DOCSLIB.ORG

Production Development on the Norwegian Continental Shelf 2 Table of Contents Summary and Conclusions

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
Production Development on the Norwegian Continental Shelf 2 Table of Contents Summary and Conclusions KonKraft report 2 Production development on the Norwegian continental shelf 2 Table of Contents Summary and conclusions . 5 1 . Introduction . 11 1.1 Background and mandate.............................................. 11 1.2 Context............................................................ 12 1.3 Methodology . 13 1.4 Content of the report . 14 2 . History of and business environment for production on the NCS . 15 2.1 Chapter summary.................................................... 15 2.2 The NCS is a maturing hydrocarbon province.............................. 15 2.3 Exploration on the NCS . 18 2.4 Level of activity increasing despite rising costs . 21 2.5 A number of key differences exist between the UK and Norwegian business environments . 23 3. Improving oil and gas recovery from existing fields . 24 3.1 Chapter summary.................................................... 24 3.2 The average ultimate recovery factor on the NCS is high ..................... 25 3.3 Contingent resources in existing fields are still considerable, but reserves and contingent resources are declining rapidly . 26 3.3.1 Ensuring that activity and investment levels remain high in maturing fields will be challenging .................................................... 27 3.3.2 Maintaining the track record for applying new technology will be challenging 29 3.3.3 A debate exists on the contribution of EOR to growing reserves in existing fields 30 3.3.4 IO can contribute significantly to increasing production and reserves ........ 32 3.4 Recommendations ................................................... 35 4 . Continuing to encourage exploration activity in currently accessible areas . 39 4.1 Chapter summary . 39 4.2 A significant undiscovered resource potential remains in currently accessible areas 40 4.3 The authorities have taken steps to boost exploration activity ................. 41 4.3.1 Action by the authorities .......................................... 41 4.3.2 Impact of action by he authorities to date .............................. 42 4.4 It is too early to say that high exploration activity is sustainable and will translate into significant production and investment ....................................... 43 4.5 Recommendations ................................................... 45 5. Building a “small field” development mindset . 46 5.1 Chapter summary . 46 5.2 Most future discoveries are expected to be small ........................... 47 5.3 E&P companies in Norway have historically tended not to explore for and develop small discoveries . 48 5.4 An opportunity still exists to add to yet-to-be-found resources by making development of small discoveries more attractive ........................................ 51 5.4.1 Some early signs of success have been seen, but progress is far from secure . 52 5.4.2 Exploring for and developing small prospects which depend on existing infrastructure is a matter of urgency, especially in the North Sea . 53 3 5.4.3 The potential price for reducing the minimum volume required for economic development . 53 5.5 Recommendations . 56 6 . Opening new areas . 58 6.1 Chapter summary.................................................... 58 6.2 Production and investment levels are predicted to decline in existing areas....... 59 6.3 Opening new areas can have a significant impact on long-term production and investment levels . 59 6.4 Why a decision in 2010 to open new areas is urgent......................... 61 6.5 Maintaining a robust petroleum industry.................................. 62 6.6 Recommendations . 63 7 . Industry is adapting to the sharp rise in activity . 66 7.1 Chapter summary.................................................... 66 7.2 Coping with change .................................................. 66 7.2.1 Declining performance for well delivery .............................. 66 7.2.2 Shortage of qualified mobile drilling rigs . 68 7.2.3 Production-related activities on some older platforms have been delayed by growing maintenance requirements . 71 7.3 The impact of the transitional period . 71 7.3.1 The impact of the high level of activity on production.................... 71 7.3.2 Other possible impacts from the increased level of activity . 72 7.4 What would help the industry to cope better with changes? . 73 8 . Attract, retain and make best use of the necessary people and expertise . 74 8.1 Chapter summary . 74 8.2 Shortage of qualified labour on the NCS .................................. 74 8.3 The impact of demographic change...................................... 75 8.4 The influx of new players has generated competition over personnel . 76 8.5 Recommendations . 76 Appendix 1: The project team’s modelling tool and assumptions . 79 A1.1 Introduction....................................................... 79 A1.2 Input assumptions for scenario modelling . 79 A1.3 Scenario description . 86 A1.4 Results of the scenario modelling . 86 Appendix 2: Project team’s engagement with stakeholders . 88 Appendix 3: NPD resource classification . 89 Appendix 4: Assumptions for estimating contingent resources and a comparison with the NPD estimates . 90 A 4.1 Contingent resources in existing fields.................................. 90 A.4.2 Contingent resources in discoveries.................................... 91 Terms and definitions . 