Annual Report & 20-F 2012
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Prices and Crisis – LNG and Australia's East Coast Gas Market
March 2018 Prices and crisis: LNG and Australia’s East Coast gas market Introduction In 2017, a gas crisis emerged in Australia’s East Coast gas market. Gas prices had increased rapidly from mid-2016 as the full effect of the three LNG projects starting operations on Curtis Island worked through the gas market, putting domestic energy users under pressure. In March 2017, the Australian Energy Market Operator (AEMO) forecast gas shortages in coming years, potentially leading to blackouts and industrial closures. While gas shortages are no longer forecast, challenges in the East Coast gas market remain. This paper examines recent events in Australia’s East Coast gas market, the challenges ahead, and the relevance of these developments for other countries.1 The paper identifies three phases in the East Coast gas market’s recent history. Firstly, between 2010 and mid-2016, prices in the East Coast gas market rose gradually, driven by LNG netbacks and the rising cost of gas production. Then, between mid-2016 and mid-2017, prices climbed above export parity levels, as gas that was previously being supplied to domestic consumers (both by LNG projects and by other producers) was diverted for export, leading to a deterioration in competition in the domestic market. Finally, as of mid-2017, prices appear to have stabilised around export parity levels,2 with LNG projects and other producers increasing gas sales to the domestic market. The episode of high prices during much of 2016 and 2017 highlights the impact that LNG projects can have on domestic gas prices on Australia’s East Coast. -
Changing LNG Market Dynamics – Implications on Supply Security in the APEC Region
Changing LNG Market Dynamics – Implications on Supply Security in the APEC Region APEC Oil and Gas Security Studies | Series 17 APEC Energy Working Group September 2020 APEC Project: EWG 01 2020S Produced by Asia Pacific Energy Research Centre (APERC) Institute of Energy Economics, Japan Inui Building, Kachidoki 11F, 1-13-1 Kachidoki Chuo-ku, Tokyo 104-0054 Japan Tel: (813) 5144-8551 Fax: (813) 5144-8555 E-mail: [email protected] (administration) Website: http://aperc.or.jp/ For Asia-Pacific Economic Cooperation Secretariat 35 Heng Mui Keng Terrace Singapore 119616 Tel: (65) 68919 600 Fax: (65) 68919 690 Email: [email protected] Website: www.apec.org © 2020 APEC Secretariat APEC#220-RE-01.9 ISBN: 978-981-14-7794-2 OGSS Series 17 Changing LNG Market Dynamics – Implications on Supply Security in the APEC Region 3 | P a g e TABLE OF CONTENTS Table of Contents .......................................................................................................................... 3 Foreword ....................................................................................................................................... 6 Acknowledgements ....................................................................................................................... 7 Project coordinators .................................................................................................................. 7 Authors ...................................................................................................................................... 7 Editors -
The Oman Liquefied Natural Gas Project L' Usine De
THE OMAN LIQUEFIED NATURAL GAS PROJECT L’ USINE DE LIQUEFACTION DE GAZ NATUREL D’ OMAN G.Searle General Manager and CEO M.J.J.Koekkoek Operations Manager Oman LNG, Qalhat Sultanate of Oman ABSTRACT Oman Liquefied Natural Gas L.L.C. (OLNG) is a limited liability incorporated joint venture Company organised, since 1994, under the Laws of the Sultanate of Oman. It engages in the business of producing and selling Liquefied Natural Gas (LNG) and by- product Natural Gas Liquids (NGL’s). The plant liquefies Natural gas using two identical process trains, with currently the single largest LNG production capacity of 3.3. mtpa in the world. Since the start in April 2000 the plant is now delivering LNG to Korea and Japan on a regular basis as well as spot cargoes to USA and Spain. The LNG plant has been successfully commissioned well within budget and on time due to the good collaboration between OLNG and its Contractors. Technically the plant is characterized by a very low specific capital cost, compared to other recent LNG projects. The paper describes the experience during engineering, construction and initial operation of the project characteristics that are new in the LNG industry and gives an overview of the key lessons learned. RESUME La societe Oman LNG LLC (OLNG) est une entreprise en coparticipation etablie en 1994 sous le regime du Sultanat d'Oman. Son activite premiere est la production et la commercialisation de Gaz Naturel Liquefie (GNL) et d'essence legere. L’ usine de GNL, comporte deux modules de liquefaction, chacun d’une capacite de 3,3 millions de tonnes par an qui sont actuellement les plus grands au monde de ce type. -
