DOCSLIB.ORG

SUPPLEMENTAL Published July 22, 2020

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
SUPPLEMENTAL Published July 22, 2020 SUNCOR ENERGY Investor Information SUPPLEMENTAL Published July 22, 2020 SUNCOR ENERGY Table of Contents 1. Energy Sources 2. Processing, Infrastructure & Logistics 3. Consumer Channels 4. Sustainability 5. Technology Development 6. Integrated Model Calculation 7. Glossary SUNCOR ENERGY 2 SUNCOR ENERGY EnergyAppendix Sources 3 202003- 038 Oil Sands Energy Sources *All values net to Suncor In Situ Mining Firebag Base Plant 203,000 bpd capacity 350,000 bpd capacity Suncor WI 100% Suncor WI 100% 2,603 mmbbls 2P reserves1 1,350 mmbbls 2P reserves1 Note: Millennium and North Steepank Mines do not supply full 350,000 bpd of capacity as significant in-situ volumes are sent through Base Plant MacKay River Syncrude 38,000 bpd capacity Syncrude operated Suncor WI 100% 205,600 bpd net coking capacity 501 mmbbls 2P reserves1 Suncor WI 58.74% 1,217 mmbbls 2P reserves1 Future opportunities Fort Hills ES-SAGD Firebag Expansion Suncor operated Lewis (SU WI 100%) 105,000 bpd net capacity Meadow Creek (SU WI 75%) Suncor WI 54.11% 1,365 mmbbls 2P reserves1 First oil achieved in January 2018 SUNCOR ENERGY 1 See Slide Notes and Advisories. 4 1 Regional synergy opportunities for existing assets Crude logistics Upgrader feedstock optionality from multiple oil sands assets Crude feedstock optionality for Edmonton refinery Supply chain Sparing, warehousing & supply chain management Consolidation of regional contracts (lodging, busing, flights, etc.) Operational optimizations Unplanned outage impact mitigations In Situ Turnaround planning optimization Process and technology sharing 100% WI Joint ownership Base mine upgrader and terminal U Syncrude upgrader Assets and resource developments C In situ central processing facility Lease development and asset utilization optimization P Fort Hills primary/secondary extraction Pipelines Sanctioned bi-directional pipelines1 SUNCOR ENERGY 1 See Slide Notes and Advisories 5 Long life, low decline reserves base 1 Typical attributes of North American oil plays Initial Decline Sustaining Operating Reservoir Recovery 2 3 Illustrative annual FFO profiles capital rate costs cost risk factor Mining High Very low Low Medium Very low Very high ~85% of Suncor’s 2020 production guidance In Situ Medium Low Low Low Low High Offshore ~15% of Suncor’s 2020 High Medium Medium Very low Medium Medium production guidance Tight Oil Low Very high High Medium High Low 50 Years Beneficial attribute Challenging attribute SUNCOR ENERGY 1, 2, 3 See Slide Notes and Advisories 6 Offshore with >370 million barrels of 2P reserves 1 East Coast Canada North Sea Hibernia ExxonMobil operated Buzzard (UK) Suncor working interest 20% CNOOC Petroleum Europe Limited operated 61 mmboe 2P reserves1 (Suncor WI) Suncor working interest 29.9% 1 2019 avg net production: 20.1 mbbls/d 63 mmboe 2P reserves (Suncor WI) 2019 avg net production: 31.9 mboe/d Hebron ExxonMobil operated Suncor working interest 21.0% 138 mmboe 2P reserves1 (Suncor WI) Golden Eagle (UK) 2019 avg net production: 23.5 mbbls/d CNOOC Petroleum Europe Limited operated Suncor working interest 26.7% 10 mmboe 2P reserves1 (Suncor WI) 2019 avg net production: 9.0 mboe/d Terra Nova Suncor Energy operated Suncor working interest 37.7% 25 mmboe 2P reserves1 (Suncor WI) Oda (Norway) 2019 avg net production: 11.6 mbbls/d Spirit Energy operated3 Suncor working interest 30% 7 mmboe 2P reserves1 (Suncor WI) White Rose First oil achieved March 2019 Husky Energy operated 2019 avg net production: 3.7 mboe/d Suncor working