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Net Zero Targets and GHG Emission Reduction in the UK and Norwegian Upstream Oil and Gas Industry: a Comparative Assessment
November 2020 Net Zero Targets and GHG Emission Reduction in the UK and Norwegian Upstream Oil and Gas Industry: A Comparative Assessment OIES PAPER: NG 164 Marshall Hall, Senior Research Fellow, OIES The contents of this paper are the author’s sole responsibility. They do not necessarily represent the views of the Oxford Institute for Energy Studies or any of its members. Copyright © 2020 Oxford Institute for Energy Studies (Registered Charity, No. 286084) This publication may be reproduced in part for educational or non-profit purposes without special permission from the copyright holder, provided acknowledgment of the source is made. No use of this publication may be made for resale or for any other commercial purpose whatsoever without prior permission in writing from the Oxford Institute for Energy Studies. ISBN 978-1-78467-168-6 i Abstract The recent adoption by the UK and Norway of net zero and climate neutrality targets by 2050 has galvanised the upstream oil and gas industry in both countries to adopt GHG emission reduction targets for 2030 and 2050 for the first time. Meeting these targets, ensuring an appropriate sharing of costs between investors and taxpayers and preserving investor confidence will present a lasting challenge to governments and industry, especially in periods of low oil and gas prices. The scale of the challenge on the Norwegian Continental Shelf (NCS) is far greater than on more mature UK Continental Shelf (UKCS) since the remaining resource base is much larger, the expected future production decline is less severe and the emission intensity on the NCS is already much lower (10 kg CO2e/boe) than on the UKCS (28 kgCO2e/boe) due to the long history of tighter emission standards and offshore CO2 taxation. -
Stratigraphy of the Upper Carboniferous Schooner Formation, Southern North Sea: Chemostratigraphy, Mineralogy, Palynology and Sm–Nd Isotope Analysis
Stratigraphy of the Upper Carboniferous Schooner Formation, southern North Sea: chemostratigraphy, mineralogy, palynology and Sm–Nd isotope analysis T. J. Pearce,1 D. McLean,2 D. Wray,3 D. K. Wright,4 C. J. Jeans,5 E. W. Mearns6 1, 4: Chemostrat Ltd, Units 3 & 4, Llanfyllin Enterprise Park, Llanfyllin, Powys, SY22 5DD 2: Palynology Research Facility, Department of Animal and Plant Sciences, Western Bank, Sheffield, S10 2TN 3: Department of Earth Sciences, University of Greenwich, Chatham Maritime, Kent, ME4 4TB 5: Department of Earth Sciences, Cambridge University, Downing Street, Cambridge, CB2 3EQ 6: Isotopic Ltd, Craigiebuckler House, Macaulay Drive, Aberdeen, AB15 8QH Summary The continental, predominantly redbed sequences of the Upper Carboniferous Schooner Formation (“Barren Red Measures”) from the southern North Sea represent a significant gas reservoir, but, as they are largely devoid of microfossils, interwell corre- lations are difficult. The stratigraphy of the formation is re-evaluated by applying a multidisciplinary approach, which includes chemostratigraphy, mineralogy, palynology, Sm–Nd isotopes, petrophysics and sedimentology, to well 44/21-3, as it has encountered a thick, relatively complete section through the Schooner Formation. The formation is divided into three chemo- stratigraphical units (S1, S2 and S3) and eleven sub-units on the basis of variations in the mudstone and sandstone data, these variations being linked to changes in provenance, depositional environment and climate. The chemostratigraphical zonation is compared with the biostratigraphical zonation of the same section – heavy-mineral data confirm the sediment source, and Sm– Nd isotope data provide a provenance age for the well 44/21-3 interval. The correlation potential of the new stratigraphical frame- work is tested on several scales, using data acquired from other southern North Sea wells and from Upper Carboniferous strata of the English Midlands. -
