Hydrocarbon Impacts = Incidences des hydrocarbures

Key Publications

Mackenzie Gas Project : preliminary information package. Volume 1 : project description. Volume 2 : project maps   /   Imperial Oil Resources Ventures Limited   Aboriginal Pipeline Group   ConocoPhillips Canada (North) Limited   ExxonMobil Canada Properties   Shell Canada Limited
[Calgary, Alta. : Imperial Oil Resources Ventures Limited], 2003.
2 v. : ill., maps ; 28-28 45 cm.
Cover title.
Glossary.
Also available on CD-ROM.
Volume 1: Project description; Volume 2: Project maps.
Updates to the PIP are available on the Northern Gas Project Secretariat website at http://www.ngps.nt.ca/publications_e.html.
Report date: April 2003.
Report number: IPRCC.PR.2002.07.
ASTIS record 51801.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/pipSubmission/PIPfulldetails/PIPFullDetails.html
Web: http://www.ngps.nt.ca/docs/PIP.pdf
Web: http://pubs.aina.ucalgary.ca/ngps/PIP.pdf
Libraries: ACU

This PIP [preliminary information package], dated April 2003, has been submitted to the required regulatory agencies by Imperial Oil Resources Ventures Limited, the Aboriginal Pipeline Group, ConocoPhillips Canada (North) Limited, Shell Canada Limited and ExxonMobil Canada Properties (the proponents) pursuant to the Cooperation Plan for the Environmental Impact Assessment and Regulatory Review of a Northern Gas Pipeline Project through the Northwest Territories, dated June 2002. This PIP describes the Mackenzie Gas Project components and activities, and identifies potential environmental and socio-economic issues requiring consideration. The PIP makes reference to ongoing studies and consultations. The proponents are continuing to pursue these activities in preparation for filing the required applications for the Mackenzie Gas Project as soon as possible. The project schedule shown in the PIP reflects project start-up in 2008. As a result of the delay in filing this PIP, we now expect to file regulatory applications for the project in 2004, after the Terms of Reference for the Environmental Impact Statement have been finalized. Accordingly, first gas from the Mackenzie Delta is now expected to occur in 2009. The application for the transmission pipeline is now expected to be based on a connection with the Alberta natural gas pipeline system at a location in Alberta near the boundary with the Northwest Territories. The existing Alberta system will be extended to the southern terminus of the transmission pipeline. This extension, including obtaining the necessary regulatory approvals, is to be done by TransCanada PipeLines Limited. The PIP is being submitted to assist the regulators and environmental impact agencies in developing a timely schedule for a coordinated review process. (Au)

Mackenzie Gas Project environmental impact statement supplemental information - northwestern Alberta   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources, 2004.
xvi, [270] p. : ill., maps (17 folded) ; 30 cm.
Loose-leaf.
Glossary.
References.
Submitted to Joint Review Panel for the Mackenzie Gas Project.
Also available on the Web.
ASTIS record 53646.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/EIS.html
Libraries: ACU

Executive Summary - Purpose: This document provides supplemental information not available when the Mackenzie Gas Project Environmental Impact Statement (EIS) was filed in October 2004. The filed EIS included an assessment of the three anchor fields, gathering pipelines and associated facilities, and NGL and gas pipelines and associated facilities and infrastructure. Dickins Lake Section: The assessment also included the NOVA Gas Transmission Limited (NGTL) Northwest Mainline (NWML) (Dickins Lake Section) in northwestern Alberta, referred to as the Dickins Lake Section. This NGTL facility will connect the Mackenzie Valley pipeline with NGTL's existing pipeline system in northwestern Alberta. Vardie River Section: The supplemental information in this document includes biophysical and socio-economic baseline data and an environmental impact assessment for the NGTL NWML Loop (Vardie River Section), referred to as the Vardie River Section. This 37-km pipeline loop represents a 3% addition to the length of the previously assessed pipeline. The Vardie River Section will loop 37 km of NGTL's NWML from the existing NGTL Thunder Creek compressor station north to a point near Bootis Hill. There, the Vardie River Section will join the Dickins Lake Section. Infrastructure required for the Vardie River Section is minimal: a natural gas line heater will be added at the existing NGTL Thunder Creek compressor station. This heater will increase the temperature of the natural gas that was transported in the Mackenzie Valley pipeline, to bring it to NGTL's pipeline specifications; existing all-weather roads and winter access roads will be used; no borrow sites will be developed as no granular resource requirements are expected; construction camp facilities could be located at an existing commercial camp. Alternatively, an existing camp clearing could be expanded to accommodate the construction camp. Approach and Scope: The approach used to assess the Vardie River Section and updateinformation for the Dickins Lake Section is consistent with the approach used in the EIS. Subject areas assessed include: air quality; noise; groundwater; hydrology; water quality; fish and fish habitat; soils, landforms and permafrost; vegetation; wildlife; socio-economics; public participation; cumulative effects. This document also includes environmental alignment sheets for the Dickins Lake and Vardie River sections. Combined Project Effects: The EIS concluded that no significant effects were associated with the Mackenzie Gas Project in combination with NGTL's Dickins Lake Section. This assessment for northwestern Alberta concludes that when the Mackenzie Gas Project is combined with NGTL's Dickins Lake and Vardie River sections, no significant effects will occur. (Au)

Application for approval of the Mackenzie Valley pipeline [Volume 1: Pipeline project overview; Volume 2: Economics, tolls and tariffs; Volume 3: Engineering design; Volume 4: Construction and operations; Volume 5: Gas pipeline route maps]   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources, 2004.
4 v. (loose-leaf) : ill., maps (some folded) ; 30 cm + 1 v. ([135] leaves : 119 maps ; 28 45 cm).
Appendix.
Glossaries.
Contents: Volume 1: Pipeline overview - Volume 2: Economics, tolls and tariffs - Volume 3: Engineering design - Volume 4: Construction and operations - Volume 5: Gas pipeline route maps.
Cover title.
Also available as a CD under title: Application for approval of the Mackenzie Valley pipeline : Volume 1: Pipeline overview, Volume 2: Economics, tolls and tariffs, Volume 3: Engineering design, Volume 4: Construction and operations, Volume 5: Route maps.
This application was submitted to National Energy Board for approval
Two maps, 16 of 119 and 18 of 119, have been stapled into volume 5: gas pipeline route maps, replacing two incorrect maps.
Also available on the Web.
ASTIS record 54823.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/CPCN.html
Libraries: ACU

