Cenovus TL ULC Telephone Lake Project Volume 1 – Project Description December 2011

SECTION 1.0 – INTRODUCTION TABLE OF CONTENTS

PAGE

1.0 INTRODUCTION ...... 1-1 1.1 Corporate Overview ...... 1-1 1.2 Project Overview ...... 1-2 1.3 Project Location ...... 1-3 1.4 Surface Rights ...... 1-5 1.5 Minerals Land ...... 1-5 1.6 Resource and Development Need ...... 1-8 1.7 Project Schedule ...... 1-10 1.8 Application for Approval ...... 1-11 1.9 Related Statutory Consents ...... 1-11 1.10 Contact Information ...... 1-12 1.11 Literature Cited ...... 1-13

LIST OF TABLES

Table 1.5-1: Cenovus’s Oil Sands Leases in the PPA ...... 1-5 Table 1.7-1: Project Schedule ...... 1-10

LIST OF FIGURES

Figure 1.3-1: Telephone Lake Project Location ...... 1-4 Figure 1.3-2: Layout of Project Facilities ...... 1-6 Figure 1.5-1: Oil Sands Leases in the Vicinity of the PPA ...... 1-7 Figure 1.5-2: Petroleum and Natural Gas Leases in the Vicinity of the PPA ...... 1-9

Table of Contents Cenovus TL ULC Telephone Lake Project Volume 1 – Project Description December 2011

1.0 INTRODUCTION 1.1 Corporate Overview The Cenovus group of companies develops and operates commercial schemes for the recovery of bitumen from the McMurray Formation at Christina Lake located in Section 16, Township 76, Range 6, West of the Fourth Meridian (W4M) and at Foster Creek located in Township 70, Ranges 3, 4 and 5 and Township 71, Ranges 3 and 4, W4M. The Telephone Lake Project (Project), previously called the “Borealis In Situ Project”,1 seeks to recover bitumen from the McMurray Formation in Townships 93 and 94, Range 3, W4M.

The Christina Lake Thermal Project (CLTP) is located in the southern Athabasca Region and is approximately 20 km southeast of the Hamlet of Conklin, Alberta. The CLTP commercial scheme includes the use of in situ steam assisted gravity drainage (SAGD) well-pairs and an on-site plant and operates under Approval No. 8591 issued by the ERCB pursuant to the Oil Sands Conservation Act (OSCA) and Approval No. 48522 issued by Alberta Environment and Water (AENV) pursuant to the Environmental Protection and Enhancement Act (EPEA). Cenovus FCCL Ltd. is developing, managing and operating the CLTP and holds the operating approvals.

The Foster Creek Thermal Project (FCTP) is located in the Cold Lake Air Weapons Range and is approximately 70 km north of the Hamlet of La Corey, Alberta. The FCTP commercial scheme includes in situ SAGD well-pairs and an on-site plant and operates under Approval No. 8623 issued by the ERCB pursuant to the OSCA and Approval No. 68492 issued by AENV pursuant to the EPEA. Cenovus FCCL Ltd. is developing, managing and operating the FCTP and holds the operating approvals.

Cenovus Energy Inc. is a successor in interest to EnCana Corporation (EnCana). Cenovus FCCL Ltd. became, as a result of a reorganization of EnCana that was completed on 30 November 2009, a subsidiary of Cenovus Energy Inc. As a result of a reorganization of Cenovus Energy Inc. that was completed on 1 September 2011, Cenovus TL ULC became a subsidiary of Cenovus Energy Inc. Cenovus TL ULC will be the operator of the Project. In this application, unless otherwise noted, references to “Cenovus”, and references to “EnCana” and to any member of the EnCana group of companies, should be taken to mean Cenovus TL ULC.

1Cenovus filed a joint application and environmental impact assessment (EIA) for the Borealis In-Situ Project with Alberta Environment and Water (AENV) and the Energy Resources Conservation Board (ERCB) on 21 December 2007. The application for the Borealis In Situ Project was not reviewed by the regulators. The Borealis In-Situ Project has since been modified and renamed as the Telephone Lake Project. This joint application and EIA for the Telephone Lake Project is intended to replace the previously filed application and EIA for the Borealis In-Situ Project in its entirety.