93 References . 95 4 Summary and conclusions Production on the NCS is maturing After almost 40 years of virtually uninterrupted growth, total hydrocarbon production on the Norwegian continental shelf (NCS) has reached its highest level ever, with a daily output of 4-4.5 million barrels of oil equivalent per day. It is expected to remain at this level for the next 7 years. After 2015 or thereabouts, however, total oil and gas produc- tion is forecast to start declining. Oil production is already falling. Gas output has been increasing, but this is not expected to continue offsetting the drop in liquid production beyond 2015 or thereabouts if no action is taken. Only half the combined oil and gas resources predicted by the Norwegian Petroleum Directorate (NPD) will have been produced in 2015. Remaining recoverable resources, including those expected to be found by further exploration, are currently estimated to be 38-77 billion barrels of oil equivalent (boe). This estimate could be 25-65 billion boe in 2015. Only 40 per cent of the total expected remaining hydrocarbon resources remains to be discovered today, which explains the wide range in the estimates. This huge potential must be managed well to avoid a sharp decline in production and to support a healthy level of long-term investment. The report on production development on the Norwegian continental shelf is published at a time when major changes are taking place both inside and outside the petroleum indus- try. Several factors make a review of what can be done to address the production decline particularly urgent. Although the current level of activity in the Norwegian petroleum sector is high, assessing the long-term perspectives for the industry is very important. In many cases, the period between the award of licences and the start of production can be 15 years or more. Decisions taken now may have important implications for levels of production and activity in the 2020s. Overview of production development on the NCS • The largest hydrocarbon accumulations were discovered in the 1970s and 1980s. Many smaller discoveries were made in the course of the 1990s. An exception is Ormen Lange, found in 1997 as the last big discovery on the NCS. • Development of these large fields required high levels of investment and expertise as well as extensive use of new technology. These new technologies were subsequently applied worldwide. • The recovery factor for fields on the NCS is amongst the highest in the world.This is largely a result of the extensive use of new technology. Over the past 10 years, however, the addition of resources to replace the oil and gas produced has declined sharply. • The large fields which accounted for the bulk of oil production from the NCS are now getting older. More than 60 per cent of their expected recoverable reserves has been recovered, and their output is declining rapidly. The remaining oil in these fields is more technically difficult to recover and therefore more labour-intensive and expensive. Limited time is also available for applying new technology to improve recovery from these fields. Debate exists, for example, over the extent and pace of 5 the contribution which enhanced oil recovery (EOR) methods can make on the NCS. In addition, more attention needs to be paid to research into and development of improved oil recovery (IOR) methods. • An increasing share of production on the NCS comes from small and medium- sized fields. Most of these have been developed as subsea tiebacks to existing infrastructure rather than as stand-alone projects. The ultimate recovery factor for small and subsea fields is lower on average, and extending the production life of these fields in a cost-effective way will be challenging. • Economic development of small fields often depends on the presence of existing infrastructure in the vicinity. Since many platforms are approaching retirement, the time window for achieving full exploration of the North Sea is rapidly closing. • Future developments in areas currently accessible for petroleum activities are expected to be small. However, the sum of these could have a significant impact on the level of investment. Economic development of future small
Load more

Recommended publications
  • 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.
    [Show full text]
  • 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
    [Show full text]
  • 10Fields in Production
    eng_fakta_2005_kap10 12-04-05 15:26 Side 66 10 Fields in production eng_fakta_2005_kap10 12-04-05 15:26 Side 67 Keys to tables in chapters 10–12 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 decimal places, licensee holdings in a field may add up to less than 100 percent. Interests are shown at 1 January 2005. “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). Resource category 0: Petroleum sold and delivered Resource category 1: Reserves in production Resource category 2: Reserves with an approved plan for development and operation Resource category 3: Reserves which the licensees have decided to develop FACTS 2005 67 eng_fakta_2005_kap10 12-04-05 15:26 Side 68 Southern North Sea The southern part of the North Sea sector became important for the country at an early stage, with Ekofisk as the first Norwegian offshore field to come on stream, more than 30 years ago. Ekofisk serves as a hub for petroleum operations in this area, with surrounding developments utilising the infrastructure which ties it to continental Europe and Britain. Norwegian oil and gas is exported from Ekofisk to Teesside in the UK and Emden in Germany respectively.