[This 5-volume set contains the] ... application for a Certificate of Public Convenience and Necessity, and for related orders, respecting the Mackenzie Valley pipeline component of the Mackenzie Gas Project (the Application). In addition to the Mackenzie Valley pipeline, which will transport gas from the Inuvik area facility to an interconnection with the NOVA Gas Transmission Ltd. system in Alberta, the other components of the Mackenzie Gas Project are: three onshore natural gas fields: Taglu, Parsons Lake and Niglintgak [and] the Mackenzie gathering system, which includes: gathering pipelines to transport production from the three gas fields to the Inuvik area facility; the Inuvik area facility, which will process production from the three gas fields into gas and natural gas liquids; a pipeline to transport natural gas liquids from the Inuvik area facility to Norman Wells. Imperial Oil Resources Ventures Limited is filing the Application on behalf of the owners of the Mackenzie Valley pipeline. The owners and Imperial Oil Resources Ventures Limited, the Mackenzie Valley Aboriginal Pipeline Limited Partnership, Conoco Phillips Canada (North) Limited, Shell Canada Limited and ExxonMobil Canada Properties. The Application is presented as follows: Volume 1: Pipeline Overview, which contains the formal application document, a guide to the Application, including a concordance table, and Mackenzie Valley pipeline overview; Volume 2: Economics, Tolls and Tariffs, Volume 3: Engineering Design; Volume 4: Construction and Operations; Volume 5: Gas Pipeline Route Maps; Gas Resource and Supply Study, Mackenzie Valley Pipeline Market Demand, Supply and Infrastructure Analysis. In addition to these volumes, the Application is supported by an Environmental Impact Statement ... [comprising] eight volumes (the EIS), and public consultation program ... [comprising] two volumes. The EIS and public consultation program information, which are each being submitted to the National Energy Board (NEB) under separate cover, also support concurrent applications for the other components of the Mackenzie Gas Project that are being submitted to the NEB by the respective operators. (Au)

Mackenzie Valley pipeline market demand, supply, and infrastructure analysis : final report   /   Navigant Consulting, Inc.   Energy and Environmental Analysis, Inc.   Imperial Oil Resources Ventures Limited [Sponsor]
[S.l.] : Navigant Consulting, 2004.
v, 134 p. : ill., maps ; 28 cm.
Cover title.
Also available on the Web.
Undertaking - Joint Review Panel - Mackenzie Gas Project, volume 106, September 28, 2007, undertaking no. J U-266.
ASTIS record 54837.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/navigant.html
Libraries: ACU

This report presents the findings and conclusions of the gas demand, supply and infrastructure analysis prepared by the NCI-EEA Team. The analysis considered a Base Case and three Sensitivity Cases incorporating alternative assumptions concerning the initial capacity of the Mackenzie Pipeline potential expansion of the Pipeline's capacity, alternative levels of gas demand in Canada and the United States, and the potential commencement of operation of a pipeline delivering Alaskan gas to markets in Canada and the U.S. Lower 48 states. Taken together, the scenarios bracket the range of market conditions likely to exist during the first two decades of Mackenzie Pipeline operations. Analysis of the Sensitivity Case results underscores the robustness of the Study's basic conclusions regarding the need for the incremental gas supplies transported by the Pipeline. ...The overall conclusion of this Report is that Canadian and U.S. gas markets support construction of the proposed 34.0 million cubic metre per day (Mmd) or 1.2 billion cubic feet per day (Bcfd) Mackenzie Pipeline in the 2009 timeframe and possible expansion of the Pipeline's capacity in 2015 and 2020. Further, the analysis indicates that there will be sufficient capacity on the intra-Alberta gas transmission system, and on the pipelines with takeaway capacity from the Western Canada Sedimentary Basin (WCSB), to accommodate the projected deliveries of Mackenzie Delta gas. During the study period, the outlook is for steady increases in residential and commercial gas consumption, robust growth in gas demand for electric power generation, and a large increase in gas usage for bitumen extraction, processing, and related cogeneration in the Alberta oil sands industry. As a result of these trends, by the first full year of Mackenzie Pipeline deliveries, in 2010, natural gas demand in Canada and the U.S. Lower 48 is projected to be 313.4 Mmd (11.1 Bcfd) or 16% greater than in 2002 (See Table ES-1). The growth in demand is expected to outstrip gas production in traditional producing basins by a widening margin, including frontier gas resources and liquefied natural gas (LNG). By bringing a large incremental supply of gas to the marketplace, the Mackenzie Pipeline will help fill the growing supply shortfall. The fundamental conclusions of the study are consistent in all the scenarios examined in the analysis, further indicating the importance of the Mackenzie Pipeline in meeting future gas requirements in Canada and the U.S. Lower 48. Table ES-1 summarizes the major findings of the analysis for the Base Case and the three Sensitivity Cases. The specific findings of the Base Case and the Sensitivity Cases regarding gas demand and supply, and intra-Alberta pipeline infrastructure and takeaway capacity, are summarized in the following pages. (Au)

Mackenzie Gas Project gas resource and supply study   /   Gilbert Laustsen Jung Associates Ltd.   Imperial Oil Resources Ventures Limited [Sponsor]
Calgary, Alta. : Gilbert Laustsen Jung Assoc. Ltd., 2004.
iii, 94 p. : ill., folded maps ; 28 cm.
Cover title.
One folded map in pocket.
References.
Also available on the Web.
ASTIS record 54838.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/GLJ.html
Libraries: ACU

Imperial Oil Resources Ventures Limited (IORVL), on behalf of the Mackenzie Valley Pipeline Group, retained Gilbert Laustsen Jung Associates Ltd. (GLJ) to prepare a study of future gas supply for the Mackenzie Gas Project. The primary objective of the study was to provide an assessment of the economically recoverable gas resources and deliverability in the region to support construction of the Mackenzie Valley Pipeline and Gas Gathering System. The time frame considered for development of resources for this supply study is 25 years from the projected on-stream date of November 1, 2009. Production forecasts have been prepared for a period of 50 years from the effective date of the study. The effective date of the study is May 1, 2004. All gas supply volumes quoted herein represent those volumes that are recovered within the 50-year period. The study area encompasses approximately 99,700 square kilometres (38,500 square miles) and includes the following regions: 1) Onshore Mackenzie Delta region including the Anchor Fields" which consist of the Niglintgak, Parsons Lake and Taglu Fields. 2) Central Mackenzie Valley region extending from the Mackenzie Delta south to latitude of approximately 63. 3) Northern portion of the Yukon Territory including the Eagle Plain Basin. 4) Portions of the offshore Mackenzie Delta region (Beaufort Sea) limited to a water depth of 30 metres. ... This study utilizes resource assessments conducted by the operators for the Anchor Fields and existing publicly available studies and other documents relating to the ultimate gas potential of the various geological plays of the area. The operators of the Anchor Fields provided estimates of resources and production forecasts for the Niglintgak, Parsons Lake and Taglu Fields for the base case forecast. GLJ has classified these estimates as best estimate contingent resources. The anchor fields and their operators are: Taglu - Imperial Oil Resources Ventures Limited; Parsons Lake - ConocoPhillips Canada (North) Limited; Niglintgak - Shell Canada Limited .... Forecasts were prepared for each scenario using the planned design pipeline capacity of 34.0 million cubic metres per day (10**6 m/d) or 1.2 billion cubic feet per day (BCFD). The Mackenzie Delta gas gathering and Inuvik Area Facility has a planned design capacity of 30.9 10**6 m/d (1.090 BCFD). For the purpose of this study, marketable gas production from the Mackenzie Delta and Beaufort Sea regions was limited to 30.5 10**6 m/d (1.075 BCFD). Gas from other areas to the south was allowed to fill the pipeline to full capacity of 34.0 10**6 m/d (1.2 BCFD). Sensitivity forecasts were prepared for the following two cases: 1) Fully expanded pipeline capacity of 51.0 10**6 m/d (1.8 BCFD) with the gathering system capacity also increased to 51.0 10**6 m/d (1.8 BCFD). 2) The National Energy Board (NEB) estimates of resources for the three anchor fields were used in place of the operator's estimates. The main report has been prepared in metric units with imperial units in brackets in the text or as separate Tables or Figures. (Au)

