DOCSLIB.ORG

Annual Statements of Reserves 2017 1

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
Annual Statements of Reserves 2017 1 Point Resources AS Annual Statements of Reserves 2017 1 Annual Statements of Reserves 2017 Point Resources AS 2 Point Resources AS Annual Statements of Reserves 2017 Content 1 Classification of Reserves and Resources 3 2 Reserves, Developed and Non-Developed 4 3 Description of Reserves 6 3.1 Producing Assets 6 3.1.1 Balder 6 3.1.2 Ringhorne 8 3.1.3 Ringhorne East 9 3.1.4 Brage 10 3.1.5 Snorre 11 3.1.6 Bøyla 12 3.1.7 Hyme 13 3.2 Development Projects 14 3.2.1 Bauge 14 3.2.2 Fenja 15 4 Contingent Resources 16 5 Management’s Discussion and Analysis 17 Point Resources AS Annual Statements of Reserves 2017 3 1 Classification of Reserves and Resources Point Resources reserve and contingent resource volumes have been classified in accordance with the Society of Petroleum Engineer’s (SPE) Petroleum Resources Management System (PRMS). This classification system is consistent with Oslo Stock Exchange’s require- ments for the disclosure of hydrocarbon reserves and contingent resources. An overview of the classification system is illustrated in the figure below. SPE reserves and classification system (PRMS) Prouction L A I REReSEsReVrvEeSs C R E M M 11P 2P 3P ) O C P I IIP I P P y ( Proved Probable Possible t D li E a i CE R E c A r V L e P - CO L COCNoTnINtinGEeNntT N S I A I - I D Y RESOURCEresourcesS L RC Comm E L A f M I o T M I O 11CC 22C 33C e N I C c - B M an U U h S E C L UNRECOVERABLE O R ng i T s a P PROPrSoPsEpCTIVEectie PE L PII A RESreOsURCESources cre D T n I E O R T VE LLooww BBeesstt HHiigghh O EEssttiimaattee EEssttiimaattee EEssttiimaattee UNDISC UNRECOVERABLE Not to scale Range of Uncertainty 4 Point Resources AS Annual Statements of Reserves 2017 2 Reserves, Developed and Non-Developed The reserves estimates produced by Point Resources with a valuation date of 31.12.2017 have been certified by an independent reserves auditor, AGR Reservoir Services. Point Resources has a working interest in eight assets containing reserves. Within the reserves category, there are six producing assets, one of which is shut-in awaiting an upgrade on the Njord facility, and three development projects. These assets are listed in the table below. Overview of assets containing reserves FIELD/PROJECT INTEREST (%) OPERATOR RESOURCE CLASS COMMENT Developed Reserves Balder 100.00 % Point Resources Producing New – Acquisition from Exxon Ringhorne 100.00 % Point Resources Producing New – Acquisition from Exxon Ringhorne East 77.38 % Point Resources Producing New – Acquisition from Exxon Brage 12.26 % Wintershall Producing Snorre 1.11 % Statoil Producing Bøyla 20.00 % Aker BP Producing Hyme 17.50 % Statoil Non-producing Shut in awaiting Njord upgrade Undeveloped Reserves Bauge 17.50 % Statoil Approved for development Snorre exp. project 1.11 % Statoil Approved for development Ringhorne 100.00 % Point Resources Approved for development Ringhorne East 77.38 % Point Resources Approved for development Fenja 45.00 % VNG Justified for development FID taken end of year 2017 Point Resources AS Annual Statements of Reserves 2017 5 Total net proven and probable reserves (2P/P50) for Point Resources as of 31.12.2017 is estimated at 193.5 million barrels of oil equivalents. The corresponding estimate for net proven reserves (1P/P90) is 148.4 million barrels of oil equivalents. The split between oil, gas and NGL is given in the table below. 