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Refining Bitumen: Costs,Benefits and Analysis
Study No. 145 December 2014 CANADIAN ENERGY REFINING BITUMEN: RESEARCH COSTS, BENEFITS AND ANALYSIS INSTITUTE Canadian Energy Research Institute | Relevant • Independent • Objective REFINING BITUMEN: COSTS, BENEFITS AND ANALYSIS Refining Bitumen: Costs, Benefits and Analysis Copyright © Canadian Energy Research Institute, 2014 Sections of this study may be reproduced in magazines and newspapers with acknowledgement to the Canadian Energy Research Institute ISBN 1-927037-30-0 Authors: Dinara Millington Rob McWhinney Zoey Walden Acknowledgements: The authors of this report would like to extend their thanks to all CERI staff that provided insightful comments required for the completion of this report, as well as those involved in the production, reviewing, and editing of the material, including but not limited to Allan Fogwill and Megan Murphy CANADIAN ENERGY RESEARCH INSTITUTE 150, 3512 – 33 Street NW Calgary, Alberta T2L 2A6 Canada www.ceri.ca December 2014 Printed in Canada Refining Bitumen: Costs, Benefits and Analysis iii Table of Contents LIST OF FIGURES .............................................................................................................. v LIST OF TABLES ................................................................................................................ vii EXECUTIVE SUMMARY ..................................................................................................... ix CHAPTER 1 INTRODUCTION AND BACKGROUND INFORMATION .................................. 1 Introduction ....................................................................................................................... -
PUBLICATIONS SPP Briefing Paper
PUBLICATIONS SPP Briefing Paper Volume 11:18 June 2018 THE NORTH WEST REDWATER STURGEON REFINERY: WHAT ARE THE NUMBERS FOR ALBERTA’S INVESTMENT? Brian Livingston SUMMARY Since 2006, the government of Alberta has tried to increase the volume of raw bitumen upgraded and refined in the province. More specifically, the Alberta Petroleum Marketing Commission (APMC) and Canadian Natural Resources Ltd. (CNRL) have entered into agreements with a facility northeast of Edmonton called the North West Redwater (NWR) Sturgeon Refinery. The NWR Sturgeon Refinery is designed to process 79,000 barrels per day (bpd) of feedstock, consisting of 50,000 bpd of bitumen and 29,000 bpd of diluent (referred to as dilbit). The refinery will produce petroleum products consisting of approximately 40,000 bpd of low sulphur diesel, 28,000 bpd of diluent and 13,000 bpd of other lighter petroleum products. It will also be able to capture 1.2 million tonnes per year of carbon dioxide emitted from the refinery’s operations. This captured carbon dioxide will be compressed, put into a pipeline and then injected into an existing oil field in order to achieve increased production of crude oil (referred to as enhanced oil recovery or EOR). It is the first refinery built in Canada since 1984, and the first one in Canada to refine bitumen into petroleum products such as diesel fuel. It differs from the upgrader built in Lloydminster which only upgrades bitumen into synthetic crude oil that requires further refining at a conventional refinery in order to produce petroleum products. This paper gives a description of the structure of this support by APMC and CNRL using a mechanism whereby those two parties agree to enter into tolling agreements to process the diluted bitumen feedstock into refined petroleum products for sale. -
Carbon Dioxide Enhanced Oil Recovery (CO2 EOR)
