DOCSLIB.ORG

In Situ Oil Sands Technology Trends

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
In Situ Oil Sands Technology Trends STUDY NO. 193 DECEMBER 2020 IN SITU OIL SANDS TECHNOLOGY TRENDS 3512 - 33 Street NW, #150, Calgary, AB T2L 2A6 350 Sparks Street, #805, Ottawa, ON K1R 7S8 403.282.1231 | www.ceri.ca | [email protected] @ceri_canada Canadian Energy Research Institute In Situ Oil Sands Technology Trends Authors: Evar Umeozor, Madie Zamzadeh, Dinara Millington Recommended Citation (Author-date style): Umeozor, Evar, Madie Zamzadeh, and Dinara Millington. 2021. “In Situ Oil Sands Technology Trends.” Study No. 193 Calgary, AB: Canadian Energy Research Institute. https://ceri.ca/assets/files/Study_193_Full_Report.pdf Recommended Citation (Numbered style): E. Umeozor, M. Zamzadeh and D. Millington, “In Situ Oil Sands Technology Trends,” Canadian Energy Research Institute, Calgary, AB, Study No. 193, 2021. URL: https://ceri.ca/assets/files/Study_193_Full_Report.pdf Copyright © Canadian Energy Research Institute, 2021 Sections of this study may be reproduced in magazines and newspapers with acknowledgment to the Canadian Energy Research Institute January 2021 Printed in Canada Acknowledgements: The authors of this report would like to extend their thanks and sincere gratitude to all CERI staff involved in the production and editing of the material. ABOUT THE CANADIAN ENERGY RESEARCH INSTITUTE Founded in 1975, the Canadian Energy Research Institute (CERI) is an independent, registered charitable organization specializing in the analyses of economic and environmental issues in the energy production, transportation and consumption sectors. Our studies examine the most relevant energy issues affecting Canadians, painting a comprehensive picture of the impact policies and business decisions can have so that decision-makers in government, industry and other market segments can make sound decisions to help move Canada forward. For more information about CERI, visit www.ceri.ca CANADIAN ENERGY RESEARCH INSTITUTE 150, 3512 – 33 Street NW Calgary, Alberta T2L 2A6 Email: [email protected] Phone: 403-282-1231 January 2021 In Situ Oil Sands Technology Trends iii Table of Contents List of Figures .................................................................................................................................. vi List of Tables .................................................................................................................................. vii Acronyms and Abbreviations ........................................................................................................ viii Executive Summary ......................................................................................................................... xi : Objectives and Scope ................................................................................................. 13 : Oil Sands Business Environment ................................................................................ 14 2.1 Background ....................................................................................................................................... 14 2.2 Market Access ................................................................................................................................... 18 2.3 Regulatory Environment ................................................................................................................... 21 2.4 Climate Change and Greenhouse Gas Emissions Management ....................................................... 22 Alberta Technology Innovation and Emissions Reduction Regulation (Government of Alberta 2019b) ............................................................................................................................................ 22 Federal Clean Fuel Standard (ECCC 2017b; 2017a) ....................................................................... 23 2.5 In Situ Bitumen Supply Cost.............................................................................................................. 24 : In Situ Technologies and Processes ........................................................................... 27 3.1 Overview ........................................................................................................................................... 27 3.2 Emerging Technologies for Steam Generation ................................................................................. 28 Drum Boilers .................................................................................................................................. 28 Dual Loop Steam Generation ......................................................................................................... 30 Direct Contact Steam Generation .................................................................................................. 30 Flash Boilers ................................................................................................................................... 31 Plasma Fired Steam Generator (PFSG) .......................................................................................... 32 Boiler Blowdown Reduction Technology (BBRT) ........................................................................... 33 Partial and Full Cogeneration through Heat Recovery Steam Generation .................................... 34 Cogeneration through Fuel Cells ................................................................................................... 35 3.3 Solvent and Solvent-Assisted Extraction Processes ......................................................................... 38 Steam-Solvent Co-injection Processes ........................................................................................... 38 Expanding Solvent SAGD (ES-SAGD) / Solvent-Assisted SAGD (SA-SAGD)..................................... 38 Solvent-Aided Process (SAP) .......................................................................................................... 39 Pure Solvent Injection Processes ................................................................................................... 39 January 2021 iv Canadian Energy Research Institute Nsolv .............................................................................................................................................. 39 VAPEX ............................................................................................................................................. 39 Non-Condensable Gas Co-Injection Processes .............................................................................. 40 Steam and Gas Push (SAGP)........................................................................................................... 