interest 27.5%2 Note: Q4 2019 avg net production: 7.8 mboe/d 54 mmboe 2P reserves1 (Suncor WI) 2019 avg net production: 4.7 mbbls/d SUNCOR ENERGY 1, 2, 3 See Slide Notes and Advisories 7 E&P – Investing in high value, low risk projects Recent performance Sanctioned projects1 mboe/d Fenja (Norway) 120 • 17.5% working interest 100 • 6 mbbls/d anticipated net peak production Hebron 80 White Rose Buzzard Phase 2 (UK) Hibernia 60 Terra Nova • 29.9% working interest 40 Golden Eagle • Production anticipated to offset natural declines Buzzard 20 4 West White Rose Project (ECC ) 0 2012 2013 2014 2015 2016 2017 2018 2019 • ~26% working interest • 20 mbbls/d anticipated net peak production 112 109 99 4 $billions Terra Nova Asset Life Extension (ECC ) 2.5 • 37.7% working interest 71 64 54 Brent • Extend asset life by approximately a decade 2.0 52 44 ($US/bbl) • Expect to produce additional 30 million barrels (Suncor WI) 1.5 FFO2 Free funds flow3 Capital spend 1.0 Future opportunities 0.5 • Rosebank-UK (40% Suncor WI) - • Near field developments including subsea 2012 2013 2014 2015 2016 2017 2018 2019 tie-backs, field extensions and infill drilling SUNCOR ENERGY 1, 2, 3, 4 See Slide Notes and Advisories 8 Power Generation Generating power for internal use & sale to the grid, including EV applications; currently 5th largest power producer in Alberta. 2,400 MW 1,400 MW 1 CURRENT CURRENT + SANCTIONED PROJECTS Cogen: 96%; Renewables: 4% (online by YE 2025) Cogen: 89%; Renewables: 11% MW Working interest nameplate capacity Net power sold to grid Net internally consumed power SUNCOR ENERGY 1 See Slide Notes and Advisories. 9 SUNCOR ENERGY Processing,Appendix Infrastructure & Logistics 10 202003- 038 Operations & Consumer Network 29 year Oil Sands Reserve Life Index1 ~25 mmbbl storage Western Canada ~1,850 PetroCanada sites2 ~15 mmbbl storage Eastern Canada Only refinery in Colorado ~10 mmbbl storage Central US & Gulf Coast OIL & REFINED PRODUCT STORAGE (SUNCOR OPERATED) SUNCOR ENERGY 1, 2 See Slide Notes & Advisories 11 Upgrading Upgrading processes heavy bitumen into a lighter, higher value product with a density Upgrading Process similar to that of WTI. LOW Once upgraded, the product can flow on a VALUE Mined & In-Situ Bitumen pipeline without the addition of diluent. HEAVY OIL (10° API) Total Suncor Net Upgrading Capacity: ~555 kbpd1 Coking, hydroconversion, • Base Plant ~15 – 20% yield loss thermal cracking &/or through upgrading process – 2 Upgrading Units hydrocracking • U1: 110 kbpd • U2: 240 kbpd – Produces sour & sweet SCO & diesel HIGH Sour Synthetic Crude Oil Optional: Hydrotreating (remove sulfur) • Syncrude (Gross values below – Suncor WI 58.74%) VALUE (30 - 35° API) LIGHT – 3 Upgrading Units OIL • U1: 100 kbpd • U2: 100 kbpd • U3: 150 kbpd Refinery Sweet Synthetic Crude Oil – Produces sweet SCO (30 - 35° API) • Edmonton Refinery – 30 kbpd coking capacity SUNCOR ENERGY 1 See Slide Notes & Advisories 12 Suncor’s proven oil sands reliability journey Suncor Base Plant upgrader reliability Multi-year journey to reach >90% reliability 1 2 91% 90% 91% 90% 90% 83% 81% 79% Suncor began focusing on upgrader reliability initiatives in 2011 Firebag to Base Mine Culture – Operational excellence mindset interconnect Process – Integrated maintenance strategy/approach pipeline fully operational Infrastructure – Asset integration between Firebag and Base Plant 2012 2013 2014 2015 2016 2017 2018 2019 Syncrude plant reliability In 2019, Syncrude achieved 2nd best A similar multi year journey targeting >90% reliability3 annual production in asset’s history with 85% utilization5 2016/17 2018/19 2020/21 (Target >90% reliability) Collaboration Culture Infrastructure Suncor’s active involvement in 31 technical/management Two bi-directional pipelines connecting Syncrude & Suncor’s base mine Syncrude’s reliability secondees from Suncor sharing Expected cost for the <15 km distance is ~$200M (gross)4 improvement plan operational discipline learnings Better utilization of existing assets: Sharing technical & reliability Process synergies • Normal operations - Transfer of sour synthetic and bitumen between assets best practices and support to Leveraging service & materials • Planned and unplanned outages - Asset and production optimizations improve productivity, reliability economies of scale and reduce costs Maintenance planning & execution Anticipated in-service 2H 2020 coordination SUNCOR ENERGY 1, 2, 3, 4, 5 See Slide Notes & Advisories 13 Market Access Suncor has made strategic investments in refineries and current/proposed logistics infrastructure to mitigate Alberta egress limitations & market disconnects Fort McMurray ~750 Alberta egress bottleneck does not impact the ability to move Suncor barrels1 142 Edmonton Hardisty Enbridge Line 3 Potential Markets Regina Central & Eastern Vancouver Cromer Canada, US Midwest & Gulf Coast 137 Montreal TMEP Potential Superior Markets Asia & California 85 Sarnia Steele City Chicago 98 Commerce Patoka City San Francisco Cushing Los Angeles KXL Potential Markets Pipelines 2 Heavy oil refineries (current and forecasted gross capacity ) along the Gulf Coast Feeder lines 2 Houston/Texas City Trans Mountain Pipeline, TMPL (300 mbpd) Suncor refinery capacity mbpd Trans Mountain Expansion , TMEP – Proposed3 (+590 mbpd)2 Industry approximate rail Express, Platte and Rocky Mountain (280 mbpd)2 mbpd loading capacity in TransCanada Keystone (590 mbpd)2 AB/SK TransCanada Keystone XL – Proposed3 (+830 mbpd) 2 Enbridge Mainline (2,600 mbpd)2 Enbridge Line 3 – Proposed3 (+370 mbpd) 2 Enbridge Line 9 (300 mbpd)2 Flanagan South Pipeline (585 mbpd)2 SUNCOR ENERGY 1, 2, 3 See Slide Notes & Advisories Marine opportunities 14 SUNCOR ENERGY ConsumerAppendix Channels 15 202003- 038 Refined Product Markets ~540 mbpd Product sales in 1 2019 Edmonton refinery services region from BC to Ontario Montreal and 20% Sarnia have a local market Canadian reach over 22mm Export consumer fuel people5 capability 2 market to US Pacific NW ~300 Wholesale Cardlock Locations3 Commerce City’ s asphalt Commerce
Load more

Recommended publications
  • Kern River, CA
    Heavy Liquid Hydrocarbons: Their Production and the Resulting CO2 Footprint Tony Kovscek Stanford University Energy Resources Engineering email:[email protected] First, a little quiz … Where does imported oil originate? Jan - Jul 2007 1%1%1%1%0% 4% 4%1%1% Domestic Production 3% 3% 36% 6% 7% 9% 9% 12% Energy Information Administration, www.eia.doe.gov Where does imported oil originate? 0% 4% 1%1%1%1%1%1% 4% Domestic 3% Canada 3% 36% Mexico Saudi Arabia 6% Venezuela Nigeria Algeria Iraq Angola Saudi Colombia 7% Kuwait Arabia Libya Mexico United Kingdom 9% Canada Ecuador 9% Brazil Equatorial Guinea 12% Other Energy Information Administration, www.eia.doe.gov Who has large proved oil reserves? Oil and Gas J., 2003 300 250 200 150 reserves (Bbbl) 100 50 0 Reserve≠Resource Reserve is energy that you can recover economically with existing technology. reserves (Bbbl) oil reserves? large proved has Who 300 250 200 150 100 50 0 Saudi Arabia Canada Oil and Gas J., 2003 Iraq Iran Kuwait United Arab Emirates Russia Venezuela Libya Nigeria United States Today’s Presentation • What has Canada got? – What is heavy oil? – What is heavy oil? – Why do you care about heavy oil? • Heavy-oil recovery methods are energy intensive – Alberta Canada Oil Sands – Kern River, CA • CO2 foot print for heavy oil production – energy needed to produce heavy oil – implications for CO2 production • Summary USA-Alaska Middle East 80 Bbbl 1400 Bbbl conventional oil Canada 2732 Bbbl USA-Continental 137 Bbbl Venezuela Oil Resource 700-3000 Bbbl - Heavy Say that world What
