Your CDP Climate Change Questionnaire 2020 C0. Introduction
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Manual of Petroleum Measurement Standards Chapter 20—Allocation Measurement
Manual of Petroleum Measurement Standards Chapter 20—Allocation Measurement Section 1—Allocation Measurement FIRST EDITION, SEPTEMBER 1993 REAFFIRMED, SEPTEMBER 2011 Manual of Petroleum Measurement Standards Chapter 20—Allocation Mesurement Section 1—Allocation Measurement Measurement Coordination FIRST EDITION, SEPTEMBER 1993 REAFFIRMED, SEPTEMBER 2011 SPECIAL NOTES 1. API PUBLICATIONS NECESSARILY ADDRESS PROBLEMS OF A GENERAL NATURE. WITH RESPECT TO PARTICULAR CIRCUMSTANCES, LOCAL, STATE, AND FEDERAL LAWS AND REGULATIONS SHOULD BE REVIEWED. 2. API IS NOT UNDERTAKING TO MEET THE DUTIES OF EMPLOYERS, MANU FACTURERS, OR SUPPLIERS TO WARN AND PROPERLY TRAIN AND EQUIP THEIR EMPLOYEES, AND OTHERS EXPOSED, CONCERNING HEALTH AND SAFETY RISKS AND PRECAUTIONS, NOR UNDERTAKING THEIR OBLIGATIONS UNDER LOCAL, STATE OR FEDERAL LAWS. 3. INFORMATION CONCERNING SAFETY AND HEALTH RISKS AND PROPER PRECAUTIONS WITH RESPECT TO PARTICULAR MATERIALS AND CONDI TIONS SHOULD BE OBTAINED FROM THE EMPLOYER, THE MANUFACTURER OR SUPPLIER OF THAT MATERIAL, OR THE MATERIAL SAFETY DATA SHEET. 4. NOTHING CONTAINED IN ANY API PUBLICATION IS TO BE CONSTRUED AS GRANTING ANY RIGHT, BY IMPLICATION OR OTHERWISE, FOR THE MANU FACTURE, SALE OR USE OF ANY METHOD, APPARATUS, OR PRODUCT COVERED BY LETTERS PATENT. NEITHER SHOULD ANYTHING CONTAINED IN THE PUBLICATION BE CONSTRUED AS INSURING ANYONE AGAINST LIABILITY FOR INFRINGEMENT OF LETTERS PATENT. 5. GENERALLY, API STANDARDS ARE REVIEWED AND REVISED, REAF FIRMED OR WITHDRAWN AT LEAST EVERY FIVE YEARS. SOMETIMES A ONE TIME EXTENSION OF UP TO TWO YEARS WILL BE ADDED TO THIS REVIEW CYCLE. THIS PUBLICATION WILL NO LONGER BE IN EFFECT FIVE YEARS AFTER ITS PUBLICATION DATE AS AN OPERATIVE API STANDARD OR, WHERE AN EXTENSION HAS BEEN GRANTED, UPON REPUBLICATION. -
Climate and Energy Benchmark in Oil and Gas Insights Report
Climate and Energy Benchmark in Oil and Gas Insights Report Partners XxxxContents Introduction 3 Five key findings 5 Key finding 1: Staying within 1.5°C means companies must 6 keep oil and gas in the ground Key finding 2: Smoke and mirrors: companies are deflecting 8 attention from their inaction and ineffective climate strategies Key finding 3: Greatest contributors to climate change show 11 limited recognition of emissions responsibility through targets and planning Key finding 4: Empty promises: companies’ capital 12 expenditure in low-carbon technologies not nearly enough Key finding 5:National oil companies: big emissions, 16 little transparency, virtually no accountability Ranking 19 Module Summaries 25 Module 1: Targets 25 Module 2: Material Investment 28 Module 3: Intangible Investment 31 Module 4: Sold Products 32 Module 5: Management 34 Module 6: Supplier Engagement 37 Module 7: Client Engagement 39 Module 8: Policy Engagement 41 Module 9: Business Model 43 CLIMATE AND ENERGY BENCHMARK IN OIL AND GAS - INSIGHTS REPORT 2 Introduction Our world needs a major decarbonisation and energy transformation to WBA’s Climate and Energy Benchmark measures and ranks the world’s prevent the climate crisis we’re facing and meet the Paris Agreement goal 100 most influential oil and gas companies on their low-carbon transition. of limiting global warming to 1.5°C. Without urgent climate action, we will The Oil and Gas Benchmark is the first comprehensive assessment experience more extreme weather events, rising sea levels and immense of companies in the oil and gas sector using the International Energy negative impacts on ecosystems. -
Statoil ASA Statoil Petroleum AS