Carbon Dioxide Enhanced Oil Recovery (CO2 EOR): Factors Involved in Adding Carbon Capture, Utilization and Storage (CCUS) to Enhanced Oil Recovery L. Stephen Melzer CO2 Consultant and Annual CO2 Flooding Conference Director Midland, TX February 2012 Carbon Dioxide Enhanced Oil Recovery (CO2 EOR): Factors Involved in Adding Carbon Capture, Utilization and Storage (CCUS) to Enhanced Oil Recovery Table of Contents I. Introduction II. The Background and Fundamentals of Oil Production and CO2 EOR a. Primary Production Phase b. Secondary Production Phase c. Tertiary Phase III. Current and Projected Flooding CO2 EOR Activity In the U.S. & Permian Basin a. Long-Term Nature of The Industry b. U.S. Project Planning Underway IV. The Effectiveness of CO2 Storage in an EOR Project V. Monitoring CO2 Within The Reservoir: Existing Practices VI. CCUS: Incremental Requirements VII. CO2 Recycle, Reservoir Retention, and CO2 ‘Losses’ During EOR: The Metrics and Experience Base a. Purchases and Recycle Volumes b. CO2 Retention c. CO2 Losses During EOR: Causes and the Experience Base VIII. How to Move Forward? The Urgency and Areas for Caution a. Storage Frameworks b. Recommended Action References FIGURES AND TABLES Figure 1: Number of CO2 EOR Projects (Worldwide, U.S. and Permian Basin) Figure 2: U.S. CO2 EOR Projects, Supply Sources and Pipelines Figure 3: CO2 EOR Production (U.S. and Permian Basin, 1992-2010) Table 1: Basin Scale Criteria for Storage Figure 4: Crossectional Representation of the Various Types of Geologic Basins Table 2: Reservoir Surveillance Tools Commonly Used in CO2 EOR Figure 5: CO2 Flood Surveillance vs. CCUS Monitoring, Measurement and Verification Figure 6: Example CO2 Purchase vs. -
Opportunities in Alberta's Industrial Heartland
OPPORTUNITIES IN ALBERTA’S INDUSTRIAL HEARTLAND Mark Plamondon, P.Eng Executive Director Alberta’s Industrial Heartland Association CANADIAN GLOBAL AFFAIRS INSTITUTE NOVEMBER 1, 2019 www.IndustrialHeartland.com Suite 300, 9940 – 99 Avenue, Fort Saskatchewan, Alberta T8L 4G8 1.888.414.0032 ALBERTA’S INDUSTRIAL HEARTLAND ASSOCIATION Alberta’s Industrial Heartland is guided by a non profit association of municipalities dedicated to sustainable eco-industrial development. Alberta’s Industrial Heartland Association is a collaborative 20-year partnership of five municipalities and three associate members. www.IndustrialHeartland.com Suite 300, 9940 – 99 Avenue, Fort Saskatchewan, Alberta T8L 4G8 1.888.414.0032 WHAT WE DO • Business Case • Transportation Development • Pipeline Corridors • Investor Outreach • Land Use • Investor Awareness & Hosting Business Infrastructure & Development Planning Communications Government & Community Relations Relations • Provincial Advocacy • Education and Awareness • Federal Advocacy • Social Awareness • Municipal Relations • Community Engagement www.IndustrialHeartland.com Suite 300, 9940 – 99 Avenue, Fort Saskatchewan, Alberta T8L 4G8 1.888.414.0032 STRATEGIC STAKEHOLDER PARTNERSHIPS www.IndustrialHeartland.com Suite 300, 9940 – 99 Avenue, Fort Saskatchewan, Alberta T8L 4G8 1.888.414.0032 ALBERTA’S INDUSTRIAL HEARTLAND 582 sq.km We are Canada’s largest hydrocarbon processing centre Local Spending $1.5 billion Annually Jobs 6,000+ direct $40 billion in 25,000+ existing indirect 40+ Industrial Heartland Investment -
CMTC-485111-MS Feasibility of CO2-EOR in Shale-Oil
CMTC-485111-MS Feasibility of CO2-EOR in Shale-Oil Reservoirs: Numerical Simulation Study and Pilot Tests Dheiaa Alfarge, Iraqi Ministry of Oil, Missouri University of Science and Technology; Mingzhen Wei and Baojun Bai, Missouri University of Science and Technology Copyright 2017, Carbon Management Technology Conference This paper was prepared for presentation at the Carbon Management Technology Conference held in Houston, Texas, USA, 17-20 July 2017. This paper was selected for presentation by a CMTC program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed and are subject to correction by the author(s). The material does not necessarily reflect any position of the Carbon Management Technology Conference, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Carbon Management Technology Conference is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of CMTC copyright. Abstract Shale oil reservoirs such as Bakken, Niobrara, and Eagle Ford have become the main target for oil and gas investors as conventional formations started to be depleted and diminished in number. These unconventional plays have a huge oil potential; however, the predicted primary oil recovery is still low as an average of 7.5 %. Injecting carbon dioxide (CO2) to enhance oil recovery in these poor-quality formations is still a debatable issue among investigators. In this study, three steps of research have been integrated to investigate the parameters which control the success of CO2 huff-n-puff process in the field scale of shale oil reservoirs. -