    [Show full text]
  • 2015 Annual Report Mission
    2015 annual report Mission Our mission is to facilitate innovation, collaborative research and technology development, demonstration and deployment for a responsible Canadian hydrocarbon energy industry. 2 Vision Our vision is to help Canada become a global hydrocarbon energy technology leader. PTAC Technology Areas Manage Environmental Impacts • Air Quality • Alternative Energy Improve Oil and Gas Recovery • Ecological • CO2 Enhanced Hydrocarbon Recovery • Emission Reduction / Eco-Efficiency • Coalbed Methane, Shale Gas, Tight Gas, Gas Hydrates, • Energy Efficiency and other Unconventional Gas • Resource Access • Conventional Heavy Oil, Cold Heavy Oil Production with • Soil and Groundwater Sands • Water • Conventional Oil and Gas Recovery • Wellsite Abandonment • Development of Arctic Resources • Development of Remote Resources Additional PTAC Technical Areas • Enhanced Heavy Oil Recovery • e-Business • Enhanced Oil and Gas Recovery • Genomics • Enhanced Oil Sands Recovery • Geomatics • Emerging Technologies to Recover Oil Sands from Deposits • Geosciences with Existing Zero Recovery • Health and Safety • Tight Oil, Shale Oil, and other Unconventional Oil • Instrumentation/Measurement • Nano Technology Reduce Capital, Operating, and G&A Costs • Operations • Automation • Photonics • Capital Cost Optimization • Production Engineering • Cost Reduction Using Emerging Drilling and Completion • Remote Sensing Technologies • Reservoir Engineering • Cost Reduction Using Surface Facilities • Security • Eco-Efficiency and Energy Efficiencyechnologies
    [Show full text]
  • Q3 2020 Husky-MDA
    MANAGEMENT’S DISCUSSION AND ANALYSIS October 29, 2020 Table of Contents 1.0 Summary of Quarterly Results 2.0 Business Overview 3.0 Business Environment 4.0 Results of Operations 5.0 Risk Management and Financial Risks 6.0 Liquidity and Capital Resources 7.0 Critical Accounting Estimates and Key Judgments 8.0 Recent Accounting Standards and Changes in Accounting Policies 9.0 Outstanding Share Data 10.0 Reader Advisories 1.0 Summary of Quarterly Results Three months ended Quarterly Summary Sep. 30 Jun. 30 Mar. 31 Dec. 31 Sept. 30 Jun. 30 Mar. 31 Dec. 31 ($ millions, except where indicated) 2020 2020 2020 2019 2019 2019 2019 2018(1) Production (mboe/day) 258.4 246.5 298.9 311.3 294.8 268.4 285.2 304.3 Throughput (mbbls/day) 300.1 281.3 307.8 203.4 356.4 340.3 333.6 286.9 Gross revenues and Marketing and other(1) 3,379 2,408 4,113 4,921 5,373 5,321 4,610 5,042 Net earnings (loss) (7,081) (304) (1,705) (2,341) 273 370 328 216 Per share – Basic (7.05) (0.31) (1.71) (2.34) 0.26 0.36 0.32 0.21 Per share – Diluted (7.06) (0.31) (1.71) (2.34) 0.25 0.36 0.31 0.16 Cash flow – operating activities 79 (10) 355 866 800 760 545 1,313 Funds from operations(2) 148 18 25 469 1,021 802 959 583 Per share – Basic 0.15 0.02 0.02 0.47 1.02 0.80 0.95 0.58 Per share – Diluted 0.15 0.02 0.02 0.47 1.02 0.80 0.95 0.58 (1) Gross revenues and Marketing and other results reported for 2019 have been recast to reflect a change in reclassification of intersegment sales eliminations and a change in presentation of the Integrated Corridor and Offshore business units.