Page 1-1 Cenovus TL ULC Telephone Lake Project Volume 1 – Project Description December 2011

1.2 Project Overview Cenovus is seeking regulatory approval to recover bitumen from the McMurray Formation (which is directly overlain by a layer of non-saline groundwater (top water)) using SAGD and Cenovus’s patented Wedge Well™ Technology. The proposed Project is expected to have an oil production capacity of 14,308 cubic metres per day (m3/d), or 90,000 barrels per day (bbl/d), in two phases (Phase A and Phase B), with an estimated operational life of over 40 years.

Cenovus has successfully implemented SAGD plus Wedge Well™ Technology at the FCTP and also requests approval for the use of Wedge Well™ Technology at the Project. The Project plans to use reduced well spacing of 67 metres (m) versus 100 m used on existing SAGD projects. For specific reservoir circumstances, Cenovus would request prior approval for Wedge Well™ Technology as required without the need to file further amendments.

The Project will also involve the use of dewatering technology (Cenovus patent pending) at the majority of well pads at the Project. Dewatering technology will facilitate the replacement (with air) of a portion of the top water located directly above the bitumen zone prior to SAGD operations. This technology involves additional wells and well pads beyond a typical SAGD project; where required, these additional wells and well pads would be in operation one to two years prior to the first steam injection for SAGD.2

Cenovus is also requesting blanket approval and/or flexibility for the following: • cold water dilation enhanced start-up (Volume 1, Section 4.2.1.2); • steam dilation enhanced start-up (Volume 1, Section 4.2.1.3; Cenovus patent pending); • solvent-enhanced start-up operations (Volume 1, Section 4.2.1.4; Cenovus patent pending); • well pair spacing ranging from 50 to 200 m (Volume 1, Section 4.5.3.1); • well pair lengths up to 1,200 m (Volume 1, Section 4.5.3.1); • two operating pressures—a high pressure based on specific well parameters during the start-up stage, and a lower limit based on field-wide maximum operating pressure during ramp-up (Volume 1, Section 4.5.3.2); and • Wedge Well™ Technology (Section 4.5.4.1).

2As per a joint application filed with AENV and the ERCB in May 2011, and as per corresponding approvals received in November 2011, Cenovus intends to conduct a test of the proposed dewatering technology over a period of six to twelve months commencing in 2012 (application and approval numbers are provided in Section 1.9). A report of the results and conclusions from this test will be submitted as an addendum to the application for the Project.

Page 1-2 Cenovus TL ULC Telephone Lake Project Volume 1 – Project Description December 2011

The Project is expected to include the following facilities: • a central processing facility consisting of: ‰ oil treating facilities to create a maximum oil treating capacity of 14,308 m3/d (90,000 bbl/d); ‰ steam production facilities with up to ten boilers (including six once-through steam generators (OTSGs), two OTSGs in reboiler configuration, and two heat recovery steam generators (HRSGs), with each HRSG being paired with a separate 40 to 50 megawatt gas turbine; ‰ water treatment facilities; and ‰ sulphur removal facilities • dewatering facilities including centralized air compression and water treatment facilities along with air injection, water injection and water production wells at various pad locations; • an estimated total of 104 well pads over the Project life, consisting of 36 SAGD-only well pads, 54 SAGD well pads including dewatering wells, 10 dewatering-only well pads, and four water disposal pads; • an estimated total of 961 SAGD well-pairs and 378 dewatering wells, the latter to include air injection wells, water production wells and water reinjection wells in various configurations to optimize dewatering; • an estimated total of two fresh water source wells for domestic use; and • an estimated total of ten remote water disposal wells, five for excess process wastewater and five for reinjection of excess top water from the dewatering process.

The Project will require additional infrastructure, including electrical power lines, an all-weather access road, a fuel gas pipeline, a diluent supply pipeline, and a produced sales oil pipeline. These infrastructure items will be applied for separately, as appropriate.

Cenovus will develop, manage and operate the Project and will hold the operating approvals for the Project.

1.3 Project Location The Project is located approximately 90 km northeast of the Urban Service Area of Fort McMurray, and approximately 70 km due east of the Hamlet of Fort McKay, in the Regional Municipality of Wood Buffalo in northeastern Alberta. Administratively, the Project location falls within Alberta’s Lower Athabasca integrated planning region. The Project location is shown on Figure 1.3-1 and is represented by a Proposed Project Area (PPA), which outlines the boundary within which surface and subsurface development is anticipated to occur over the life of the Project.