Offering Circular A9.4.1.1 Statoil ASA (incorporated with limited liability in the Kingdom of Norway) Notes issued under the programme may be unconditionally and irrevocably guaranteed by Statoil Petroleum AS (incorporated with limited liability in the Kingdom of Norway) €20,000,000,000 Euro Medium Term Note Programme On 21 March 1997, Statoil ASA (the Issuer) entered into a Euro Medium Term Note Programme (the Programme) and issued an Offering Circular on that date describing the Programme. The Programme has been subsequently amended and updated. This Offering Circular supersedes any previous dated offering circulars. Any Notes (as defined below) issued under the Programme on or after the date of this Offering Circular are issued subject to the provisions described herein. This does not affect any Notes issued prior to the date hereof. Under this Programme, Statoil ASA may from time to time issue notes (the Notes) denominated in any currency agreed between the Issuer and the relevant Dealer (as defined below). The Notes may be issued in bearer form or in uncertificated book entry form (VPS Notes) settled through the Norwegian Central Securities Depositary, Verdipapirsentralen ASA (the VPS). The maximum aggregate nominal amount of all Notes from time to time outstanding will not exceed €20,000,000,000 (or its equivalent in other currencies calculated as described herein). The payments of all amounts due in respect of the Notes issued by the Issuer may be unconditionally and irrevocably guaranteed by Statoil A6.1 Petroleum AS (the Guarantor). The Notes may be issued on a continuing basis to one or more of the Dealers specified on page 6 and any additional Dealer appointed under the Programme from time to time, which appointment may be for a specific issue or on an ongoing basis (each a Dealer and together the Dealers). -
Preparing for Carbon Pricing: Case Studies from Company Experience
TECHNICAL NOTE 9 | JANUARY 2015 Preparing for Carbon Pricing Case Studies from Company Experience: Royal Dutch Shell, Rio Tinto, and Pacific Gas and Electric Company Acknowledgments and Methodology This Technical Note was prepared for the PMR Secretariat by Janet Peace, Tim Juliani, Anthony Mansell, and Jason Ye (Center for Climate and Energy Solutions—C2ES), with input and supervision from Pierre Guigon and Sarah Moyer (PMR Secretariat). The note comprises case studies with three companies: Royal Dutch Shell, Rio Tinto, and Pacific Gas and Electric Company (PG&E). All three have operated in jurisdictions where carbon emissions are regulated. This note captures their experiences and lessons learned preparing for and operating under policies that price carbon emissions. The following information sources were used during the research for these case studies: 1. Interviews conducted between February and October 2014 with current and former employees who had first-hand knowledge of these companies’ activities related to preparing for and operating under carbon pricing regulation. 2. Publicly available resources, including corporate sustainability reports, annual reports, and Carbon Disclosure Project responses. 3. Internal company review of the draft case studies. 4. C2ES’s history of engagement with corporations on carbon pricing policies. Early insights from this research were presented at a business-government dialogue co-hosted by the PMR, the International Finance Corporation, and the Business-PMR of the International Emissions Trading Association (IETA) in Cologne, Germany, in May 2014. Feedback from that event has also been incorporated into the final version. We would like to acknowledge experts at Royal Dutch Shell, Rio Tinto, and Pacific Gas and Electric Company (PG&E)—among whom Laurel Green, David Hone, Sue Lacey and Neil Marshman—for their collaboration and for sharing insights during the preparation of the report. -
Mongstad Mongstad
North Sea Sweden Project Profile Norway Mongstad Mongstad The Mongstad facilities in western Norway have been in operation since the mid-1970’s and today encompass a refinery, a crude oil terminal, a technical development center and a wet gas processing factory. Throughout decades of expansion and modernization, ABB has kept pace with Mongstad’s dynamic process control and electrification requirements by providing advanced, flexible solutions designed to meet both current and future needs. A key link in the Norwegian oil supply chain OilUpstream & andGas Midstream Comprising Norway’s largest oil refinery, a high-traffic shipping port and storage facilities for around one-third of the crude oil produced by the Norwegian state, Mongstad is vital to the Norwegian oil industry. Keeping the oil flowing in and out of Mongstad in a safe, efficient and environmental manner takes state-of-the-art technology, including electric power and process Facts about Mongstad: automation systems from ABB. ABB is the leading supplier of integrated The oil refinery is the largest of its kind electrotechnical solutions to the oil and gas industry, and has provided in Norway with an annual capacity of innovative solutions to the Mongstad facilities for over 30 years. 