Equinor Environmental Plan in Brief
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Chapter 5: Biostratigraphy
1 • PETROLEUM GEOLOGY OF SOUTH AUSTRALIA Volume 5: Great Australian Bight Biostratigraphy R Morgan1, AI Rowett2 and MR White3 5INTRODUCTION . 2 TERTIARY . 21 REFERENCES . 31 MIDDLE JURASSIC TO CRETACEOUS . 2 Palynology . .21 PLATE Palynology . .2 Zonation . .21 5.1 Horologinella sp. A, B, C and D, History of zonation . .2 Wells . .21 Jerboa 1 cuttings, 2400–05 m . 12 Zonation framework . .5 Western Bight Basin: FIGURES Wells . .8 Eyre Sub-basin . .21 5.1. Major features and well locations, Great Western Bight Basin: Central Bight Basin: Australian Bight . 4 central Ceduna Sub-basin . .22 Eyre Sub-basin . .10 5.2 Middle Jurassic to Cretaceous North–central Bight Basin: Eastern Bight Basin: Duntroon and biostratigraphic zonation of the Madura Shelf . .13 eastern Ceduna Sub-basins . .22 Bight and Polda Basins. 7 Central Bight Basin: central Foraminifera . .25 5.3 Middle Jurassic to Cretaceous Ceduna Sub-basin . .14 Zonation . .25 biostratigraphy (and older stratigraphy) Polda Basin . .14 Wells . .25 of wells in the Bight and Polda Basins . 9 Eastern Bight Basin: Duntroon Western Bight Basin: 5.4 Tertiary biostratigraphic zonation of the and eastern Ceduna Sub-basins . .15 Eyre Sub-basin . 25 portion of the Eucla Basin which overlies North–central Bight Basin: Foraminifera . .18 the Bight Basin and Tertiary foraminiferal Madura Shelf . .28 events recognised in southern Australia. 26 Summary . .19 Central Bight Basin: central 5.5 Integrated microfossil and palynological Permian to Middle Jurassic . .19 Ceduna Sub-basin . .29 Tertiary biostratigraphy of wells Cretaceous . .19 Eastern Bight Basin: Duntroon and penetrating the Eucla and Bight Basins 27 eastern Ceduna Sub-basins . -
Case No COMP/M.7579 - ROYAL DUTCH SHELL / KEELE OY / AVIATION FUEL SERVICES NORWAY
EN Case No COMP/M.7579 - ROYAL DUTCH SHELL / KEELE OY / AVIATION FUEL SERVICES NORWAY Only the English text is available and authentic. REGULATION (EC) No 139/2004 MERGER PROCEDURE Article 6(1)(b) NON-OPPOSITION Date: 19/06/2015 In electronic form on the EUR-Lex website under document number 32015M7579 EUROPEAN COMMISSION Brussels, 19.6.2015 C(2015) 4285 final In the published version of this decision, some information has been omitted pursuant to Article PUBLIC VERSION 17(2) of Council Regulation (EC) No 139/2004 concerning non-disclosure of business secrets and other confidential information. The omissions are shown thus […]. Where possible the information omitted has been replaced by ranges of figures or a MERGER PROCEDURE general description. To the notifying parties Dear Sir/Madam, Subject: Case M.7579 - ROYAL DUTCH SHELL / KEELE OY / AVIATION FUEL SERVICES NORWAY Commission decision pursuant to Article 6(1)(b) of Council Regulation No 139/20041 and Article 57 of the Agreement on the European Economic Area2 (1) On 12th May 2015, the European Commission received a notification of a proposed concentration pursuant to Article (4) of Council Regulation (EC) No 139/2004 by which Shell Exploration and Production Holding B.V. ("SEPH", the Netherlands), ultimately controlled by Royal Dutch Shell plc ("RDS", England), and St1 Group Oy and St1 Nordic Oy (collectively, "St1", Finland) both controlled by Keele Oy, will acquire within the meaning of Article 3(1)(b) and 3(4) of the Merger Regulation joint control of Aviation Fuelling Services Norway AS ("AFSN" or "JV", Norway), currently a 100% subsidiary of SEPH, by way of purchase of 1 OJ L 24, 29.1.2004, p. -
Frequently Asked Questions About Hydraulic Fracturing
Frequently Asked Questions About Hydraulic Fracturing: What is hydraulic fracturing? Hydraulic fracturing, commonly referred to as fracing, is the process of creating small cracks, or fractures, in underground geological formations to allow oil or natural gas to flow into the wellbore and thereby increase production. Prior to initiating hydraulic fracturing, engineers and geoscientists study and model the physical characteristics of the hydrocarbon bearing rock formation, including its permeability, porosity and thickness. Using this information, they design the process to keep the resulting fractures within the target formation. In Colorado, the target formation is often more than 