Amarinth's New Export Sales Manager Secures
FOR IMMEDIATE RELEASE – 26 November 2013 Amarinth increases its foothold in the Norwegian oil and gas sector with multiple pump orders from Statoil Amarinth, a leading company specialising in the design, application and manufacture of centrifugal pumps and associated equipment to the Oil & Gas, petrochemical, chemical and industrial markets, has secured three new orders this year from Statoil, the leading operator on the Norwegian continental shelf in the North Sea. Working closely with Axflow, the largest distributor of positive displacement pumps in Europe, Amarinth followed an initial order from Statoil that was successfully completed earlier in the year with a second order to supply pumps for use in the Oseberg oil field on a very tight 24 week delivery. Amarinth then quickly secured a third order from Statoil to supply close coupled motor pumps in 316 stainless steel with API 682 seal support systems for use in the Gullfaks field, this time on a challenging 30 week delivery. Statoil requires its suppliers to follow strict processes and manage their supply chain stringently. This includes compliance with Norsok M650 which establishes a set of qualification requirements to verify that the manufacturer has sufficient competence and experience of the relevant material grades and necessary facilities and equipment to manufacture to the required shapes and sizes with acceptable properties. The foundries used to manufacture the castings also have to be approved by Statoil. – MORE – Amarinth increases its foothold in the Norwegian oil and gas sector Page 2 of 4 Alex Brigginshaw Tel: +44 (0)1394 462131 Phil Harland Tel: +44 (0)118 971 3790 Amarinth has established close working relationships with its own supply chain and had already ensured that all of the foundries used by the company in the UK are approved by Statoil. -
Total E&P Norge AS
ANNUAL REPORT TOTAL E&P NORGE AS E&P NORGE TOTAL TOTAL E&P NORGE AS ANNUAL REPORT 2014 CONTENTS IFC KEY FIGURES 02 ABOUT TOTAL E&P NORGE 05 BETTER TOGETHER IN CHALLENGING TIMES 07 BOARD OF DIRECTORS’ REPORT 15 INCOME STATEMENT 16 BALANCE SHEET 18 CASH FLOW STATEMENT 19 ACCOUNTING POLICIES 20 NOTES 30 AUDITIOR’S REPORT 31 ORGANISATION CHART IBC OUR INTERESTS ON THE NCS TOTAL E&P IS INVOLVED IN EXPLORATION AND PRODUCTION O F OIL AND GAS ON THE NORWEGIAN CONTINENTAL SHELF, AND PRODUCED ON AVERAGE 242 000 BARRELS OF OIL EQUIVALENTS EVERY DAY IN 2014. BETTER TOGETHER IN CHALLENGING TIMES Total E&P Norge holds a strong position in Norway. The Company has been present since 1965 and will mark its 50th anniversary in 2015. TOTAL E&P NORGE AS ANNUAL REPORT TOTAL REVENUES MILLION NOK 42 624 OPERATING PROFIT MILLION NOK 22 323 PRODUCTION (NET AVERAGE DAILY PRODUCTION) THOUSAND BOE 242 RESERVES OF OIL AND GAS (PROVED DEVELOPED AND UNDEVELOPED RESERVES AT 31.12) MILLION BOE 958 EMPLOYEES (AVERAGE NUMBER DURING 2013) 424 KEY FIGURES MILLION NOK 2014 2013 2012 INCOME STATEMENT Total revenues 42 624 45 007 51 109 Operating profit 22 323 24 017 33 196 Financial income/(expenses) – net (364) (350) (358) Net income before taxes 21 959 23 667 32 838 Taxes on income 14 529 16 889 23 417 Net income 7 431 6 778 9 421 Cash flow from operations 17 038 15 894 17 093 BALANCE SHEET Intangible assets 2 326 2 548 2 813 Investments, property, plant and equipment 76 002 67 105 57 126 Current assets 7 814 10 506 10 027 Total equity 15 032 13 782 6 848 Long-term provisions -
