DOCSLIB.ORG

Kearl Oil Sands Project Description Update

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
Kearl Oil Sands Project Description Update Kearl Project Description Update – Kearl Mine Development May 2006 This document contains forward-looking information on future production, project start-ups and future capital spending. Actual results could differ materially due to changes in project schedules, operating performance, demand for oil and gas, commercial negotiations or other technical and economic factors. WB00200 06 05 PROPOSED DEVELOPMENT exploring for and producing oil and natural gas, The Kearl Oil Sands Project is a potential oil-sands refining and marketing petroleum products, and mining, pipeline and upgrading project in Alberta, manufacturing and selling petrochemicals. It has proposed by Imperial Oil Resources Ventures about 5,100 employees in two operating divisions - Limited (Imperial Oil) and ExxonMobil Canada the Resources Division and the Products and Properties (ExxonMobil Canada). Imperial Oil Chemicals Division. Resources, as designated operator, submitted the Resources Division mine application (leases included in Kearl Imperial's Resources Division manages the application are shown in figure) and related company's natural resource operations and is based environmental impact assessment to the Alberta in Calgary, Alberta. It is one of Canada's largest Energy and Utilities Board and Alberta Environment producers of crude oil and natural gas. It is a in July 2005. The company responded to the leading developer of Canada's vast oil sands regulators' information requests in March 2006 and resources through its 25 percent ownership of the expects to hold public hearings in the second half of Syncrude project and its operations at Cold Lake, 2006. Alberta. Imperial is the only original owner of Syncrude still involved in the project and, as a Athabasca River result, has a long history of contributing to the Fort McMurray community and Wood Buffalo Region. Imperial is also the leader of a Canadian group Imperial Oil advancing the development of natural-gas Fort McKay 6 resources in the Mackenzie Delta region of 88A Petro- Shell Canada Canada's Far North. The company also operates 18 CNRL 87 36 Syncrude 31A pipelines and has ownership interests in several Deer Creek Shell ExxonMobil others. Syncrude Products and Chemicals Division The Products and Chemicals Division manages the Syncrude Syncrude company's petroleum products and chemicals businesses, under the Esso and Mobil brands. The Suncor Suncor products group operates four refineries, and an extensive network of retail and wholesale outlets. It is one of the largest suppliers of refined products in Canada. Of the company's four refineries, three have some capability to process bitumen and are pipeline-connected to the proposed Kearl Fort McMurray development region. The chemicals group operates four manufacturing WHO ARE WE? plants and a number of strategically located Imperial Oil Limited distribution centres across the country. It's one of Imperial Oil Limited is Canada's largest integrated the largest chemical companies in Canada. (production, refining and product delivery) Chemical products include primary petrochemicals, petroleum company. It's a leading producer of crude plastic resins, solvents and additives for lubricating oils. oil and natural gas and a major company by international standards. The company's focus is on 2 ExxonMobil Canada ExxonMobil Canada (formerly Mobil Oil Canada) is a wholly owned subsidiary of Exxon Mobil Corporation and a major petroleum producer in Canada. The company holds a leadership position in key petroleum exploration and production areas, with large working interests in the Hibernia, Terra Nova and Sable offshore energy projects off Canada's East Coast. The company has about 1,100 employees who support its operations across Canada. In western Canada, ExxonMobil operates nine oil and gas facilities and has ownership interests in 13 other facilities. It's also part of the Imperial-led, Canadian group advancing the development of Mackenzie Delta natural-gas resources in Canada's Far North. ExxonMobil's western Canadian holdings include interests in more than three million acres of exploration lands. This includes portions of Leases 36, 31A and 88 in the Athabasca region. PROJECT DETAILS Estimated Production The proposed development will be an open-pit mining operation. Expected eventual production, based on a phased development scenario, could average about 300,000 barrels of bitumen a day, with variations above and below this volume. This will likely involve an initial mine development as early as 2010 with design capacity of about 100,000 barrels-a-day, with two additional phases in 2012 and 2018. Maximum production could be up to 345,000 barrels-a-day. Estimated Resources Based on evaluation drilling carried out to date, total recoverable bitumen before royalties is estimated to be 4.6 billion barrels using current government guidelines. Estimated Cost The initial cost estimate for the mine development was estimated to fall in the $5-8 billion range in 2005 dollars. Work is being done to refine this preliminary cost estimate and fully understand the impact of high industry activity on this estimate. Estimated Schedule Following is a preliminary schedule for the project. 