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± Cenovus TL ULC Telephone Lake Project Volume 1 – Project Description December 2011

The PPA encompasses all of Cenovus’s lease holdings in Township 093-03W4M, virtually all of Cenovus’s lease holdings in Township 094-03W4M, and a portion of Cenovus’s lease holdings in Township 095-03W4M. Initial development within the PPA will take place in areas where the delineation well density will be 16 wells per section, or where the delineation well density is eight wells per section accompanied by three-dimensional (3D) seismic. Sustaining development within the PPA will require further delineation drilling. A detailed Project layout within the PPA is shown in Figure 1.3-2.

1.4 Surface Rights The PPA is situated on provincial Crown land, which is administered on behalf of the Crown by Alberta Sustainable Resource Development (ASRD). Within ASRD’s Fish and Wildlife and Area Operations Division, the PPA falls administratively within the Waterways/Lac La Biche Area and operationally within the Fort McMurray Fisheries Management Area and the Fort McMurray Wildlife Management Area. Within ASRD’s Forestry Division, the PPA falls within Forest Management Unit A6. Cenovus will apply to ASRD for the appropriate surface rights—Mineral Surface Leases, Pipeline Agreements, Licences of Occupation and other dispositions—as required for access and operation of the Project.

There are no privately held lands or Forest Management Agreements within the PPA. Two registered trappers hold Trapping Area dispositions within the PPA; these trappers have been contacted regarding this application. In addition, there are three surface dispositions within the PPA that are held by other oil and gas companies (two by Oilsands Quest Inc. and one by SilverBirch Energy Corp.); Cenovus will obtain road use agreements, pipeline crossing agreements and proximity agreements with these companies as required in conjunction with activities related to the Project.

1.5 Minerals Land The PPA is situated in the Athabasca Oil Sands area in northeastern Alberta. Cenovus is the operator and 100 percent lease holder of several oil sands leases issued by the Alberta Department of Energy that cover lands within, and in the vicinity of, the PPA, as shown in Figure 1.5-1. All of these oil sands leases are within their primary term. The oil sands leases covering the PPA (shown in Figure 1.5-1) are summarized in Table 1.5-1. Figure 1.5-1 also shows other operators that hold oil sands leases in the vicinity of the PPA. The PPA is bordered to the west by oil sands leases held by Suncor Energy Inc. and Koch Exploration Canada G/P Ltd. and to the south by broker-held oil sands leases.

Table 1.5-1: Cenovus’s Oil Sands Leases in the PPA

Oil Sands Land Description Expiry Date Lease No. Rights and Formations 7407020392 Township 094-03W4M, sections 1-18 inclusive, 22-27 inclusive, 34-36 6 February 2022 inclusive; Oil Sands from top Viking to base Woodbend 7407020393 Township 093-03W4M, sections 2, 5, 7-9 inclusive, 11, 13-36 inclusive; Oil 6 February 2022 Sands from Top Viking to base Woodbend 7407020394 Township 095-03W4M, portions of sections 2, 3; Oil Sands from top Viking to 6 February 2022 base Woodbend