RKU Nordsjøen – Konsekvenser Av Regulære Utslipp Til Sjø
Lars Petter Myhre, Gunnar Henriksen, Grethe Kjeilen-Eilertsen, Arnfinn Skadsheim, Øyvind F Tvedten. RKU Nordsjøen – Konsekvenser av regulære utslipp til sjø Rapport IRIS – 2006/113 www.irisresearch.no © Kopiering er kun tillatt etter avtale med IRIS eller oppdragsgiver. International Research Institute of Stavanger (IRIS) er sertifisert etter et kvalitetssystem basert på standard NS - EN ISO 9001 International Research Institute of Stavanger AS. www.irisresearch.no Lars Petter Myhre, Gunnar Henriksen, Grethe Kjeilen-Eilertsen, Arnfinn Skadsheim, Øyvind F Tvedten. RKU Nordsjøen – Konsekvenser av regulære utslipp til sjø Rapport IRIS – 2006/113 Prosjektnummer: 7151743 Kvalitetssikrer: Jan Fredrik Børseth Oppdragsgiver: OLF/Statoil ISBN: 82-490-0450-7 www.irisresearch.no © Kopiering er kun tillatt etter avtale med IRIS eller oppdragsgiver. International Research Institute of Stavanger (IRIS) er sertifisert etter et kvalitetssystem basert på standard NS - EN ISO 9001 IRIS – International Research Institute of Stavanger. http://www.irisresearch.no Forord Denne rapporten inngår som en del av “Regional konsekvensutredning for petroleumsvirksomheten i Nordsjøen” (RKU-Nordsjøen). RKU-Nordsjøen består av en rekke temarapporter som dokumenterer konsekvensene av den samlede nåværende og framtidige petroleumsaktiviteten på norsk sokkel sør for 62. breddegrad. Hensikten med regionale konsekvensutredninger er primært å gi en bedre oversikt over konsekvensene av petroleumsaktiviteten på sokkelen enn det enkeltstående feltvise konsekvensutredninger gir. -
Paper No Paper Title Author Details Company Page 1
1997 Paper Paper Title Author Details Company Page No Comparing Performance of 1 Multiphase Meters (How to See the C J M Wolff Shell International E&P 3 Wood from the Trees) The Porsgrunn 2 Test Programme of Multiphase Meters – General S A Kjølberg Norsk Hydro 2 Results, Errors vs. Operating 18 H Berentsen Statoil Conditions and New Ways of Error Presentation Topside and Subsea Experience B H Torkildsen, P B Hlemers 3 with the Framo Multiphase Flow Framo Engineering AS 31 and S Kanstaf Meter Åsgard and Gullfaks Satellite Field H Berentsen and S Klemp Statoil 4 Developments – Efficient 50 B L Pedersen Multi-Fluid Integration of Multiphase Meters X-ray Visualisation and Dissolved Gas Quantification: Multiphase A R W Hall and 5 NEL 57 Flow Research and Development at A E Corlett NEL G A Johansen, Measurement Strategies for 6 E A Hammer, E Åbro and University of Bergen 70 Downhole Multiphase Metering J Tollefsen The New DTI Petroleum 7 D Griffin and L Philp DTI 81 Measurement Guidelines The Norwegian Regulations 8 Relating to Fiscal Measurements of O Selvikvåg NPD 141 Oil and Gas – 1997 Update Flow Metering Concepts. An 9 L Brunborg and D Dales Kvaerner Oil & Gas as 152 Engineering Contractors Experience Software Testability in Fiscal Oil and Gas Flowmetering Based on 10 K S P Mylvaganam Bergen College 161 Volume, Density, Temperature and Pressure Measurements Recent Developments in the 11 Uncertainty Analysis of Flow J G V van der Grinten Nederlands Meetinstituut 189 Measurement Processes A Practical Example of Uncertainty 12 Calculations for a Metering Station Ø Midtveie and J Nilsson Christian Michelsen Research AS 202 – Conventional and New Methods European Calibration Intercomparison on Flow Meters – Swedish National Testing and 13 P Lau 221 How Accurate Can One Expect to Research Institute Measure Flow Rates? Experience with Ultrasonic Flow G J de Noble and 14 Meter at the Gasunie Export N.V. -