10 million tons of crude. It is owned by By consistently providing reliable, high performance process control capabilities Mongstad Refining (79% StatoilHydro to Mongstad, the scope of ABB automation technology has steadily increased. and 21% Shell). Today, ABB automation technology at Mongstad encompasses: The crude oil terminal provides inter- 2,700 I/O boards with over 25,000 I/O´s 4 INFINET rings mediate storage of more than 1/3 of 150 redundant controllers distributed 13 HMI servers, 33 dual-VDU consoles over 17 equipment outstations all crude oil produced on the Norwegian 500 process graphics continental shelf. -
Methane Emissions Estimation Protocol
Methane Emissions Estimation Protocol Prepared for: August 2020 V3.2020 i DOCUMENT VERSION CONTROL PAGE Version Date Explanation Original August 3, 2016 Original Version of Protocol, approved by ONE Future members, posted to website Version 2 August 27, 2018 Revised by ONE Future to reflect minor changes Version 3 August 3 , 2020 Updated to show T&S mileage surrogate for throughput, corrected Appendix C Equations, added Appendix D to clarify annual ONE Future segment intensity calculations, updated some “examples”, corrected format errors, and made other minor clarifications ii TABLE OF CONTENTS EXECUTIVE SUMMARY ......................................................................................................... viii CHAPTER 1: INTRODUCTION .............................................................................................. 10 1.1 Background .................................................................................................................... 10 1.2 ONE Future and the EPA Methane Challenge ............................................................... 12 1.3 Methane Emissions Estimation Protocol ....................................................................... 13 1.4 Natural Gas Systems Supply Chain ............................................................................... 14 CHAPTER 2: GHG EMISSION ESTIMATION METHODS .................................................. 17 2.1 Scope and Boundaries ................................................................................................... -
Presentation Title
Understanding changes to EIA’s hydrocarbon gas liquids (HGL) supply/disposition tables September 13, 2017 | Washington, D.C. By Warren Wilczewski, Office of Petroleum, Natural Gas, & Biofuels Analysis U.S. Energy Information Administration Independent Statistics & Analysis www.eia.gov EIA mission: independent statistics and analysis • EIA was created by the U.S. Congress in 1977 • EIA collects, analyzes, and disseminates independent and impartial energy information to promote sound policymaking, efficient markets, and public understanding of energy and its interaction with the economy and the environment • EIA is the Nation's premier source of energy information and, by law, its data, analyses, and forecasts are independent of approval by any other officer or employee of the U.S. Government • EIA does not propose or advocate any policy positions Changes to HGL tables in the Petroleum Supply Monthly Webinar September 13, 2017 2 Key takeaways • EIA implemented the alkanes/olefins split in its monthly tables back to January 2010 – both on the web and in the Petroleum Supply Monthly, on August 31, alongside the release of the 2016 Petroleum Supply Annual • Surveys remain the same, and the data remain the same, only the labels and the table layouts have changed • Based on industry stakeholder insight, EIA developed an allocation methodology for alkanes and olefins in stocks to generate datasets that do not precisely reflect data collected through surveys • The only data that will no longer appear in EIA tables is ethylene, with the exception of refinery production of ethylene Changes to HGL tables in the Petroleum Supply Monthly Webinar September 13, 2017 3 E IA’s HGL terminology bridges how the commodities are supplied, marketed and consumed Refinery Olefins Refinery Olefins Natural Gasoline) Natural Gasoline) Natural Gasoline, & Ref inery Olef ins) Refinery/ Condensate Splitter Crude Oil/ Plant Condensate Lease Condensate Field/Lease Separator Ga s Well Oil Well *Butanes include normal butane and isobutane. -