Application for approval of the development plan for Taglu field : project description   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources, 2004.
1 v. (loose-leaf) : ill., maps, 1 folded plan ; 30 cm.
Cover title.
Glossary.
Submitted to National Energy Board.
Also available on CD under title: Application for approval of the development plan for Taglu field: project description.
Also available on the Web.
ASTIS record 54840.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/taglu.html
Libraries: ACU

Executive Summary: Purpose: Imperial Oil Resources Limited, a wholly owned subsidiary of Imperial Oil Limited and the registered interest holder of Significant Discovery Licence (SDL) 063 for the Taglu field, is applying for approval to develop the natural gas and natural gas liquids (NGLs) contained within the Taglu field. The Taglu field is located near the northern margin of the Mackenzie Delta, about 120 km northwest of lnuvik and about 70 km west of Tuktoyaktuk. This development plan application is being submitted to the National Energy Board (NEB) for approval under the Canada Oil and Gas Operations Act (COGOA). Scope: Taglu is currently the largest discovered onshore natural gas field in the Mackenzie Delta. It is one of three natural gas fields proposed for development as part of the Mackenzie Gas Project to deliver sweet natural gas and NGLs to market. The other two gas fields are Parsons Lake and Niglintgak. In addition to the field development facilities at Taglu, Parsons Lake and Niglintgak (the anchor fields), the project will consist of: the Mackenzie gathering system, consisting of: gathering pipelines to transport production from the three gas fields to a facility located near Inuvik (the Inuvik area facility); the Inuvik area facility, which will process production from the three gas fields into gas and NGLs; a pipeline to transport NGLs from the Inuvik area facility to Norman Wells the Mackenzie Valley pipeline, which will transport gas from the Inuvik area facility to an interconnection with the NOVA Gas Transmission Ltd. system in Alberta. This development plan application is limited to the Taglu field only and describes the general approach to developing the natural gas resource from the Taglu reservoir. Supporting documents for this development plan application include the: Mackenzie Gas Project Environmental Impact Statement (EIS), Volumes 1 to 8, and Mackenzie Gas Project Public Consultation, volumes 1 and 2. Resource: ... Taglu contains an estimated 109 Gm (3.8 Tcf) of raw gas-in-place. The ultimate gas recovery is expected to be 81 Gm (2.8 Tcf). The initial production rate is about 12.6 Mm/d (445 MMscf/d), declining over the predicted 30-year life of the field. Development: The development plan for Taglu, which is a northern frontier natural gas field, is flexible enough to accommodate contingencies that could arise during the detailed design, construction and operation of the development. The Taglu development concept was assessed as an integral component of the Mackenzie Gas Project. Opportunities to obtain synergies with the other two anchor gas fields and take advantage of coordinating infrastructure requirements for the Mackenzie Gas Project were evaluated. The Taglu field will be developed in stages. When complete, the following will be located on a common site: a well pad consisting of: 10 to 15 production wells; one or two disposal wells; a gas conditioning facility; above-ground flow lines from the well pad to the gas conditioning facility; supporting infrastructure, including an airstrip. ... Subject to the timely receipt of regulatory approvals and a decision to proceed with construction, construction activities are expected to begin in 2006. In 2007, construction of the site infrastructure will begin. Drilling will start early in 2008 and will continue year-round for about 16 months to complete the first stage. Natural gas production is expected to begin in 2009. Future phases, included as part of this development plan, will occur about three to 10 years after start-up and will include drilling additional wells and adding inlet compression. Cost: The estimated capital cost to develop the Taglu field is about $935 million (constant Q1 2003 Canadian dollars), which includes the initial development phase and all future drilling and compression costs. The estimated annual cost to operate and maintain facilities at Taglu over the 30-year life of the field is about $18 million (constant Q 1 2003 Canadian dollars). (Au)

Application for approval of the development plan for Parsons Lake field : project description   /   ConocoPhillips Canada (North) Limited   ExxonMobil Canada
Calgary, Alta. : ConocoPhillips, 2004.
1 v. (loose-leaf) : ill., maps, plans (some folded) ; 30 cm.
Appendices.
Cover title.
Glossary.
Report date: August 2004.
Submitted to National Energy Board.
Also available on CD under title: Application for approval of the development plan for Parsons Lake field: project description.
Also available on the Web.
ASTIS record 61198 describes "Application for approval of the development plan for Parsons Lake field: supplemental information". ASTIS record 69135 describes "Application for approval of the development plan for Parsons Lake field: supplemental information - submission two".
ASTIS record 54841.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/parsons.html
Libraries: ACU

Executive Summary: Purpose of this plan: ConocoPhillips Canada (North) Limited (ConocoPhillips), a wholly owned indirect subsidiary of ConocoPhillips Canada Limited, and ExxonMobil Canada Properties (ExxonMobil) propose to develop natural gas and natural gas liquids (NGLs) from Significant Discovery Licences SDL 32 and SDL 30 (the Parsons Lake field). The Parsons Lake field is located at Parsons Lake in the Northwest Territories, about midway between Inuvik and Tuktoyaktuk. ConocoPhillips, the field operator, holds 75% of the Parsons Lake field and ExxonMobil holds 25%. ConocoPhillips, on behalf of itself and ExxonMobil, is submitting this development plan for the Parsons Lake field to the National Energy Board (NEB) for approval under the Canada Oil and Gas Operations Act (COGOA). ... Production facilities: Main production pads: The main production facilities at the Parsons Lake field will be located on two main gravel pads, the most northerly and larger of the two near the northeast shore of Parsons Lake. This north pad will be build first, with construction currently planned to begin in late 2006. The gas conditioning facility for the Parsons Lake field will be located there, as will two injection wells for disposing of drilling cuttings, produced water and other waste from the field. The connection to the planned Mackenzie gathering system will also be located at the north pad. The second, smaller well pad will be constructed about five or six years after construction of the north pad (around 2015) and will be located about 14 km from it, south of Parsons Lake. An elevated, two-phase flow line will transport natural gas from the south pad to the north pad's gas conditioning facility. Planned wells: Nine producing wells are expected to be located on the north pad, although space has been reserved for drilling about 10 additional wells. The south pad is expected to require three producing wells, although space has been reserved for drilling about four additional wells. Although additional wells are planned to be drilled on both the north and south pads, the final number of wells will depend on the drilling and production results. Potential additional pads and wells: In addition to the two main pads, one or more small pads, for one or several wells, might also be required. These wells are contingent upon the results of the drilling of the currently planned wells, as well as on the results of potential continued exploration drilling in SDLs 32 and 30. Therefore, the number, potential locations and timing for such contingent wells and well pads have not been determined. If any of these single well pads are eventually required, elevated flow lines will connect them to the gas conditioning facility on the north pad. Estimated capital and operating costs: Currently, ConocoPhillips and ExxonMobil initially plan a design rate of about 8.5 Mm/d (300 MMcf/d) at the Northwest Territories-Alberta boundary, over an estimated field life of 25 to 30 years. The estimated capital costs for field development, using the base case of the north and south pads and an inter-pad flow line, are about $895 million (2003$), including a 25% contingency. Operating coasts over 25 years are currently estimated to be about $252 million (2003$). Transportation plan: One of the main conditions required for realizing the opportunity presented by the resources of the Parsons Lake field is a means of transporting the natural gas and NGLs to market. The Mackenzie Gas Project, ... includes the development of three gas fields, known as the anchor fields: Parsons Lake; Taglu, held by Imperial Oil Resources Limited; Niglintgak, held by Shell Canada Limited (Shell). The proponents of the three anchor fields are proposing to construct: a gathering system, including gathering pipelines, a processing facility near Inuvik and an NGL pipeline from Inuvik to Norman Wells; a natural gas pipeline from Inuvik to northwestern Alberta. ... (Au)

