This website will change as a result of the dissolution of Indigenous and Northern Affairs Canada. Consult the new Crown-Indigenous Relations and Northern Affairs Canada home page or the new Indigenous Services Canada home page.
This Web page has been archived on the Web. Archived information is provided for reference, research or record keeping purposes. It is not subject to the Government of Canada Web Standards and has not been altered or updated since it was archived. Please contact us to request a format other than those available.
Date : May 2014
PDF Version PDF Version of Northern Oil & Gas Annual Report 2013 (1.9 Mb, 31 Pages)
The management of oil and gas resources on Crown lands north of latitude 60° N in the Northwest Territories, Nunavut and the northern offshore is a federal responsibility administered by the Northern Petroleum Resources Directorate on behalf of the Minister of Aboriginal Affairs and Northern Development.
Petroleum resource management on Crown lands is exercised under federal legislation. The Canada Petroleum Resources Act and its regulations govern the granting and administration of Crown exploration and production rights and set the royalty regime. The Canada Oil and Gas Operations Act governs the regulation of petroleum operations and associated benefits requirements. Land, royalty and benefit matters are managed by the Department on behalf of the Minister of Aboriginal Affairs and Northern Development Canada while the National Energy Board takes the lead role in approval of operations.
Information on northern petroleum resource management may be found at www.aadnc-aandc.gc.ca/nth/og/index-eng.asp.
Message from the Honourable Bernard Valcourt, PC, MP
Minister of Aboriginal Affairs and Northern Development
I am pleased to table before Parliament the annual report on the administration of oil and gas in the Northwest Territories, Nunavut and northern offshore for the year ending December 31, 2013.
Northern Canada is rich in oil and natural gas resources. An estimated one-quarter of the country's discovered conventional oil and one-third of the country's natural gas are in the North. Developing these natural resources in a responsible and environmentally sound manner is a priority for Canada.
In 2013, industry and government continued to collaborate with Northern partners to advance knowledge to support responsible resource development in the North. Initiatives include the Beaufort Regional Environmental Assessment in the third year of a $21.8 million, five-year program; and the Environmental Studies Research Fund, which directs research focused on exploration regions through levies on lands held by industry.
On April 1, 2014, the Government of the Northwest Territories assumed responsibility for land and resources management in the territory with the Northwest Territories Devolution Agreement coming into effect. This includes responsibilities for management of onshore oil and gas reserves. Offshore oil and gas reserves remain under federal authority.
The responsible management of Canada's Northern petroleum resources supports the Government of Canada's Northern Strategy to ensure the North achieves its true promise as a healthy, prosperous region within a strong and sovereign Canada.
I invite you to consult this report for further details on the exploration and development of Canada's Northern oil and gas resources over the past year.
Frontier LandsFootnote 1 under the administrative responsibility of the Minister of Aboriginal Affairs and Northern Development
Much of Canada's North has high geological potential for oil and gas offering diverse opportunities for petroleum exploration companies. Onshore, the northern extension of the prolific Western Canada Sedimentary Basin extends from 60° N to the Beaufort Sea and provides ample exploration interest for both conventional and unconventional reservoirs.
Extending offshore, the proven resources of the Beaufort Sea and Mackenzie Delta represent the most explored fraction of Canada's extensive Arctic continental margin bordering the Arctic Ocean in the west and Baffin Bay in the east. The oil and gas potential of Canada's Arctic Islands is already proven by several major gas discoveries in earlier phases of exploration. Modern exploration methods could expect to boost this potential towards economic thresholds.
Issuance of exploration licences by the Minister of Aboriginal Affairs and Northern Development initiates the cycle of exploration. Typically, exploration activities progress from seismic programs to identify favourable well locations, followed by drilling which can lead to discoveries and eventual development. With licence in hand, a company can invest in exploration with the confidence that licensing confers the right to develop and produce what they discover.
Opening lands to issuance is the first step in encouraging economic development from exploration activity. Currently, only certain regions of the Northwest Territories and Nunavut with high petroleum potential are regularly opened for industry to nominate and acquire exploration rights. To sustain investment, regular opportunities for industry to bid and win new exploration licences are key. Each new cycle of Calls for Nominations and Bids ensures that new companies can acquire lands on a fair, competitive basis to test new methods and explore new exploration targets such as unconventional resources in shale.
Once an exploration licence is awarded, the successful company can pursue exploration activities subject to meeting the regulatory requirements governing operations, including comprehensive safety planning and financial assurance. Operational authorizations are issued by the National Energy Board subject to environmental screening and assessment as may be required for the specific project.