    [Show full text]
  • 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).
    [Show full text]
  • 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.
    [Show full text]
  • 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.
    [Show full text]
  • Technical Report Challenge 6
    2011 Technical Report Challenge 6 Ahmed Awol Tebarek, Brigite Caleca Cabenguela, Farid Abadli, Håkon Eidem Christiansen and Øystein Texmo Prytz NTNU 13.04.2011 Table of content 1 Abstract............................................................................................................................... 3 2 Introduction ........................................................................................................................ 4 2.1 Gullfaks Main Field......................................................................................................... 5 2.2 Gulltopp ........................................................................................................................... 8 2.2.1 Source: ................................................................................................................ 12 3 Plot the inflow along the wellbore.................................................................................... 13 3.1 Segments........................................................................................................................ 13 3.2 Base Case....................................................................................................................... 16 3.2.1 Oil Production .................................................................................................... 16 3.2.2 Segment flow rate ............................................................................................... 17 3.2.3 Sands..................................................................................................................
    [Show full text]
  • 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.
    [Show full text]
  • Annual Report 2005 for the Sdfi and Petoro
    ANNUAL REPORT 2005 FOR THE SDFI AND PETORO One of our values in Petoro is boldness and innovative thinking, a theme we Contents touch on in this annual report – including the way we have chosen to illustrate it. We challenged art historian Lau Albrektsen to select and provide brief 2 Key figures for the SDFI descriptions of artworks or architectural gems which represent transitions or paradigm shifts in European comprehension, thought and expression over 3 Highlights of 2005 20 generations. 4 Kjell Pedersen: Boldness and innovative thinking 8 Directors’ report 2005 Our interest lies in the actual change, in the processes which get us to see, 24 Health, safety and the environment understand and do things differently. And innovative thinking is by no means 27 Management team for Petoro AS confined to broad trends in world art. We have more than enough practical 30 Carbon dioxide injection: double dividends themes and issues in the Norwegian petroleum industry which need to be approached in new ways. 34 Carbon dioxide injection: important for improving the recovery factor 36 Improving governance boosts value creation If the illustrations in this report succeed in arousing a little curiosity, 40 Corporate governance encouraging reflection and perhaps even stimulating innovative thinking, we 43 SDFI appropriation accounts will have achieved our aim. 44 SDFI capital accounts 45 SDFI income statement 46 SDFI balance sheet at 31 December 2005 47 SDFI cash flow statement 48 SDFI notes 67 Audit letter from the Office of the Auditor General 70 Petoro AS income statement 71 Petoro AS Balance sheet 72 Petoro AS Cash flow statement 73 Petoro AS Notes 79 Auditor´s report Development of Emergence of Impressionism/ Vitalism/Cubism Painting as an space and per- glass and iron in Expressionism: in the early 20th autonomous mode spective in the architecture during the birth of century – of expression – Renaissance – the 19th century – modern painting – page 38 page 68 page 6 page 22 page 28 Front cover: Detail of Interior of the Gare Saint Lazare, Claude Monet, 1877.
    [Show full text]
  • Downloaded from the SEC Website At
    2015 Annual Report on Form 20-F The Annual Report on Form 20-F is our SEC filing for the fiscal year ended December 31, 2015, as submitted to the US Securities and Exchange Commission. © Statoil 2016 STATOIL ASA BOX 8500 NO-4035 STAVANGER NORWAY TELEPHONE: +47 51 99 00 00 www.statoil.com Cover photo: Øyvind Hagen 2015 Annual Report on Form 20-F 1 Introduction ...................................................................................................................................................................................................................................................................................... 6 1.1 About the report ..................................................................................................................................................................................................................................................................... 6 1.2 Key figures and highlights ................................................................................................................................................................................................................................................... 7 2 Strategy and market overview ................................................................................................................................................................................................................................................. 8 2.1 Statoil’s business environment .........................................................................................................................................................................................................................................