Fields in Production
12 Fields in production Southern North Sea sector Ekofisk area (Ekofisk, Eldfisk, Embla and Tor) . 71 Glitne . 74 Gungne . 75 Gyda (incl Gyda South) . 76 Hod . 77 Sigyn . 78 Sleipner West . 79 Sleipner East . 80 Tambar . 81 Ula . 82 Valhall ( incl Valhall flanks and Valhall water injection) . 83 Varg . 84 Northern North Sea sector Balder (incl Ringhorne) . 86 Brage . 87 Frigg . 88 Gullfaks (incl Gullfaks Vest) . 90 Gullfaks South (incl Rimfaks and Gullveig) . 92 Heimdal . 94 Huldra . 95 Jotun . 96 Murchison . 97 Oseberg (Oseberg, Oseberg West, Oseberg East, Oseberg South) . 98 Snorre (incl Snorre B) . 101 Statfjord . 103 Statfjord North . 105 Statfjord East . 106 Sygna . 107 Tordis (incl Tordis East and Borg) . 108 Troll phase I . 110 Troll phase II . 112 Tune . 114 Vale . 115 Veslefrikk . 116 Vigdis . 117 Visund . 118 Norwegian Sea Draugen . 120 Heidrun . 121 Njord . 122 Norne . 123 Åsgard . 124 Fields which have ceased production . 126 12 Explanation of the tables in chapters 12–14 Interests in fields do not necessarily correspond with interests in the individual production licences (unitised fields or ones for which the sliding scale has been exercised have a different composition of interests than the production licence). Because interests are shown up to two deci- mal places, licensee holdings in a field may add up to less than 100 per cent. Interests are shown at 1 January 2003. Recoverable reserves originally present refers to reserves in resource categories 0, 1, 2 and 3 in the NPD’s classification system (see the definitions below). Recoverable reserves remaining refers to reserves in resource categories 1, 2 and 3 in the NPD’s classification system (see the definitions below). -
Natural Radioactivity in Produced Water from the Norwegian Oil and Gas Industry in 2003
Strålevern Rapport 2005:2 Natural Radioactivity in Produced Water from the Norwegian Oil and Gas Industry in 2003 Norwegian Radiation Protection Authority Postboks 55 N-1332 Østerås Norway Reference: NRPA (2004). Natural Radioactivity in Produced Water from the Norwegian Oil and Gas Industry in 2003. StrålevernRapport 2005:2. Østerås: Norwegian Radiation Protection Authority, 2004. Authors: Gäfvert T, Færevik I Key words: Radioactivity, Produced Water, Radium, 226Ra, 228Ra, 210Pb, Oil and gas industry, The North Sea Abstract: This report presents results of a survey of natural radioactivity (226Ra, 228Ra and 210Pb) in produced water from all 41 Norwegian platforms in the North Sea discharging produced water. The sampling campaign took place from September 2003 to January 2004. Based on the data presented the average activity concentrations of 226Ra and 228Ra in produced water from the Norwegian oil and gas industry have been estimated to 3.3 Bq l-1 and 2.8 Bq l-1, respectively. With one exception, all results obtained for 210Pb were below the detection limit of about 1 Bq l-1.The estimated total activities of 226Ra and 228Ra discharged in 2003 are 440 GBq (range 310-590 GBq) and 380 GBq (range 270-490 GBq), respectively. Referanse: Statens strålevern (2004). Naturlig radioaktivitet i produsertvann fra den norske olje- og gassindustrien i 2003. StrålevernRapport 2005:2. Østerås: Statens strålevern, 2004. Språk: engelsk. Forfattere: Gäfvert T, Færevik I Emneord: Radioaktivitet, Produsertvann, Radium, 226Ra, 228Ra, 210Pb, Nordsjøen Resymé: Rapporten viser resultater fra en undersøkelse av naturlig radioaktivitet (226Ra, 228Ra and 210Pb) i produsert vann fra samtlige 41 norske plattformer i Nordsjøen med slike utslipp. -