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Task Environmental Baseline Studies Public Consultation and Info. Sharing Release Project Update and Draft EIA Terms EIA Terms of Reference Finalized Environmental Impact Assessment Prepare/File Regulatory Application Regulatory Process/Approvals Engineering, Procurement and Construction First Oil Construction of Second Train Second Train Start-up Third Train (2018) 3 Preliminary Development Concept Shovel Trucks Crusher Conveyor Slurry Plant Oil Sands Slurry Water Mining Hydrotransport/ Conditioning Froth Treatment Diluent Extraction Froth Sand/Water To Market Recycle Water Tailings PROPOSED FACILITIES AND OPERATION Oil-Sands Mine The mine's design concept is similar to existing oil-sands mines in the Fort McMurray region. Plans are to use state-of-the-art, large scale shovels, trucks, crushers and an oil-sands hydrotransport system. The base mine will be developed in a staged approach. The initial mine development (the first train) will involve clearing and draining the surface area, removing the muskeg overburden before mining the oil sands can begin, and stockpiling the muskeg for use in future reclamation. The current planning basis includes an initial mine train with production capacity of about 100,000 barrels-a-day. A second train will follow. These developments would take place on Leases 6 and 87. Bitumen Extraction The mined ore will be crushed, mixed with water for slurrying, transported and conditioned in a pipeline, and fed to a bitumen-extraction facility. The bitumen will be separated as froth – a mixture of bitumen, water and solids. The froth will be further treated in a froth treatment plant to produce bitumen for sale. Bitumen Upgrading Current plans do not include any on-site upgrading facilities for the first phase of development. To reduce the bitumen's viscocity such that it can be shipped by pipeline, a number of blending options are being considered. The product will be transported to market through a pipeline system. Imperial and ExxonMobil own extensive refinery infrastructure in Canada and the U.S. that could receive bitumen or upgraded feedstock to make a variety of refined products. Production may also be sold to third parties. Any future Kearl upgrading capacity or related pipelines to support future mine phases would be the subject of a separate application. Proposed Mining Sequence 4 Tailings Management R11 R10 R9 R8 R7 R6 W4 Proposed T99 Tailings (a mixture of fine clay, River Water Intake sand and water) are a by-product Winter Road Proposed Raw Water Pipe of the bitumen-extraction process. Proposed T98 Powerline N r e v The application includes an i line R a c McClellend Lake Fi s rebagR er a iv b a t h external tailings area in the A Potential northeast portion of Lease 6. External Water Tailings Area Storage T97 Conventional tailings-treatment Plant Site Administration Maintenance and Operations technology is planned for use until Bitumount Shop Camp North Pit r East e iv Pit tailings can be stored in a R Proposed g e k s Powerline T96 u M South depleted mine pit, at which time Pit West Pit consolidated tailings technology Kearl Proposed Lake Project Roads Proposed will be implemented. This will Compensation nterra Road Proposed a Lake C Industry Hot T95 Airstrip Bitumen allow Imperial to minimize surface Natural Product Gas Pipeline Pipeline disturbance, reduce the ultimate Steepbank Gas Pipeline Kinder Mor Fort fine tailings volume and McKay ga n Corridor P T94 Fort accelerate the reclamation of McKay I.R. ipeline the external tailings area. Infrastructure The project includes development of related infrastructure, including a water intake and water pipeline (to allow water to be withdrawn from the Athabasca River), water storage, an operations camp, and roads. Given the project's remote location and estimated commuting time of at least 90 minutes each way, Imperial is planning to have a camp-based operation with a workforce on a rotating schedule. This will allow Imperial Oil to have a safe, healthy, productive and efficient work environment with minimal impact on the Fort McMurray infrastructure. Imperial is planning to fly operators to the site, likely from Edmonton. For this reason Imperial is currently working with other operators on a joint industry airstrip just south of the Kearl leases. Fresh Water Source The current design basis for the project has the Athabasca River as the water source for this development and includes 30 days of on-site contingency water storage which would allow Imperial to reduce withdrawals during low-flow periods that occur in the winter. Streams, small water bodies and the upper reaches of the Muskeg River will be diverted from time to time during the mine operations. These diversions will affect fish and fish habitat in the area. The lost fish habitat will be more than offset with created fish habitat by extending the northern part of Kearl Lake.