Integrated Gas
UPSTREAM 17 SHELL INVESTORS’ HANDBOOK 2013 INTEGRATED GAS Strong growth in gas markets is a major opportunity The Repsol LNG portfolio acquisition in late 2013 LNG LEADERSHIP [A] for Shell. Our integrated gas earnings have is another growth leg for integrated gas, with new increased by around 400% since 2009 to some equity supply in South America, and new year-end mtpa $9 billion in 2013 or about 60% of Upstream trading opportunities. earnings. This was mainly driven by several large 40 liquefied natural gas (LNG) and gas-to-liquids (GTL) LNG projects that came on-stream, including Pearl GTL, Shell is a pioneer of the LNG industry with expertise Pluto LNG Train 1 (Woodside), North Rankin based on 50 years of experience. Shell was 30 Redevelopment, Qatargas 4 and Sakhalin-2. instrumental in delivery of the world’s first LNG Integrated gas earnings incorporate LNG, including plant, in Algeria, which came on-stream in 1964. LNG marketing and trading, and GTL operations. In the years since, LNG has become a truly global 20 In addition, the associated upstream oil and gas commodity with demand expected to grow rapidly production activities from the Sakhalin-2, North in the coming years. Currently around 240 mpta, West Shelf, Pluto LNG Train 1 (Woodside), the global LNG market is expected to reach about 10 Qatargas 4 and Pearl GTL projects are included 430 mtpa by 2025. This growth will be driven by in integrated gas earnings. Power generation expanding economies in China, India and the and coal gasification activities are also part Middle East, by demand in Europe and by new 0 of integrated gas. -
2005-2009 Financial and Operational Information
FIVE-YEAR FACT BOOK Royal Dutch Shell plc FINaNcIAL aND OPERATIoNAL INFoRMATIoN 2005–2009 ABBREVIATIONS WE help meet ThE world’S growing demand for energy in Currencies € euro economically, environmentally £ pound sterling and socially responsible wayS. $ US dollar Units of measurement acre approximately 0.4 hectares or 4 square kilometres About This report b(/d) barrels (per day) bcf/d billion cubic feet per day This five-year fact book enables the reader to see our boe(/d) barrel of oil equivalent (per day); natural gas has financial and operational performance over varying been converted to oil equivalent using a factor of timescales – from 2005 to 2009, with every year in 5,800 scf per barrel between. Wherever possible, the facts and figures have dwt deadweight tonnes kboe/d thousand barrels of oil equivalent per day been made comparable. The information in this publication km kilometres is best understood in combination with the narrative km2 square kilometres contained in our Annual Report and Form 20-F 2009. m metres MM million Information from this and our other reports is available for MMBtu million British thermal unit online reading and downloading at: mtpa million tonnes per annum www.shell.com/annualreports mscm million standard cubic metres MW megawatts The webpages contain interactive chart generators, per day volumes are converted to a daily basis using a downloadable tables in Excel format, hyperlinks to other calendar year webpages and an enhanced search tool. Sections of the scf standard cubic feet reports can also be downloaded separately or combined tcf trillion cubic feet into a custom-made PDF file. -
2005 Annual Report on Form 20-F
United States Securities and Exchange Commission Washington, D.C. 20549 FORM 20-F Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the fiscal year ended December 31, 2005 Commission file number 1-32575 Royal Dutch Shell plc (Exact name of registrant as specified in its charter) England and Wales (Jurisdiction of incorporation or organisation) Carel van Bylandtlaan 30, 2596 HR, The Hague, The Netherlands tel. no: (011 31 70) 377 9111 (Address of principal executive offices) Securities Registered Pursuant to Section 12(b) of the Act Title of Each Class Name of Each Exchange on Which Registered American Depositary Receipts representing Class A ordinary shares of the New York Stock Exchange issuer of an aggregate nominal value €0.07 each American Depositary Receipts representing Class B ordinary shares of the New York Stock Exchange issuer of an aggregate nominal value of €0.07 each Securities Registered Pursuant to Section 12(g) of the Act None Securities For Which There is a Reporting Obligation Pursuant to Section 15(d) of the Act None Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the annual report. Outstanding as of December 31, 2005: 3,817,240,213 Class A ordinary shares of the nominal value of €0.07 each. 2,707,858,347 Class B ordinary shares of the nominal value of €0.07 each. Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. -
Embracing the Benefits of Digitalisation in Lng Projects