Structural Framework of the Statfjord Formation (Rhaetian-Sinemurian) in the Oseberg South Field, Norwegian North Sea
Structural Framework of the Statfjord Formation (Rhaetian-Sinemurian) in the Oseberg South Field, Norwegian North Sea Jeffrey John Catterall Petroleum Geosciences Submission date: May 2012 Supervisor: Stephen John Lippard, IGB Norwegian University of Science and Technology Department of Geology and Mineral Resources Engineering Acknowledgements First and foremost, I would like to thank Statoil ASA for the opportunity to work on this project, and for providing me with a place to sit in the Bergen office while writing the thesis. In addition, I would like to thank both of my supervisors Hugo Sese at Statoil and Stephen Lippard at NTNU for their support and feedback throughout the project, and also to Jim Daniels who helped turn this project into one suitable for a Master’s thesis. I have received support from many individuals from the Oseberg South Petroleum Technology Group. Their constant feedback, mentorship, and support during the many aspects of this project have been greatly appreciated. Lastly, thank you to all of my friends and fellow classmates that have made my two years at NTNU such a wonderful experience. Jeffrey John Catterall June 2012 ii Abstract The Statfjord Formation (Rhaetian-Sinemurian) produces from six fields across the North Sea, but no discoveries have yet been made in the 12 exploration wells across the Oseberg South Field. The field has undergone two major periods of rifting in the Permian-Triassic and from the mid-Jurassic to Early Cretaceous. The Statfjord Formation was deposited during the Permian-Triassic post-rift period, but its tectonic influence on the paleogeography of the formation is not well understood. -
E&P Transactions on The
February 2020 E&P transactions on the NCS The year in review: 2019 Deals The energy transition is shaping the M&A landscape on the NCS How to maneuver in the energy transition is core to Following a number of years where companies looking to E&P players acquisition and divestment behaviour. divest E&P all-together have been the strongest driver for Fundamentally, we see three approaches to the corporate transactions, 2019 turned out to be a relatively opportunities and threats associated with reducing the quiet year for E&P transactions, in particular corporate carbon footprint of the production of energy: deals. Nonetheless, we saw a number of companies, with private equity fuelled entities in particular leading 1. “Stick to your guns”. O&G companies that strongly the way, acquiring packages of assets. Indeed, Vår believe oil and gas will be needed to fuel global Energi’s acquisition of Exxon’s Norwegian portfolio was requirements for energy for a long time. one of the largest ever E&P deals by value in Norway. Companies will maintain that their core Similar to Vår Energi where HitecVision is the main competencies are within upstream, and that E&P minority shareholder, another HitecVision portfolio will continue to be an attractive and profitable company, Sval Energi (formerly known as Solveig Gas) business for the foreseeable future.These was an active dealmaker involved in all together three companies tend to be acquisitive and are looking acquisitions and one divestment across pipeline and to grow their production on the NCS. terminal infrastructure and E&P assets. -
D3.3.3 Re-Use of Infrastructure Norway
