DOCSLIB.ORG

Fact Sheet 1999. Norwegian Petroleum Activity

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
Fact Sheet 1999. Norwegian Petroleum Activity NORWEGIAN 1999 PETROLEUM ACTIVITY | PUBLISHED BY THE ROYAL MINISTRY OF PETROLEUM AND ENERGY FACT SHEET • Norwegian petroleum activity The Royal Ministry of Petroleum and Energy Einar Gerhardsens plass 1 P O Box 8148 Dep, N-0033 OSLO Norway Tel: +47 22 24 90 90 Fax: + 47 22 24 95 65 E-mail: [email protected] Internet homepage: www.oed.dep.no X.400: S=postmaster; 0=oed; P=dep; A=telemax; C=no; Telex: 21486 oedep n _ ^ OLJE- OG ENERGIDEPARTEMENTET Editor: Jan Breivik, MPE Edeting completed in May 1999 Layout/Design: Apropos Advertising Agency, www.apropos.no Sune Aabo Parker, Stig-ErikTokvam, Henning Bakke, Klas Jonsson and Merete Skeibrok Photos: ©Leif Berge and ®0yvind Hagen, Statoil, Elf archives and ©Husmo Foto Field Photos:The operators archives. Print: Kai Hansen Printers DISCLAIMER Portions of this document may be illegible in electronic image products. Images are produced from the best available original document. FOREWORD We have been reminded over the past year of the uncertainty associated with the pro ­ duction of oil and gas resources.The decline in oil prices through 1998 and the early part of 1999 produced a sharp fall in revenues both for the Norwegian state and for the oil com ­ panies. This has meant substantially lower transfers to the Government Petroleum Fund than earlier expected. Company plans for exploration and further development have also been cut back sharply. Postponements have been announced for several projects as a result of the low oil prices, and exploration operations have been cut back substantially. In many respects, a new era has been initiated for Norwegian petroleum operations in that investments is now probably past its peak.This reflects just as much a very high level of capital spending in 1998 as it does a future reduction. Norway's oil and gas industry has developed into an internationally competitive busi­ ness. Norwegian companies are world leaders in many areas, such as subsea production. Exports of oil/gas-related products and services have expanded sharply in recent years. The decline in domestic investment will increase the significance of foreign involvement. Given today's low oil prices, however, it will be a challenge to ensure that the Norwegian offshore sector remains an attractive petroleum region and thereby prevent a substantial fall in the level of investment into the next century. Active efforts by the companies and the authorities to bring costs down even further and to adopt more efficient forms of organisation off Norway are important. The authorities have also initiated an extensive review of the policy framework. Norwegian oil production declined by four per cent in 1998, to 2.9 million barrels per day. This fall reflected both official regulation of production as well as postponement of and delays to new projects. The reduction in oil production contrasts with developments in the 1980s and early 1990s, when Norwegian oil output showed continuous growth. Production is expected to grow somewhat in 1999, even when it has been regulated by an average of 200 000 barrels per day for the final nine months of the year. Norway's oil output is expected to peak in 2001 at 3.6 million barrels per day. Norway's total recoverable petroleum resources were put at 13.2 billion scm oe at 31 December 1998 - up by three per cent from last year's estimate. This increase largely reflects an upgrading of undiscovered resources and new finds. As a result, estimated remaining reserves rose again in 1998. Anne Enger Lahnstein Minister CONTENTS Foreword by the Minister.......................................................................................... 5 Concepts and conversion factors .............................................................................. 10 Chapter 1 - Summary................................................................................................. 11 Petroleum resources ........................................................................................................... 11 Exploration ........................................................................................................................... 11 Development ....................................................................................................................... 11 Oil and gas production ....................................................................................................... 11 Proceeds from oil and gas sales .......................................................................................... 11 Chapter 2 - A Brief History......................................................................................... 12 North Sea............................................................................................................................. 14 Norwegian Sea.................................................................................................................... 14 Barents Sea........................................................................................................................... 14 Chapter 3 - State Organisation of Petroleum Operations....................................... 16 Ministry of Petroleum and Energy ...................................................................................... 17 Ministry of Local Government and Regional Development ............................................ 19 Norwegian Petroleum Directorate ..................................................................................... 19 State's direct financial interest (SDFI)................................................................................ 19 Chapter 4 - Petroleum Operations in the Norwegian Economy ............................. 20 Investments......................................................................................................................... 21 Other key figures ................................................................................................................. 22 Chapter 5 - State Revenue .......................................................................................... 24 Tax and royalty system........................................................................................................ 25 SDFI....................................................................................................................................... 27 Chapter 6 - Mainland Activities and Petroleum Research ....................................... 