1P and 2P reserves, gross and net, by asset 1P 2P GROSS GROSS GROSS GROSS GROSS GROSS OIL GAS NGL GROSS OE NET OE OIL GAS NGL GROSS OE NET OE AS OF 31.12.2017 INTEREST (%) MMBOE MMBOE MMBOE MMBOE MMBOE MMBOE MMBOE MMBOE MMBOE MMBOE On Production Balder 100.00 % 38.5 0.5 0.0 39.1 39.1 48.2 0.7 0.0 48.8 48.8 Ringhorne 100.00 % 19.3 0.0 0.0 19.3 19.3 24.1 0.0 0.0 24.1 24.1 Ringhorne East 77.38 % 18.3 0.0 0.0 18.3 14.1 22.8 0.0 0.0 22.8 17.7 Brage 12.26 % 20.9 4.4 2.8 28.1 3.4 26.1 5.5 3.5 35.1 4.3 Snorre 1.11 % 275.9 0.0 0.0 275.9 3.1 392.0 0.0 0.0 392.0 4.3 Hyme 17.50 % 4.5 1.9 1.3 7.7 1.3 8.2 3.5 2.4 14.0 2.5 Bøyla 20.00 % 5.8 0.2 0.0 6.0 1.2 8.1 0.3 0.0 8.4 1.7 Total 383.3 7.0 4.0 394.3 81.6 529.5 9.9 5.8 545.3 103.4 Approved for Development Brage 12.26 % 34.4 8.3 8.1 50.8 8.9 49.6 11.6 11.8 73.0 12.8 Snorre Expansion 1.11 % 152.3 0.0 0.0 152.3 1.7 175.7 0.0 0.0 175.7 1.9 Ringhorne 100.00 % 18.7 0.1 0.0 18.8 18.8 26.7 0.2 0.0 26.9 26.9 Ringhorne East 77.38 % 5.2 0.0 0.0 5.2 4.0 7.4 0.0 0.0 7.4 5.7 Fenja 45.00 % 55.4 14.4 4.6 74.4 33.5 69.1 19.7 6.3 95.1 42.8 Total 266.0 22.8 12.8 301.5 66.8 328.4 31.5 18.1 378.0 90.1 Total Reserves 649.3 29.7 16.8 695.8 148.4 857.9 41.4 23.9 923.3 193.5 The table below shows the reconciliation of reserves between the current reporting and the previous year’s reporting at an aggregated level. Reconciliations for 1P and 2P reserves NET MILLION BARRELS OF OIL EQUIVALENTS 1P/P90 2P/P50 Balance as of 31.12.2016 9.6 14.0 Year 2017 Production -17.5 -17.5 Acquisitions/Sales of reserves 107.5 134.3 Discoveries, additions and extensions 42.5 55.7 Revisions of previous estimates 6.3 6.9 Balance as of 31.12.2017 148.4 193.5 6 Point Resources AS Annual Statements of Reserves 2017 3 Description of Reserves 3.1 Producing Assets This section gives a short summary of the producing fields in the Point Resources portfolio. 3.1.1 Balder Asset overview 1°40'E 2°E 2°20'E 2°40'E Balder field is an oil field located in the North Sea in blocks 25/10 59°30'N Alvheim and 25/11 within production licenses PL 001 and PL 028. The Jotun A water depth in the area is 125 m and the reservoir depth is around FPSO 1700 m TVD MSL. Discovery Bøyla Ring- The Balder field was the first discovery in the Norwegian North Sea horne in 1967 by well 25/11-1. This was the second well drilled on the East Norwegian Continental Shelf (NCS). This field has a long explora- Ringhorne 59°15'N tion and production history and consists of a complex petroleum system with hydrocarbons in Paleocene and Eocene reservoirs Balder Fields & Discoveries Point Licenses Reservoir 0 5 10Km The Balder field is a low-relief structural/stratigraphic trap with complex remobilized/injected Paleocene/Eocene deep water sands (mounds) with a common OWC across the field. There is strong aquifer support and a gas cap in the main part of the field. extension program has been initiated extending the lifetime of The field shows excellent reservoir quality and a relatively viscous Balder from 2025 to 2030. oil at 3 cP (23°API). Gas is reinjected if the gas export system is inoperative and gas lift is essential. Status Development 20 wells are on production, where nine of them are cyclic produc- ers due to a high water cut. The main drilling has been performed The Balder field is produced from five subsea sites tied back to the in three phases. The last of these campaigns drilled ten wells in Balder FPSO, where the oil and gas is processed. Gas from Balder the period of 2013 to 2016, eight of which are currently