Enhanced Oil Recovery (EOR) Strategy
Enhanced Oil Recovery (EOR) Strategy Contents 1. Foreword 3 2. Executive summary 4 3. Strategy context 5 3.1 Where are we now and what’s the opportunity? 5 3.2 EOR opportunities (un-risked incremental oil potential) 5 3.3 EOR opportunities (risked) 6 3.4 Industry context – impact of oil price and activity levels 6 4. EOR ambition and implementation 7 4.1 OGA EOR ambition 7 4.2 Implementation programme 7 5. Implementation and accountabilities 8 5.1 Eight-step programme 8 Programme 1: Existing EOR projects 8 Programme 2: MER for future EOR projects 8 Programme 3: Workgroups and industry partnerships 8 Programme 4: Technology development and deployment 8 Programme 5: Creating value – improving economics 9 Programme 6: Advance next EOR and support CO2 storage 9 Programme 7: Knowledge management 9 Programme 8: Communication and stakeholder plans 9 6. Communication and dialogue 12 6.1 Communication plan 12 6.2 Risks to achieving the strategy 12 7. Conclusion 13 8. Acknowledgements 14 1. Foreword | EOR Strategy 3 1. Foreword The OGA has been set up to influence, promote and regulate the UK oil and gas industry and has been provided with a range of new powers to enable it to do so. The development of a series of strategies represents a key step in setting the strategic direction of how the OGA and industry will work to maximise economic recovery (MER) from the United Kingdom Continental Shelf (UKCS) and was one of the core recommendations of the Wood Maximising Recovery Review. The MER UK Strategy underpins our work and came into force in March 2016. -
Oil and Gas Technologies Supplemental Information
Quadrennial Technology Review 2015 Chapter 7: Advancing Systems and Technologies to Produce Cleaner Fuels Supplemental Information Oil and Gas Technologies Subsurface Science, Technology, and Engineering U.S. DEPARTMENT OF ENERGY Quadrennial Technology Review 2015 Oil and Gas Technologies Chapter 7: Advancing Systems and Technologies to Produce Cleaner Fuels Oil and Gas in the Energy Economy of the United States Fossil fuel resources account for 82% of total U.S. primary energy use because they are abundant, have a relatively low cost of production, and have a high energy density—enabling easy transport and storage. The infrastructure built over decades to supply fossil fuels is the world’s largest enterprise with the largest market capitalization. Of fossil fuels, oil and natural gas make up 63% of energy usage.1 Across the energy economy, the source and mix of fuels used across these sectors is changing, particularly the rapid increase in natural gas production from unconventional resources for electricity generation and the rapid increase in domestic production of shale oil. While oil and gas fuels are essential for the United States’ and the global economy, they also pose challenges: Economic: They must be delivered to users and the markets at competitive prices that encourage economic growth. High fuel prices and/or price volatility can impede this progress. Security: They must be available to the nation in a reliable, continuous way that supports national security and economic needs. Disruption of international fuel supply lines presents a serious geopolitical risk. Environment: They must be supplied and used in ways that have minimal environmental impacts on local, national, and global ecosystems and enables their sustainability. -
World Oil Outlook 2040
Organization of the Petroleum Exporting Countries 2019 World Oil Outlook 2040 2019 World Oil Outlook 2040 Organization of the Petroleum Exporting Countries Digital access to the WOO: an interactive user experience 24/7 OPEC’s World Oil Outlook (WOO) is part of the Organization’s commitment to market stability. The publication is a means to highlight and further the understanding of the many possible future challenges and opportunities for the oil industry. It is also a channel to encourage dialogue, cooperation and transparency between OPEC and other stakeholders within the industry. As part of OPEC’s ongoing efforts to improve user experience of the WOO and provide data transparency, two