ACT ALIGN CCUS Project No 271501 This project has received funding from RVO (NL), FZJ/PtJ (DE), Gassnova (NO), UEFISCDI (RO), BEIS (UK) and is cofunded by the European Commission under the Horizon 2020 programme ACT, Grant Agreement No 691712 Accelerating Low carboN Industrial Growth through CCUS Deliverable D3.3.3 Re-use of infrastructure Norway Dissemination level Public Written By Alv-Arne Grimstad (SINTEF) and Cathrine Ringstad 14.05.2019 (SINTEF) Checked by WP3 Leader Maxine C. Akhurst (BGS) 17.07.2019 Approved by the coordinator Peter van Os (TNO) 17.07.2019 Issue date 17.07.2019 Document No. ALIGN-CCUS D3.3.3 Re-use of Infrastructure, Norway Issue date 17.07.2019 Dissemination Level Public Page 2/36 Executive summary The North Sea is a mature petroleum province and hosts an extensive network of infrastructure that will become increasingly available for re-use for CO2 transport and storage as oil and gas production declines. Once available, existing oil and gas infrastructure may be adapted to support the deployment of CO2 transport and storage networks. Re-use of infrastructure can help to reduce the cost of CO2 capture, transport and storage projects, which is critical to ensuring widespread commercialisation of these technologies to meet European and national targets for decarbonisation. Re-use of some of the existing infrastructure is technically feasible and can be cost effective. There are, however, both technical and legal challenges with re-use of existing infrastructure, and neither its suitability, nor availability can be presumed. Previously published criteria for evaluation of re-use of offshore oil and gas infrastructure in a CO2 transport and storage infrastructure has been applied to infrastructure in the northern part of the Norwegian North Sea. -
Total E&P Norge AS
TOTAL E&P NORGE AS ANNUAL REPORT 20 16 CONTENTS 04 KEY FIGURES 05 BOARD OF DIRECTORS’ REPORT 12 INCOME STATEMENT 13 CASH FLOW STATEMENT 14 BALANCE SHEET 16 ACCOUNTING POLICIES 17 NOTES 27 AUDITORS' REPORT 29 OUR INTERESTS ON THE NCS 30 MANAGEMENT STRUCTURE 2 2016 TOTAL REVENUES MILLION NOK 24 762 OPERATING PROFIT MILLION NOK 4 164 PRODUCTION (NET AVERAGE DAILY PRODUCTION) THOUSAND BOE 235 RESERVES OF OIL AND GAS (PROVED DEVELOPED AND UNDEVELOPED RESERVES AT 31.12) MILLION BOE 816 EMPLOYEES (AVERAGE NUMBER) 438 3 ANNUAL REPORT 2016 | TOTAL E&P NORGE AS | KEY FIGURES KEY FIGURES MILLION NOK 2016 2015 2014 INCOME STATEMENT Total revenues 24 762 30 423 42 624 Operating profit 4 164 10 864 22 323 Financial income / (expenses) - net (204) (1 020) (364) Net income before taxes 3 960 9 844 21 959 Taxes on income 1 663 6 014 14 529 Net income 2 297 3 830 7 431 Cash flow from operations 13 351 15 644 17 038 BALANCE SHEET Intangible assets 1 763 2 090 2 326 Investments, property, plant and equipment 85 103 84 056 76 002 Current assets 9 385 7 106 7 814 Total equity 17 154 18 880 15 032 Long-term provisions 37 922 36 139 31 884 Long-term liabilities 32 856 33 504 26 774 Current liabilities 8 319 4 730 12 452 OTHER KEY FIGURES Acquisition of property, plant and equipment IN (MNOK) 13 583 15 476 16 902 Exploration activity, costs and investments IN (MNOK) 1 512 1 270 1 237 Rate of return on capital employed *) 4,8 % 8,8 % 20,1 % Production cost USD/BBL 5,5 6,9 9,2 Transport cost USD/BBL 3,6 3,6 5,3 PRODUCTION IN THOUSAND BOE Net average daily production 235 239 242 RESERVES OF OIL AND GAS IN MILLION BOE Proved developed and undeveloped reserves at 31.12 816 869 958 EMPLOYEES Average number of employees 438 447 424 *) Net income plus financial expense after tax as a percentage of capital employed at 1 January.