active is routed to the Jotun FPSO for final processing and sales, while producers. the oil is offloaded from the Balder FPSO to shuttle tankers. The illustration on the next page shows an illustration of the Balder The Balder oil has an imposed penalty due to the salt and water infrastructure complex. content above specifications and a project with an objective to optimize and improve the processing facility is ongoing. The Jotun FPSO is assumed to be removed from site in March 2020 and from this date gas sales will be terminated, and all The Balder FPSO processes and services Ringhorne and Ringhorne gas will be used for injection, gas lift and fuel/flare. Ringhorne East through a highly integrated area comprising Balder, Ringhorne production will be rerouted to the Balder FPSO where the gas and Jotun production facilities. The further utilization of the Jotun handling/compression capacity at Balder will be a bottleneck FPSO beyond abandonment of the Jotun Field is now in the (42 MMScf/d) and therefore constrain oil production. A lifetime planning phase. License shares for the Balder field Licences Point Resources PL 001 & PL 028 100.00 % Point Resources AS Annual Statements of Reserves 2017 7 Jotun A Jotun B r as 12 l ort elne elne 2m m Ringhorne R as assle elne 2m 10 est 12 l State as lft Grane Pipeline Balder Site as lft lne m 12 l lnes m Fer ot ale 2A as A1AH elne 2m SS aler to otun A-8H 1 A21AH2 SS A-5BH 22 10 A2 2AH2 2A A-4CH Site D Site A m 10 R A22AH2 SS as lne AA A27AH 12 A20 C-3FH 12 17A 1AH Site 11 2 7A Site 1 l Water Susea l ells Susea as ells as ft Rear as ut of Serve Susea ater ells A Susea ells The Balder infrastructure complex.
Load more

Recommended publications
  • Tectonic and Climatic Control of Triassic Sedimentation in the Beryl Basin, Northern North Sea
    Journal of the Geological Society, London, Vol. 149, 1992, pp. 13-26, 12 figs, Printed in Northern Ireland Tectonic and climatic control of Triassic sedimentation in the Beryl Basin, northern North Sea L. E. FROSTICK’,T. K. LINSEY’ & I. REID2 ‘Postgraduate Research Institute for Sedimentology, The University, Reading RG6 2AB, UK 2Department of Geography, Birkbeck College, University of London, Malet Street, London WClE 7HX, UK, Abstract: The Beryl Basin (Embayment) occupies a central position along the Viking Graben of the northern North Sea and has been a hydrocarbon play since the early 1970s. Detailed analysis reveals a complex half graben that was established during a rift-phase of development that occurred in the Early Triassic (Teist Formation), after which, a long period of thermal subsidence (Lomvi and Lunde Forma- tions) provided accommodation forin excess of 1OOOm of sediment. The Teist Formation sediments are complex, they include shales, sands and conglomerates, and their superimposition on Zechstein salts is indicative of both uplift and the development of a moderate relief. They give way to the comparatively clean and occasionally pebbly sands of the Lomvi Formation,for which an analysis of both bedding and texture suggests depositionby a westerly-directed river system draining the hanging-wall ramp. The Lunde Formation records the spreading influence of a bajaddplaya complex and its eventual conversion to a more persistent lake. The growing importance and eventual dominance of the succession by lacustrine sediments gives clear indication a of change in climate, and this has been attributed to the rapid northward drift of Pangea during the Triassic period.