Load more

Recommended publications
  • Notice of Application Application No. 1583822
    Fifth Avenue Place #400, 425 – 1 Street SW Calgary, Alberta T2P 3L8 Canada NOTICE OF APPLICATION APPLICATION NO. 1583822 IMPERIAL OIL RESOURCES VENTURES LIMITED TRANSMISSION FACILITIES TO SERVE THE KEARL OIL SANDS PROJECT TAKE NOTICE that Imperial Oil Resources Ventures Limited (IORVL) filed an application with the Alberta Utilities Commission (AUC or the Commission) on August 20, 2008 respecting permits and licenses to construct and operate transmission facilities to serve the Kearl Oil Sands Project. Any party having concerns with Application No. 1583822 (the Application) should file an intervention letter with the AUC by 2:30 p.m. on November 17, 2008. If no bona fide objections are received by the above date, the AUC will process the application in accordance with sections 14 and 15 of the Hydro and Electric Energy Act (the Act) without a hearing or other proceeding. Nature of the Application The Kearl Oil Sands Project will be located in the Athabasca oil sands area approximately 70 km north of Fort McMurray. There will be a raw water intake (RWI) station on the Athabasca River banks, approximately 29 kilometres northwest of the main lease area, that will supply water for the Kearl project via a pipeline connecting the RWI and the project’s main plant. This project was the subject of public hearings and subsequently approved by the regulator in 2007. This application is for permits and licenses, pursuant to sections 14 and 15 of the Act, to construct and operate the following transmission facilities to serve the Kearl Oil Sands Project: • The Kearl Main Substation housing 240/72-kV step down transformers; • The Kearl Facility Substation housing 72-kV switchgear; • The Raw Water Intake Substation containing a 72/13.8-kV step down transformer; • A 240-kV transmission line between the Fort Hills Substation and the Kearl Main Substation; • A 72-kV transmission line from the Kearl Main Substation to the Raw Water Intake Substation; and • A 72-kV transmission line from the Kearl Main Substation to the Kearl Facility Substation.
    [Show full text]
  • First Pipe Arrives for Nord Stream 2
    ISSUE 32 | JUNE 2017 Cover story: First pipe arrives for North Sea resources Interview with SPX Nord Stream 2 update Flow’s Jose Larios Page 20 Page 44 Page 28 CONTENTS STATS GROUP Managing Pressure, Minimising Risk Issue 32 | June 2017 REGULARS INTEGRITY From the editor 4 Best practices in pipeline integrity for gas World wrap 6 pipelines 34 Accurate fatigue assessment for gas Tecno Plug™ News in brief 8 pipeline systems Events update 54 36 Pipelines International is Advertisers’ index 56 SECURITY a proud media partner of Features and deadlines 2017‒18 56 Non-intrusive Inline Isolation Atmos International’s Theft Net IPLOCA NEWS technology 40 Transneft and Technical Productions to RISK MANAGEMENT produce pipeline journal 10 Exciting times for pipeline risk Taper Lock Grips Mitigating the risk of ‘pipe walking’ 12 Self-Energisation management 42 UNPIGGABLE PIPELINES INTERVIEW Unpiggable Pipeline Solutions Forum 14 Pipeline people: Jose Larios 44 Using MFL-equipped robotic unit to Five minutes with NDT Global’s assess an unpiggable pipeline 16 John Fallon 45 REGION IN FOCUS COMPANY NEWS The North Sea 20 ISSUE 32 | JUNE 2017 Clock Spring’s new look and management team PIGGING & ILI 46 POSCO and ExxonMobil pipeline Impact of crack profiles on production partnership 48 pipeline integrity 22 Isolating and pigging a 36 inch trunkline 26 EVENTS PPIM marks 29th year with biggest Cover story: First pipe arrives for North Sea resources Nord Stream 2 Interview with SPX update PROJECTS Page 28 Flow’s Jose Larios Page 20 show to date 50 Page 44 Nord