EMBRACING THE BENEFITS OF DIGITALISATION IN LNG PROJECTS Janani Mittal, Paul Bosma, Emile de Jong, Ron van Wolferen, Sjarel van de Lisdonk Copyright: Shell Global Solutions International B.V., April 2019 Global energy demand is surging. Gas is likely to make up a significant proportion of the world’s energy supply for decades to come, but the LNG industry is facing a number of significant challenges. New LNG projects are located in harsh or remote locations, which make them more challenging and expensive to develop and operate. LNG projects have to become more cost competitive in the future while enabling the energy transition. Additionally, companies are facing the prospect of staff shortages with experts retiring from the industry and new generations preferring to live in the cities. Traditional project, engineering and operations in the LNG value chain may not be adequate to cut enough costs and reach the required levels of performance. The (r) evolution in the world of digital technology provides an opportunity to make the necessary step changes. This paper reviews areas where Shell is introducing new technologies that are expected to make a substantial contribution to the development of new LNG projects and the success of future operations – digitalisation, robotics, sensing and process control. Recent advances will enable the industry to further digitalise project planning and development tools reducing capital costs and schedule. New robotics and sensing minimises risks to personnel in harsh, frontier locations, enhance and accelerate decision making to minimise deferment and reduce facility turnaround times, achieve and maintain performance excellence in process operations. They will help to increase productivity and efficiency and boost asset integrity. -
The Corrib Gas Tunnel >>>
The Corrib Gas Tunnel >>> Contents > The Corrib Tunnel > The Aughoose and Glengad sites > BAM Civil/Wayss & Freytag Joint Venture > A brief history of tunnelling > ‘Fionnuala’ – the Corrib TBM > Tunnelling traditions > How does the TBM work? > The TBM operator > Maintaining the tunnel > Installation of the pipeline & reinstatement 1 The Corrib Tunnel The onshore pipeline is the final phase of the Corrib gas project to be completed. The onshore pipeline section is 8.3km long and 4.9km of this will be installed in a tunnel, 5.5m the majority of which will run under Sruwaddacon Bay, in north Mayo. The tunnel will have an external diameter of 4.2m and an internal 12m diameter of 3.5m and will run at depths of between 5.5m and 12m under Sruwaddacon Bay. The building of the tunnel requires 4.2m 3.5m the use of a large tunnel boring machine (TBM). “This will be the longest tunnel in Ireland and 2 the longest gas pipeline 3 tunnel in Europe” “The rock, sand and gravel from the TBM is pumped back through the tunnel to Aughoose” “The compound has been surrounded by a visual barrier and an acoustic fence” The Aughoose and Glengad sites Excavation of the tunnel is in one direction, starting at a launch shaft The compound at Aughoose contains all of the services and Aughoose compound was designed and constructed to limit its site water treatment plant where the water discharges into on a SEPIL-owned site in the townland of Aughoose and running to a materials needed for the tunnelling process. -
The Corrib Debacle
1. THE CORRIB DEBACLE – WHY IRELAND IS COMPLETELY OFF LIMITS FOR INVESTMENT 1.1 The background to the debacle Natural gas generates over 60% of the electricity in Ireland and fuels homes and industry. While the Kinsale Field was discovered and developed in the early seventies, gas from the European network is currently pumped into the reservoir there over the summer and drawn out over the winter months. Very little is drawn any more from the field itself. Indeed a single gas pipeline from the European grid goes to a compressor station in South Western Scotland and then is routed under the Irish Sea to North of Dublin. The country is hanging off that pipe! Ireland has not had a good innings with petroleum exploration. About 150 exploration wells have been drilled in the Irish Sector, outside of Kinsale Field we had to wait until 1996 until Enterprise Energy Ireland finally hit pay dirt with the Corrib Natural Gas Field. Note: Shell Exploration and Production Ireland Ltd (SEPIL) acquired Enterprise Energy Ireland in 2002. A pretty poor run from exploration in Irish waters, in particular given that a drilling rig costs about €0.6 million per day and the success ratio in the North Sea sector is about one producing field for every four exploration wells drilled. 1 Bit of a difference in petroleum finds in North Sea and Irish waters. However, many Irish are insistent that the same exploration terms should apply in both jurisdictions. The Corrib field is marginal by international standards; the well head is 80 km off the exposed North Western Coast and at a depth of 300 m. -
Kyma Shaft Power Meter