Application for approval of the development plan for Niglintgak field : project description   /   Shell Canada Limited
Calgary, Alta. : Shell Canada Limited, 2004.
1 v. (loose-leaf) : ill. (some folded), maps ; 30 cm.
Cover title.
Glossary.
Submitted to National Energy Board.
Also available on CD under title: Application for approval of the development plan for Niglintgak field : project description.
Also available on the Web.
ASTIS record 54842.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/nig.html
Web: http://www.ngps.nt.ca/applicationsubmission/Documents/MGP_Nig_Application_Signed.pdf
Libraries: ACU

Shell Canada Limited (Shell) proposes to develop the natural gas resources recoverable from Significant Discovery Licence 19 (the Niglintgak field). The Niglintgak field is located about 120 km northwest of Inuvik and 85 km west of Tuktoyaktuk in the Northwest Territories. Shell is submitting this development plan for the Niglintgak field to the National Energy Board (NEB) for approval under the Canada Oil and Gas Operations Act (COGOA). The Niglintgak field was discovered by Shell in 1973 when the H-30 well was drilled. Appraisal well C-58, drilled the same year, was located 6 km to the southeast. Three infill wells were also drilled: M-19 in 1975, B-19 in 1976, E-58 in 1977. All of these wells have been abandoned. Shell has spent in excess of $120 million (2003$) on exploring the Niglintgak field and preparing regulatory applications for its development. Shell's proposed development seeks to recover the company's investment and realize the full value of the Niglintgak field in a manner that is consistent with its seven principles of sustainable development. Based on the most recent interpretations of the exploration data obtained, the proponent estimates that the Niglintgak field might contain about 27 Gm of recoverable natural gas and natural gas liquids (NGLs). Production Facilities: The main production facilities at the Niglintgak field will consist of six to 12 production wells located on three well pads. A system of above-ground flow lines will bring the produced gas and associated NGLs to a gas conditioning facility located in the Kumak Channel. The development will also include a disposal well, a disposal sump for cuttings disposal, and associated infrastructure, such as an emergency shelter and helipads. One deep sand well and three A sand wells will be drilled from the north well pad. One A sand well will be drilled from the centre well pad, while a deep sand well will be drilled from the south well pad. Based on the results of the reservoir monitoring plan, up to six additional wells might be required after start-up to deplete the reservoir. Construction is planned over the three winter seasons following NEB approval for the Niglintgak field, from 2006 until 2009. The Operations Phase is planned to begin in 2009 and continue for about 25 years. ... Initial capital expenditures for drilling and facilities at the Niglintgak field are expected to total $369 million. The estimated operations and maintenance expenditure at Niglintgak over the life of the gas field is $250 million. ... In keeping with the direction provided by the various regulatory agencies responsible for assessing and regulating energy developments in the Northwest Territories, Shell, together with the other proponents of the Mackenzie Gas Project, developed an Environmental Impact Statement (EIS) for the Mackenzie Gas Project. The EIS describes the existing baseline conditions, the potential effects of the project, the associated measures to reduce these effects and the predicted residual effects after mitigation. The environmental assessment of the project focused on identifying issues most important to potentially affected northern communities. These key issues were identified through a public consultation process that began in 2001 and will continue throughout the life of the project. ... Although some studies are ongoing, the field development is not expected to have any significant adverse environmental or socio-economic effects, taking into account available mitigation strategies and extensive monitoring commitments. The concept of environmental and socio-economic sustainability was used as the basis for determining the significance of the project's effects. ... The Niglintgak development will be managed to ensure that key sustainable development principles are maintained throughout the design, construction and operations phases of the project. (Au)

Application for approval of the Mackenzie gathering system [Volume 1: Gathering system overview, Volume 2: Engineering design, Volume 3: Construction and operations, Volume 4: Gathering pipelines and NGL pipeline route maps]   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources, 2004.
3 v. (loose-leaf) : ill., maps (some folded), 27 folded plans ; 30 cm + 1 v. ([75] leaves : all maps ; 28 45 cm).
Cover title.
Glossaries.
Contents: Volume 1: Gathering system overview - Volume 2: Engineering design - Volume 3: Construction and operation - Volume 4: Gathering pipelines and NGL pipeline route maps.
Also available on CD under title: Application for approval of the Mackenzie gathering system : Volume 1: Gathering system overview, Volume 2: Engineering design, Volume 3: Construction and operations, Volume 4: Gathering pipelines and NGL pipeline route maps.
Submitted to National Energy Board.
Also available on the Web.
ASTIS record 54845.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/COGOA.html
Libraries: ACU

This application for the Mackenzie gathering system is presented in four volumes: Volume 1: Gathering System Overview, which presents the application to the National Energy Board, describes the key elements of the Mackenzie gathering system, discusses the purpose, need and justification for the gathering system, the proposed timing for implementation and the gathering system's regulatory context, identifies the route selection process and the land requirements for the gathering pipelines, the NGL pipeline and related facilities, summarizes the project's biophysical and socio-economic impacts, outlines the approach to public consultation. Volume 2: Engineering Design, which: describes the special geotechnical, hydraulic and other considerations given to pipeline design and construction in an Arctic environment, provides the design basis and alternatives considered for the gathering system, outlines the design methods, codes and standards used in the design, describes the routes of the gathering pipelines and the NGL pipeline, the alternatives considered and the requirements for land access. Volume 3: Construction and Operations, which: describes the logistical, transportation and construction infrastructure required, provides the plan for procuring the required materials from the suppliers and transporting the materials to the required work sites, outlines the construction plan, including the construction activities and requirements; outlines the operations and maintenance plan. Volume 4: Gathering Pipelines and NGL Pipeline Route Maps, which illustrates the proposed route of the gathering pipelines and the NGL Pipelines. Supporting documents: the following documents are being filed in support of this application for the Mackenzie gathering system: Public Consultation, which includes: Volume 1: Consultation program, Volume 2: Appendices. An eight-volume environmental impact statement (EIS): Volume 1: Overview and impact summary; Volume 2: Project description; Volume 3: Biophysical baseline: Part A - Environmental setting, air quality and noise, Part B - Aquatic resources: groundwater, hydrology and water quality, Part C - Aquatic resources: fish and fish habitat, Part D - Terrestrial resources: soils, landforms, permafrost and vegetation, Part E - Terrestrial resources: wildlife; Volume 4: Socio-economic baseline; Volume 5: Biophysical impact assessment: Part A - Introduction, air quality and noise, Part B - Aquatic resources: groundwater, hydrology and water quality, Part C - Aquatic resources: fish and fish habitat, Part D - Terrestrial resources: Soils, landforms, permafrost and vegetation; Part E - Terrestrial Resources: Wildlife; Part F - Climate change, cumulative effects, biodiversity and environmental effects on the project; Volume 6: Socio-economic impact assessment: Part A - Expenditures, employment, economy, infrastructure and community services, Part B - Wellness, traditional culture, land and resource use and heritage resources, Volume 7: Environmental management; Volume 8: Environmental alignment sheets. (Au)