This year saw acquisition of one exploration licence in the Central Mackenzie Valley of the Northwest Territories. The new licence adjoins the 14 licences acquired in this region over recent Calls for Bids by companies actively exploring the Canol Shale play. An area of over 1.2 million hectares is currently under licence covering this region of intense exploration interest northwest and southeast of the North's largest producing oil field at Norman Wells. Four wells were drilled in the Central Mackenzie Valley and one seismic program was undertaken during 2013. This activity generated employment benefits and business opportunities, building capacity in Mackenzie Valley communities.
Outside the Mackenzie Valley, no new exploration licences were acquired in the North in 2013 and no seismic or drilling operations were conducted on existing licences. Seismic data acquired over previous years can be used by companies to evaluate their existing licences in the Beaufort Sea and no further work proved necessary this year.
A concentration of exploration licences in the Beaufort Sea is focused in the deeper water areas unexplored in earlier phases of exploration. Globally, deep water exploration along continental margins has been a particularly successful target for offshore drilling. Late in the year, a drilling proposal was filed by Imperial Oil as operator of Beaufort Sea exploration licences EL476 and EL477 describing a plan to drill towards the end of the decade. The proposal was entering environmental assessment at year end.
Industry and government continues to collaborate with northern partners to advance knowledge to support responsible resource development in the North. Initiatives include the Beaufort Regional Environmental Assessment which is in the third year of a $21.8 million, five-year program; and the Environmental Studies Research Fund, which directs research focused on exploration regions such as the Central Mackenzie Valley, through levies on lands held by industry. In the eastern Arctic, discussions continued with Inuit organizations, federal and territorial governments, and relevant stakeholders to advance a strategic environmental assessment to support decisions regarding future issuance of exploration rights in the offshore area.
Two Calls for Bids in the Central Mackenzie Valley and in the Arctic Islands of Nunavut closed on September 17, 2013. One exploration licence was issued to International Frontier Resources Corporation in the Central Mackenzie Valley. No bids were received for the parcel offered as a significant discovery licence in the Arctic Islands of Nunavut.
Three wells were drilled and suspended in the Central Mackenzie Valley. A fourth well was spudded in the area at the end of December 2013 and reached its target depth in the following month. The four wells add up to a total drilled depth of 6,161 metres in 2013.
One ongoing seismic survey continued in the Central Mackenzie Valley with a total of 71 kilometres of 2-D seismic. No other exploration activities were recorded elsewhere in the North.
The total aggregate oil production in 2013 was of 4.1 million barrels (654.4 x 103 m3), a 13% decrease from 2012. Total aggregate natural gas production in the Northwest Territories in 2013 was of 4.7 billion cubic feet (133.0 x 106 m3), a 18% decrease from the previous year.
Royalties received in the 2013 calendar year from oil and gas production on northern frontier lands amounted to $10,046,685.
In 2013, the Department of Aboriginal Affairs and Northern Development Canada finalized new Benefits Plan Guidelines for the North. These Guidelines are now in effect. They will assist operators to develop a Benefits Plan that meets the requirements of the Canada Oil and Gas Operations Act and the Canada Petroleum Resources Act.
The Environmental Studies Research Fund (ESRF) is a provision of the Canada Petroleum Resources Act, and is funded through levies applied to oil and gas lands held by companies under licence. In 2013, the ESRF Management Board approved funding for five new research studies in the North, in both the Central Mackenzie Valley and Beaufort Sea and Mackenzie Delta Regions. These environmental studies are related to the exploration, development and production of oil and gas resources on frontier lands. The budget approved by the Minister for these northern studies, based upon the recommendations of the Board, was $1,995,000. More details on ESRF, including annual reports and publications can be found at www.esrfunds.org.
The Beaufort Regional Environmental Assessment (BREA) continued to build regional knowledge and information in support of its goals of ensuring preparedness for offshore oil and gas in the Beaufort Sea. Research and working group progress and results were shared through meetings in the Inuvialuit Settlement Region and through reports and other publications. The third year of the program saw ongoing participation and engagement of stakeholders, representing Inuvialuit, industry, and government organizations. Issues related to oil spill preparedness and response, waste management, climate change, socio-cultural and economic indicators, and cumulative effects were advanced in the last year. More details on BREA, including reports and publications can be found at: www.beaufortrea.ca.
Approximately 38%Footnote 2 of Canada's remaining marketable resources of natural gas in conventional fields are located in northern Canada, as well as 35% of the remaining light crudeFootnote 3. This slight increase in the percentage of natural gas assigned to the North over the last year reflects a downward revision, by the National Energy Board, of the remaining conventional natural gas in the southern Western Canada Sedimentary Basin. This new estimate also includes unconventional gas resources (which were not included in 2012), effectively tripling resources assigned to tight and shale gas resources. If unconventional numbers are added to conventional gas numbers, the northern Canada portion of remaining natural gas resources drops to 11%.
