Hydrocarbon Impacts = Incidences des hydrocarbures

Key Publications

Mackenzie Gas Project : proceedings from the NGO Environmental Impact Assessment Workshop, Yellowknife, Northwest Territories, December 9-10, 2003   /   AMEC   Imperial Oil Resources Ventures Limited [Sponsor]
Calgary, Alta. : AMEC, 2004.
[76] p. ; 28 cm.
Appendix A: List of attendees - Appendix B: Proceedings of the small group discussions - Appendix C: Exit questionnaire: summary responses.
Distributed to workshop participants by Tate Communications and Consulting, Yellowknife, N.W.T., as a Microsoft Word file.
ASTIS record 53460.
Languages: English
Libraries: ACU

Workshop Purpose: The main purpose of the NGO Workshop was to introduce the [Mackenzie Gas Project] to those NGOs that have expressed interest in it. It was also a chance for representatives of potentially affected communities, the project and its environmental assessment team to develop a better understanding about the NGO's concerns and suggestions about the proposed project. Workshop Objectives: To realize this purpose, the workshop was organized with the following objectives in mind: review and discuss with NGOs the work completed to the end of November 2003 and, in particular, the issues that scoped with the communities and some northern-based NGO representatives; describe project effects identified to this point and the steps being taken to assess them; discuss the remaining steps to be undertaken for preparation of the EIS; review suggestions about when and how additional community and NGO input might be gathered; help facilitate an understanding among the NGO representatives for the various community perspectives associated with the project, and register the importance of these perspectives to preparation of the EIS; ensure that community representatives are aware of NGO concerns about the project, and their suggestions for how project effects might be managed. As with input received from community representatives, input received from NGO representatives will be distributed directly to the members of the assessment team. Having members of the assessment team participate in the workshop enables a direct exchange of information to occur between the assessment team and NGO representatives. This will increase the assessment team's understanding of the NGOs' suggestions and recommendations. Workshop Approach: ... Workshop attendees included representatives of local, national and international NGOs, and representatives from key leadership organizations within the Inuvialuit Settlement Region, Gwich'in Settlement Area, Sahtu Settlement Area and Deh Cho Region. Names of the invitees and attendees and their organizations are listed in Appendix A. Representatives of the project proponents, along with MPEG and ColtKBR representatives were present to facilitate discussions and to provide resources where needed. ... The format of the workshop consisted of a combination of facilitated plenary sessions and small breakout group discussions. ... The points and issues raised and discussed in these small groups are contained in Appendix B. (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 Mm³/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)

Comprehensive study report : Devon Beaufort Sea exploration drilling program   /   Devon Canada Corporation
Calgary, Alta. : Devon Canada Corporation, 2004.
xii, 1-1 - 1-4, 2-1 - 2-14, 3-1 - 3-2, 4-1 - 4-4, 5-1 - 5-8, 6-1 - 6-6, 7-1 - 7-8, 8-1 - 8-10, 9-1 - 9-6, 10-1 - 10-6, 11-1 - 11-6, 12-1 - 12-6, 13-1 - 13-8, 14-1 - 14-8, 15-1 - 15-10, 16-1 - 6-14, 17-1 - 17-20, 18-1 - 18-4, 19-1 - 19-2, 20-1 - 20-10, 21-1 - 21-6, 22-1 - 22-14, 23-1 - 23-12, 24-1 - 24-10 : ill., maps ; 28 cm.
Indexed from PDF files on the Web.
The report is in six parts, contained in six PDF files on the Web. The first URL provides a link to both the English and French versions of this report, as well as other reports. Subsequent URLs link to chapters 1 through 24 of the English version of the report.
Appendix.
References.
Report date: August 2004.
BREA Report Type: Comprehensive Study Report.
BREA Baseline Data: Yes.
BREA Biophysical / Valued Components: Yes.
BREA Development Scenarios / Activities: Yes, only for offshore exploration.
BREA Impact Hypotheses: Yes, effects attributes and program effects described for each valued component.
BREA Environmental Concerns Identified: Yes.
BREA Harvest Concerns Identified: Yes.
BREA Social Concerns Identified: Yes, section 17.
BREA Research / Monitoring Recommendations: Yes, effects monitoring proposed.
ASTIS record 65912.
Languages: English
Web: http://www.neb.gc.ca/clf-nsi/rthnb/pblcrgstr/pblcrgstrsrchv/dvncndbfrts/dvncndbfrts-eng.html#csr

Introduction: This Comprehensive Study Report (CS Report) presents a summary of the potential biophysical and socio-economic effects of Devon Canada Corporation's (Devon) proposed Beaufort Sea Exploration Drilling Program (the Program). More detailed information is provided in a series of biophysical and socio-economic baseline reports (KAVIK-AXYS Inc. 2004a), as well as in the discipline-specific assessments in the supporting Technical Assessment Report (TA Report) (KAVIK-AXYS Inc. 2004b). The TA Report includes details on assessment methods, findings of the assessment, proposed environmental management and mitigation programs, the determination of significance, and recommended monitoring and follow-up programs. Program Overview: The Program entails exploration drilling on Devon's offshore Exploration Licence (EL) 420 in the southern Beaufort Sea, north of the Mackenzie River Delta, to evaluate potential hydrocarbon reservoirs. EL 420 comprises 338,469 ha in two blocks, the Eastern Block (Areas A and B) and the Western Block (Areas C and D), located in relatively shallow water (Figure 1-1). Devon has identified ten potential drilling targets within EL 420, nine of which are located offshore within the landfast ice zone. The exploration drilling will be conducted during the winter, within the landfast ice zone, from one of three potential drilling platform systems: a steel drilling caisson (SDC), a landfast tender-assist drill unit (LTD) or an ice island platform. ... The report is presented in six sections, in six separate PDF files: [1] Table of Contents, Introduction, Project Description, Project Setting, Public Engagement and Consultation, Impact Assessment Methodology, Air Quality, Noise (Chapters 1 to 7) [PDF 3920 KB]; [2] Ice and Physical Oceanography, Geology, Terrain and Sediments, Coastal Processes (Chapters 8 to 10) [PDF 3300 KB]; [3] Chemical Oceanography, Plankton(Chapters 11 and 12) [PDF 2237 KB]; [4] Benthos, Fish and Fish Habitat, Birds (Chapters 13 and 15) [PDF 5291 KB]; [5] Marine Mammals, Socio-economic Conditions (Chapters 16 and 17) [PDF 4175 KB]; [6] Traditional Knowledge and Land Use, Heritage Resources, Land and Resource Use, Effects of the Environment on the Program, Accidents and Malfunctions, Summary and Conclusions, References (Chapters 18 to 24 and Appendix A - Scope of the Environmental Assessment and Environmental Impact Screening and Review) [PDF 4303 KB]. (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 Gm³ (3.8 Tcf) of raw gas-in-place. The ultimate gas recovery is expected to be 81 Gm³ (2.8 Tcf). The initial production rate is about 12.6 Mm³/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 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)

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 Gm³ 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)

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