Environmental impact statement for the Mackenzie Gas Project : [Volume 1: Overview and impact summary, Volume 2: Project description, Volume 3: Biophysical baseline (Parts A-E), Volume 4: Socio-economic baseline, Volume 5: Biophysical impact assessment (Parts A-F), Volume 6: Socio-economic impact assessment (Parts A & B), Volume 7: Environmental management, Volume 8: Environmental alignment sheets]   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources, 2004.
7 v. in 17 (loose-leaf) : ill., maps (some folded), plans (some folded) ; 30 cm + 1 v. ([207] leaves : all maps ; 28 45 cm).
Cover title.
Glossaries.
Contents: Volume 1: Overview and impact summary; Volume 2: Project description; Volume 3: Biophysical baseline: Part A - Environmental setting, air quality and noise, Part B - Aquatic resources: groundwater, hydrology and water quality, Part C - Aquatic resources: fish and fish habitat, Part D - Terrestrial resources: soils, landforms, permafrost and vegetation, Part E - Terrestrial resources: wildlife; Volume 4: Socio-economic baseline; Volume 5: Biophysical impact assessment: Part A - Introduction, air quality and noise, Part B - Aquatic resources: groundwater, hydrology and water quality, Part C - Aquatic resources: fish and fish habitat, Part D - Terrestrial resources: Soils, landforms, permafrost and vegetation, Part E - Terrestrial Resources: Wildlife, Part F - Climate change, cumulative effects, biodiversity and environmental effects on the project; Volume 6: Socio-economic impact assessment: Part A - Expenditures, employment, economy, infrastructure and community services, Part B - Wellness, traditional culture, land and resource use and heritage resources; Volume 7: Environmental management; Volume 8: Environmental alignment sheets.
Also available on 2 CD-ROMs. The first CD-ROM is entitled: Environmental impact statement for the Mackenzie Gas Project: Volume 1: Overview and impact summary, Volume 2: Project description, Volume 3: Biophysical baseline, Volume 4: Socio-economic baseline, Volume 5: Biophysical impact assessment, Volume 6: Socio-economic impact assessment, Volume 7: Environmental management. The second CD-ROM is entitled: Environmental impact statement for the Mackenzie Gas Project: Volume 8: Environmental alignment sheets.
Submitted to National Energy Board and the Joint Review Panel.
References.
Also available on the Web.
ASTIS record 56526 describes the environmental impact statement "in brief".
Volume 4: Part B Socio-Economic Baseline Community Reports and Volume 6: Part C Socio-Economic Impact Assessment Community Reports, each consisting of 30 individual reports, were published separately in May 2005 and have been indexed individually in ASTIS.
ASTIS record 54846.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/EIS.html
Libraries: ACU

This Environmental Impact Statement (EIS) for the Mackenzie Gas Project has been developed over the last three years using a community, issue-focused approach that incorporates the input of those communities likely to be affected by the project. This is in keeping with the direction provided by the various regulatory agencies that are responsible for assessing and regulating energy developments in the Northwest Territories (see the Cooperation Plan [ASTIS record 49743], Northern Pipeline Environmental Impact Assessment and Regulatory Chairs' Committee [Chairs' Committee] 2002a). This EIS presents: an overview of the project, for the purpose of an environmental assessment, a description of biophysical and socio-economic baseline conditions, an assessment of potential impacts organized according to key questions and developed with community input, a description of mitigation measures to reduce adverse biophysical and socio-economic impacts, a summary of environmental management plans designed to reduce or manage adverse biophysical project effects while enhancing beneficial effects to the communities of the Northwest Territories. The operator of each field will develop the anchor fields after individual approvals by the National Energy Board (NEB) have been received. The project proponents have agreed to participate in a common EIS submission and review process. As a result, the EIS submission has been prepared on behalf of the anchor field operators, the owners of the gathering system (including the natural gas liquid [NGL] pipeline), and the owners of the gas pipeline. [This environmental impact statement (EIS) consists of: Volume 1: Overview and impact summary; Volume 2: Project description; Volume 3: Biophysical baseline: Part A - Environmental setting, air quality and noise, Part B - Aquatic resources: groundwater, hydrology and water quality, Part C - Aquatic resources: fish and fish habitat, Part D - Terrestrial resources: soils, landforms, permafrost and vegetation, Part E - Terrestrial resources: wildlife; Volume 4: Socio-economic baseline; Volume 5: Biophysical impact assessment: Part A - Introduction, air quality and noise, Part B - Aquatic resources: groundwater, hydrology and water quality, Part C - Aquatic resources: fish and fish habitat, Part D - Terrestrial resources: Soils, landforms, permafrost and vegetation, Part E - Terrestrial Resources: Wildlife; Part F - Climate change, cumulative effects, biodiversity and environmental effects on the project; Volume 6: Socio-economic impact assessment: Part A - Expenditures, employment, economy, infrastructure and community services, Part B - Wellness, traditional culture, land and resource use and heritage resources, Volume 7: Environmental management; Volume 8: Environmental alignment sheets. Related documents include: the Application for the Mackenzie gathering system (ASTIS record 54845), presented in four volumes: Volume 1: Gathering System Overview, Volume 2: Engineering Design, Volume 3: Construction and Operations, Volume 4: Gathering Pipelines and NGL Pipeline Route Maps. ASTIS record 54842 describes: Application for Approval of the Development Plan for Niglintgak Field; ASTIS record 54841 describes: Application for Approval of the Development Plan for Parson Lake Field; and ASTIS record 54840 describes: Application for Approval of the Development Plan for Taglu Field. Supporting documents filed in support of the application for the Mackenzie gathering system include: Public Consultation (ASTIS record 54827): Volume 1: Consultation program, Volume 2: Appendices.] (Au)