40 Modified SAGP (eMSAGP) .............................................................................................................. 40 3.4 Other Extraction Technologies and Processes ................................................................................. 41 Electromagnetic (EM) Heating Processes ...................................................................................... 41 Enhanced Solvent Extraction Incorporating Electromagnetic Heating (ESEIEH) Process .............. 41 Radio Frequency (RF) XL Process ................................................................................................... 41 Steam-Surfactant Processes .......................................................................................................... 41 Exothermic Chemical Treatment (ECT) .......................................................................................... 42 NextStream Catalyst Additive ........................................................................................................ 42 3.5 Wells and Well Pads ......................................................................................................................... 44 Lean Manufacturing to Lean Drilling.............................................................................................. 45 Modularization ............................................................................................................................... 45 3.6 Water and Wastewater Treatment .................................................................................................. 45 Oil and Water Separation .............................................................................................................. 47 De-oiling ......................................................................................................................................... 47 Wastewater Treatment.................................................................................................................. 47 Warm Lime Softening (WLS) .......................................................................................................... 47 Adding Dissolved Mg in Warm Lime Softening .............................................................................. 48 Elimination of Warm Lime Softening ............................................................................................. 48 Evaporation .................................................................................................................................... 49 Zero Liquid Discharge (ZLD) ........................................................................................................... 49 Electrocoagulation (EC) .................................................................................................................. 50 High Temperature Reverse Osmosis (HTRO) ................................................................................
Load more

Recommended publications
  • Module 22: Inorganics Removal Basics
    Drinking Water Operator Certification Training Module 22: Inorganics Removal Basics Revised May 4, 2018 This course module was developed by the Pennsylvania Department of Environmental Protection. Content sources are referenced at the end of every module unit. 1 2 DISCLAIMER: This module was designed as a training module for Pennsylvania drinking water operators to study prior to taking the drinking water subclass 9 ion exchange and greensand exam. The focus of this exam is the removal of inorganic constituents from drinking water using the treatment processes ion exchange or greensand filtration. As a result, this training module focuses on the treatment methods of ion exchange units and greensand filters. In addition, there is a focus on the removal of some of the inorganic contaminants common in Pennsylvania groundwater systems: nitrates, iron, and manganese. Since arsenic, barium and mercury, may sporadically be found in Pa. groundwater, treatment options for these contaminants will also be mentioned in this module. Because radionuclides, radon, and hydrogen sulfide may also be found in Pa groundwaters, they are also briefly mentioned. Water softening is also discussed. Note that since lead and copper treatment is covered in Module 20: Corrosion Control and Sequestering, treatment of those inorganic contaminants is not discussed in this module. The 2006 version of the Pa. DEP Inorganic Contaminant Removal module has detailed advanced treatment information on this topic and can be obtained by e-mailing the Pa. DEP Safe Drinking Water Training Section at [email protected] to request a copy. This advanced module has additional information on the removal of various inorganic contaminants as well as on oxidation, ion exchange, activated alumina and sequestration.
    [Show full text]
  • Sulfate Scale
    TECHNICAL SERVICE GUIDE Sulfate Scale The following are general recommendations for controlling sulfate scale in systems using reverse osmosis (RO) and nanofiltration (NF) elements. For additional information on pretreatment or cleaning elements, please see MANN+HUMMEL Water & Fluid Solutions Pretreatment and Cleaning Guides or contact MANN+HUMMEL Water & Fluid Solutions Technical Service. INTRODUCTION Scaling is when sparingly soluble salts precipitate and deposit on the surface of a membrane element. The solubility of barium, calcium and strontium is low and may lead to scale formation on the membrane surface where the salts are most concentrated. This typically affects the elements in the last stage first and then gradually affects the stages upstream. Barium sulfate (BaSO4) is the most insoluble of all the alkaline-earth sulfates. When present in water, it may precipitate and act as a catalyst for calcium and strontium sulfate scaling. Typically, barium can be found in well waters, with typical concentrations less than 0.05 ppm to 0.2 ppm. However, in most natural waters, barium is present at a level that may cause barium sulfate scaling. The critical feed concentration of barium may be as low as 0.015 ppm in seawaters, 0.005 ppm in brackish waters or even 0.002 ppm if sulfuric acid is dosed to brackish waters. Early detection of sulfate scaling is essential to prevent possible damage on the membrane surface. A number of factors can affect the rate of scale formation including temperature and pH control, as well as the use of antiscalants. If the scaling potential for barium, calcium and/or strontium sulfates is high, some common methods to control scaling potential include: • The use of a scale inhibitor or antiscalant is the most common method to reduce sulfate scale • Decreasing the calcium and alkalinity concentrations in the feed solution by means of lime or lime-soda ash softening to lower pHs (the pH of saturation).