Page 1-5 S:\Gis\Projects\CE\Cenovus\CE0339901_TelephoneLake_EIA\ArcGIS\ApplicationReportFigures\Volume 01 Section 01\Fig01.03-02 A PPA Layout.mxd Source:Cenovus, Spatial Data Warehouse Ltd. Legend 1012 Watercourse Open Water Proposed Project Area Telephone LakeTelephone Project 3 0.5 Cenovus TL ULC 34 27 22 15 10 34 27 22 3 15 10 3 Kilometres 1:110,000 2 35 26 23 14 11 35 26 23 2 14 11 2 Project Layout 1 RGE RGE 4 3 RGE 36 25 24 13 12 36 25 24 1 13 12 SAGD/Dewatering Only SAGD ROW Project ROW Main Access Laydown Disposal Dewatering Camp CPF Pit Borrow 1 TLS14 1 TL19 TL23 TL65 6 9 Telephone 6 Layout ofProject Facilities 31 30 19 18 31 30 7 Lake 19 6 18 7 6 TL105 TL08 TL53 TL64 TLS31 TLS23 TLS17 10 TLS04 TLS33 3 TL29 TL13 9 TL87 TLS11 TLS28 TL06 TLS09 5 TLS02 TL78 TL89 32 TL41 29 TL05 20 17 32 29 8 20 5 17 TL88 8 5 TL47 TLS16 8 2 TL70 TLS22 TLS08 TLS20 3 TL81 TLS19 TL61 TLS10 4 TLS12 33 28 21 16 33 28 9 21 4 16 9 4 TL85 TL84 TL07 TL51 TL67 TL96 TLS25 1 2 2 5 TL26 TLS01 7 TL95 TL83 TL14 TL79 8 4 TL63 TLS15 TL101 TL99 TL32 TL31 3 5 TL18 34 27 22 15 10 34 TL20 27 3 22 15 TL16 10 34 3 TL103 TL34 TL72 7 TL04 TL93 TL01 TL77 TL74 TL02 TL55 TL46 1 TL24 TL28 TL56 TL48 TL91 TL73 TL40 2 6 35 26 TL90 23 10 14 11 35 26 2 23 14 ANALYST: PROJECT: DATE: 11 TL12 35 4 TL39 2 TL59 TL21 KW CE0339901 December 2011 TL44 TL25 TL17 1 TL106 TL75 QA/QC: TL50 KW TL97 1 RGE 3 RGE 2W4 RGE RGE 3 36 25 24 13 12 TL49 36 25 1 24 13 12 36 1 REH LR 4 2 3 6 31 30 19 PROVIDED BY: PROVIDED PROJECTION/DATUM: 18 31 7 30 6 19 18 UTM Zone 12 NAD83 12 Zone UTM 31 7 6 Fig01.03-02 Project Layout AMEC 11-11-15 5 32 29 20 17 32 8 FINAL MAPPING BY: 29 5 20 17 32 8 5 AMEC 4 33 28 21 16 33 9 28 4 21 16 33 9 4 Figure 1.3-2 TWP 92 TWP 93 TWP 93 TWP 94 TWP 94 TWP 95 ± 34 F i S:\Gis\Projects\CE\Cenovus\CE0339901_TelephoneLake_EIA\ArcGIS\ApplicationReportFigures\Volume 01 Section 01 - Introduction\Fig01.05-01 TLSA Leases.mxd Source: Cenovus, Spatial Data Warehouse Ltd. Legend Suncor 2.502.55 Watercourse Open Water Park/Protected Area Proposed Project Area Terrestrial LSA Telephone L Telephone Broker CENOVUS Cenovus TL ULC TL Cenovus 1.25 ENERGY Suncor Suncor INC. Suncor Suncor 1:225,000 Kilometres RGE RGE 5 4 ake Project Koch Broker Oil Sands Lease Koch Koch CENOVUS Suncor Stone Oilsands Quest Koch Grizzly Cenovus Broker Stone ULC TL CENOVUS ULC Suncor TL Suncor Suncor CENOVUS ULC TL CENOVUS Koch ULC TL Oil Sands Leases in the CENOVUS ULC TL Koch

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The overlying petroleum and natural gas (P&NG) rights fall within the ERCB-designated Wabiskaw-McMurray Gas Production Application Area (Application Area) that is set out in General Bulletin 2003-28 (ERCB 2003). In accordance with Information Letter 2003-24 (ADOE 2003), P&NG rights associated with the Mannville group of formations in the Application Area are reserved from disposition. The nearest existing P&NG lease holders are shown on Figure 1.5-2.

1.6 Resource and Development Need Development of Cenovus’s leases at Telephone Lake is a natural progression in the region and is necessary to recover the bitumen resource in the area and to supply oil to world markets. Delay in proceeding with the Project in a timely manner will result in: • reduced hydrocarbon supply; and • reduced economic benefits, including employment, for local area residents.

Cenovus will continue to supply energy in a responsible way and to be a responsible member of the communities in which it operates. To continue to be a viable company, Cenovus must also provide a reasonable return to shareholders, employment for its employees and support to the communities where it operates. Cenovus’s application for regulatory approval of the Project is based on a detailed investigation of technical feasibility and economic analysis. Economic benefits of the Project include the following: • the Project will offer economic benefits to the Regional Municipality of Wood Buffalo , Government of Alberta, Government of Canada, local area residents and other stakeholders in the region through Project expenditures, employment, taxes and royalties paid; • total capital expenditures expected up to and including start-up of the second phase (Phase B) of the Project amount to almost $3,000 million in 2011 dollars, while operating expenditures will be an additional $440 million annually; • in excess of two million man hours will be required for construction of the central processing facility and off-site facilities, and for drilling and completion of the initial wells; • on an annual basis, operations and maintenance of the 14,308 m3/d (90,000 bbl/d) facility will require the equivalent of approximately 335 full time equivalent workers on site (staff and contractors); and • the Project meets resource recovery objectives specified in section 3 of the OSCA by: (i) effecting the conservation and preventing the waste of the oil sands resources of Alberta, and (ii) ensuring the orderly, efficient and economical development in the public interest of the oil sands resources of Alberta.