Regional estimates of Canada's northern discovered resources are listed in Table 1. These are totals for conventional oil and gas resources in discovered fields and do not include estimates of potential in undrilled prospects and basins. Ultimate potential (which includes discovered resources and undiscovered potential) is estimated at about 12 billion barrels (1.91 x 109 m3) of recoverable oil and 150 trillion cubic feet (4.25 x 1012 m3) of gas but much uncertainty remains about the resource potential in many of Canada's northern petroleum basins, especially those which have yet to be tested.
Unconventional hydrocarbon resources are attracting oil and gas industry investment in the Mackenzie Valley. These potential resources include shale gas and shale oil in the extensive high-quality Devonian Canol Formation, a source rock known to have generated the oil in the major Norman Wells field nearby. Exploration activities for shale oil in the area between Norman Wells and Tulita are likely to generate information to allow quantitative estimates of unconventional resources in the future, but in the absence of this information no unconventional resources have been included in Table 1.
No estimates for unconventional resources in the North have been released by either the Geological Survey of Canada or the National Energy Board.
|Region||Crude Oil||Natural Gas|
|106 m3||Million Barrels||109 m3||Trillion cubic feet|
|Northwest Territories and Arctic Offshore||187.9||1,182.3||457.6||16.2|
|Nunavut and Arctic Offshore||51.3||322.8||449.7||15.9|
|Arctic Offshore Yukon||62.5||393.3||4.5||0.2|
The Minister of Aboriginal Affairs and Northern Development provides industry with an annual opportunity to obtain exploration rights in the Northwest Territories, Nunavut and the northern offshore. The exploration rights are issued pursuant to the Canada Petroleum Resources Act which provides for an open, competitive bidding process. In accordance with the provisions of land claim agreements, the views and support of Aboriginal communities and organizations on the terms and conditions of the issuance and related matters are sought prior to rights issuance. Similarly, the Department consults and engages territorial governments and other federal bodies for environmental sensitivity information. After consideration of responses received, the areas opened for exploration may be adjusted from year to year.
A Call for Nominations normally precedes each Call for Bids, allowing industry to specify lands of interest for inclusion in a subsequent Call for Bids process. Calls for Bids are open for the statutory minimum of 120 days, and are published in Part I of the Canada Gazette. The rights issuance process is based on a single, quantifiable bidding criterion with rights going to the best bid. The Minister has authority to reject any and all bids. Currently, the bidding criterion for exploration licences is the work proposal bid, which is the total amount of money that the bidder proposes to spend doing exploratory work on the parcel within a specified period. The winning bidder is issued an exploration licence of up to nine years, comprising two periods. The exploration licence holder is expected to spend the dollar value of the work proposal bid during the first period of the licence and is required to drill at least one well in order to maintain tenure for the second period.
When exploration results in a petroleum discovery, the legislation provides that application may be made for a declaration of significant discovery. The declaration process, administered by the National Energy Board, confirms a hydrocarbon discovery which satisfies specific technical criteria and describes the extent of discovery. The issuance of a significant discovery licence for lands covering the extent of the discovery is possible either:
The significant discovery licence rewards exploration by allowing for indefinite tenure to the petroleum discovery, recognizing that some discoveries may not be immediately economic to produce. A significant discovery licence may be subject to a drilling order pursuant to section 33 of the Canada Petroleum Resources Act.
Once a developer has determined that a discovery is commercial and wishes to commence oil or gas production, legislation allows for application to the National Energy Board for a declaration of commercial discovery. Similar to the provisions for issuance of a significant discovery licence, issuance of a production licence is possible either:
A production licence has a term of 25 years which is renewable so long as commercial production continues. A company may proceed directly to commercial discovery and a production licence without the intervening step of obtaining a significant discovery licence.
Current oil and gas disposition maps are available on the Aboriginal Affairs and Northern Development Canada website at www.aadnc-aandc.gc.ca/eng/1100100036125.
In 2013, the Northern Petroleum Resources Directorate undertook a review of its administrative practices for the issuance of oil and gas rights. Changes that were implemented include the increase of the bid deposit from $10,000 to $50,000 and the modification of the timing to submit the issuance fee; now only required from the winning bidder with its work deposit, rather than from all bidders when they submit their bids.
The Call for Nominations closed on April 24, 2013 with seven parcels nominated. Each parcel was included in the Call for Bids which was launched on May 18, 2013 and closed on September 17, 2013. On June 26, 2013, the Call for Bids was amended by the removal of one parcel. Bids were received for two of the remaining six parcels, however, only one exploration licence was issued. The successful bidder for one parcel failed to provide the required issuance fee and work deposit by the prescribed date, as a result, this bid was disqualified and bid deposit forfeited.