    [Show full text]
  • Back Matter (PDF)
    Index Page numbers in italic denote figures. Page numbers in bold denote tables. Aachenia sp. [gymnosperm] 211, 215, 217 selachians 251–271 Abathomphalus mayaroensis [foraminifera] 311, 314, stratigraphy 243 321, 323, 324 ash fall and false rings 141 actinopterygian fish 2, 3 asteroid impact 245 actinopterygian fish, Sweden 277–288 Atlantic opening 33, 128 palaeoecology 286 Australosomus [fish] 3 preservation 280 autotrophy 89 previous study 277–278 avian fossils 17 stratigraphy 278 study method 281 bacteria 2, 97, 98, 106 systematic palaeontology 281–286 Balsvik locality, fish 278, 279–280 taphonomy and biostratigraphy 286–287 Baltic region taxa and localities 278–280 Jurassic palaeogeography 159 Adventdalen Group 190 Baltic Sea, ice flow 156, 157–158 Aepyornis [bird] 22 barite, mineralization in bones 184, 185 Agardhfjellet Formation 190 bathymetry 315–319, 323 see also depth Ahrensburg Glacial Erratics Assemblage 149–151 beach, dinosaur tracks 194, 202 erratic source 155–158 belemnite, informal zones 232, 243, 253–255 algae 133, 219 Bennettitales 87, 95–97 Amerasian Basin, opening 191 leaf 89 ammonite 150 root 100 diversity 158 sporangia 90 amniote 113 benthic fauna 313 dispersal 160 benthic foraminifera 316, 322 in glacial erratics 149–160 taxa, abundance and depth 306–310 amphibian see under temnospondyl 113–122 bentonite 191 Andersson, Johan G. 20, 25–26, 27 biostratigraphy angel shark 251, 271 A˚ sen site 254–255 angiosperm 4, 6, 209, 217–225 foraminifera 305–312 pollen 218–219, 223 palynology 131 Anomoeodus sp. [fish] 284 biota in silicified
    [Show full text]
  • Diagenesis and Sequence Stratigraphy
    Comprehensive Summaries of Uppsala Dissertations from the Faculty of Science and Technology 762 _____________________________ _____________________________ Diagenesis and Sequence Stratigraphy An Integrated Approach to Constrain Evolution of Reservoir Quality in Sandstones BY JOÃO MARCELO MEDINA KETZER ACTA UNIVERSITATIS UPSALIENSIS UPPSALA 2002 Dissertation for the Degree of Doctor of Philosophy in Mineral Chemistry, Petrology and Tectonics at the Department of Earth Sciences, Uppsala University, 2002 Abstract Ketzer, J. 2002. Diagenesis and Sequence Stratigraphy. an integrated approach to constrain evolution of reservoir quality in sandstones. Acta Universitatis Upsaliensis. Comprehensive Summaries of Uppsala Dissertations from the Faculty of Science and Technology 762. 30 pp. Uppsala. ISBN 91-554-5439-9 Diagenesis and sequence stratigraphy have been formally treated as two separate disciplines in sedimentary petrology. This thesis demonstrates that synergy between these two subjects can be used to constrain evolution of reservoir quality in sandstones. Such integrated approach is possible because sequence stratigraphy provides useful information on parameters such as pore water chemistry, residence time of sediments under certain geochemistry conditions, and detrital composition, which ultimately control diagenesis of sandstones. Evidence from five case studies and from literature, enabled the development of a conceptual model for the spatial and temporal distribution of diagenetic alterations and related evolution of reservoir quality
    [Show full text]
  • Comparing Middle Permian and Early Triassic Environments: Mud Aggregates As a Proxy for Climate Change in the Karoo Basin, South Africa
    Colby College Digital Commons @ Colby Honors Theses Student Research 2011 Comparing Middle Permian and Early Triassic Environments: Mud Aggregates as a Proxy for Climate Change in the Karoo Basin, South Africa Bryce Pludow Colby College Follow this and additional works at: https://digitalcommons.colby.edu/honorstheses Part of the Geology Commons Colby College theses are protected by copyright. They may be viewed or downloaded from this site for the purposes of research and scholarship. Reproduction or distribution for commercial purposes is prohibited without written permission of the author. Recommended Citation Pludow, Bryce, "Comparing Middle Permian and Early Triassic Environments: Mud Aggregates as a Proxy for Climate Change in the Karoo Basin, South Africa" (2011). Honors Theses. Paper 622. https://digitalcommons.colby.edu/honorstheses/622 This Honors Thesis (Open Access) is brought to you for free and open access by the Student Research at Digital