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DATE: Fig01.05-02 TLSA P&G Leases 40482 December 2011 11-12-17 Petroleum and Natural Gas Leases PROJECT: PROJECTION/DATUM: Figure Kilometres CE0339901 UTM Zone 12 NAD83 1:275,000 in the Vicinity of the PPA 1.5-2 Cenovus TL ULC ANALYST: QA/QC: PROVIDED BY: FINAL MAPPING BY: Sources: Cenovus, AB TPR, GeoBase®, Spatial Data Warehouse Ltd. Telephone Lake Project KW KW EH EH Cenovus AMEC S:\Gis\Projects\CE\Cenovus\CE0339901_TelephoneLake_EIA\ArcGIS\ApplicationReportFigures\Volume 01 Section - 01 Introduction\Fig0 Cenovus TL ULC Telephone Lake Project Volume 1 – Project Description December 2011

The above calculations assume that regulatory and company approvals, construction and operations proceed as per the proposed schedule outlined in Section 1.7.

The implications of not going ahead with the Project include that the economic benefits outlined above would not be achieved, the potential contribution of the Project to world hydrocarbon supply would not be realized, and Alberta’s oil sands resource in the PPA would remain unrecovered.

Presently, SAGD is the appropriate bitumen recovery technology to use during the Project. Cenovus continues to evaluate emerging recovery technologies and alternatives for optimal resource recovery. Additional discussions of the selection of resource recovery technologies and process alternatives are presented in Volume 1, Sections 4.2, 10.8, 10.9 and 10.10.

1.7 Project Schedule The Project timeline depends on regulatory approvals, market conditions and corporate sanction. Once corporate sanction and regulatory approvals are received, construction will commence and is expected to last for up to 72 months, followed by an operational life of approximately 40 years.

Commissioning for each phase will occur upon construction completion. Table 1.7-1 shows the proposed schedule for the Project. This proposed schedule has been assumed for the purpose of the application and supporting EIA. The Project consists of two phases, each with three OTSGs plus one reboiler OTSG and one HRSG paired with a 40 to 50 megawatt gas turbine, since these best fit Cenovus’s history and experience with phased development of CLTP and FCTP.

Table 1.7-1: Project Schedule

Activity Phase A Phase B Public Consultation Ongoing Ongoing Project Application Submission Q4 2011 Q4 2011 Regulatory Approval Q4 20131F Q4 20131F Start Field Construction 20141F 20161F Commissioning/Start-Up (First Steam) 20181F 20191F Start Pad Reclamation 20301F 20321F Start Decommissioning 20581F 20581F

1 Target date based on conceptual schedule. F Forecast. Q4 Fourth quarter.

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1.8 Application for Approval Cenovus hereby applies for regulatory approval to construct, operate and reclaim the Project. Under the Activities Designation Regulation, the Project is listed in Schedule 1 and is, therefore, designated as an activity for which an approval is required. The Project is also a mandatory activity described in Schedule 1 of the Environmental Assessment (Mandatory and Exempted Activities) Regulation and thus, the preparation of an EIA is required. Cenovus received formal notice from AENV, in a letter dated 27 July 2007, that an EIA is required. Final Terms of Reference for the Project was issued 19 December 2007 and is provided in Volume 1, Attachment 1.