7,000 feet below the ground surface and more than 5,000 feet below any drinking water aquifers. To fracture the formation, special fracturing fluids are injected down the well bore and into the formation. These fluids typically consist of water, sand, and chemical additives. The pressure created by injecting the fluid opens the fractures. Sand is carried into the fractures by the fluid and keeps the fractures open to increase the flow of oil or natural gas to the well bore. The chemicals serve a variety of purposes, including increasing viscosity, reducing friction, controlling bacteria, and decreasing corrosion. Following the treatment, much of the fracturing fluid flows back up the well bore and is collected at the surface in tanks or lined pits. Why is hydraulic fracturing necessary in Colorado? Most of the hydrocarbon bearing formations in Colorado have low porosity and permeability. These formations would not produce economic quantities of hydrocarbons without hydraulic fracturing. Fracture treatment of oil and gas wells in Colorado began in the 1970s and has evolved since then. -
Untested Waters: the Rise of Hydraulic Fracturing in Oil and Gas Production and the Need to Revisit Regulation
Fordham Environmental Law Review Volume 20, Number 1 2009 Article 3 Untested Waters: The Rise of Hydraulic Fracturing in Oil and Gas Production and the Need to Revisit Regulation Hannah Wiseman∗ ∗University of Texas School of Law Copyright c 2009 by the authors. Fordham Environmental Law Review is produced by The Berkeley Electronic Press (bepress). http://ir.lawnet.fordham.edu/elr UNTESTED WATERS: THE RISE OF HYDRAULIC FRACTURING IN OIL AND GAS PRODUCTION AND THE NEED TO REVISIT REGULATION Hannah Wiseman * I. INTRODUCTION As conventional sources of oil and gas become less productive and energy prices rise, production companies are developing creative extraction methods to tap sources like oil shales and tar sands that were previously not worth drilling. Companies are also using new technologies to wring more oil or gas from existing conventional wells. This article argues that as the hunt for these resources ramps up, more extraction is occurring closer to human populations - in north Texas' Barnett Shale and the Marcellus Shale in New York and Pennsylvania. And much of this extraction is occurring through a well-established and increasingly popular method of wringing re- sources from stubborn underground formations called hydraulic frac- turing, which is alternately described as hydrofracturing or "fracing," wherein fluids are pumped at high pressure underground to force out oil or natural gas. Coastal Oil and Gas Corp. v. Garza Energy Trust,1 a recent Texas case addressing disputes over fracing in Hidalgo County, Texas, ex- emplifies the human conflicts that are likely to accompany such creative extraction efforts. One conflict is trespass: whether extend- ing fractures onto adjacent property and sending fluids and agents into the fractures to keep them open constitutes a common law tres- pass. -
Dale Edward Bird
Dale Edward Bird 16903 Clan Macintosh 281-463-3816 (tel.) [email protected] Houston, Texas 77084 281-463-7899 (fax) www.birdgeo.com 713-203-1927 (cell.) Over thirty years experience in acquisition, processing, interpreting and marketing geophysical data, with an emphasis on gravity and magnetic data; Ph.D. in Geophysics; a volunteer in local and international earth science societies; a functional understanding of Spanish; and an avid chess player. Interpretation experience includes work in many basins, globally, including cratonic sag, rift, foreland, and passive margin environments. Research interests include regional geology / plate tectonics and marine geophysics, especially along continental margins and plate boundaries. EXPERIENCE Sole Proprietor. Bird Geophysical 1997-present . Consultancy providing potential fields data interpretation and management services to the petroleum exploration industry. Non-exclusive projects include: - Gulf of Mexico Evolution and Structure (GoMES) interpretation - Western Caribbean Plate interpretation - Southeast Asian basins interpretations; two phases: 1) Sunda Shelf and South China Sea, and 2) Central Indonesia - Reprocessed GEODAS open-file marine gravity and magnetic data; six areas: 1) Gulf of Mexico, 2) Caribbean, 3) Brazil & Argentina, 4) West Africa, 5) East Africa, and 6) India - Global Seismic refraction Catalog (GSC) ongoing joint project with the U.S. Geological Survey to compile and digitally capture published seismic refraction stations worldwide Adjunct Professor. University of Houston, Department of Earth & Atmospheric Sciences 2005-present . Teach graduate-level semester course: Basin Studies using Gravity & Magnetic Data . Participate with University of Houston faculty teaching short courses for industry professionals, and with invited programs at Universities abroad General Manager, Hydrocarbons. Aerodat, Inc. 1994-1997 . -