28 The offshore supplies industry.......................................................................................... 29 Employment effects............................................................................................................ 29 Petroleum research............................................................................................................. 30 Chapter 7 - Petroleum Resources .............................................................................. 32 Chapter 8 - Production .............................................................................................. 36 Production forecast ............................................................................................................. 39 Chapter 9 - Marketing Status for Norwegian Petroleum Products......................... 42 The norm price................................................................................................................... 43 Norwegian crude oil in the world market...................................................................... 44 Sales of natural gas liquids (NGLs).................................................................................. 44 CONTENTS Dry gas sales....................................................................................................................... 46 Refining ............................................................................................................................... 49 Retail sales.......................................................................................................................... 49 Petrochemical industry.................................................................................................... 49 Chapter 10-Environmental Aspects............................................................................. 50 Emissions to air.................................................................................................................. 51 Discharges to sea............................................................................................................... 53 Framework conditions ...................................................................................................... 54 Cooperation with the industry........................................................................................ 55 Chapter 11 - Legal and License Framework .................................................................. 56 Introduction ....................................................................................................................... 57 Main features of the licensing system........................................................................... 57 Key documents and legal provisions in the licensing system.......................................... 58 Other key legal provisions ............................................................................................... 59 Chapter 12 - Licencing Rounds ......................................................................................
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]
  • The Economics of the Nord Stream Pipeline System
    The Economics of the Nord Stream Pipeline System Chi Kong Chyong, Pierre Noël and David M. Reiner September 2010 CWPE 1051 & EPRG 1026 The Economics of the Nord Stream Pipeline System EPRG Working Paper 1026 Cambridge Working Paper in Economics 1051 Chi Kong Chyong, Pierre Noёl and David M. Reiner Abstract We calculate the total cost of building Nord Stream and compare its levelised unit transportation cost with the existing options to transport Russian gas to western Europe. We find that the unit cost of shipping through Nord Stream is clearly lower than using the Ukrainian route and is only slightly above shipping through the Yamal-Europe pipeline. Using a large-scale gas simulation model we find a positive economic value for Nord Stream under various scenarios of demand for Russian gas in Europe. We disaggregate the value of Nord Stream into project economics (cost advantage), strategic value (impact on Ukraine’s transit fee) and security of supply value (insurance against disruption of the Ukrainian transit corridor). The economic fundamentals account for the bulk of Nord Stream’s positive value in all our scenarios. Keywords Nord Stream, Russia, Europe, Ukraine, Natural gas, Pipeline, Gazprom JEL Classification L95, H43, C63 Contact [email protected] Publication September 2010 EPRG WORKING PAPER Financial Support ESRC TSEC 3 www.eprg.group.cam.ac.uk The Economics of the Nord Stream Pipeline System1 Chi Kong Chyong* Electricity Policy Research Group (EPRG), Judge Business School, University of Cambridge (PhD Candidate) Pierre Noёl EPRG, Judge Business School, University of Cambridge David M. Reiner EPRG, Judge Business School, University of Cambridge 1.
    [Show full text]
  • Oil and Gas Fields in Norway
    This book is a work of reference which provides an easily understandable Oil and gas fields in n survey of all the areas, fields and installations on the Norwegian continental shelf. It also describes developments in these waters since the 1960s, Oil and gas fields including why Norway was able to become an oil nation, the role of government and the rapid technological progress made. In addition, the book serves as an industrial heritage plan for the oil in nOrway and gas industry. This provides the basis for prioritising offshore installations worth designating as national monuments and which should be documented. industrial heritage plan The book will help to raise awareness of the oil industry as industrial heritage and the management of these assets. Harald Tønnesen (b 1947) is curator of the O Norwegian Petroleum Museum. rway rway With an engineering degree from the University of Newcastle-upon- Tyne, he has broad experience in the petroleum industry. He began his career at Robertson Radio i Elektro before moving to ndustrial Rogaland Research, and was head of research at Esso Norge AS before joining the museum. h eritage plan Gunleiv Hadland (b 1971) is a researcher at the Norwegian Petroleum Museum. He has an MA, majoring in history, from the University of Bergen and wrote his thesis on hydropower ????????? development and nature conser- Photo: Øyvind Hagen/Statoil vation. He has earlier worked on projects for the Norwegian Museum of Science and Technology, the ????????? Norwegian Water Resources and Photo: Øyvind Hagen/Statoil Energy Directorate (NVE) and others. 55 tHe ekoFIsk AReA The Ekofisk area lies in 70-75 metres of water at the southern end of Norway’s North Sea sector, about 280 kilometres south-west of Stavanger.