    [Show full text]
  • Initial Project Description Summary
    SUNCOR ENERGY INC. Base Mine Extension INITIAL PROJECT DESCRIPTION SUMMARY February 2020 SUNCOR ENERGY INC. Base Mine Extension - Initial Project Description Summary February 2020 This Page Intentionally Left Blank SUNCOR ENERGY INC. Base Mine Extension - Initial Project Description Summary February 2020 EXECUTIVE SUMMARY Suncor Energy Inc. (Suncor) is submitting a proposal to develop the Base Mine Extension Project (the Project). All plausible pathways to address global emissions need energy from fossil fuels and Suncor views Canada’s world class, strategic oil sands resource as a key part of the energy future for decades to come. Commensurate with Canada’s ambitions, Suncor is committed to a long-term strategy of reducing absolute emissions. With the innovation we are known for, Suncor can provide the world with trusted low carbon energy. Suncor has invested billions of dollars in infrastructure that produces value added products to meet the energy needs of Albertans and Canadians. This Project is necessary to continue to add value with this infrastructure. The bitumen from this project will be used to supply the existing upgraders at Suncor’s Oil Sands Base Plant operations (Base Plant), when the existing mines are depleted. The Project is adjacent to Base Plant and includes an open pit mining operation and extraction facilities. Production is expected to be nominally 225 thousand barrels per day of replacement bitumen during its estimated 25-year operational life. The Project application will be based on best-available technology. In parallel, Suncor is developing new technologies, such as non-aqueous extraction. These new technologies have the potential to significantly reduce the overall footprint, reclamation timeline, and GHG emissions of mining and will be incorporated as appropriate.
    [Show full text]
  • Suncor Q3 2020 Investor Relations Supplemental Information Package
    SUNCOR ENERGY Investor Information SUPPLEMENTAL Published October 28, 2020 SUNCOR ENERGY Table of Contents 1. Energy Sources 2. Processing, Infrastructure & Logistics 3. Consumer Channels 4. Sustainability 5. Technology Development 6. Integrated Model Calculation 7. Glossary SUNCOR ENERGY 2 SUNCOR ENERGY EnergyAppendix Sources 3 202003- 038 Oil Sands Energy Sources *All values net to Suncor In Situ Mining Firebag Base Plant 215,000 bpd capacity 350,000 bpd capacity Suncor WI 100% Suncor WI 100% 2,603 mmbbls 2P reserves1 1,350 mmbbls 2P reserves1 Note: Millennium and North Steepank Mines do not supply full 350,000 bpd of capacity as significant in-situ volumes are sent through Base Plant MacKay River Syncrude 38,000 bpd capacity Syncrude operated Suncor WI 100% 205,600 bpd net coking capacity 501 mmbbls 2P reserves1 Suncor WI 58.74% 1,217 mmbbls 2P reserves1 Future opportunities Fort Hills ES-SAGD Firebag Expansion Suncor operated Lewis (SU WI 100%) 105,000 bpd net capacity Meadow Creek (SU WI 75%) Suncor WI 54.11% 1,365 mmbbls 2P reserves1 First oil achieved in January 2018 SUNCOR ENERGY 1 See Slide Notes and Advisories. 4 1 Regional synergy opportunities for existing assets Crude logistics Upgrader feedstock optionality from multiple oil sands assets Crude feedstock optionality for Edmonton refinery Supply chain Sparing, warehousing & supply chain management Consolidation of regional contracts (lodging, busing, flights, etc.) Operational optimizations Unplanned outage impact mitigations In Situ Turnaround planning optimization Process