    [Show full text]
  • UNITED STATES DISTRICT COURT NORTHERN DISTRICT of TEXAS DALLAS DIVISION SARAH VON COLDITZ, Derivatively on Behalf of EXXON MOBIL
    Case 3:19-cv-01067 Document 1 Filed 05/02/19 Page 1 of 142 PageID 1 UNITED STATES DISTRICT COURT NORTHERN DISTRICT OF TEXAS DALLAS DIVISION SARAH VON COLDITZ, Derivatively on ) Case No. Behalf of EXXON MOBIL ) CORPORATION, ) ) VERIFIED SHAREHOLDER Plaintiff, ) DERIVATIVE COMPLAINT FOR v. ) VIOLATIONS OF THE FEDERAL ) SECURITIES LAWS, BREACH OF DARREN W. WOODS, ANDREW P. ) FIDUCIARY DUTY, WASTE OF SWIGER, DAVID S. ROSENTHAL, ) CORPORATE ASSETS, AND UNJUST JEFFREY J. WOODBURY, STEVEN S. ) ENRICHMENT REINEMUND, MICHAEL J. BOSKIN, ) SAMUEL J. PALMISANO, KENNETH C. ) FRAZIER, URSULA M. BURNS, ) HENRIETTA H. FORE, WILLIAM C. ) WELDON, REX W. TILLERSON, ) WILLIAM W. GEORGE, LARRY R. ) FAULKNER, DOUGLAS R. ) OBERHELMAN, and PETER BRABECK- ) LETMATHE, ) ) Defendants, ) -and- ) ) EXXON MOBIL CORPORATION, a New ) Jersey corporation, ) ) Nominal Defendant. ) ) ) ) ) DEMAND FOR JURY TRIAL Case 3:19-cv-01067 Document 1 Filed 05/02/19 Page 2 of 142 PageID 2 TABLE OF CONTENTS Page I. NATURE AND SUMMARY OF THE ACTION ...............................................................1 II. JURISDICTION AND VENUE ........................................................................................10 III. THE PARTIES...................................................................................................................11 A. Plaintiff ..................................................................................................................11 B. Nominal Defendant ................................................................................................11
    [Show full text]
  • THE SUSTAINABLE MANAGEMENT of GROUNDWATER in CANADA the Expert Panel on Groundwater
    THE SUSTAINABLE MANAGEMENT OF GROUNDWATER IN CANADA The Expert Panel on Groundwater Council of Canadian Academies Science Advice in the Public Interest Conseil des académies canadiennes THE SUSTAINABLE MANAGEMENT OF GROUNDWATER IN CANADA Report of the Expert Panel on Groundwater iv The Sustainable Management of Groundwater in Canada THE COUNCIL OF CANADIAN ACADEMIES 180 Elgin Street, Ottawa, ON Canada K2P 2K3 Notice: The project that is the subject of this report was undertaken with the approval of the Board of Governors of the Council of Canadian Academies. Board members are drawn from the RSC: The Academies of Arts, Humanities and Sciences of Canada, the Canadian Academy of Engineering (CAE) and the Canadian Academy of Health Sciences (CAHS), as well as from the general public. The members of the expert panel responsible for the report were selected by the Council for their special competences and with regard for appropriate balance. This report was prepared for the Government of Canada in response to a request from Natural Resources Canada via the Minister of Industry. Any opinions, findings, conclusions or recommendations expressed in this publication are those of the authors – the Expert Panel on Groundwater. Library and Archives Canada Cataloguing in Publication The sustainable management of groundwater in Canada [electronic resource] / Expert Panel on Groundwater Issued also in French under title: La gestion durable des eaux souterraines au Canada. Includes bibliographical references. Issued also in print format ISBN 978-1-926558-11-0 1. Groundwater--Canada--Management. 2. Groundwater-- Government policy--Canada. 3. Groundwater ecology--Canada. 4. Water quality management--Canada. I. Council of Canadian Academies.