Commons @ Colby. It has been accepted for inclusion in Honors Theses by an authorized administrator of Digital Commons @ Colby. COMPARING MIDDLE PERMIAN AND EARLY TRIASSIC ENVIRONMENTS: MUD AGGREGATES AS A PROXY FOR CLIMATE CHANGE IN THE KAROO BASIN, SOUTH AFRICA B. Amelia Pludow „11 A Thesis Submitted to the Faculty of the Geology Department of Colby College in Fulfillment of the Requirements for Honors in Geology Waterville, Maine May, 2011 COMPARING MIDDLE PERMIAN AND EARLY TRIASSIC ENVIRONMENTS: MUD AGGREGATES AS A PROXY FOR CLIMATE CHANGE IN THE KAROO BASIN, SOUTH AFRICA Except where reference is made to the work of others, the work described in this thesis is my own or was done in collaboration with my advisory committee B.
    [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]
  • Reservoir Characterization of Triassic and Jurassic Sandstones of Snorre Field, the Northern North Sea
    Reservoir Characterization of Triassic and Jurassic sandstones of Snorre Field, the northern North Sea Owais Hameed Master Thesis, Autumn 2016 Reservoir Characterization of Triassic and Jurassic sandstones of Snorre Field, the northern North Sea Owais Hameed Thesis submitted for degree of Master in Geology 60 credits Department of Mathematics and Natural Science UNIVERSITY OF OSLO December / 2016 © Owais Hameed, 2016 Tutor(s): Nazmul Haque Mondol (UiO) This work is published digitally through DUO – Digital Utgivelser ved UiO http://www.duo.uio.no It is catalogued in BIBSYS (http://www.bibsys.no/English) All rights reserved. No part of this publication may be reproduced or transmitted, in any form or by any means, without permission. Preface This thesis is submitted to the Department of Geosciences, University of Oslo (UiO) in candidacy of M.Sc. degree in Geology. The research has been performed at Department of Geosciences, University of Oslo during the period of January 2016 to December 2016 under supervision of Dr. Nazmul Haque Mondol, Associate Professor, Department of Geosciences, UiO. i ii Acknowledgement I would like to express my gratitude to my supervisor Dr. Nazmul Haque Mondol, Associate Professor, Department of Geosciences, University of Oslo, for giving me the opportunity to work under his supervision and learn from his immense knowledge and experience. His guidance, patience and encouragement throughout the study helped me to complete this thesis. I am grateful to PhD candidate Mohammad Nooraipour and Irfan Baig for their precious time and help. Special thanks to Manzar Fawad and Mohammad Koochak Zadeh for their help and time when it was needed.
    [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]
  • Sess Report 2019
    SESS REPORT 2019 The State of Environmental Science in Svalbard – an annual report SESS REPORT 2019 The State of Environmental Science in Svalbard – an annual report Floor van den Heuvel, Christiane Hübner, Malgorzata Błaszczyk, Martin Heimann, Heikki Lihavainen (Editors) SESS report 2019 The State of Environmental Science in Svalbard – an annual report ISSN 2535-809X (printed) ISSN 2535-6321 (pdf) ISBN 978-82-691528-7-6 (printed, stapled) ISBN 978-82-691528-6-9 (pdf) Publisher: Svalbard Integrated Arctic Earth Observing System (SIOS) Editors: Floor van den Heuvel, Christiane Hübner, Malgorzata Błaszczyk, Martin Heimann, Heikki Lihavainen Editor popular science summaries: Janet Holmén Layout: Melkeveien designkontor, Oslo CITATION: Entire report: Van den Heuvel F, Hübner C, Błaszczyk M, Heimann M, Lihavainen H (eds) 2020: SESS report 2019, Svalbard Integrated Arctic Earth Observing System, Longyearbyen Chapters in report: All authors (2020) Title of chapter. In: Van den Heuvel et al. (eds): SESS report 2019, Svalbard Integrated Arctic Earth Observing System, Longyearbyen, pp. xx - xx The report is published as electronic document, available from the SIOS web site www.sios-svalbard.org/SESSreport Contents Foreword ..................................................................................................................................................................... 6 Authors from following institutions contributed to this report ....................................................................... 8 Excecutive summary ..............................................................................................................................................