Mackenzie gathering system, Mackenzie Valley pipeline : supplemental information - project update   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources Ventures Limited, 2005.
1 v. (loose-leaf) : ill., maps (some folded) ; 29 cm.
Submitted to National Energy Board and Joint Review Panel.
Glossary.
References.
Also available on CD.
Also available on the Web.
Report date: November 2005.
Report no. IPRCC.PR.2005.15.
ASTIS record 58530.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Documents/PU_2005_Contents.pdf
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/projectupdate.html
Libraries: ACU

On October 7, 2004, Imperial Oil Resources Ventures Limited (Imperial) submitted to the National Energy Board: an application for a Certificate of Public Convenience and Necessity for the Mackenzie Valley Pipeline, pursuant to Part III of the National Energy Board Act; an application for authorization of the Mackenzie Gathering System, pursuant to paragraph 5(1)(b) of the Canada Oil and Gas Operations Act. An Environmental Impact Statement (EIS) supporting these applications was also filed with the Joint Review Panel. Since filing these applications and the EIS, some changes have been made to the proposed design and the location of certain of the Mackenzie gathering system and Mackenzie Valley pipeline facilities. The changes to the Mackenzie gathering system include: relocating the Inuvik area facility about 16 km south; increasing the length and size of the Storm Hills lateral; moving some infrastructure sites to support construction of the relocated Inuvik area facility. The changes to the Mackenzie Valley pipeline include: increasing the pipeline design pressure from 18.0 MPa to 18.7 MPa; reducing the number of initial compressor stations from four to three, while maintaining the capability of the pipeline system of about 34 Mm/d (1.2 Bcf/d); shortening the length of the pipeline by about 26 km; relocating some infrastructure sites to support construction of the revised facility locations; moving some infrastructure sites to support construction of the relocated compressor stations. Imperial is now submitting a document entitled Supplementary Information - Project Update detailing the changes and their associated environmental assessment. An electronic copy of the document is being filed with the NEB and JRP. Hard copies of the document are also being sent via courier. (Au)

Mackenzie Gas Project environmental impact statement, additional information   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources Ventures Limited, 2005.
2 v. (various pagings) : ill., maps (some fold-out) ; 30 cm.
Appendices.
References.
Submitted to Joint Review Panel.
Loose-leaf in 2 binders.
Some tables on fold-out pages.
Cover title: Environmental impact statement for the Mackenzie Gas Project, additional information [part 1 and part 2].
Spine title: Mackenzie Gas Project EIS, additional information.
Available as a PDF file on CD-ROM titled "Mackenzie Gas Project environmental impact statement, additional information, March 2005". The first 3 pages of the PDF file comprise the accompanying cover letter, dated March 28, 2005, from A.D. Martin, Manager of Regulatory Affairs for Imperial Oil Resources Ventures Limited to Paula Pacholek, Manager of the Joint Review Panel for the Mackenzie Gas Project.
Also available from the Web.
ASTIS record 54846 describes the Mackenzie Gas Project environmental impact statement.
ASTIS record 58887.
Languages: English
Web: http://www.ngps.nt.ca/additionalinfo/MGP_Dec_03_Response.html
Libraries: ACU

... In a letter to the project proponents, dated December 3, 2004, the JRP [Joint Review Panel] indicated that they had conducted a conformity check between the Terms of Reference and the EIS [Environmental Impact Statement] contents. They identified some areas of the EIS where additional information was needed to enable the JRP to complete its initial EIS review. The purpose of this document is to provide the additional information that the JRP requires to enable it to complete its initial EIS review. ... The JRP requested information in the following categories: 1. Sustainability; 2. Traditional and Local Knowledge; 3. Public Participation; 4. Project Description, the Proponents and Personnel; 5. Human Environment; 6. Biophysical Environment; 7. Cumulative Effects; 8. Accidents and Malfunctions; 9. Emergency Preparedness and Emergency Response; 10. Unfinished Work Identified by the Proponents; 11. Additional Information Requested by the Panel. The contents of this document have been organized to reflect, as far as possible, the organization of the information in the JRP's letter. ... (Au)

Mackenzie gathering system and Mackenzie Valley pipeline updated preliminary engineering alignment sheets   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources Ventures Limited, 2006.
1 v. (various pagings) : ill., maps ; 28 45 cm.
Contents: Contents - Overview - Glossary - Gathering Pipelines (one 1:4,500,000 overview map, two 1:250,000 index maps, twenty-six 1:30,000 alignment sheets) - NGL Pipeline (one 1:4,500,000 overview map, seven 1:250,000 index maps, fifty-nine 1:30,000 alignment sheets) - Gas Pipeline (one 1:4,500,000 overview map, sixteen 1:250,000 index maps, one hundred fifty three 1:30,000 alignment sheets).
Submitted to the National Energy Board.
Report date: May 2006.
Report no. IPRCC.PR.2006.05.
The printed document includes a cover letter, dated May 24, 2006, from A.D. Martin, Manager of Regulatory Affairs for Imperial Oil Resources Ventures Limited, to Michel Mantha, Secretary of the National Energy Board.
Available as a PDF files on CD-ROM entitled "Mackenzie Gathering System and Mackenzie Valley Updated Pipeline Preliminary Engineering Alignment Sheets, May 2006".
Also available as PDF files from the Web. The PDF files include a cover letter, dated May 31, 2006, from A.D. Martin, Manager of Regulatory Affairs for Imperial Oil Resources Ventures Limited, to Paula Pacholek, Manager of the Joint Review Panel.
ASTIS record 63742.
Languages: English
Web: https://apps.neb-one.gc.ca/REGDOCS/File/Download/440342
Libraries: ACU

... This document contains: 1) a series of updated preliminary engineering alignment sheets for the proposed gathering, NGL and gas pipelines; 2) overview maps and index maps for the preliminary engineering alignment sheets. In this document, the updated preliminary engineering alignment sheets (Rev. B), dated May 2006, supersede those previously filed as Rev. A in January 2005 [see ASTIS record 58889]. ... The updated preliminary engineering alignment sheets have been prepared at a scale of 1:30,000 and contain: [1] a ground surface profile at a 1:1,000 vertical scale, where possible, otherwise the scale factor is increased by increments of 1,000; [2] the preliminary location of heavy wall pipe for watercourse crossings and road crossings; [3] kilometre posts; [4] terrain types; [5] the location of landforms and geological features, such as patterned ground, pingos and karst topography; [6] the location of facilities, including compressor stations and valve sites; [7] the location of longitudinal slopes greater than: 7 within the Inuvialuit Settlement Region, 11 from the Inuvik area facility to Loon River, 8.5 from Loon River to Great Bear River, 7.5 from Great Bear River to the NOVA Gas Transmission Ltd. (NGTL) interconnect facility system just south of the Northwest Territories-Alberta boundary; [8] the preliminary location of temporary workspace for watercourse crossings and road crossings. ... A preferred 1-km-wide corridor has been identified for the gathering, NGL, and gas pipelines and related facilities .... The updated preliminary alignment engineering sheets are presented from north to south, which is the direction of flow for each pipeline. Each sheet consists of: a photomosaic showing the planned pipeline route; a pipeline schematic; a construction right-of-way plan; a ground surface elevation profile; data bands showing terrain type and longitudinal slopes greater than 7. ... Photomosaics include the pipeline route, other project components and other features. The features are identified in a legend at the top right of the sheet or by callout boxes, or labels, on the photomosaic. The line feature representing the pipeline route indicates the centre of the planned right-of-way. ... (Au)