    [Show full text]
  • Midstreamnews | PLS Inc | 44 Characters Or Less
    January 21, 2013 • Volume 06, No. 01 MIDSTREAMNEWS Serving the marketplace with news, analysis and business opportunities TransCanada tapped for $5.0 billion B.C. gas pipeline Buffett & Icahn arrive at Newly acquired Petronas sub Progress Energy Canada has chosen TransCanada shale boom by rail to design, build, own and operate the proposed $5.0 billion Prince Rupert gas Warren Buffett’s Berkshire transmission project to transport British Columbia shale gas to the West Coast, where Hathaway and Carl Icahn’s Icahn the gas will be exported as LNG to lucrative Asian markets. The proposed Capital LP are cashing in on continued pipeline will transport gas produced primarily from the North Montney tight transportation capacity in the region near Fort St. John, British May spend $1.5 billion on extension of Bakken. The increasing use Columbia to Progress’ recently proposed Nova line to complement Prince Rupert. of rail to move oil cargo has Pacific Northwest LNG export facility in caused a shortage of tanker cars. Buffett’s Port Edward near Prince Rupert, BC. Although the route has yet to be determined, the Berkshire owns 60% of Marmon pipeline is expected to stretch 466 miles and will have an initial capacity of 2.0 Bcfd Holdings, which in turn owns tank car expandable to 3.6 Bcfd. builder Union Tank Car. (Berkshire is Progress and TransCanada are finalizing agreements, and TransCanada has scheduled to acquire the remaining 40% already begun preparing provincial regulatory filings and is gearing up for talks with of Marmon by 2015.) First Nations and other stakeholders. Input from these groups will help TransCanada formulate the proposed pipeline route.
    [Show full text]
  • And in the MATTER of An
    Enbridge – Line 9 Appendix A-7.1 NATIONAL ENERGY BOARD IN THE MATTER OF the National Energy Board Act and the Regulations made under it; and IN THE MATTER OF an Application by Enbridge Pipelines Inc. pursuant to Part IV of the National Energy Board Act for the approval of tolls and tariffs for westbound service on its Line 9. ENBRIDGE PIPELINES INC. APPENDIX A-7.1 TO LINE 9 APPLICATION Expert Evidence – Report of Muse, Stancil & Co. MMEDIUM-TTERM PPROSPECTS FOR LLINE 99 WWESTBOUND SSERVICE FOR December 2009 15455 Dallas Parkway Two Allen Center 48/54 Moorgate Level 58 Republic Plaza Suite 350 Suite 1600, 1200 Smith Street London EC2R 6EJ 9 Raffles Place Addison, TX 75001-4690 Houston, TX 77002 United Kingdom Singapore 048619 Phone: 214-954-4455 Phone: 713-890-1182 Phone: 44-0-207-374-8994 Phone: 65-6832-1341 Fax: 214-954-1521 Fax: 214-954-1521 Fax: 44-0-207- 374-8995 Fax: 65-6832-1491 TABLE OF CONTENTS Page INTRODUCTION................................................................................................. 1 EXECUTIVE SUMMARY .................................................................................... 2 ONTARIO REFINING OVERVIEW ..................................................................... 6 CANADIAN CRUDE PRODUCTION ..................................................................11 NORTH SEA CRUDE PRODUCTION OUTLOOK............................................ 13 ASSESSMENT OF LINE 9 THROUGHPUT RISK............................................ 17 APPENDIX..........................................................................................................29
    [Show full text]
  • 2013 Financial and Operating Review
    Financial & Operating Review 2 013 Financial & Operating Summary 1 Delivering Profitable Growth 3 Global Operations 14 Upstream 16 Downstream 58 Chemical 72 Financial Information 82 Frequently Used Terms 90 Index 94 General Information 95 COVER PHOTO: Liquefied natural gas (LNG) produced at our joint ventures with Qatar Petroleum is transported to global markets at constant temperature and pressure by dedicated carriers designed and built to meet the most rigorous safety standards. Statements of future events or conditions in this report, including projections, targets, expectations, estimates, and business plans, are forward-looking statements. Actual future results, including demand growth and energy mix; capacity growth; the impact of new technologies; capital expenditures; project plans, dates, costs, and capacities; resource additions, production rates, and resource recoveries; efficiency gains; cost savings; product sales; and financial results could differ materially due to, for example, changes in oil and gas prices or other market conditions affecting the oil and gas industry; reservoir performance; timely completion of development projects; war and other political or security disturbances; changes in law or government regulation; the actions of competitors and customers; unexpected technological developments; general economic conditions, including the occurrence and duration of economic recessions; the outcome of commercial negotiations; unforeseen technical difficulties; unanticipated operational disruptions; and other factors discussed in this report and in Item 1A of ExxonMobil’s most recent Form 10-K. Definitions of certain financial and operating measures and other terms used in this report are contained in the section titled “Frequently Used Terms” on pages 90 through 93. In the case of financial measures, the definitions also include information required by SEC Regulation G.