    [Show full text]
  • Impacts and Mitigations of in Situ Bitumen Production from Alberta Oil Sands
    Impacts and Mitigations of In Situ Bitumen Production from Alberta Oil Sands Neil Edmunds, P.Eng. V.P. Enhanced Oil Recovery Laricina Energy Ltd. Calgary, Alberta Submission to the XXIst World Energy Congress Montréal 2010 - 1 - Introduction: In Situ is the Future of Oil Sands The currently recognized recoverable resource in Alberta’s oil sands is 174 billion barrels, second largest in the world. Of this, about 150 billion bbls, or 85%, is too deep to mine and must be recovered by in situ methods, i.e. from drill holes. This estimate does not include any contributions from the Grosmont carbonate platform, or other reservoirs that are now at the early stages of development. Considering these additions, together with foreseeable technological advances, the ultimate resource potential is probably some 50% higher, perhaps 315 billion bbls. Commercial in situ bitumen recovery was made possible in the 1980's and '90s by the development in Alberta, of the Steam Assisted Gravity Drainage (SAGD) process. SAGD employs surface facilities very similar to steamflooding technology developed in California in the ’50’s and 60’s, but differs significantly in terms of the well count, geometry and reservoir flow. Conventional steamflooding employs vertical wells and is based on the idea of pushing the oil from one well to another. SAGD uses closely spaced pairs of horizontal wells, and effectively creates a melt cavity in the reservoir, from which mobilized bitumen can be collected at the bottom well. Figure 1. Schematic of a SAGD Well Pair (courtesy Cenovus) Economically and environmentally, SAGD is a major advance compared to California-style steam processes: it uses about 30% less steam (hence water and emissions) for the same oil recovery; it recovers more of the oil in place; and its surface impact is modest.
    [Show full text]
  • Alberta Site Rehabilitation Program Period 5 Eligible Licensees and Allocation Eligibility Amounts
    Alberta Site Rehabilitation Program Period 5 Eligible Licensees and Allocation Eligibility Amounts Please see the Supplemental Guidelines as well as the Main Guidelines for the Program for full details Period 5 Licensee Name Allocation Amount 2155192 Alberta Ltd. $15,845.09 2214896 Alberta Ltd. $121,809.11 611890 Alberta Inc. $35,651.45 840586 Alberta Ltd. $13,864.45 ACCEL Canada Holdings Limited $960,608.45 Conifer Energy Inc. $464,459.14 Acquisition Oil Corp. $302,046.99 Advantage Oil & Gas Ltd. $460,497.87 Aeneid Exploration Inc. $54,467.49 Aeraden Energy Corp. $113,886.57 AlphaBow Energy Ltd. $3,704,779.60 Altima Resources Ltd. $1,980.64 Amicus Petroleum Inc. $123,789.75 Anegada Oil Corp. $123,789.75 APL Oil & Gas (1998) Ltd. $8,912.86 Apogee Petroleum Inc. $331,756.53 ARC Resources Ltd. $2,664,945.71 Artis Exploration Ltd. $89,128.62 Ascensun Oil and Gas Ltd. $124,780.07 Aspenleaf Energy Limited $278,279.35 ATCO Energy Solutions Ltd. $68,331.94 Athabasca Oil Corporation $550,616.80 Avalon Energy Ltd. $35,651.45 Avila Exploration & Development Canada Ltd $21,787.00 Axiom Oil and Gas Inc. $219,850.59 Baccalieu Energy Inc. $249,560.13 Barnwell of Canada, Limited $110,915.62 Barrel Oil Corp. $196,083.36 #Classification: Public Page 1 of 10 Alberta Site Rehabilitation Program Period 5 Eligible Licensees and Allocation Eligibility Amounts Please see the Supplemental Guidelines as well as the Main Guidelines for the Program for full details Period 5 Licensee Name Allocation Amount Battle River Energy Ltd.