Mackenzie Gas Project : supplemental information, project update   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources Ventures Limited, 2007.
1 v. (loose-leaf) : ill., maps (some fold-out) ; 30 cm.
Appendix.
Glossary.
Submitted to National Energy Board and Joint Review Panel.
Report date: May 2007.
Report no. IPRCC.PR.2007.08.
Also available on CD.
Also available from the Web.
ASTIS record 63737.
Languages: English
Web: http://www.mackenziegasproject.com/theProject/regulatoryProcess/applicationSubmission/Applicationscope/projectupdate2007.html
Libraries: ACU

... On March 12, 2007, the proponents filed an updated cost estimate and schedule with the NEB and JRP. The cost of the initial and future facilities for the Mackenzie Gas Project is estimated to be about $16.2 billion (2006 Cdn), with an earliest project start in 2014. The ongoing engineering and construction planning continues to improve the technical definition of project requirements. However, the fundamental design of all project pipelines and facilities is unchanged. ... This update describes refinements to the project that respond to community input, workforce availability and increasing costs. The update has been structured to address the March 26, 2007, letter from the JRP. In many areas, this document consolidates the changes from the 2004 regulatory filings and supplemental filings up to March 31, 2007. As the fundamental design of the project has not changed, this update focuses on the ongoing refinements of the construction plans. These refinements are largely related to the timing of activities and some location changes. Specifically, this update: identifies changes, discussed during the public hearings, that have been made to the location of some project sites in response to community input; describes improvements to the construction plans that have been made in response to workforce availability and increased costs; provides the results of the updated biophysical and socio-economic assessments associated with the refinements and location changes; consolidates and updates the project descriptions provided in the previously filed applications for the anchor fields, the Mackenzie gathering system, the Mackenzie Valley pipeline and Volume 2 of the EIS. During the JRP Topic 10 hearings on Project-Related Expenditures and Economic Benefits in Yellowknife from November 6 to 8, 2006, the proponents indicated that they would consider the need to provide a revised assessment of economic effects, based on the updated cost. The summary of economic effects is provided in Section 10. Detailed information on the predicted economic impacts is being filed separately with the JRP [see ASTIS record 63741] .... Information in this update is structured to align with EIS Volume 2, Project Description, as follows: Anchor Fields (see Section 2); Pipelines (see Section 3); Facilities (see Section 4); Infrastructure (see Section 5); Logistics and Transportation (see Section 6); Expenditures and Workforce (see Section 7); Environmental Inputs and Outputs (see Section 8); Biophysical Assessment (see Section 9); Socio-Economic Assessment (see Section 10). ... (Au)

Mackenzie gathering system, Mackenzie Valley pipeline : updated costs, tolls and fees   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources Ventures Limited, 2007.
iv, 1-1 - 1-8, 2-1 - 2-14, 3-1 - 3-10, 4-1 - 4-8 : ill. ; 28 cm.
Submitted to National Energy Board.
Report date: March 2007.
Report no. IPRCC.PR.2007.03.
The printed document includes a cover letter, dated March 30, 2007, from Rick Pawlik, Manager of Regulatory Affairs for Imperial Oil Resources Ventures Limited, to Michel Mantha, Secretary of the National Energy Board.
Also available from the Web.
ASTIS record 63739.
Languages: English
Web: https://apps.neb-one.gc.ca/REGDOCS/Item/View/458031
Libraries: ACU

... The estimated capital costs related to the design and construction of the Mackenzie gathering system and the Mackenzie Valley pipeline have been updated. ... Although the design of the pipelines and facilities are unchanged from that described in the applications for approval of the Mackenzie gathering system and the Mackenzie Valley pipeline that were submitted to the National Energy Board (NEB) in October 2004, the estimate includes more detailed definition of facility, pipeline and construction requirements. ... This updated estimate includes current data on the costs of such key items as: steel; construction equipment; labour; fuel. Costs for these inputs are very different today than they were in August 2004 when the previously filed project costs were estimated. Other factors contributing to higher costs include: an improved understanding of the costs for developing extensive infrastructure in remote areas in the North; additional costs associated with the duration of the review process The updated cost estimates reflect: growth in unit prices from 2003 for such items as materials, equipment and labour; revisions to the project construction plan, based on the current schedule and three full years of pipeline installation; revisions to the project scope, as described in the Project Update submitted in November 2005; increases in the quantities of materials and total work hours based on detailed definition and crewing estimates for most construction activities; allowances for contingency and risk; the extended length of the regulatory process leading to the receipt of permits and authorizations required before the proponents can make a decision to proceed. ... The updated estimates are expressed in constant Q2 2006 Canadian dollars. ... (Au)

Estimated economic impacts of the Mackenzie Gas Project : construction and operations update with revised capital expenditure   /   Ellis Consulting Services   AMEC Earth & Environmental Limited [Sponsor]
[S.l.] : Ellis Consulting Services, 2007.
viii, 1-1 - 1-2, 2-1 - 2-42, 3-1 - 3-8, 4-1 - 4-8, 5-1 - 5-8, 6-1 - 6-8, 7-1 - 7-8, 8-1 - 8-8, 9-1 - 9-8, 10-1 - 10-10, G-1 - G-6 ; 28 cm.
Report date: May 2007.
Many tables.
This report supersedes the previously filed report: Predicted Economic Impacts of the Proposed MGP Construction and Operations (November 15, 2004).
Also available from the Web.
The on-line PDF file includes a cover letter, dated May 17, 2007, from Rick Pawlik, Manager of Regulatory Affairs for Imperial Oil Resources Ventures Limited, to Paula Pacholek, Manager of the Joint Review Panel.
ASTIS record 63741.
Languages: English
Web: http://www.ngps.nt.ca/Upload/Proponent/Imperial%20Oil%20Resources%20Ventures%20Limited/070517_Est_Economic_Impacts_MGP_rep_and_cl.pdf
Libraries: ACU