Kyma Shaft Power Meter Reference list May 2021 Kyma a.s Tel: +47 55 53 00 14 Aasamyrane 88B Fax: +47 55 53 00 17 N-5116 Ulset (Bergen) E-mail: [email protected] NORWAY Web: www.kyma.no Page 2 Advantage Verdict Vessel name Yard/hull Type Delivery Product Power Daewoo H5492 2021 KPM-P 24510 kW Daewoo H5493 2021 KPM-P Daewoo H5494 2021 KPM-P Daewoo H5495 2022 KPM-P Aegean Shipping Vessel name Yard/hull Type Delivery Product Power COSCO Yangzhou N984 Crude Oil 2021 KPM-P 11350 kW COSCO Yangzhou N985 Crude Oil 2022 KPM-P COSCO Yangzhou N986 2022 KPM-P COSCO Yangzhou N987 2022 KPM-P AET Vessel name Yard/hull Type Delivery Product Power Daewoo H5499 2022 KPM-P Daewoo H5500 2022 KPM-P Daewoo H5506 2022 KPM-P Al Kharsaah Inc Vessel name Yard/hull Type Delivery Product Power Al Kharsaah Samsung 1644 LNG Carrier 2006 KSP Al Shamal Inc Vessel name Yard/hull Type Delivery Product Power Al Shamal Samsung 1645 LNG Carrier 2007 KSP Alaska Transport Vessel name Yard/hull Type Delivery Product Power Polar Alaska 1983 TTM 20000 PS Arctic Tokyo 1983 TTM 20000 PS Alberta Shipping Vessel name Yard/hull Type Delivery Product Power Sumitomo S1407 KPM-P 11110 kW Albro Navigation Co Inc Vessel name Yard/hull Type Delivery Product Power Fiora Topic Namura S401 Bulk Carrier 2015 KSP 5720 kW Alcyon shipping Vessel name Yard/hull Type Delivery Product Power Bluemoon IHI 3137 Bulk Carrier 2001 KPM-P 21798 PS Aleutian Spray Fisheries Inc Vessel name Yard/hull Type Delivery Product Power Starbound Dakota Creek 22 Factory Stern 2016 KPM-P 3677 kW Algoma Central Corp Vessel -
WHO's WHO Shell Brian Foley, Contracts Manager, Corrib Project
OSSL SHELL CORRIB SAGA - WHO'S WHO Shell Brian Foley, Contracts Manager, Corrib Project: [email protected] Julia Busby, Head of Shell Legal: [email protected] Frances van Dam, from Shell's business integrity department: [email protected] Charles Hornsby, Ethics and Compliance Officer at Shell Downstream [email protected] Bridgit Lowe, head of Shell Legal, Ireland [email protected] John Gallagher: [email protected] (Exec VP Shell Global Upstream) Alan Mee: Assistance Mayo Manager: [email protected] Ann Hamilton, Shell Corrib Financial Director: [email protected] Wim-Peter Vanbel, [email protected] (regional head Business Integrity Dept Europe & Russia Christy Loftus, Shell Ireland Communications: Christy Loftus [email protected] Michiel Brandjes, Company Sec. & General Counsel: [email protected] Agnes Mclaverty, Permits and Consents Manager for Shell E&P Ireland Limited: [email protected] Mary Barrett, Emergency Response Co-Ordinator Shell [email protected] Peter Voser, RDS PIc CEO: [email protected] Conner Byrne, Shell EP Ireland" (said to have demanded that invoices be falsified and diverted to Roadbridge to avoid any direct connection with Shell - also said to have threatened that OSSL would never work again in oil and gas industry if it revealed any of the activity) Terry Nolan, former CEO, Shell E&P Ireland Michael Crothers, CEO Shell E&P Ireland: [email protected] (said to have "personally felt some moral obligation ..." ) Roadbridge (Main Contractor on Corrib Project?) OSSL people Desmond Kane: [email protected] Amanda Kane Neil Rooney: [email protected] OSSL Supporter/agent/employee? - GEORGE HAMILTON George Hamilton: georgehamiltoneollve.ie Sent email in support of OSSL to Shell to Sea, also made several postings on our "Shell Blog", all supportive of OSSL. -
E Corrib Gas Project: the Deposition of 450,000 Tonnes of Peat
PEAT IN ENERGY e Corrib gas project: the deposition of 450,000 tonnes of peat B. Moyles Bord na Móna Energy Ltd, Leabeg, Tullamore, Co. Offaly, Ireland Phone: +353-87-9612077, e-mail: [email protected] Summary As part of Shell’s Corrib gas project to construct an onshore gas terminal at Bellanaboy, North-west Mayo, Ireland it was necessary to remove approximately 450,000 m³ of peat from the terminal footprint. The excavation works were carried out by a civil engineering contractor (Roadbridge Ltd.) and this excavated peat was then transported by a road haulier (Iggy Madden Transport Ltd.) a distance of 11km by road to a specially constructed deposition site owned and operated by Bord na Móna. This peat deposition site, where the removed peat was received, re-loaded for internal site haulage and finally placed, is located on industrial cutaway peatlands in Srahmore, near Bangor-Erris in Co. Mayo, Ireland. The peat deposition process was included as part of the planning application for Shell E&P Ireland Ltd (SEPIL) to construct a gas terminal for the reception and separation of gas from the Corrib gas field. The deposition was governed by numerous planning conditions, also separate conditions imposed as part of the waste licence as issued by the EPA. The peat was received at Srahmore and spread over low areas (bays) to depths of on average 1.4m - 1.8m. The deposited peat was then profiled allowing for water run off. Following deposition activities and the im - plementation of the agreed monitoring programme vegetation was allowed to establish naturally, primarily soft rush ( Juncus effusus ) as well as other native peatland species.