This image is a map of the Central Mackenzie Valley region displaying Oil and Gas dispositions as outlined in Table 3.
Although industry did not respond to the Call for Nominations for exploration licences, launched on February 25, 2013, a Call for Bids to obtain a significant discovery licence for the Bent Horn oil field was launched on May 18, 2013, with a closing date of September 17, 2013. Unique to this Call for Bids, the significant discovery licence was offered using a cash bidding criterion and included an incremental rental provision. No bids were received.
The Call for Nominations, which closed on September 24, 2013, attracted the posting of one parcel in the shallow Beaufort Sea. The parcel was included in a Call for Bids which was launched on October 19, 2013, with a closing date of February 25, 2014.
This image is a map of the Beaufort Sea and Mackenzie Delta region displaying Oil and Gas dispositions as outlined in Table 3.
|Region||Exploration Licence||Significant Discovery Licence||Production Licence||Former RightsFootnote 1||Total|
|Arctic Islands of Nunavut||0||332,882||0||0||332,882|
|Eastern Arctic Offshore||0||11,184||0||862,500||873,684|
|Hudson BayFootnote 2||0||0||0||126,376||126,376|
|Central Mackenzie Valley||1,280,375||52,725||0||654||1,333,754|
|Southern Northwest Territories||0||65,729||32,842||21,107||119,678|
|Region||Exploration Licence||Significant Discovery Licence||Production Licence||Former RightsFootnote 1||Total|
|Arctic Islands of Nunavut||0||20||0||0||20|
|Eastern Arctic Offshore||0||1||0||30||31|
|Hudson BayFootnote 2||0||0||0||8||8|
|Central Mackenzie Valley||15||11||0||6||32|
|Southern Northwest Territories||0||31||23||8||60|
Permits and/or Leases issued under former legislative regimes pursuant to ss. 112(2) of the Canada Petroleum Resources Act.
Permits onshore islands in northern Hudson Bay are under the jurisdiction of the Department of Aboriginal Affairs and Northern Development Canada. Offshore permits in Hudson Bay (not included in this table) are under the jurisdiction of Natural Resources Canada.
In 2013, ten interests were issued and ten interests terminated.
Exploration licences EL462 and EL463 were terminated by surrender and exploration licence EL494 was issued to Husky Oil Operations Limited pursuant to subsection 25(3) of the Canada Petroleum Resources Act which provides for the consolidation of one or more exploration licences.
With respect to the remaining eight terminations, exploration licences EL456, EL457, EL458, EL459, EL461, EL482, EL484 and EL490, were, at the request of the Minister, surrendered by the interest owner and their associated work deposits were returned. These licences were issued in error, entitling the interest holder to the return of the work deposit for these particular licences. Table 3 as well as Figures 1 and 2 lists and illustrate exploration licences disposition for 2013.
Oil and gas leases numbers 703-70, 704-70, 705-70, 707-R-70, 708-R-70, 709-R-70, 710-R-70 and 838-70, originally issued in the 1970s under the Canada Oil and Gas Land Regulations and currently held by Lone Pine Resources Canada Ltd., were renewed for a further term of 21 years. The National Energy Board commercial discovery declaration of May 1, 2013, substantiated the view that the lease areas were capable of producing oil and gas. The renewal was under section 62 of the Canada Oil and Gas Land Regulations, and subsection 114(4) of the Canada Petroleum Resources Act.
The Department maintains a public registry of petroleum interests and instruments registered under Part VIII of the Canada Petroleum Resources Act. This is the official record of rights holders and any transfer of rights or change of ownership must be registered. Monthly registry activity reports are available at www.aadnc-aandc.gc.ca/eng/1100100036878.