Unconventional Gas Production
Engineering Energy: Unconventional Gas Production A study of shale gas in Australia. FINAL REPORT PROJECT AUSTRALIAN ACADEMY OF THE HUMANITIES AUSTRALIAN ACADEMY OF SCIENCE ACADEMY OF THE SOCIAL SCIENCES IN AUSTRALIA AUSTRALIAN ACADEMY OF TECHNOLOGICAL SCIENCES AND ENGINEERING SECURING EXPERT AUSTRALIA’S WORKING FUTURE GROUP – PROJECT 6 A three-year research Professor Peter Cook CBE, FTSE (Chair) program funded by the Dr Vaughan Beck FTSE (Deputy Chair) Australian Research Professor David Brereton Council and conducted Professor Robert Clark AO, FAA, FRSN Dr Brian Fisher AO, PSM, FASSA by the four Learned Professor Sandra Kentish Academies through Mr John Toomey FTSE the Australian Council Dr John Williams FTSE of Learned Academies for PMSEIC, through AUTHORS the Office of the Chief Professor Peter Cook CBE, FTSE Scientist. Securing Dr Vaughan Beck FTSE Australia’s Future delivers Professor David Brereton research-based evidence Professor Robert Clark AO, FAA, FRSN and findings to support Dr Brian Fisher AO, PSM, FASSA policy development in Professor Sandra Kentish areas of importance to Mr John Toomey FTSE Australia’s future. Dr John Williams FTSE © Australian Council of Learned Academies (ACOLA) ISBN 978 0 9875798 1 2 This work is copyright. Apart from any use permitted under the Copyright Act 1968, no part of it may be reproduced by any process without written permission from the publisher. Requests and inquiries concerning reproduction rights should be directed to the publisher. DATE OF PUBLICATION May 2013 PUBLISHER Australian Council of Learned Academies Level 1, 1 Bowen Crescent Melbourne Victoria 3004 Australia Telephone: +61 (0)3 98640923 www.acola.org.au SUGGESTED CITATION Cook, P, Beck, V, Brereton, D, Clark, R, Fisher, B, Kentish, S, Toomey, J and Williams, J (2013). -
Annual Report on Form 20-F ANNUAL REPORT /2012 Annual Report on Form 20-F
ANNUAL REPORT /2012 Annual Report on Form 20-F ANNUAL REPORT /2012 Annual Report on Form 20-F The Annual Report on Form 20-F is our SEC filing for the fiscal year ended December 31, 2012, as submitted to the US Securities and Exchange Commission. The complete edition of our Annual Report is available online at www.statoil.com/2012 © Statoil 2013 STATOIL ASA BOX 8500 NO-4035 STAVANGER NORWAY TELEPHONE: +47 51 99 00 00 www.statoil.com Cover photo: Ole Jørgen Bratland Annual report on Form 20-F Cover Page 1 1 Introduction 3 1.1 About the report 3 1.2 Key figures and highlights 4 2 Strategy and market overview 5 2.1 Our business environment 5 2.1.1 Market overview 5 2.1.2 Oil prices and refining margins 6 2.1.3 Natural gas prices 6 2.2 Our corporate strategy 7 2.3 Our technology 9 2.4 Group outlook 10 3 Business overview 11 3.1 Our history 11 3.2 Our business 12 3.3 Our competitive position 12 3.4 Corporate structure 13 3.5 Development and Production Norway (DPN) 14 3.5.1 DPN overview 14 3.5.2 Fields in production on the NCS 15 3.5.2.1 Operations North 17 3.5.2.2 Operations North Sea West 18 3.5.2.3 Operations North Sea East 19 3.5.2.4 Operations South 19 3.5.2.5 Partner-operated fields 20 3.5.3 Exploration on the NCS 20 3.5.4 Fields under development on the NCS 22 3.5.5 Decommissioning on the NCS 23 3.6 Development and Production International (DPI) 24 3.6.1 DPI overview 24 3.6.2 International production 25 3.6.2.1 North America 27 3.6.2.2 South America and sub-Saharan Africa 28 3.6.2.3 Middle East and North Africa 29 3.6.2.4 Europe and Asia -
ALLOCATION of COSTS Between PETROLEUM LIQUIDS and GASES
FEATURE ALLOCATION of COSTS between PETROLEUM LIQUIDS and GASES HUMBLE OIL & REFINING CO. E. E. HUNTER HOUSTON, TEX. Downloaded from http://onepetro.org/jpt/article-pdf/6/07/11/2237694/spe-292-g.pdf by guest on 02 October 2021 Introduction increased to a rate of about 7.5 trillion cu ft in 1951 and over 8 trillion in 1952. The increase in demand Petroleum producers have been engaged for many thus indicated has been close to 12 per cent a year years in supplying several different types of materials since 1946, more than twice as great as the rate of from the leases they operate. Some leases produce crude increase in demand for crude oil. oil and casinghead gas, others produce