    [Show full text]
  • Gastech 2017 Heads to the Land of the Rising
    VISIT OUR STAND C430, HALL 4 The O cial 2015 Conference Newspaper DAY FOUR Published by , and Friday, 30 October 2015 Gastech 2017 heads to the INSIDE THIS ISSUE 3 Conference Programme Land of the Rising Sun 5 CoTEs Programme Japanese and international industry leaders will examine the critical role 6 China’s gas-fired energy of gas and LNG for Japan’s future energy security at Gastech Japan 2017 in Tokyo. revolution is on the move The Gastech Conference & Exhibi- tion, Japan will be held 4–7 April 2017 in Chiba/Tokyo. This is the largest and most important business and technology event for the gas and LNG sector, creating Siemens technology is helping a global platform to address and discuss move gas through China’s vital the latest challenges faced in Asia and on and extensive WEGP system a wider international scale. 10 Observe unique design Gastech moves to Japan for the first time and is being hosted by The Japan requirements for LNG Gastech Consortium, which is made up of pumps and valves 10 of Japan’s leading energy companies, The Makuhari Messe International Convention Complex, the site of Gastech 2017, Fluor discusses the exclusive including: JERA; Mitsubishi Corporation; is located in the Chiba Prefecture along the shores of Tokyo Bay. design specifications of pumps Mitsui & Co.; Tokyo Gas; INPEX; ITO- and valves for LNG service CHU Corporation; JAPEX; JX Group— ENEOS; Marubeni Corporation; and Sum- 13 LNG projects pull itomo Corporation. big financing with Bringing the international energy eco- long-term contracts system to the world’s number one con- Special Focus discussion on sumer of LNG and leading global tech- developments and investments nology hub is an exciting and unique for emerging gas markets opportunity for the gas market.
    [Show full text]
  • Market Index Uniflex 10%
    Investment and retirement 5% 10% Market Index Uniflex 10% 25% Main Product Features 25% 6-year term (not redeemable before maturity) Guarantee of principal on maturity of 100% Low management fees of 1% per year 10% 15% $500 minimum deposit An easy way to diversify Cut-off age: 64 y/o (registered) and 70 y/o (non-registered) Even under a scenario where the return of each share is negative, this product may produce a global positive return Sector diversification of the Market Index Uniflex How it works On the settlement date, a starting level will be determined for each Canadian share included in the portfolio. On the maturity date, a ratio of the closing level over the starting level for each share will be computed. The 8 best performing shares during the 6-year term will be automatically assigned a fixed return of 60%, regardless of whether the actual return was positive or negative. The remaining 12 shares will be assigned their actual return. The global return (maximum 60%) will be calculated by averaging these 20 returns. The value at maturity will be the highest value between: the initial deposit; or the initial deposit PLUS global return (maximum 60%) Exposure to 20 Canadian companies included in the S&P/TSX 60 Index Company Sector Company Sector Metro Inc. Scotiabank Consumer staples Loblaw Companies Limited The Toronto-Dominion Bank Royal Bank of Canada Financial services Bank of Montreal Enbridge Inc. Sun Life Financial Inc. TransCanada Corporation Cenovus Energy Inc. Energy Canadian Natural Resources Limited Canadian National Railway Industrials Suncor Energy Inc.