    [Show full text]
  • Cold Lime Softening Soda Ash May Be Added to Remove Calcium Hardness Hard Water Is Water That Has High Mineral Content
    The WWETCO FlexFilter™ from WesTech provides an innovative solution for industrial water pretreatment and/or tertiary treatment. The combination of tapered media compression, porosity gradient within the media bed, and a low flow backwash system make the WWETCO FlexFilter™ one of the most versatile and efficient filters on the market. Cold Lime Softening Soda ash may be added to remove calcium hardness Hard water is water that has high mineral content. if the raw water does contain sufficient alkalinity The name comes from the hard scale that forms when for complete removal of hardness. Settled solids this water is boiled. It is not harmful to human react with lime and soda ash to form larger and health, but in the industrial setting it causes costly faster settling particles. The clarified water flows breakdowns in boilers, cooling towers, and other over weirs and the solids (sludge) are scraped to the water handling equipment. The divalent cations center for removal and dewatering. The overflow Mg and Ca are the most frequently found minerals typically has less than 10 mg/L of suspended solids. causing hard water. These ions enter water supplies The amount of hardness remaining will depend on by leaching from minerals in underground aquifers. the water chemistry and proper chemical addition. Cold lime softening is the addition of chemicals Recarbonation to remove the calcium and magnesium ions by After softening, the pH is lowered to less than 8 to precipitation. Cold (ambient temperature) lime stop the softening reaction. This prevents what is softening is used when the mineral content of the called “post-precipitation” where softening continues source water ranges from 150 ppm – 500 ppm.
    [Show full text]
  • Lime Softening Sources, Have Relatively Stable Water Which and the Complexity of the Chemistry of Variable Source Water Quality Quality
    A NATIONAL DRINKING WATER CLEARINGHOUSE FACT SHEET Lime Softening Summary Hard water can cause scaling problems in water heaters and soap does not lather well in hard water. Therefore, some water utilities soften water to improve its quality for domestic use. Lime softening is best suited to groundwater sources, which have relatively stable water quality. The combination of variable source water quality and the complexity of the chemistry of lime softening may make lime softening too complex for small systems that use surface water sources. Although lime softening has been used successfully by groundwater systems serving fewer than 3,000 people, it is unlikely to be suitable for ○○○○○○○○○○○○ treating groundwater in systems serving 500 or fewer people unless those systems have some form of contract or satellite operation that would enable a trained operator to monitor the treatment process. Prefabricated lime softening equipment is available for small systems. Also, there is an American Water Works Association Standard for quicklime and hydrated lime (ANSI/AWWA B202-93) that provides purchasers, manufacturers, and suppliers with the minimum requirements, including physical, chemical, packaging, shipping, and testing requirements. Either hydrated lime [Ca(OH)2] or quicklime (CaO) may be used in the softening process. The choice depends upon economic factors, such as the○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○○ relative cost per ton of the two materials as well as the size and equipment of the softening plant. Hydrated lime is generally used more in smaller plants because it stores better and does not require slaking (producing a chemical change in lime by combining it with water) equipment. On the other hand, quick- lime costs less per ton of available calcium oxide and is thus more economical for use in large plants.
    [Show full text]
  • 2010 Annual Report
    2010 Annual Report MISSION Our mission is to facilitate innovation, collaborative research and technology development, demonstration and deployment for a responsible Canadian hydrocarbon energy industry. VISION Our vision is to help Canada become a global hydrocarbon energy technology leader. Contact Us For further information please contact: PTAC Petroleum Technology Alliance Canada Suite 400, Chevron Plaza, 500 Fifth Avenue SW, Calgary, Alberta, Canada T2P 3L5 MAIN: 403-218-7700 FAX: 403-920-0054 EMAIL: [email protected] WEB SITE: www.ptac.org PERSONNEL SOHEIL ASGARPOUR BRENDA BELLAND SUSIE DWYER LORIE FREI MARC GODIN President Manager, Knowledge Centre Innovation and Technology R&D Initiatives Assistant and Technical Advisor (403) 218-7701 (403) 218-7712 Development Web Site (403) 870-5402 [email protected] [email protected] Coordinator Administrator marc.godin@portfi re.com (403) 218-7708 (403) 218-7707 [email protected] [email protected] ARLENE MERLING TRUDY HIGH BOBBI SINGH LAURA SMITH TANNIS SUCH Director, Operations Administrative and Registration Accountant Controller Manager, Environmental (403) 218-7702 Coordinator (403) 218-7723 (403) 218-7701 Research [email protected] (403) 218-7711 [email protected] [email protected] Initiatives [email protected] (403) 218-7703 [email protected] PETROLEUM TECHNOLOGY ALLIANCE CANADA 2010 ANNUAL REPORT 3 Message from the Board A New Decade – A New Direction 2010 proved to be a turning point for PTAC as we redeined our role and PTAC Technology Areas set new strategies in motion. Over the past year PTAC has achieved goals in diverse areas of our organization: improving our inances, rebalancing our MANAGE ENVIRONMENTAL IMPACTS project portfolios to address a broad spectrum of needs, leveraging support • Emission Reduction / Eco-eficiency for ield implementations, and building a measurably more effective and • Energy Eficiency eficient organization.