    [Show full text]
  • Master's Thesis
    Faculty of Science and Technology MASTER’S THESIS Study program/ Specialization: Spring semester, 2019 Petroleum Geosciences Engineering Open Writer: Sofie Knutdatter Arntzen ………………………………………… (Writer’s signature) Faculty supervisor: Nestor Cardozo, University of Stavanger External supervisor: Tore Skar, Suncor Energy A/S Thesis title: Tectonic evolution of the Marulk Basin and adjacent highs, northern North Sea Credits (ECTS): 30 Key words: Marulk Basin Pages: 86 Tampen Spur Structural evolution Rift evolution Stavanger, 14th June 2019 Tectonic evolution of the Marulk Basin and adjacent highs, northern North Sea By Sofie Knutdatter Arntzen MSc Thesis Presented to the Faculty of Science and Technology University of Stavanger University of Stavanger June 2019 Acknowledgement Firstly, I want to thank my thesis advisor at Suncor Energy Norge A/S, Tore Skar, for his guidance, sharing of ideas and support throughout this thesis study. I would also like express my gratitude to Professor Nestor Cardozo, for valuable feedback and comments. Secondly, I want to thank Suncor Energy Norge A/S for providing me the data, facilities and guidance making this thesis possible. A special thanks also goes to colleagues in Suncor Energy, for the knowledge and discussions you have shared with me the past two years. i Abstract The Marulk Basin is located in the northern North Sea, at the boarder towards the Mid- Norwegian Margin. The geological evolution of the Marulk Basin has received limited attention in the literature, and thus, the main motivation of this thesis study is to improve the geological understanding of this marginal area of the northern North Sea. Interpretation of 3D seismic data combined with regional 2D seismic lines and exploration wells are used to assess the tectonic evolution of the Marulk Basin with adjacent highs and put it into a regional context with regards to the northernmost propagation of the North Sea rift system.
    [Show full text]
  • NGU Report 2002.010
    NGU Report 2002.010 CO2 point sources and subsurface storage capacities for CO2 in aquifers in Norway Geological Survey of Norway N-7441 Trondheim, Norway Tel.: 47 73 90 40 00 Telefax 47 73 92 16 20 REPORT Report no.: 2002.010 ISSN 0800-3416 Grading: Open Title: CO2 point sources and subsurface storage capacities for CO2 in aquifers in Norway Authors: Client: Reidulv Bøe, Christian Magnus, Per Terje NGU, EU Osmundsen and Bjørn Ivar Rindstad County: Commune: Norway Map-sheet name (M=1:250.000) Map-sheet no. and -name (M=1:50.000) Deposit name and grid-reference: Number of pages: 132 Price (NOK): 295,- Map enclosures: 0 Fieldwork carried out: Date of report: Project no.: Person responsible: 1 September 2002 287300 Summary: The GESTCO (GEological STorage of CO2 from fossil fuel combustion) project comprises a study of the distribution and coincidence of thermal CO2 emission sources and location/quality of geological storage capacity in Europe. The GESTCO project is a joint research project conducted by 8 national geological surveys and several industry partners/end users, partly funded by the European Union 5th Framework Programme for Research and Development. Four of the most promising types of geological storage are being studied: 1) onshore/offshore saline aquifers with or without lateral seal, 2) low entalpy geothermal reservoirs, 3) deep methane-bearing coal beds and abandoned coal and salt mines, and 4) exhausted or near exhausted hydrocarbon structures. In this report, we present an inventory of CO2 point sources in Norway (1999) and the results of the work within Study Area C: deep saline aquifers offshore/near shore Northern and Central Norway.