|Licence||Well (Footnote X)|
|EL317Footnote 4||175,810||Talisman Energy Inc.||5-Oct-1986||N/A||N/A|
|EL329Footnote 4||349,981||BP Canada Energy Resources Company||5-Sep-1987||N/A||N/A|
|EL476||205,321||Imperial Oil Resources Ventures Limited||1-Sep-2012||31-Jul-2017||31-Jul-2019||585,000,000|
|EL477||202,380||Imperial Oil Resources Ventures Limited||1-Sep-2012||30-Sep-2018||30-Sep-2020||1,180,100,000|
|EL478||205,359||BP Exploration Operating Company Limited||1-Sep-2012||30-Sep-2018||30-Sep-2020||15,100,000|
|EL479||203,635||BP Exploration Operating Company Limited||1-Sep-2012||30-Sep-2018||30-Sep-2020||1,100,000|
|EL480||108,185||Chevron Canada Limited||1-Sep-2012||31-Oct-2015||31-Oct-2019||1,010,100|
|EL481||205,946||Chevron Canada Limited||1-Sep-2012||31-Aug-2019||31-Aug-2021||103,300,000|
|EL483||196,497||ConocoPhillips Canada Resources Corp.||1-Sep-2012||30-Sep-2018||30-Sep-2020||2,543,896|
|EL485||120,814||Franklin Petroleum Canada Limited||1-Sep-2012||31-Aug-2019||31-Aug-2021||1,000,000|
|EL488||134,142||Franklin Petroleum Canada Limited||6-Mar-2013||5-Mar-2020||5-Mar-2022||1,251,088|
|EL489||93,483||Franklin Petroleum Canada Limited||6-Mar-2013||5-Mar-2020||5-Mar-2022||1,251,088|
|EL491||201,101||Franklin Petroleum Canada Limited||6-Mar-2013||5-Mar-2020||5-Mar-2022||1,251,088|
|EL492||187,200||Franklin Petroleum Canada Limited||6-Mar-2013||5-Mar-2020||5-Mar-2022||1,251,088|
|EL493||190,650||Franklin Petroleum Canada Limited||6-Mar-2013||5-Mar-2020||5-Mar-2022||1,251,088|
|Licence termination (by expiry or surrender) in 2013|
|EL456||73,391||MGM Energy Corp.||5-Jan-2011||4-Jan-2016||4-Jan-2020||1,697,000|
|EL457||67,284||MGM Energy Corp.||5-Jan-2011||4-Jan-2016||4-Jan-2020||1,530,000|
|EL458||75,244||MGM Energy Corp.||5-Jan-2011||4-Jan-2016||4-Jan-2020||1,299,600|
|EL459||74,618||MGM Energy Corp.||5-Jan-2011||4-Jan-2016||2-May-2015||1,160,000|
|EL461AFootnote 5||50,552||MGM Energy Corp.||14-Mar-2011||2-Jun-2013||2-Jun-2017||41,923,636|
|EL461BFootnote 5||41,323||MGM Energy Corp.||14-Mar-2011||2-Jun-2013||2-Jun-2017|
|EL482||103,711||ConocoPhillips Canada Resources Corp.||29-Aug-2012||28-Jun-2015||28-Jun-2019||12,084,131|
|EL484||90,381||Franklin Petroleum Canada Limited||1-Sep-2012||31-Aug-2017||31-Aug-2021||1,000,000|
|EL490||99,324||Franklin Petroleum Canada Limited||6-Mar-2013||5-Mar-2018||5-Mar-2022||1,251,088|
|Licence||Well (Footnote X)|
|EL455||80,240||MGM Energy Corp.||5-Jan-2011||4-Jan-2016||4-Jan-2020||1,699,990|
|EL466Footnote 5||82,100||MGM Energy Corp.||15-Jan-2011||9-May-2012||Footnote X||09-Jul-2016||5,487,626|
|EL467||87,948||Shell Canada Limited||20-Dec-2011||19-Dec-2016||19-Dec-2020||18,296,208|
|EL468||87,117||Shell Canada Limited||20-Dec-2011||19-Dec-2016||19-Dec-2020||18,098,660|
|EL469||26,533||Shell Canada Limited||20-Dec-2011||19-Dec-2016||19-Dec-2020||7,049,269|
|EL470||87,495||ConocoPhillips Canada Resources Corp.||20-Dec-2011||19-Dec-2016||Footnote X||19-Dec-2020||66,712,035|
|EL471||88,848||Imperial Oil Resources Ventures Limited||20-Dec-2011||19-Dec-2016||19-Dec-2020||21,500,003|
|EL472||90,632||Imperial Oil Resources Ventures Limited||20-Dec-2011||19-Dec-2016||19-Dec-2020||21,500,003|
|EL473||82,643||MGM Energy Corp.||20-Dec-2011||19-Dec-2016||19-Dec-2020||1,512,122|
|EL474||86,602||MGM Energy Corp.||20-Dec-2011||19-Dec-2016||19-Dec-2020||1,502,503|
|EL475||85,288||MGM Energy Corp.||20-Dec-2011||19-Dec-2016||19-Dec-2020||2,021,213|
|EL486||69,649||Shell Canada Limited||18-Dec-2012||17-Dec-2017||17-Dec-2021||76,864,864|
|EL487||84,504||Shell Canada Limited||18-Dec-2012||17-Dec-2017||17-Dec-2021||15,276,444|
|Licences issued in 2013|
|EL494Footnote 5||174,782||Husky Oil Operations Limited||29-Aug-13||29-Aug-16||Footnote X||29-Aug-20||376,000,000|
|EL495||65,994||International Frontier Resources Corporation||16-Mar-14||15-Mar-19||15-Mar-23||1,200,000|
|Licence termination (by expiry or surrender) in 2013|
|EL462Footnote 6||87,748||Husky Oil Operations Limited||30-Aug-2011||29-Aug-2016||29-Aug-2020||188,000,000|
|EL463Footnote 6||87,034||Husky Oil Operations Limited||30-Aug-2011||29-Aug-2016||29-Aug-2020||188,000,000|
These representatives are current as of December 31, 2013.