    [Show full text]
  • Emerging Oil Sands Producers
    RBC Dominion Securities Inc. Emerging Oil Sands Producers Mark Friesen (Analyst) (403) 299-2389 Initiating Coverage: The Oil Sands Manifesto [email protected] Sam Roach (Associate) Investment Summary & Thesis (403) 299-5045 We initiate coverage of six emerging oil sands focused companies. We are bullish with [email protected] respect to the oil sands sector and selectively within this peer group of new players. We see decades of growth in the oil sands sector, much of which is in the control of the emerging companies. Our target prices are based on Net Asset Value (NAV), which are based on a long-term flat oil price assumption of US$85.00/bbl WTI. The primary support for our December 13, 2010 valuations and our recommendations is our view of each management team’s ability to execute projects. This report is priced as of market close December 9, 2010 ET. We believe that emerging oil sands companies are an attractive investment opportunity in the near, medium and longer term, but investors must selectively choose the All values are in Canadian dollars companies with the best assets and greatest likelihood of project execution. unless otherwise noted. For Required Non-U.S. Analyst and Investment Highlights Conflicts Disclosures, please see • page 198. MEG Energy is our favourite stock, which we have rated as Outperform, Above Average Risk. We have also assigned an Outperform rating to Ivanhoe Energy (Speculative Risk). • We have rated Athabasca Oil Sands and Connacher Oil & Gas both as Sector Perform, (Above Average Risk). We have also assigned a Sector Perform rating to SilverBirch Energy (Speculative Risk).
    [Show full text]
  • Notice of Applications Connacher Oil and Gas Limited Great Divide Expansion Project Athabasca Oil Sands Area
    NOTICE OF APPLICATIONS CONNACHER OIL AND GAS LIMITED GREAT DIVIDE EXPANSION PROJECT ATHABASCA OIL SANDS AREA ENERGY RESOURCES CONSERVATION BOARD APPLICATION NO. 1650859 ALBERTA ENVIRONMENT ENVIRONMENTAL PROTECTION AND ENHANCEMENT ACT APPLICATION NO. 003-240008 WATER ACT FILE NO. 00271543 ENVIRONMENTAL IMPACT ASSESSMENT The Energy Resources Conservation Board (ERCB/Board) has received Application No. 1650859 and Alberta Environment (AENV) has received Environmental Protection and Enhancement Act (EPEA) Application No. 003-240008 and Water Act File No. 00271543 from Connacher Oil and Gas Limited (Connacher) for approval of the proposed Great Divide Expansion Project (the Project). This notice is to advise interested parties that the applications are available for viewing and that the ERCB, AENV, and other government departments are now undertaking a review of the applications and associated environmental impact assessment (EIA). Description of the Project Connacher has applied to construct, operate, and reclaim an in-situ oil sands project about 70 kilometres (km) south of the City of Fort McMurray in Townships 81, 82, and 83, Ranges 11 and 12, West of the 4th Meridian. Construction of the Project is proposed to begin in 2011, with increased production starting by 2012. The proposed Project would amalgamate Connacher’s existing Great Divide (EPEA Approval No. 223216-00-00) and Algar (EPEA Approval No. 240008-00-00) projects which were each designed to produce 1600 cubic metres per day (m3/day) (10 000 barrels per day [bbl/d]) of bitumen. The proposed Project would also increase Connacher’s bitumen production capacity to 7000 m3/day (44 000 bbl/d) at peak production using the in situ steam assisted gravity drainage (SADG) thermal recovery process.