digital interfaces are available: the OPEC WOO App and the interactive version of the WOO. The OPEC WOO App provides increased access to the publication’s vital analysis and energy-related data. It is ideal for energy professionals, oil industry stakeholders, policymakers, market analysts, academics and the media. The App’s search engine enables users to easily find information, and its bookmarking function allows them to store and review their favourite articles. Its versatility also allows users to compare graphs and tables interactively, thereby maximizing information extraction and empowering users to undertake their own analysis. The interactive version of the WOO also provides the possibility to download specific data and information, thereby enhancing user experience. Download Access the OPEC WOO App interactive version Available for Android and iOS OPEC is a permanent, intergovernmental organization, established in Baghdad, Iraq, on 10–14 September 1960. The Organization comprises 14 Members: Algeria, Angola, Republic of the Congo, Ecuador, Equatorial Guinea, Gabon, the Islamic Republic of Iran, Iraq, Kuwait, Libya, Nigeria, Saudi Arabia, the United Arab Emirates and Venezuela. -
Overview of the Enhanced Oil Recovery Tax Credit
LB&I Concept Unit Knowledge Base – Corporate/Business Issues & Credits Library Level Number Title Shelf General Business and Energy Credits Book 277 Specific Industry Credits Chapter 5 Enhanced Oil Recovery Credit Section Unit Name Overview of the Enhanced Oil Recovery Tax Credit Primary UIL Code 43.00-00 Enhanced Oil Recovery Credit Document Control Number (DCN) ECR/C/277_05-01 Date of Last Update 01/15/20 Note: This document is not an official pronouncement of law, and cannot be used, cited or relied upon as such. Further, this document may not contain a comprehensive discussion of all pertinent issues or law or the IRS's interpretation of current law. DRAFT Table of Contents (View this PowerPoint in “Presentation View” to click on the links below) General Overview Diagram of Concept Detailed Explanation of the Concept Examples of the Concept Index of Referenced Resources Training and Additional Resources Glossary of Terms and Acronyms Index of Related Practice Units 2 DRAFT General Overview Overview of the Enhanced Oil Recovery Tax Credit Congress enacted IRC 43 in 1990 to provide an investment credit for certain costs a taxpayer pays or incurs for qualified Enhanced Oil Recovery (EOR) projects. The amount of the credit is a maximum of 15 percent of the qualified expenditures the taxpayer makes, but can be less as described later in this Practice Unit. The EOR credit becomes part of the general business credit. The taxpayer claims the credit on Form 8830 - Enhanced Oil Recovery Credit. Large corporations and partnerships usually claim the credit. Before further discussion, let’s start with the definitions of some common terms: . -
Alberta Energy Oil Sands Production Profile : 2004-2014
A L B E R T A ENERGY O I L S A N D S PRODUCTION PROFIL E : 2 0 0 4 - 2 0 1 4 Energy Technical Services Resource Development Policy Division January 31, 2016 2004 - 2014 Christopher Holly Martin Mader Shoshi Soni Jesse Toor ISBN: 978-1-4601-2723-0 (PDF) This paper was prepared by the Energy Technical Services Branch, Alberta Energy, to illustrate technology developments in the Alberta oil and gas industry. The Government of Alberta shall have no liability whatsoever to third parties for any defect, deficiency, error or omission in the contents, analyses and evaluations presented in this paper. Any questions about this paper should be directed to Branch Head Energy Technical Services Alberta Energy 9945 – 108 Street Edmonton, Alberta Canada T5K 2G6 Alberta Energy| Oil Sands Production Profile 2004 - 2014 P a g e | 2 Table of Contents Introduction ............................................................................................................................................ 4 Methodology .......................................................................................................................................... 5 Oil Sands Areas ..................................................................................................................................... 6 Production Technologies ....................................................................................................................... 7 Primary/Enhanced Oil Recovery ............................................................................................................................7 -