Per the original licence, Period 1 may be extended using drilling deposits or through amendment to the licence.
Work Bids rounded to the nearest $.
Under work prohibition orders pursuant to paragraph 12(1)(a) of the Canada Petroleum Resources Act.
Consolidation as per subsection 25(3) of the Canada Petroleum Resources Act.
Pursuant to subsection 25(3) of the Canada Petroleum Resources Act, Licences EL462 & EL463 were terminated and replaced by a new consolidated licence EL494.
Well requirement met. The drilling of one exploratory or delineation well prior to the end of Period 1 of the term is a condition precedent to obtaining tenure to Period 2.
This image is a map displaying Oil and Gas dispositions as outlined in Table 3.
The Department holds financial security deposits with respect to exploration licences. Following a Call for Bids for exploration licences, successful bidders are required to post 25% of the work proposal bids as security against the performance of work. This deposit is referred to as the work deposit. The Deposit is refundable as expenditures are incurred within Period 1 of the term. Since work deposits represent 25% of the total bid amount, refunds are likewise prorated on the basis of 25% of the allowable expenditures incurred. Any work deposit balance remaining at the end of Period 1 is forfeited.
Period 2 exploration licences carries rental obligations. Period 2 rentals are also refundable as expenditures are incurred at the rate of one dollar refund for one dollar of allowable expenditure.
Financial deposits held for Period 1 work deposits and Period 2 rentals as of December 31, 2013 totaled $617,885,139.
Non-refundable rentals are revenues collected from oil and gas leases issued under the Canada Oil and Gas Land Regulations. These are payable annually, in advance of the anniversary date of the leases.
Pursuant to section 15 of Frontier Lands Registration Regulations, various fees for services are payable, such as for the issuance of new exploration licences, registration of instruments or provision of copies of abstracts.
Table 4 outlines revenues from administration of interests in 2013.
|Non refundable rentals (Leases)Footnote 1||62,749||61,127||53,195||53,195||53,195|
Leases issued under the Canada Oil and Gas Land Regulations and continue in force pursuant to section 114 of the Canada Petroleum Resources Act.
Issuance fees and fees for service (section 15 of the Frontier Lands Registration Regulations).
Forfeiture revenues come from bid deposits, drilling deposits as well as work deposits and rentals which were not offset by work expenditures in either Period 1 or 2 of an exploration licence.
Revenue adjustments, correction to financial coding.
Subsection 5.2 of the Canada Oil and Gas Operations Act and section 21 of the Canada Petroleum Resources Act requires that a Benefits Plan be approved by the Minister of Aboriginal Affairs and Northern Development before authorization of any oil and gas work or activity or approval of a development plan relating to a pool or field in the Northwest Territories, Nunavut and Arctic offshore within the area of the Minister's administrative responsibility.
A Benefits Plan represents a documented commitment by a company to provide employment to Canadians and full and fair opportunity to Canadian businesses. A Benefits Plan should include a detailed description of the proposed project as well as the major components, activities and milestones; supporting maps, tables and figures; and time frames. A company is encouraged to give first consideration to local northern Aboriginal and other northern residents and businesses.
In 2013, four new exploration wells were drilled in the Central Mackenzie Valley to a total drill depth of 6,161 metres. In addition, five previously drilled wells were re-entered for work-over, re-completion or abandonment. There was no development drilling in 2013.
There was one geophysical field operation in 2013 which was located in the Central Mackenzie Valley. Figure 3 outlines the key operating areas in the North in 2013.
This image is a map of the Key Operating Areas in the Western Arctic displaying outlined below.
In 2013, there were no new exploration or development wells drilled or seismic acquired in the southern Northwest Territories. In the Liard field, one well was re-entered by Paramount Resources Ltd. and, in the producing Cameron Hills field, one well was re-entered for well work by Strategic Oil & Gas Ltd.
In 2013, ConocoPhillips Canada Resources Corp. drilled three wells in the Tulita District: Loon Creek O-06, Mirror Lake P-20 and Dodo Canyon E-76. MGM Energy Corp. also drilled one well in the Tulita district: East MacKay I-78. Two wells were re-entered by Husky Oil Operations Limited for completion in the same area and MGM Energy Corp. re-entered its East Mackay I-78 well. There were no new development wells drilled in the Normans Wells Field.