    [Show full text]
  • Kearl Oil Sands Project – Mine Development
    REVIEW OF COMPONENTS OF THE IMPERIAL OIL RESOURCES VENTURES LIMITED SUPPLEMENTARY INFORMATION AND RESPONSE TO THE MIKISEW CREE STATEMENT OF CONCERN REGARDING THE KEARL OIL SANDS PROJECT – MINE DEVELOPMENT Prepared for: Mikisew Cree First Nation (Mikisew Cree) Industrial Relations Council (IRC) Fort McMurray, Alberta Prepared by: Integrated Environments Ltd. In Association with: DTC Consulting October 2006 Supplementary Information Review Kearl Oil Sands Project TABLE OF CONTENTS 1. Background ..................................................................................................................2 2. Review Process.............................................................................................................3 3. Environmental Management Systems ..........................................................................4 4. Tailings Management...................................................................................................6 5. Liability and Closure Management ..............................................................................7 Integrated Environments Page 1 of 10 Supplementary Information Review Kearl Oil Sands Project 1. Background The Mikisew Cree First Nation (Mikisew Cree) has become increasingly concerned about the long-term effects of Oil Sands and other related developments in North-eastern Alberta. The Mikisew Cree have stated, and continue to state, these concerns directly to Industry and Government in private meetings, and at various regional forums. The reviews of several Oil
    [Show full text]
  • Financial & Operating Review
    Financial & Operating Review 2 013 Financial & Operating Summary 1 Delivering Profitable Growth 3 Global Operations 14 Upstream 16 Downstream 58 Chemical 72 Financial Information 82 Frequently Used Terms 90 Index 94 General Information 95 COVER PHOTO: Liquefied natural gas (LNG) produced at our joint ventures with Qatar Petroleum is transported to global markets at constant temperature and pressure by dedicated carriers designed and built to meet the most rigorous safety standards. Statements of future events or conditions in this report, including projections, targets, expectations, estimates, and business plans, are forward-looking statements. Actual future results, including demand growth and energy mix; capacity growth; the impact of new technologies; capital expenditures; project plans, dates, costs, and capacities; resource additions, production rates, and resource recoveries; efficiency gains; cost savings; product sales; and financial results could differ materially due to, for example, changes in oil and gas prices or other market conditions affecting the oil and gas industry; reservoir performance; timely completion of development projects; war and other political or security disturbances; changes in law or government regulation; the actions of competitors and customers; unexpected technological developments; general economic conditions, including the occurrence and duration of economic recessions; the outcome of commercial negotiations; unforeseen technical difficulties; unanticipated operational disruptions; and other factors discussed in this report and in Item 1A of ExxonMobil’s most recent Form 10-K. Definitions of certain financial and operating measures and other terms used in this report are contained in the section titled “Frequently Used Terms” on pages 90 through 93. In the case of financial measures, the definitions also include information required by SEC Regulation G.
