology Initiative includes a maximum five per cent royalty rate for the first 36 producing months with a volume limit of 750 million cubic feet (MMcf) of equivalent gas production for coalbed methane wells as defined by the Energy Resources Conservation Board.
There are a number of authorizations—approvals, licences, dispositions, permits and registrations— required from Energy, Energy Resources Conservation Board, Environment, and Sustainable Resource Development for the development of upstream oil and gas activity, including coalbed methane. The Upstream Oil and Gas Authorizations and Consultation Guide is a tool that identifies these authorizations.
In 2003, a multi-stakeholder advisory committee (the MAC) was established to review existing regulations and policies to ensure continued responsible coalbed methane development. The MAC Final Report submitted to the government contained 44 recommendations on water, surface and air impacts, royalties, tenure, industry best practices, and non-specific coalbed methane issues/broad energy topics. A second multi-stakeholder group (the MAC II) issued three annual update reports in 2007, 2008 and 2009.
(in Alberta, defined as groundwater having greater than 4,000 milligrams per litre of total dissolved solids). Both 
and the Energy Resources Conservation Board regulate varying aspects of the production of non-saline water (in Alberta, defined as groundwater with less than or equal to 4,000 milligrams per litre of total dissolved solids). 