Explor Geophysical Ltd continued a 2-D seismic program in the Tulita District that had begun near the end of 2011. This non-exclusive program was suspended in April 2013 and collected 71 kilometres of 2-D seismic.
Table 5 and Table 6 as well as Figure 4 outline drilling and seismic data in the North for 2013.
|Well name||Lat (NAD 27)||Long (NAD 27)||ClassFootnote 1||Total Depth (m)||Metres Drilled 2013||Begun||Rig Released||Well StatusFootnote 2||InterestFootnote 3|
|Southern Northwest Territories|
|Re-Entries of previously drilled wells|
|Paramount et al CAMERON M-73||60° 2' 51.9"||117° 29' 31.9"||DEL||1,653.3||22-Feb-13||25-Feb-13||S||PL4|
|Paramount et al LIARD K-29A||60° 28' 41.0"||123° 35' 4.1"||DEV||3,610.8||13-Sep-13||28-Sep-13||S||PL9|
|Central Mackenzie Valley|
|COPRC LOON CREEK O-06||65° 05' 51.5"||127° 0' 30.7"||EX||1,850||1850||26-Jan-13||20-Feb-13||S||EL470|
|MGM – Shell EAST MACKAY I-78Footnote 4||64° 47' 42.1"||125° 43' 18.3"||EX||1,995.3||1995.3||27-Jan-13||16-Mar-13||S||EL466|
|COPRC MIRROR LAKE N-20||64° 59' 46.8"||126° 48' 14.6"||EX||2,140||2104||25-Feb-13||30-Mar-13||S||EL470|
|COPRC DODO CANYON E-76||65° 05' 27.0"||126° 59' 58.0"||EX||2,910||212||28-Dec-13||23-Jan-14||S||EL470|
|Re-Entries of previously drilled wells|
|Husky LITTLE BEAR N-09||64° 58' 55.2"||126° 31' 20.2"||EX||1,867.5||27-Jan-13||21-Mar-13||S||EL494|
|Husky LITTLE BEAR H-64||64° 53' 28.5"||126° 11' 20.3"||EX||1,340.8||13-Feb-13||17-Mar-13||S||EL494|
Class: EX=exploratory, DEL=delineation, DEV=development, TEST=test hole
Status: S=suspended, A=abandoned, PR=production, Re-A=Re-Abandoned
Interest: EL=Exploration Licence, SDL=Significant Discovery Licence, PL=Production Licence
Drilling and completions included in the reported time period
|2D Seismic (in Km)||189||564||3,917||6,028||12,684||1,488||6,165||59.5||837||71|
|3D Seismic (in Km2)||804||635||1,100||0||1,638||1,577||0||0||3,796||0|
Three fields produced oil and/or gas in the Northwest Territories in 2013: the Norman Wells field in the Central Mackenzie Valley, the Ikhil gas field on the Mackenzie Delta, and the Cameron Hills field southwest of Hay River in the southern Northwest Territories.
Imperial Oil's Norman Wells field in the Central Mackenzie Valley is the northern anchor for the Norman Wells oil pipeline which terminates in Zama, Alberta. This major oil field was discovered in 1920 and continues to produce oil. The field was fully developed in the early 1980s and has produced continuously since 1985, although there were earlier periods of limited production. See Figure 5.
The Norman Wells field saw a 14% decrease in oil production in 2013, compared to the 2012 level. This decrease was mainly due to impacts of a power outage event in February and natural reservoir decline.
Gas from the Ikhil field on the Mackenzie Delta is produced from one well and delivered through a 50-kilometre pipeline to Inuvik, where it is used for power generation and heating. The field is operated by AltaGas Ltd.
Production at the Ikhil field was reduced this year to conserve reservoir pressure. Lower production means that gas from this field is now used as a back-up rather than as the primary source of natural gas for the community.
In 2013, the only field producing from the southern Northwest Territories was the Cameron Hills field, operated by Strategic Oil and Gas Ltd. Effective April 2013, Strategic Oil and Gas Ltd acquired Paramount Resources Ltd.'s Cameron Hills assets. The Cameron Hills field produces both oil and gas, which are delivered by pipeline south to the Bistcho area of northern Alberta.
Production at the Cameron Hills field continues to decline due mainly to wells that have been shut in and the natural decline in production volumes. In 2013 the Cameron Hills field saw a 16% decline in gas production from the 2012 level. This was due to reservoir natural decline and Bistcho gas plant downtime. There was a slight increase in oil production.
Production from the field in the Fort Liard area continues to be suspended.
There are no producing fields in Nunavut or in offshore Arctic waters.