    [Show full text]
  • Suncor Energy – Investor Presentation 2019 Q1
    INVESTOR INFORMATION Q1 2019 Published May 1, 2019 2 Canada’s leading integrated energy company $85B ~940 mbpd ~600 mbpd 28+ years ~460 mbpd ~1750 1 Oil production Heavy upgrading 2P Reserve life Refining nameplate Enterprise value Retail sites4 As at March 31, 2019 nameplate capacity2 nameplate capacity2 index3 capacity2 1, 2, 3, 4 See Slide Notes and Advisories 3 Suncor – A resilient business focused on shareholder returns Cash flow growth Cash generation Strong potential FFO1 increase largely independent of market conditions Significant upside FFO1 sensitivity to WTI, based on TTM5 actuals US$62.80 WTI, 0.76 C$/US$, US$18.00 NYH 3-2-1 crack spread 2 (C$ billion) ~5% CAGR (Based on 2019 price guidance) $16 $14 TTM average production 750 mbbls/d $12 Debottlenecks, $10 cost reductions $8 Fort Hills, and margin Syncrude, improvements $6 and Hebron $4 $5.5B Sustaining capital6 + dividend $2 $2.8B Sustaining capital6 $0 2018 FFO1 Production Free funds flow 2023E FFO1 $60 $63 $70 $75 $80 growth 3 growth4 TTM WTI ($USD) Shareholder returns Resilience Commitment to reliable returns through the commodity cycles Managing the balance sheet as a strategic asset Dividend per share7 Liquidity Buyback per share7,8,9 Anticipated buyback per share7,9 7% $5.3B $1.9B cash and $3.4B in available lines of credit Dividend + buyback yield As at March 31, 2019 — 5% 5% A low Credit rating 1.88 Investment grade 0.85 DBRS (A Low) Stable, S&P(A-) stable, Moody’s (Baa1) Stable 1.14 3% 3% Baa1 WTI FFO Break-Even10 (USD) 1.02 1.14 1.16 1.28 1.44 1.68 ~$45 Sustaining capital6 + dividend 2014 2015 2016 2017 2018 2019E 2019 1, 2, 3, 4, 5, 6, 7, 8, 9, 10 See Slide Notes and Advisories.
    [Show full text]
  • Suncor Energy Announces Successful Acquisition of 72.9% of Canadian Oil Sands Shares
    News Release FOR IMMEDIATE RELEASE Suncor Energy announces successful acquisition of 72.9% of Canadian Oil Sands shares (All dollar amounts referenced are in Canadian dollars) Calgary, Alberta (Feb. 5, 2016) – Suncor announced today that approximately 72.9 per cent of Canadian Oil Sands shares (“COS”) equating to 353,307,264 common shares and accompanying rights have been tendered to Suncor's Offer. Suncor will take up all tendered shares and those shares will be paid for in accordance with the terms of the Offer, initially made October 5, 2015 and most recently amended January 22, 2016. All shares tendered were held by "Independent Shareholders" as such term is defined by the COS shareholder rights plan dated December 31, 2010 as amended April 30, 2013 (the “COS Rights Plan”). “We’re pleased with the strong level of support from COS shareholders,” said Steve Williams, president and chief executive officer. “From the outset, we’ve spoken about the excellent value this offer creates for both COS and Suncor shareholders and I’m looking forward to delivering on that commitment.” In accordance with the "Permitted Bid" requirements of the COS Rights Plan and the terms of the Offer, Suncor has extended its Offer to Monday, February 22, 2016 at 5:00 p.m. MT (7:00 p.m. ET) so that COS shareholders who have not yet tendered their shares can do so. Further extensions beyond February 22, 2016 are not anticipated. COS shareholders who tendered to the Offer will receive 0.28 of a common share of Suncor for each share, which will be paid in accordance with the terms of the Offer.