The Lower Bathyal and Abyssal Seafloor Fauna of Eastern Australia T
O’Hara et al. Marine Biodiversity Records (2020) 13:11 https://doi.org/10.1186/s41200-020-00194-1 RESEARCH Open Access The lower bathyal and abyssal seafloor fauna of eastern Australia T. D. O’Hara1* , A. Williams2, S. T. Ahyong3, P. Alderslade2, T. Alvestad4, D. Bray1, I. Burghardt3, N. Budaeva4, F. Criscione3, A. L. Crowther5, M. Ekins6, M. Eléaume7, C. A. Farrelly1, J. K. Finn1, M. N. Georgieva8, A. Graham9, M. Gomon1, K. Gowlett-Holmes2, L. M. Gunton3, A. Hallan3, A. M. Hosie10, P. Hutchings3,11, H. Kise12, F. Köhler3, J. A. Konsgrud4, E. Kupriyanova3,11,C.C.Lu1, M. Mackenzie1, C. Mah13, H. MacIntosh1, K. L. Merrin1, A. Miskelly3, M. L. Mitchell1, K. Moore14, A. Murray3,P.M.O’Loughlin1, H. Paxton3,11, J. J. Pogonoski9, D. Staples1, J. E. Watson1, R. S. Wilson1, J. Zhang3,15 and N. J. Bax2,16 Abstract Background: Our knowledge of the benthic fauna at lower bathyal to abyssal (LBA, > 2000 m) depths off Eastern Australia was very limited with only a few samples having been collected from these habitats over the last 150 years. In May–June 2017, the IN2017_V03 expedition of the RV Investigator sampled LBA benthic communities along the lower slope and abyss of Australia’s eastern margin from off mid-Tasmania (42°S) to the Coral Sea (23°S), with particular emphasis on describing and analysing patterns of biodiversity that occur within a newly declared network of offshore marine parks. Methods: The study design was to deploy a 4 m (metal) beam trawl and Brenke sled to collect samples on soft sediment substrata at the target seafloor depths of 2500 and 4000 m at every 1.5 degrees of latitude along the western boundary of the Tasman Sea from 42° to 23°S, traversing seven Australian Marine Parks. -
LA Petroleum Industry Facts
February 2000 Louisiana Petroleum Public Information Series No.2 Industry Facts 1934 First oil well of commercial quantities Deepest producing well in Louisiana: Texaco-SL urvey discovered in the state: 4666-1, November 1969, Caillou Island, The Heywood #1 Jules Clement well, drilled near Terrebonne Parish, 21,924 feet total depth Evangeline, Louisiana, in Acadia Parish, which S was drilled to a depth of approximately 1,700 Existing oil or gas fields as of December 31, feet in September 1901 (counties are called 1998: 1,775 Reserves “parishes” in Louisiana). Crude oil and condensate oil produced from First oil field discovered: Jennings Field, Acadia 1901 to 1998: 16,563,234,543 barrels Parish, September 1901 Crude oil and condensate produced in 1998: First over-water drilling in America: 132,376,274 barrels Caddo Lake near Shreveport, Louisiana, (Source: Louisiana Department of Natural Resources.) circa 1905 Natural gas and casinghead gas produced from First natural gas pipeline laid in Louisiana: 1901 to 1998: 144,452,229,386 thousand Caddo Field to Shreveport in 1908 cubic feet (MFC) Largest natural gas field in Louisiana: Natural gas produced in 1998: 1,565,921,421 Monroe Field, which was discovered in 1916 thousand cubic feet (MFC) (Source: Louisiana Department of Natural Resources.) Number of salt domes: 204 are known to exist, eological 77 of which are located offshore Dry Natural Gas Proven Reserves 1997 North Louisiana 3,093 billion cubic feet Parishes producing oil or gas: All 64 of South Louisiana 5,585 billion cubic feet Louisiana’s -
Ceduna 3D Marine Seismic Survey, Great Australian Bight