gas-well gas and condensate, and still others produce all four of these This extraordinary growth in the volume and value materials. Therefore, the problem of allocating costs of gas has raised it to a position of importance that com between these intermingled products is not a new one. pels recognition, even by companies interested princi pally in oil production, of its status as a joint product. While in some fields gas has been the dominant prod (For some companies and in some fields gas has for uct, most producers have been interested principally in many years been a primary product.) Good account oil. Consequently, little has been done about the cost allo ing practice and business prudence dictate that oil cation problem by oil producing companies. For account producers now adopt some method of allocating costs ing purposes, these companies have generally con to gas, or actually to all four of the joint products sidered gas a by-product, and whatever realization was involved - crude oil, casinghead gas, gas-well gas, and obtained from it was accounted for as a reduction of condensate. -
Climate and Energy Benchmark in Oil and Gas
Climate and Energy Benchmark in Oil and Gas Total score ACT rating Ranking out of 100 performance, narrative and trend 1 Neste 57.4 / 100 8.1 / 20 B 2 Engie 56.9 / 100 7.9 / 20 B 3 Naturgy Energy 44.8 / 100 6.8 / 20 C 4 Eni 43.6 / 100 7.3 / 20 C 5 bp 42.9 / 100 6.0 / 20 C 6 Total 40.7 / 100 6.1 / 20 C 7 Repsol 38.1 / 100 5.0 / 20 C 8 Equinor 37.9 / 100 4.9 / 20 C 9 Galp Energia 36.4 / 100 4.3 / 20 C 10 Royal Dutch Shell 34.3 / 100 3.4 / 20 C 11 ENEOS Holdings 32.4 / 100 2.6 / 20 C 12 Origin Energy 29.3 / 100 7.3 / 20 D 13 Marathon Petroleum Corporation 24.8 / 100 4.4 / 20 D 14 BHP Group 22.1 / 100 4.3 / 20 D 15 Hellenic Petroleum 20.7 / 100 3.7 / 20 D 15 OMV 20.7 / 100 3.7 / 20 D Total score ACT rating Ranking out of 100 performance, narrative and trend 17 MOL Magyar Olajes Gazipari Nyrt 20.2 / 100 2.5 / 20 D 18 Ampol Limited 18.8 / 100 0.9 / 20 D 19 SK Innovation 18.6 / 100 2.8 / 20 D 19 YPF 18.6 / 100 2.8 / 20 D 21 Compania Espanola de Petroleos SAU (CEPSA) 17.9 / 100 2.5 / 20 D 22 CPC Corporation, Taiwan 17.6 / 100 2.4 / 20 D 23 Ecopetrol 17.4 / 100 2.3 / 20 D 24 Formosa Petrochemical Corp 17.1 / 100 2.2 / 20 D 24 Cosmo Energy Holdings 17.1 / 100 2.2 / 20 D 26 California Resources Corporation 16.9 / 100 2.1 / 20 D 26 Polski Koncern Naftowy Orlen (PKN Orlen) 16.9 / 100 2.1 / 20 D 28 Reliance Industries 16.7 / 100 1.0 / 20 D 29 Bharat Petroleum Corporation 16.0 / 100 1.7 / 20 D 30 Santos 15.7 / 100 1.6 / 20 D 30 Inpex 15.7 / 100 1.6 / 20 D 32 Saras 15.2 / 100 1.4 / 20 D 33 Qatar Petroleum 14.5 / 100 1.1 / 20 D 34 Varo Energy 12.4 / 100 -
Trends in U.S. Oil and Natural Gas Upstream Costs
Trends in U.S. Oil and Natural Gas Upstream Costs March 2016 Independent Statistics & Analysis U.S. Department of Energy www.eia.gov Washington, DC 20585 This report was prepared by the U.S. Energy Information Administration (EIA), the statistical and analytical agency within the U.S. Department of Energy. By law, EIA’s data, analyses, and forecasts are independent of approval by any other officer or employee of the United States Government. The views in this report therefore should not be construed as representing those of the Department of Energy or other federal agencies. U.S. Energy Information Administration | Trends in U.S. Oil and Natural Gas Upstream Costs i March 2016 Contents Summary .................................................................................................................................................. 1 Onshore costs .......................................................................................................................................... 2 Offshore costs .......................................................................................................................................... 5 Approach .................................................................................................................................................. 6 Appendix ‐ IHS Oil and Gas Upstream Cost Study (Commission by EIA) ................................................. 7 I. Introduction……………..………………….……………………….…………………..……………………….. IHS‐3 II. Summary of Results and Conclusions – Onshore Basins/Plays…..………………..…….…