    [Show full text]
  • PIPELINES and LAND FACILITIES 145 Pipelines
    Pipelines and 15 land facilities Pipelines Gassled . 146 Europipe I . 146 Europipe II . 146 Franpipe . 147 Norpipe Gas . 147 Oseberg Gas Transport (OGT) . 147 Statpipe . 147 Vesterled (formerly Frigg Transport) . 148 Zeepipe . 148 Åsgard Transport . 148 Draugen Gas Export . 149 Grane Gas Pipeline . 149 Grane Oil Pipeline . 150 Haltenpipe . 150 Heidrun Gas Export . 151 Kvitebjørn Oil Pipeline . 151 Norne Gas Transport System (NGTS) . 152 Norpipe Oil AS . 152 Oseberg Transport System (OTS) . 153 Sleipner East condensate . 154 Troll Oil Pipeline I . 154 Troll Oil Pipeline II . 155 Land facilities Bygnes traffic control centre . 156 Kollsnes gas treatment plant . 156 Kårstø gas treatment and condensate complex . 156 Kårstø metering and technology laboratory . 157 Mongstad crude oil terminal . 157 Sture terminal . 158 Tjeldbergodden industrial complex . 158 Vestprosess . 159 -12˚ -10˚ -8˚ -6˚ -4˚ -2˚ 0˚ 2˚ 4˚ 6˚ 8˚ Norne 66˚ Heidrun 62˚ Åsgard Kristin Draugen PIPE 15 FAROE TEN ISLANDS AL H 64˚ Tjeldbergodden 60˚ Trondheim ÅSGARD TRANSPORT Murchison Snorre Statfjord Visund SHETLAND Gullfaks Kvitebjørn Florø 62˚ Huldra Veslefrikk Tune Brage Troll Mongstad THE ORKNEYS Oseberg OTS Stura STA Kollsnes 58˚ Frigg TPIPE Frøy Heimdal Bergen NORWAY Grane ll B IPE ZEEPIPEEEP ll A 60˚ Brae Z Kårstø Sleipner St. Fergus STATPIPE Draupner S/E Stavanger Forties 56˚ Ula SWEDEN Gyda 58˚ Ekofisk Valhall Hod NORPIPE EUROPIPE EUROPIPE 54˚ Teesside DENMARK ll NORPIP l 56˚ E GREAT 52˚ Bacton BRITAIN ZEEPIPE l CON FRANPIPE Emden INTER- 54˚ NECTOR THE GERMANY NETHERLANDS Zeebrugge 50˚ Dunkerque Existing pipeline 52˚ BELGIUM Projected pipeline Existing oil/condensate pipeline FRANCE Projected oil/condensate pipeline 0˚ 2˚ 4˚ 6˚ 8˚ 10˚ 12˚ The map shows existing and planned pipelines in the North and Norwegian Seas.
    [Show full text]
  • 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 Fram . 88 Frigg . 89 Grane . 91 Gullfaks (incl Gullfaks Vest) . 92 Gullfaks South (incl Rimfaks and Gullveig) . 94 Heimdal . 96 Huldra . 97 Jotun . 98 Murchison . 99 Oseberg (Oseberg, Oseberg West, Oseberg East, Oseberg South) . 101 Snorre (incl Snorre B) . 103 Statfjord . 104 Statfjord North . 106 Statfjord East . 107 Sygna . 108 Tordis (incl Tordis East and Borg) . 109 Troll phase I . 110 Troll phase II . 112 Tune . 114 Vale . 115 Veslefrikk . 116 Vigdis . 117 Visund ................................................................ 118 Norwegian Sea Draugen . 120 Heidrun . 121 Mikkel . 122 Njord . 123 Norne . 124 Åsgard ................................................................ 125 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 licen- ces (unitised fields or ones for which the sliding scale has been exercised have a different compo- sition of interests than the production licence). Because interests are shown up to two decimal pla- ces, licensee holdings in a field may add up to less than 100 per cent. Interests are shown at 1 January 2004. 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).
    [Show full text]