The application is being submitted as an integrated application to AENV and to the ERCB pursuant to their joint Memorandum of Understanding on the Regulation of Oil Sands Developments (AENV and ERCB 1996) and pursuant to the requirements of the OSCA and the EPEA. With this application, Cenovus is seeking the following approvals: • scheme approval from the ERCB to construct and operate a 14,308 m3/d (90,000 bbl/d) bitumen recovery scheme using SAGD, under Section 10 of the OSCA, from the Athabasca Oil Sands Deposit in the McMurray Formation, at oil sands leases located primarily in Townships 93 and 94, Range 3 and a portion in Township 95, Range 3 W4M; • approval from AENV to construct, operate and reclaim a 14,308 m3/d (90,000 bbl/d) enhanced recovery (using SAGD,) in-situ oilsands processing plant and oil production site under Division 2 of Part 2 and Section 63 of the EPEA; and • a Conservation and Reclamation Plan Approval from AENV under Division 2 of Part 2 and Part 6 of the EPEA to develop, operate and reclaim components of the Project.

This application comprises a Project Description (Volume 1) and a supporting EIA (Volumes 2 and 3). Sections 1.0 through 13.0 in Volume 1 provide the information required for ERCB approval under the OSCA, in accordance with Directive 023: Guidelines Respecting an Application for a Commercial Crude Bitumen Recovery and Upgrading Project (ERCB 1991). Section 14.0 in Volume 1 provides the information required for AENV approval under the EPEA, in accordance with the requirements of the Approvals and Registration Procedure Regulation (AR 113/93) as per AENV’s Guide to Content of Industrial Approval Applications (AENV 1999).

Volume 2 is presented in 17 sections. An introduction and Project description summary is followed by discussion of the scope of the EIA. Thereafter, baseline and impact assessments are presented for individual environmental aspects of the Project. Supporting information related to the assessments is organized into appendices in Volume 3.

1.9 Related Statutory Consents Cenovus has conducted exploratory drilling programs in the Telephone Lake area beginning in 2001. Oil Sands Exploration permits and well licenses were obtained for all delineation wells and related geophysical programs on the lease. In addition, the McMurray Formation

Page 1-11 Cenovus TL ULC Telephone Lake Project Volume 1 – Project Description December 2011

Dewatering Test Application was filed in May 2011 with AENV and the ERCB (AENV Water Act Application No. 001-00292198; ERCB Application No. 1689991) and was approved in November 2011 by AENV (Water Act Approval No. 00299973-00-00 dated 1 November 2011) and the ERCB (letter dated 2 November 2011).

Additional approvals will be required for the Project, and these will be applied for pursuant to the following legislation: • Historical Resources Act, for clearance to construct facilities; • Hydro and Electric Energy Act, for approval to construct facilities for electrical power cogeneration facilities, interconnection, transmission or distribution, as well as for industrial system designation under the Hydro and Electric Energy Act and related exemption under the Electric Utilities Act, as may be applicable; • Pipeline Act, for the construction and operation of pipelines and related infrastructure; • Public Lands Act, for surface rights; and • Water Act, for (i) a Licence to divert groundwater from a Quaternary Sand aquifer for domestic use, (ii) a Licence to divert groundwater from the Middle McMurray Top Water Zone for steam make-up and utility/seal use, and (iii) an Approval to dewater groundwater from the Middle McMurray Top Water Zone.

The three Water Act applications are provided in Volume 1, Attachment 2.

1.10 Contact Information Correspondence regarding this application should be addressed to the following:

Michael Lesyk Regulatory Applications Analyst Cenovus TL ULC 421 – 7th Avenue SW Calgary AB T2P 2S5 Telephone: 403-766-3414 Facsimile: 403-766-4536 Email: [email protected]

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1.11 Literature Cited Alberta Department of Energy (ADOE). 2003. Information Letter 2003-24: P&NG Agreements within EUB Application Area; Postings and Private Sales; Term Extensions. Edmonton, Alberta.

Alberta Environment (AENV). 1999. Guide to Content of Industrial Approval Applications. Alberta Environment. Edmonton, Alberta.

Alberta Environment and Energy Resources Conservation Board (AENV and ERCB). 1999. Memorandum of Understanding on the Regulation of Oil Sands Developments. Available at: http://www.ercb.ca/docs/ils/ils/pdf/il96-07.pdf.

Energy Resources Conservation Board (ERCB). 1991. Directive 023: Guidelines Respecting an Application for a Commercial Crude Bitumen Recovery and Upgrading Project. Energy Resources Conservation Board. Calgary, Alberta.

Energy Resources Conservation Board (ERCB). 2003. General Bulletin 2003-28: Bitumen Conservation Requirements: Athabasca Wabiskaw-McMurray. Calgary, Alberta.

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