    [Show full text]
  • New Document
    ANNUAL STATEMENT OF RESERVES 2016 AKER BP ASA Annual Statement of Reserves 2016 Annual Statement of Reserves 2016 Table of Contents 1 Classification of Reserves and Contingent Resources 1 2 Reserves, Developed and Non-Developed 2 3 Description of Reserves 5 3.1 Producing Assets 5 3.1.1 Alvheim and Viper/Kobra (PL036, Pl088BS, PL203) 5 3.1.2 Vilje (PL036D) 7 3.1.3 Volund (PL150) 8 3.1.4 Bøyla (PL340) 9 3.1.5 Atla (PL102C) 11 3.1.6 Jette (PL027D), PL169C, PL504) 11 3.1.7 Jotun (PL027B, PL203B) 12 3.1.8 Varg (PL038) 12 3.1.9 Ivar Aasen Unit and Hanz (Pl001B, PL028B, PL242, PL338BS, PL457) 13 3.1.10 Valhall (PL006B, PL033B) 15 3.1.11 Hod (PL033) 16 3.1.12 Ula (PL019) 17 3.1.13 Tambar (PL065) 19 3.1.14 Tambar East (PL065, PL300, PL019B) 20 3.1.15 Skarv/Snadd (PL262, PL159, PL212B, PL212) 21 3.2 Development Projects 22 3.2.1 Johan Sverdrup (PL265, PL501, PL502; Pl501B) 22 3.2.2 Gina Krog (PL029B) 25 3.2.3 Oda (PL405) 26 4 Contingent Resources 28 5 Management’s Discussion and Analysis 34 Annual Statement of Reserves 2016 List of Figures 1.1 SPE reserves and recourses classification systen .................................................................... 1 3.1 Alvheim and Viper/Kobra Location Map.................................................................................... 5 3.2 Vilje location map ...................................................................................................................... 7 3.3 Volund location map.................................................................................................................. 8 3.4 Bøyla location map.................................................................................................................. 10 3.5 Ivar Aasen Unit and Hanz location map.................................................................................. 13 3.6 Valhall and Hod location map.................................................................................................
    [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]
  • TYNDP 2017 FID Status (Final Investment Decision) White Sea PCI Status (Project of Common Interest) Submission
    SHTOKMAN SNØHVIT Pechora Sea ASKELADD MELKØYA KEYS ALBATROSS Hammerfest Salekhard Cross-border points / intra-country or intra balancing zone points Transport by pipeline LNG Import Terminals Storage facilities Compressor stations Barents KILDIN N Acquifer Sea 1ACross-border interconnection point Cross-border interconnection point Pipeline diameters : LNG Terminals’ entry point within Europe within Europe Diameter < 600 mm intro transmission system Salt cavity - cavern or export point to non-EU country or export point to non-EU country Operational Under construction or Planned Diameter 600 - 900 mm Depleted (Gas) eld on shore / oshore MURMAN Diameter > 900mm Other type Unknown Cross-border interconnection point Cross-border third country (import) with third country (import) Under construction or Planned Pomorskiy Project categories : Project categories : Project categories : Project categories : Strait Intra-country or Murmansk Third country cross-border FID projects FID projects FID projects intra balancing zone points interconnection point FID projects Non-FID, advanced projects Non-FID, advanced projects Non-FID, advanced projects REYKJAVIK Non-FID, advanced projects Non-FID, non-advanced projects Non-FID, non-advanced projects Non-FID, non-advanced projects Gas Reserve areas Countries Non-FID, non-advanced projects ENTSOG Member Countries ICELAND Project is part of 2nd PCI list : Project is part of 2nd PCI list : Project is part of 2nd PCI list : Project is part of 2nd PCI list : Drilling platform ENTSOG Associated Partner P ENTSOG
    [Show full text]