    [Show full text]
  • Backgrounder – Imperial Kearl Oil Sands Mine Hearings Affidavit Extracted from Federal Court of Canada Affidavit of Simon Dyer, Pembina Institute
    Backgrounder – Imperial Kearl Oil Sands Mine Hearings Affidavit Extracted from Federal Court of Canada Affidavit of Simon Dyer, Pembina Institute January 11, 2008 The Imperial Kearl Oil Sands Mine The Kearl Project is a proposed surface oil sands mine and processing facility north of Fort McMurray in Alberta. The Kearl Project is designed to produce more than 300,000 barrels per day of bitumen for a period of 50 years. Oil production is expected by 2010 and full capacity by 2018. The proposed Kearl Project will cover roughly 20,000 hectares (200 square kilometres) of land in northeast Alberta. For comparison, the Canadian Encyclopedia states that the West Edmonton Mall covers 49 hectares. This means that the landscape “footprint” of the Kearl Project will be approximately 400 times greater than that of the West Edmonton Mall. Assessment of Environmental Impacts On July 13, 2006, the federal Minister of Environment and the Chair of the Alberta Energy and Utilities Board signed the Agreement to Establish a Joint Panel for the Kearl Oil Sands Project. In November of 2006, the Panel held hearings, at which the Oil Sands Environmental Coalition (OSEC) appeared and made submissions. The Pembina Institute, as a member of OSEC, participated in and gave evidence at the hearings. On February 27, 2007, the Joint Panel published its report and recommendations concerning the Kearl Project, entitled Imperial Oil Resources Ventures Limited: Application for an Oil Sands Mine and Bitumen Process Facility (Kearl Oil Sands Project) in the Fort McMurray Area (the “Report”). This is available for download at www.ercb.ca (under 2007 Decisions).
    [Show full text]
  • Enbridge's Energy Infrastructure Assets
    Enbridge’s Energy Infrastructure Assets Last Updated: Aug. 4, 2021 Energy Infrastructure Assets Table of Contents Crude Oil and Liquids Pipelines .................................................................................................... 3 Natural Gas Transmission Pipelines ........................................................................................... 64 Natural Gas Gathering Pipelines ................................................................................................ 86 Gas Processing Plants ................................................................................................................ 91 Natural Gas Distribution .............................................................................................................. 93 Crude Oil Tank Terminals ........................................................................................................... 96 Natural Gas Liquids Pipelines ................................................................................................... 110 NGL Fractionation ..................................................................................................................... 111 Natural Gas Storage ................................................................................................................. 112 NGL Storage ............................................................................................................................. 119 LNG Storage ............................................................................................................................
    [Show full text]
  • Liquids Pipelines Customer Handbook
    Enbridge Pipelines Inc. 200, 425 – 1st Street S.W. 2020 Calgary, Alberta, Canada T2P 3L8 Telephone: 403-231-3900 enbridge.com/customerhandbook Liquids Pipelines Customer Handbook Enbridge Liquids Pipelines Customer Handbook February 2020 How to reach us c How to reach us d Table of Contents 1 President’s Message 2 Meeting the Needs of Our Customers 4 North American Supply Projection 6 The Enbridge Mainline 6 Mainline System Capacity 7 Recent Expansions 10 System Optimization 11 Mainline Tolls 12 Oil Sands Infrastructure 12 Existing 13 Development 14 Market Access 14 Eastern Access 15 Southern Access Extension 16 Spearhead Pipeline 18 U.S. Gulf Coast Access 20 Express/Platte 21 Bakken Infrastructure 22 Non-Regulated Contract Terminals 25 Diluent Access 26 Pipeline System Configuration 27 Oil Sands Regional System Configuration 28 Maps • Commodity Movement Map • Athabasca Major Pipelines • Major Canadian and U.S. Forward-looking Information Crude Oil Pipelines and Refineries This booklet includes references to forward-looking information. Although Enbridge believes these forward-looking statements are reasonable, based on the information available on the date such statements are made, they are not guarantees of future performance or outcomes. Life Takes Energy The Energy You Count On, 1 the Reliability You Expect At Enbridge, we exist to help fuel the further mainline optimizations, and of course Vern Yu our largest project, the US portion of the Line quality of life for millions of people across President, 3 Replacement project. The expansion of the Liquids Pipelines, Dakota Access Pipeline and completion of the Gray Oak Pipeline will provide North America. We are North America’s Enbridge Inc.
    [Show full text]