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https://doi.org/10.3311/PPch.17236 462|Creative Commons Attribution b Periodica Polytechnica Chemical Engineering, 65(4), pp. 462–475, 2021 Recent Approaches, Catalysts and Formulations for Enhanced Recovery of Heavy Crude Oils Umar Gaya1,2* 1 Department of Pure and Industrial Chemistry, Faculty of Physical Sciences, Bayero University, 700241 Kano, 1 Gwarzo Road, Nigeria 2 Directorate of Science and Engineering Infrastructure, National Agency for Science and Engineering Infrastructure (NASENI), Idu Industrial Layout, 900104 Garki, Abuja, Nigeria * Corresponding author, e-mail: [email protected] Received: 20 September 2020, Accepted: 04 December 2020, Published online: 16 August 2021 Abstract Crude oil deposits as light/heavy form all over the world. With the continued depletion of the conventional crude and reserves trending heavier, the interest to maximise heavy oil recovery continues to emerge in importance. Ordinarily, the traditional oil recovery stages leave behind a large amount of heavy oil trapped in porous reservoir structure, making the imperative of additional or enhanced oil recovery (EOR) technologies. Besides, the integration of downhole in-situ upgrading along with oil recovery techniques not only improves the efficiency of production but also the quality of the produced oil, avoiding several surface handling costs and processing challenges. In this review, we present an outline of chemical agents underpinning these enabling technologies with a focus on the current approaches, new formulations and future directions. Keywords in-situ upgrading, enhanced oil recovery, aquathermolysis, heavy oil, catalyst 1 Introduction The world is caught up in the ever-increasing need for Table 1 Selected definitions of heavy crude oil at 15 °C. -
City of Edmonton City of Fort Saskatchewan Lamont
Fort Industrial Estates Petrogas Praxair Inc. (OPERATIONAL) (OPERATIONAL) EnergyCorp www.praxair.com Praxair, Inc. is the largest industrial This light/medium industrial park (OPERATIONAL) services the Heartland heavy industrial gases company in North and South area as well as the agricultural www.petrogascorp.com America, and one of the largest community. worldwide. The company produces, Operated as a division of Petrogas sells and distributes atmospheric, It has direct access to Highway 15/21, Energy Corp., the Petrogas Energy process and specialty gases, and high- adjacent to the high load corridor Services Ltd. - Fort Saskatchewan performance surface coatings. Praxair to Fort McMurray and is serviced by terminal provides the service of Canada Inc. has proudly served Alberta’s municipal water and sewer, natural gas receiving, storing and loading products Industrial Heartland for over 30 years. end customer and improved tool and electricity. They also have building onto trucks and rail cars for the Taurus Industrial Aux Sable Canada Ltd. Dow Chemical Canada Ferus Inc. (OPERATIONAL) The Fort Saskatchewan personnel properties. The facility maintains ISO space for lease. sale and distribution into Alberta’s 9001 and 14001 registration and is CITY OF EDMONTON CITY OF FORT www.Ferus.ca petrochemical, refining and crude oil oversees the Heartland hydrogen Business Park Heartland Offgas Plant ULC (OPERATIONAL) pipeline network (spanning over 60 km), (OPERATIONAL) recognized by Alberta Environment as www.edmonton.ca industry. EnviroChampions. www.dowcanada.com The facility captures gaseous CO2, a Keyera (KFS) (OPERATIONAL) two large air separation units, carbon www.taurusprojects.ca SASKATCHEWAN (“HOP”) (OPERATIONAL) process by-product of Sherritt’s nearby www.keyera.com www.forstsask.ca dioxide purification facilities, and Horsehills Industrial Walton Development www.auxsable.com Serving North America, Latin America ammonia process, liquefies it and stores Plains Midstream oxygen and nitrogen pipelines.