  • System Development Map 2019 / 2020 Presents Existing Infrastructure & Capacity from the Perspective of the Year 2020
    7125/1-1 7124/3-1 SNØHVIT ASKELADD ALBATROSS 7122/6-1 7125/4-1 ALBATROSS S ASKELADD W GOLIAT 7128/4-1 Novaya Import & Transmission Capacity Zemlya 17 December 2020 (GWh/d) ALKE JAN MAYEN (Values submitted by TSO from Transparency Platform-the lowest value between the values submitted by cross border TSOs) Key DEg market area GASPOOL Den market area Net Connect Germany Barents Sea Import Capacities Cross-Border Capacities Hammerfest AZ DZ LNG LY NO RU TR AT BE BG CH CZ DEg DEn DK EE ES FI FR GR HR HU IE IT LT LU LV MD MK NL PL PT RO RS RU SE SI SK SM TR UA UK AT 0 AT 350 194 1.570 2.114 AT KILDIN N BE 477 488 965 BE 131 189 270 1.437 652 2.679 BE BG 577 577 BG 65 806 21 892 BG CH 0 CH 349 258 444 1.051 CH Pechora Sea CZ 0 CZ 2.306 400 2.706 CZ MURMAN DEg 511 2.973 3.484 DEg 129 335 34 330 932 1.760 DEg DEn 729 729 DEn 390 268 164 896 593 4 1.116 3.431 DEn MURMANSK DK 0 DK 101 23 124 DK GULYAYEV N PESCHANO-OZER EE 27 27 EE 10 168 10 EE PIRAZLOM Kolguyev POMOR ES 732 1.911 2.642 ES 165 80 245 ES Island Murmansk FI 220 220 FI 40 - FI FR 809 590 1.399 FR 850 100 609 224 1.783 FR GR 350 205 49 604 GR 118 118 GR BELUZEY HR 77 77 HR 77 54 131 HR Pomoriy SYSTEM DEVELOPMENT MAP HU 517 517 HU 153 49 50 129 517 381 HU Strait IE 0 IE 385 385 IE Kanin Peninsula IT 1.138 601 420 2.159 IT 1.150 640 291 22 2.103 IT TO TO LT 122 325 447 LT 65 65 LT 2019 / 2020 LU 0 LU 49 24 73 LU Kola Peninsula LV 63 63 LV 68 68 LV MD 0 MD 16 16 MD AASTA HANSTEEN Kandalaksha Avenue de Cortenbergh 100 Avenue de Cortenbergh 100 MK 0 MK 20 20 MK 1000 Brussels - BELGIUM 1000 Brussels - BELGIUM NL 418 963 1.381 NL 393 348 245 168 1.154 NL T +32 2 894 51 00 T +32 2 209 05 00 PL 158 1.336 1.494 PL 28 234 262 PL Twitter @ENTSOG Twitter @GIEBrussels PT 200 200 PT 144 144 PT [email protected] [email protected] RO 1.114 RO 148 77 RO www.entsog.eu www.gie.eu 1.114 225 RS 0 RS 174 142 316 RS The System Development Map 2019 / 2020 presents existing infrastructure & capacity from the perspective of the year 2020.
    [Show full text]
  • Supreme Court of Norway
    SUPREME COURT OF NORWAY On 28 June 2018, the Supreme Court gave judgment in HR-2018-1258-A (case no. 2017/1891), civil case, appeal against judgment, CapeOmega AS (Counsel Thomas G. Michelet) (Assisting counsel: Kyrre Eggen) Solveig Gas Norway AS Silex Gas Norway AS Infragas Norge AS (Counsel Jan B. Jansen Counsel Thomas K. Svensen) (Assisting counsel: Kyrre Eggen) v. The state represented by the Ministry of Petroleum and Energy (The Attorney-General represented Tolle Stabell and Christian Fredrik Michelet) (Assisting counsel: Håvard H. Holdø) VOTING : (1) Justice Bårdsen: The case concerns the validity of the Ministry of Petroleum and Energy's Regulations 26 June 2013 no. 792 relating to amendment of the Regulations relating to the stipulation of tariffs etc. for certain facilities (the Tariff Regulations), adopted under section 4-8 of the Petroleum Act, among others. 2 (2) The Tariff Regulations 20 December 2002 no. 1724 regulate the tariffs that third parties must pay for shipment of gas in the pipelines owned by the joint venture Gassled. The joint venture was established in 2003, and tariffs were stipulated in the Tariff Regulations for the various areas of the pipeline network. This network is the world’s biggest offshore system for transport and processing of gas, consisting of a number of gas pipelines on the seabed of the North Sea and the Norwegian Sea, some onshore processing plants in Norway and six receiving facilities in the UK, France, Belgium and Germany. The system is subject to licences from the Ministry of Petroleum and Energy pursuant to section 4-3 of the Petroleum Act.