Referral of proposed action Project title: Ceduna 3D Marine Seismic Survey, Great Australian Bight 1 Summary of proposed action 1.1 Short description BP Exploration (Alpha) Limited (BP) proposes to undertake the Ceduna three-dimensional (3D) marine seismic survey across petroleum exploration permits EPP 37, EPP 38, EPP 39 and EPP 40 located in the Great Australian Bight (GAB). The proposed survey area is located in Commonwealth marine waters of the Ceduna sub-basin, between 1000 m and 3000 m deep, and is about 400 km west of Port Lincoln and 300 km southwest of Ceduna in South Australia. The proposed seismic survey is scheduled to commence no earlier than October 2011 and to conclude no later than end of May 2012. The survey is expected to take approximately six months to complete allowing for typical weather downtime. Outside this time window, metocean conditions become unsuitable for 3D seismic operations. The survey will be conducted by a specialist seismic survey vessel towing a dual seismic source array and 12 streamers, each 8,100 m long. 1.2 Latitude and longitude The proposed survey area is shown in Figure 1 with boundary coordinates provided in Table 1. Table 1. Boundary coordinates for the proposed survey area (GDA94) Point Latitude Longitude 1 35°22'15.815"S 130°48'50.107"E 2 35°11'50.810"S 131°02'16.061"E 3 35°02'37.061"S 131°02'15.972"E 4 35°24'55.520"S 131°30'41.981"E 5 35°14'38.653"S 131°42'16.982"E 6 35°00'47.460"S 131°41'40.052"E 7 34°30'09.196"S 131°02'44.991"E 8 34°06'27.572"S 131°02'11.557"E 9 33°41'24.007"S 130°31'04.931"E 10 33°41'25.575"S 130°15'22.936"E 11 34°08'47.552"S 130°12'34.972"E 12 34°09'16.169"S 129°41'03.591"E 13 34°18'22.970"S 129°29'32.951"E BP Ceduna 3D MSS Referral Page 1 of 48 1.3 Locality and property description The proposed seismic survey will take place in the permit areas for EPP 37, EPP 38, EPP 39 and EPP 40. -
Pelagic Regionalisation
Cover image by Vincent Lyne CSIRO Marine Research Cover design by Louise Bell CSIRO Marine Research I Table of Contents Summary------------------------------------------------------------------------------------------------------ 1 1 Introduction--------------------------------------------------------------------------------------------- 3 1.1 Project background----------------------------------------------------------------------------- 3 1.2 Bioregionalisation background --------------------------------------------------------------- 5 2 Project Scope and Objectives -----------------------------------------------------------------------12 3 Pelagic Regionalisation Framework----------------------------------------------------------------13 3.1 Introduction ------------------------------------------------------------------------------------13 3.2 A Pelagic Classification ----------------------------------------------------------------------14 3.3 Levels in the pelagic classification framework--------------------------------------------17 3.3.1 Oceans ----------------------------------------------------------------------------------17 3.3.2 Level 1 Oceanic Zones and Water Masses-----------------------------------------17 3.3.3 Seas: Circulation Regimes -----------------------------------------------------------19 3.3.4 Fields of Features ---------------------------------------------------------------------19 3.3.5 Features --------------------------------------------------------------------------------20 3.3.6 Feature Structure----------------------------------------------------------------------20 -
Chad/Cameroon Development Project
Chad/Cameroon Development Project Project Update No. 30 Mid-Year Report 2011 Chad Export Project Project Update No. 30 Mid-Year Report 2011 This report has been prepared by Esso Exploration and Production Chad Inc., in its capacity as Operator of the Consortium and as Project Management Company on behalf of the Tchad Oil Transportation Company S.A. (TOTCO) and the Cameroon Oil Transportation Company S.A. (COTCO). Preface his Project Update, the thirtieth such report for the Chad Export Project (also referred to as the T Chad/Cameroon Development Project), covers the period from January through June, 2011. The report reflects the activities of the project operating company and its prime contractors, with a particular focus on compliance with the Environmental Management Plan (EMP). Several entities share responsibility for implementing the project. • Oilfield development and production in Chad is conducted by Esso Exploration and Production Chad Inc. (EEPCI) on behalf of the