    [Show full text]
  • Alberta Oil Sands Quarterly Update Fall 2013
    ALBERTA OIL SANDS INDUSTRY QUARTERLY UPDATE FALL 2013 Reporting on the period: June 18, 2013, to Sep. 17, 2013 2 ALBERTA OIL SANDS INDUSTRY QUARTERLY UPDATE Canada has the third-largest oil methods. Alberta will continue to rely reserves in the world, after Saudi to a greater extent on in situ production Arabia and Venezuela. Of Canada’s in the future, as 80 per cent of the 173 billion barrels of oil reserves, province’s proven bitumen reserves are 170 billion barrels are located in too deep underground to recover using All about Alberta, and about 168 billion barrels mining methods. are recoverable from bitumen. There are essentially two commercial This is a resource that has been methods of in situ (Latin for “in the oil sands developed for decades but is now place,” essentially meaning wells are gaining increased global attention Background of an used rather than trucks and shovels). as conventional supplies—so-called In cyclic steam stimulation (CSS), important global resource “easy” oil—continue to be depleted. high-pressure steam is injected into The figure of 168 billion barrels directional wells drilled from pads of bitumen represents what is for a period of time, then the steam considered economically recoverable is left to soak in the reservoir for a with today’s technology, but with period, melting the bitumen, and new technologies, this reserve then the same wells are switched estimate could be significantly into production mode, bringing the increased. In fact, total oil sands bitumen to the surface. reserves in place are estimated at 1.8 trillion barrels.
    [Show full text]
  • Alberta Oil Sands Industry Quarterly Update
    ALBERTA OIL SANDS INDUSTRY QUARTERLY UPDATE WINTER 2013 Reporting on the period: Sep. 18, 2013 to Dec. 05, 2013 2 ALBERTA OIL SANDS INDUSTRY QUARTERLY UPDATE Canada has the third-largest oil methods. Alberta will continue to rely All about reserves in the world, after Saudi to a greater extent on in situ production Arabia and Venezuela. Of Canada’s in the future, as 80 per cent of the 173 billion barrels of oil reserves, province’s proven bitumen reserves are the oil sands 170 billion barrels are located in too deep underground to recover using Background of an Alberta, and about 168 billion barrels mining methods. are recoverable from bitumen. There are essentially two commercial important global resource This is a resource that has been methods of in situ (Latin for “in developed for decades but is now place,” essentially meaning wells are gaining increased global attention used rather than trucks and shovels). as conventional supplies—so-called In cyclic steam stimulation (CSS), “easy” oil—continue to be depleted. high-pressure steam is injected into The figure of 168 billion barrels TABLE OF CONTENTS directional wells drilled from pads of bitumen represents what is for a period of time, then the steam considered economically recoverable is left to soak in the reservoir for a All about the oil sands with today’s technology, but with period, melting the bitumen, and 02 new technologies, this reserve then the same wells are switched estimate could be significantly into production mode, bringing the increased. In fact, total oil sands Mapping the oil sands bitumen to the surface.
    [Show full text]
  • 2020-03-24 the Oilsands in a Carbon-Constrained Canada FINAL
    The oilsands in a carbon- constrained Canada The collision course between overall emissions and national climate commitments Benjamin Israel Jan Gorski, Nina Lothian, Chris Severson-Baker, Nikki Way February 2020 updated March 2020 Photo: Kris Krüg, CC BY-NC-ND 2.0 The oilsands in a carbon- constrained Canada The collision course between overall emissions and national climate commitments Benjamin Israel Jan Gorski, Nina Lothian, Chris Severson-Baker and Nikki Way February 2020 updated March 2020 Production management: Michelle Bartleman Editors: Michelle Bartleman, Roberta Franchuk, ISBN 1-897390-44-0 Sarah MacWhirter Contributors: Nichole Dusyk, Simon Dyer, The Pembina Institute Duncan Kenyon, Morrigan Simpson-Marran 219 19 Street NW Calgary, AB ©2020 The Pembina Institute Canada T2N 2H9 All rights reserved. Permission is granted to Phone: 403-269-3344 reproduce all or part of this publication for non- commercial purposes, as long as you cite the Additional copies of this publication may be source. downloaded from the Pembina Institute website, www.pembina.org. Recommended citation: Israel, Benjamin. The oilsands in a carbon-constrained Canada. The Pembina Institute, 2020. Pembina Institute The oilsands in a carbon-constrained Canada | ii About the Pembina Institute The Pembina Institute is a national non-partisan think tank that advocates for strong, effective policies to support Canada’s clean energy transition. We employ multi-faceted and highly collaborative approaches to change. Producing credible, evidence-based research and analysis, we consult directly with organizations to design and implement clean energy solutions, and convene diverse sets of stakeholders to identify and move toward common solutions. ————————————————— pembina.org ————————————————— twitter.com/pembina facebook.com/pembina.institute Donate to the Pembina Institute Together, we can lead Canada's transition to clean energy.
    [Show full text]