The total aggregate oil production in 2013 was of 4.1 million barrels (654.4 x 103 m3), a 13% decrease from 2012. Total aggregate natural gas production in the Northwest Territories in 2013 was of 4.7 billion cubic feet (133.0 x 106 m3), an 18 % decrease from the previous year. Sixty-four percent of the gas produced was associated with oil production at the Norman Wells field and was used for field operations. Table 7 outlines oil and gas production data in the Northwest Territories.
|Oil Production (thousands of cubic metres)|
|Norman Wells (Imperial Oil)||840.7||588.2||740.9||638.1||-13.88%|
|Cameron Hills (Strategic)||31.4||20.4||15.5||16.4||5.81%|
|Gas Production (millions of cubic metres)|
|Norman Wells (Imperial Oil)||101.4||86.4||100.1||84.5||-15.58%|
|Cameron Hills (Strategic)||59.4||60.9||52.7||44.5||-15.56%|
Royalties received in the 2013 calendar year from oil and gas production on frontier lands amounted to $10,046,685. Despite lower production, this represents a 1% increase from 2012. See Table 8.
Note: Royalty from the Ikhil field is not included. Ikhil lies on Inuvialuit Lands and is administered on behalf of the Inuvialuit pursuant to section 7(94) of the Inuvialuit Final Agreement.
2009 revenue includes a deposit of $4 million from an interest holder against an estimated royalty assessment resulting from an audit. This audit was completed in December 2010 and an assessment was issued in March 2011. The final amount owed to the Crown was received in 2011.
The Department manages a risk-based audit and royalty assessment program, where royalty submissions are regularly monitored, periodically reviewed and selected for audits. The audit objective is to obtain reasonable audit assurance that the sales revenues and expenses claimed on the monthly oil and gas production were reported accurately in the computation of royalties paid to the Crown.
In 2013, two new audits were undertaken during the year.
Please visit our website at www.aadnc-aandc.gc.ca/nth/og/index-eng.asp.
To obtain further information, please contact appropriate individuals below by phone or in writing.
Petroleum and Mineral Resource Management Directorate
Aboriginal Affairs and Northern Development Canada
OTTAWA ON K1A 0H4
Petroleum and Mineral Resource Management Directorate
Aboriginal Affairs and Northern Development Canada
10 Wellington Street
GATINEAU QC K1A 0H4
Information on the resource management regime, calls for nominations and bids, and other related information: Manager, Land Tenure – Telephone: 819-934-9392
Information on registration procedures and regulations, exploration, significant discovery and production licences, transfers, and notices: Registrar – Telephone: 819-997-0048
Information on Northern Petroleum and Mineral Resources Directorate Maps, and Geographic Information System (GIS) Data: Geomatics Officer – Telephone: 819-934-9394
Information on northern exploration history and geological / geophysical activities: Senior Petroleum Geologist – Telephone: 819-953-8722
Information on royalty policy and royalty submissions: Manager, Fiscal Policy and Royalty Administration – Telephone: 819-953-3267
Information on Benefits Plan requirements for Nunavut and northern offshore: Policy Analyst– Telephone 819-934-2244
National Energy Board
444 Seventh Avenue SW
CALGARY AB T2P 0X8
Undertakes research to assess hydrocarbon potential of sedimentary basins in the Northwest Territories and provides data, general information and advice on petroleum geosciences. Website: www.nwtgeoscience.ca
The Geological Survey of Canada Calgary provides public viewing and sampling facilities for cores and samples, and information on wells drilled north of 60 at its offices at: Geological Survey of Canada Calgary 3303-33rd Street NW CALGARY AB T2L 2A7 Telephone: 403-292-7000 Information on geosciences in the Baffin Bay – Davis Strait region is available from: Geological Survey of Canada Atlantic Bedford Institute of Oceanography PO Box 1006 DARTMOUTH NS B2Y 4A
As illustrated above, for the reporting period of 2013, "frontier lands" were defined under section 2 of the Canada Petroleum Resources Act, as follows:
"frontier lands" means lands that belong to Her Majesty in right of Canada, or in respect of which Her Majesty in right of Canada has the right to dispose of or exploit the natural resources, and that are situated in
- the Northwest Territories, Nunavut or Sable Island, or
- submarine areas, not within a province, in the internal waters of Canada, the territorial sea of Canada or the continental shelf of Canada, but does not include the adjoining area, as defined in section 2 of the Yukon Act.
In accordance with the Northwest Territories Lands and Resources Devolution Agreement and the Northwest Territories Devolution Act, on April 1, 2014, the Government of Canada transferred administration and control of public lands, resources and rights in respect of waters in the Northwest Territories to the Commissioner of the Northwest Territories.
This estimate does not include resources in the portion of the Western Canada Sedimentary Basin that extends to the southern part of the Northwest Territories.
National Energy Board, Canada's Energy Futures 2013.