    [Show full text]
  • Discussion on Tectonic and Climatic Control of Triassic Sedimentation in the Beryl Basin, Northern North Sea Journal, Vol
    Journal of the Geological Society, London, Vol. 150, 1993, pp. 796-798, Printed in Northern Ireland Discussion on tectonic and climatic control of Triassic sedimentation in the Beryl Basin, northern North Sea Journal, Vol. 149, 1992, pp. 13-26 P. Richards writes: Frostick et al. (1992) provide a very provided include part of the Lunde Formation, and the readable and concise account of the Triassic evolution of the thickness of the Lomvi Formation should probably be Beryl Embayment area. The account is an analysis of a revised to a range of about 50 m to a maximum of about 110 sedimentary succession often glossed over by previous m (in well 9/19-2 of their fig. 4). workers, and they should be commended for attempting to Frostick et al. state that the Triassic succession generally explain the nature of these sediments. However, I have thickens westwards towards the fault zone. However, serious reservations concerning some of their lithostrat- correct correlation of the wells on their fig. 4 shows that: (a) igraphic correlations, and the assumptions that they make no assertions can be made about the thickness variations of from them and from some of their other data. Most the Teist Formation based on well data because of the seriously, their correlation of Lomvi Formation sediments termination of most wells within the Formation; (b) the appears to lead Frostick et al. to erroneous implications and Lomvi Formation does not thicken in a wedge towards the assumptions. fault, but actually appears to thicken from west to east Firstly, I would like to draw attention to Frostick et al.'s rather than from east to west on line B-B'; and (c) that the misrepresentation of the Triassic lithostratigraphic scheme Lunde Formation does thicken to the west on line A-A', postulated by Lervik et al.
    [Show full text]
  • The Late Jurassic Biorøy Formation: a Provenance Indi
    NORWEGIAN JOURNAL OF GEOLOGY The BjorøyFormation: A provenance indicator for offshore sediments 283 J F r i A The late urassic Biorøy o mat on: provenance indi­ cator for offshore sediments derived from SW Norway as based on single zircon (SIMS) data Trine-Lise Knudsen & Haakon Fossen Knudsen, T. -L. & Fossen, H.: The Late Jurassic Bjorøy Formation: A provenance indicator fo r offshore sediments derived from SW Norway as based on single zircon (SIMS) data. No rsk Geologisk Tidsskrift, Vo l. 81, pp. 283-292. Trondheim 2001. ISSN 029-196X. The Late Jurassic Bjorøy Formation is located in a fracturezone in granodioritic gneisses of the Øygarden Complex in the Bergen area, SW Nor­ way. An ion-microprobe (SIMS) U-Pb zircon study has been performed on a sand sample and the granitic basement, and the data are integrated with Nd and Sr whole rock isotopes in order to identify the provenance components to the Bjorøy Fm. The detrital zircons reflect a source area that was dominated by rocks with zircon ages in Caledonian (450 and 520 Ma), Sveconorwegian (900 to 1010 Ma) and mid-Proterozoic (ca. 1450 Ma) times. One Archaean zircon at ca. 2700 Ma is recorded. The sand sample has a relatively low Nd model age of 0.5 Ga, which can be connected to an important sediment source in Caledonian rocks of intermediate and mafic compositions. These were probably derived from units related to the Min or and Major Bergen Arcs. Thus, rocks of the Upper Allochthon of the Caledonides were probably important in the sediment source area together with Proterozoic gneisses and late-Proterozoic platform sediments, which appear as tectonically intercalated slivers in the upper alloch­ thonous units.
    [Show full text]