    [Show full text]
  • U.S.-Canada Cross- Border Petroleum Trade
    U.S.-Canada Cross- Border Petroleum Trade: An Assessment of Energy Security and Economic Benefits March 2021 Submitted to: American Petroleum Institute 200 Massachusetts Ave NW Suite 1100, Washington, DC 20001 Submitted by: Kevin DeCorla-Souza ICF Resources L.L.C. 9300 Lee Hwy Fairfax, VA 22031 U.S.-Canada Cross-Border Petroleum Trade: An Assessment of Energy Security and Economic Benefits This report was commissioned by the American Petroleum Institute (API) 2 U.S.-Canada Cross-Border Petroleum Trade: An Assessment of Energy Security and Economic Benefits Table of Contents I. Executive Summary ...................................................................................................... 4 II. Introduction ................................................................................................................... 6 III. Overview of U.S.-Canada Petroleum Trade ................................................................. 7 U.S.-Canada Petroleum Trade Volumes Have Surged ........................................................... 7 Petroleum Is a Major Component of Total U.S.-Canada Bilateral Trade ................................. 8 IV. North American Oil Production and Refining Markets Integration ...........................10 U.S.-Canada Oil Trade Reduces North American Dependence on Overseas Crude Oil Imports ..................................................................................................................................10 Cross-Border Pipelines Facilitate U.S.-Canada Oil Market Integration...................................14
    [Show full text]
  • Pride Drillships Awarded Contracts by BP, Petrobras
    D EPARTMENTS DRILLING & COMPLETION N EWS BP makes 15th discovery in ultra-deepwater Angola block Rowan jackup moving SONANGOL AND BP have announced west of Luanda, and reached 5,678 m TVD to Middle East to drill the Portia oil discovery in ultra-deepwater below sea level. This is the fourth discovery offshore Saudi Arabia Block 31, offshore Angola. Portia is the 15th in Block 31 where the exploration well has discovery that BP has drilled in Block 31. been drilled through salt to access the oil- ROWAN COMPANIES ’ Bob The well is approximately 7 km north of the bearing sandstone reservoir beneath. W ell Keller jackup has been awarded a Titania discovery . Portia was drilled in a test results confirmed the capacity of the three-year drilling contract, which water depth of 2,012 m, some 386 km north- reservoir to flow in excess of 5,000 bbl/day . includes an option for a fourth year, for work offshore Saudi Arabia. The Bob Keller recently concluded work Pride drillships in the Gulf of Mexico and is en route to the Middle East. It is expected awarded contracts to commence drilling operations during Q2 2008. Rowan re-entered by BP, Petrobras the Middle East market two years ago after a 25-year absence. This PRIDE INTERNATIONAL HAS contract expands its presence in the announced two multi-year contracts for area to nine jackups. two ultra-deepwater drillships. First, a five-year contract with a BP subsidiary Rowan also has announced a multi- will allow Pride to expand its deepwater well contract with McMoRan Oil & drilling operations and geographic reach Gas Corp that includes re-entering in deepwater drilling basins to the US the Blackbeard Prospect.
    [Show full text]
  • ANNUAL INFORMATION FORM for the YEAR ENDED DECEMBER 31, 2015 February 19, 2016
    ENBRIDGE INC. ANNUAL INFORMATION FORM FOR THE YEAR ENDED DECEMBER 31, 2015 February 19, 2016 Enbridge Inc. 2015 Annual Information Form TABLE OF CONTENTS DOCUMENTS INCORPORATED BY REFERENCE As of the date hereof, portions of the MD&A and the audited consolidated financial statements of Enbridge as at and for the year ended December 31, 2015, as filed with the securities commissions or similar authorities in each of the provinces of Canada, as detailed below, are specifically incorporated by reference into and form an integral part of this AIF. These documents are available on SEDAR which can be accessed at www.sedar.com. Page Reference From Annual Financial AIF Statements MD&A GLOSSARY ................................................................................................... 1 PRESENTATION OF INFORMATION ........................................................... 4 12 FORWARD-LOOKING INFORMATION .........................................................5 CORPORATE STRUCTURE ......................................................................... 6 GENERAL DESCRIPTION OF THE BUSINESS ............................................ 7 1-2, 14-19 GENERAL DEVELOPMENT OF THE BUSINESS ....................................... 10 2-4, 8-9, 16-21, 23-39, 59-60, 67-69, 73-74 LIQUIDS PIPELINES ................................................................................... 16 1, 40-52 GAS DISTRIBUTION ................................................................................... 17 1, 52-55 GAS PIPELINES, PROCESSING AND ENERGY SERVICES
    [Show full text]