... This report presents the results of the revised analysis [of cost estimates]. ... The impacts of the project were analyzed using four variables: gross domestic product (GDP); employment; labour income; government revenue. Estimates of economic impacts were determined from simulations using the Statistics Canada input-output model and a tax model developed by Ellis Consulting Services. ... The model simulations provide estimates of the direct impact associated with the on-site construction of the pipeline and the three anchor fields and with the impacts generated by the spin-off from this activity. The spin-off economic impacts are referred to as indirect and induced effects .... Direct impacts are derived from the employment and production generated by direct project expenditures. Indirect impacts include the economic activity associated with firms and their workers that are in the production chain, supplying goods and services to the businesses supplying the direct project requirements. Induced impacts result from workers, who are involved in direct and indirect production of consumer goods and services, spending their earnings (after withdrawing a portion for taxes and savings). ... All dollar values presented in this analysis are measured in constant 2006 Canadian (Cdn) dollars. All employment for construction is represented as number of jobs. ... The project's Construction Phase will occur over the four years between 2010-2011 and 2013-2014. ... Although project construction will result in substantial benefits to the NWT, most of the economic impacts resulting from construction will accrue to the southern provinces .... The largest portion (44%) or $5.0 billion of direct project expenditure will be made in Alberta and $1.8 billion (15%) will be made in the NWT. The foreign sector (16%) and Ontario (14%) will be the next largest spending locations. ... The largest impact [on GDP] during construction would be in Alberta, where $3.4 billion (57%) of direct GDP would be generated. The next largest impact would be in the NWT, with $1.3 billion (21%) of total GDP. An estimated total of $6.0 billion in direct GDP will be generated in Canada as a result of project construction. The annual average increase in GDP in Canada is predicted to be $1.5 billion. ... The largest impact [on employment] during construction would be in Alberta, where 36,300 (65%) indirect jobs would be generated. The next largest impact would be in Ontario, with 7,200 (13%). An estimated 1,500 (3%) indirect jobs would accrue to NWT residents. An estimated total of 55,700 indirect jobs would be generated in Canada as a result of project construction, and an average of 14,000 jobs created annually. ... The largest impact [on labour income] during construction would be in Alberta, where $785 million (48%) of direct labour income would be earned. The next largest impact would be in the NWT, with $322 million (20%). An estimated total of $1.6 billion in direct labour income would be generated in Canada during construction. Labour income in Canada would rise by a predicted average of $407 million annually. ... In addition to having a positive impact on the business and household sectors, the territorial, provincial and federal governments will benefit from project construction through higher revenue from business and personal direct taxes .... (Au)

Mackenzie Gas Project - Hearing Order GH-1-2004 : proponents' comments on JRP recommendations that fall outside the NEB's mandate   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources Ventures Limited, 2010.
9 p. ; 28 cm.
(Mackenzie Gas Project National Energy Board procedural update no. 14 : proponents' response)
No title page; title taken from the letter.
References as footnotes.
This response is in the form of a nine-page letter, dated January 28, 2010, from Rick D. Pawluk, Mackenzie Gas Project Manager of Regulatory Affairs, to Ms. Anne-Marie Erickson, Acting Secretary, National Energy Board.
Indexed a PDF file available on the Web.
ASTIS record 69250.
Languages: English
Web: https://apps.neb-one.gc.ca/REGDOCS/File/Download/593090

In response to the National Energy Board's January 6, 2010 Procedural Update No. 14, the Mackenzie Gas Project (MGP or Project) proponents hereby submit their comments regarding certain of the Joint Review Panel (JRP) recommended measures (Recommendations), which have been directed to the Government of the Northwest Territories (GNWT), to the Government of Canada and to others. The proponents' comments relate to both Recommendations that the proponents believe require clarification, as well as Recommendations that affect execution of the Mackenzie Gas Project or encumber future oil and gas development in the North. This letter addresses both general and specific concerns the proponents have with some of the Recommendations. A. General Concerns - Recommendations Regarding the Future Granting of Rights or Approvals. A number of Recommendations ask governments or regulators to refrain from granting rights or regulatory approval, or taking steps to facilitate future facility applications, unless or until some further action is completed. The proponents submit that these Recommendations should not be accepted by governments or regulators, as decisions regarding future developments are more appropriately made when a specific application is submitted for consideration. ... Recommendations Requiring Third Party Action. Numerous Recommendations are addressed to third parties over which the proponents have no influence or control. Generally, the third parties are required to complete a particular activity within a certain amount of time from the date of the Government Response to the JRP Report, or relative to a project milestone. It is the proponents' position that these Recommendations are properly interpreted as merely establishing a time frame for completing a particular activity by that third party, and should not be interpreted as preventing the proponents from obtaining necessary regulatory approvals or proceeding with project execution if the third party does not complete the activity outlined in the Recommendation. ... B. Specific Concerns: [proponents' response to 8 specific concerns, including: the storage of bulk fuel, dredging and disposal of dredge spoils, the incorporation of socio-cultural and ecological thresholds for the region, harvester compensation agreements, pit or quarry permits, heritage resources impact assessments, a benefit agreement with Dehcho First Nations, and the provision of addiction prevention and sexual education programs]. ... C. Concluding Remarks .... (Au)

Mackenzie Gas Project - Hearing Order GH-1-2004 : proponents' comments on JRP recommendations within the NEB's mandate   /   Imperial Oil Resources Ventures Limited
Calgary, Alta. : Imperial Oil Resources Ventures Limited, 2010.
15 p. ; 28 cm.
(Mackenzie Gas Project National Energy Board procedural update no. 14 : proponents' response)
No title page; title taken from the letter.
References as footnotes.
This response is in the form of a 15-page letter, dated January 28, 2010, from Rick D. Pawluk, Mackenzie Gas Project Manager of Regulatory Affairs, to Ms. Anne-Marie Erickson, Acting Secretary, National Energy Board.
Indexed a PDF file available on the Web.
ASTIS record 69251.
Languages: English
Web: https://apps.neb-one.gc.ca/REGDOCS/File/Download/593187

In accordance with Procedural Update No. 14 issued by the National Energy Board (NEB or Board) on January 6, 2010, the Mackenzie Gas Project (MGP or Project) proponents hereby submit their comments regarding certain of the Joint Review Panel (JRP) recommended measures (Recommendations), which have been directed to the NEB. Before providing comments relating to specific Recommendations, the proponents have the following comments, which apply to more than one Recommendation. A. Recommendations Concerning Future Applications. A number of Recommendations ask the NEB to refrain from granting regulatory approval for future facility applications or activities until some further action is completed. The proponents submit that the NEB should reject these Recommendations. In addition, some Recommendations ask the NEB to attach conditions to a Certificate of Public Convenience and Necessity (Certificate) which has not yet been applied for by NOVA Gas Transmission Ltd. (NGTL). The NGTL facilities were scoped and assessed as part of the Environmental Impact Statement reviewed in the JRP process. However, the appropriate time to review and consider conditions applicable to these facilities is when that application is before the NEB. ... B. Recommendations Requiring Agreement of Third Parties. Several of the conditions recommended to the NEB would require the proponents to satisfy, or obtain endorsement or approval from, a third party prior to the NEB approving a particular plan or program. The proponents submit that such a requirement is inappropriate and should be rejected. In some instances, the third parties identified in the Recommendation already have regulatory authority. ... C. Provision of information to other appropriate regulators. ... The proponents submit that this Recommendation, if accepted, may delay receipt of approvals from the Board if the Board has to wait for input from other appropriate regulators. ... D. Proposed Timing of Compliance with Construction Conditions. ... As stated in the proponents' letter to the Board dated March 30, 2007, the proponents understand that the "commencement of construction" includes preparing the right-of-way and sites for the pipelines and associated facilities. The proponents assume that "pre-construction activities" refer to constructing the required infrastructure off the right-of-way, such as barge landings, borrow sites, camps, storage sites, roads, airstrips and helipads. ... E. Comments Relating to [14] Specific Recommendations ... F. Concluding Remarks. (Au)

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