    [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]
  • Management Meeting with Equinor Low Carbon Solutions 07.05.2020
    European Gas Virtual 2021 Natural gas to blue hydrogen – Pipeline Transportation to Market and Decarbonisation in Multiple Sectors [email protected] .... Developing Clean Energy Solutions Large scale, emission-free production of hydrogen – HyPro-ZeroTM Existing technology in a new combination! Clean and affordable! Air separation unit (ASU) Purified hydrogen Oxygen (99.9-100%) Water / Gas Natural gas Reforming Hydrogen Hydrogen separation Shift by ATR (+GHR) (WGS) + CO2 Palladium-membrane* Cryogenic CO Capture Rate: 98-99% CO2 2 separation ready for transport of CO 2 and storage * Patented by HYDROGEN Mem-Tech AS (subsidiary) Competitive emission-free, blue hydrogen production Hydrogen production cost (incl. CO2 capture)*: 1.2 €/kgH2 + CO2 transport and storage cost: 0.3 - 0.5 €/kgH2 Total production cost**: 1.5 - 1.7 €/kgH2 * Natural gas price assumption: 0.12 €/SM3 ** Net cost, excl. financing, distribution of hydrogen etc. Significant global demand for new blue hydrogen production plants - and associated CCUS capacity 50 8 45 7.5 7 40 Carbon Capture 6.65 6 35 5.8 5 30 Biofuel 4.95 /YEAR 25 4 2 4.1 20 GTCO 3 3.25 15 2.4 2 NO OF NEW WORLD PLANTS/YR SCALE OF NO 10 Direct use and “E-fuel 1.7 1 5 1 0 0.5 0 2020 2025 2030 2035 2040 2045 2050 2055 2060 2065 2070 Data from: “World scale plant”: 400.000 tH2/year IAE report; Energy Technology Perspective (Sept. 2020) Concawe report; biofuel and “E-fuel” Sept. 2020 Gas pipelines for efficient hydrogen transportation - Examples Existing gas pipeline New hydrogen pipeline New pipeline
    [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]
  • Last Ned Brosjyre Om Prosessanlegget På Kollsnes
    FAKTA Kollsnes prosessanlegg Som en oase lyser prosessanlegget opp kystlandskapet en sensommerkveld Kollsnesanlegget spiller en nøkkelrolle når det gjelder transport av gass i store mengder fra felt i norsk del av Nordsjøen til kunder i Europa. Gass fra Kollsnes utgjør nærmere 40 prosent av totale norske gass- leveranser. De enorme gassmengdene i Troll-feltet var starten på det hele. Kollsnes prosessanlegg er i dag et Selve prosessanlegget består i hovedsak Troll er selve hjørne- senter for behandling av gass fra feltene av tre duggpunktsanlegg for behand- steinen i norsk gass- Troll, Fram, Visund og Kvitebjørn. På ling av henholdsvis gass, kondensat og Kollsnes blir gassen renset, tørket og monoetylenglykol (MEG). I tillegg finnes produksjon. Da feltet komprimert før den sendes som tørrgass et eget anlegg for utvinning av flytende gjennom eksportrør til Europa. I tillegg våtgass (Natural Gas Liquids -NGL). ble erklært drivverdig i transporteres noe gass i eget rør til I anlegget blir våtgass (NGL) først Naturgassparken, vest i Øygarden, der skilt ut. Deretter blir tørrgass trykket 1983, kom spørsmålet Gasnor behandler og distribuerer gass opp ved hjelp av de seks eksport- om hvilken vei de til innenlands forbruk. Kondensat, eller kompressorene og sendt ut i transport- våtgass, som er tyngre komponenter i systemet via eksportrør-ledningene enorme gassmengdene gassen, føres via Stureterminalen i rør Zeepipe IIA og IIB. til Mongstad (Vestprosess). Her videre- skulle ta for å komme behandles produktet og fraksjoneres til trygt fram til brukerne. propan, butan og nafta. Løsningen ble et mottaksanlegg på Kollsnes i Øygarden kommune nordvest 40% Gass fra Kollsnes utgjør nærmere for Bergen.
    [Show full text]