Consortium (Esso, Petronas, Chevron). • Pipeline activities in Chad are conducted by the Tchad Oil Transportation Company S.A. (TOTCO). • Pipeline activities in Cameroon are conducted by the Cameroon Oil Transportation Company S.A. (COTCO). • During construction, EEPCI provided project management services to TOTCO and COTCO. These reports are submitted through, and subject to verification by, the World Bank and Lender Group as a reporting requirement of the project’s partnership with the Bank and the two host countries. This report also represents a commitment to transparency by Esso and its co-venture partners. By publishing this information, the project wishes to make it possible for the World Bank and Lender Group, the citizens of the host countries, interested non-governmental organizations (NGOs) and others to stay well informed about the project as it unfolds. -
Energy Perspectives 2017 Long-Term Macro and Market Outlook Energy Perspectives 2017
Energy Perspectives 2017 Long-term macro and market outlook Energy Perspectives 2017 Acknowledgements The analytical basis for this outlook is long-term research on macroeconomics and energy markets undertaken by the Statoil organization during the winter of 2016 and the spring of 2017. The research process has been coordinated by Statoil’s unit for Macroeconomics and Market Analysis, with crucial analytical input, support and comments from other parts of the company. Joint efforts and close cooperation in the company have been critical for the preparation of an integrated and consistent outlook for total energy demand and for the projections of future energy mix. We hereby extend our gratitude to everybody involved. Editorial process concluded 31 May 2017. Disclaimer: This report is prepared by a variety of Statoil analyst persons, with the purpose of presenting matters for discussion and analysis, not conclusions or decisions. Findings, views, and conclusions represent first and foremost the views of the analyst persons contributing to this report and cannot be assumed to reflect the official position of policies of Statoil. Furthermore, this report contains certain statements that involve significant risks and uncertainties, especially as such statements often relate to future events and circumstances beyond the control of the analyst persons and Statoil. This report contains several forward- looking statements that involve risks and uncertainties. In some cases, we use words such as "ambition", "believe", "continue", "could", "estimate", "expect", "intend", "likely", "may", "objective", "outlook", "plan", "propose", "should", "will" and similar expressions to identify forward-looking statements. These forward-looking statements reflect current views with respect to future events and are, by their nature, subject to significant risks and uncertainties because they relate to events and depend on circumstances that will occur in the future. -
Corporation Info
PRESS RELEASE 7.4.2017 St1 partnered with Digia to have its fully cloud-based ERP solution provided as a service in Finland, Sweden and Norway Thanks to the Dynamics 365 update Microsoft published at the end of last year, companies can now buy their ERP system as a service. St1 is one of the early adopters of this new operating model. St1’s refinery in Gothenburg, Sweden, will also use Dynamics 365 for spare part and maintenance procurement. In Finland and Norway, St1 will upgrade the Microsoft Dynamics AX 2012 ERP system to the new Dynamics 365 solution, while in Sweden this is a completely new ERP implementation project. In late 2016, Microsoft announced its intention to combine the different systems in the Dynamics product range into a single D365 solution provided as a service. Buying business-critical systems as a service is a major step and a change that very few companies have opted for so far. “Considering the scale of this change, we want to build on a technology platform that will stand the test of time by partly evolving itself, and not become obsolete overnight. A cloud-based business application solutions offer great foundation for a growing business. Digia has been a valuable partner for us in our controlled cloud transition first to Azure and now to D365,” says Marko Korhonen, CIO of St1. D365 facilitates maintenance procurement at the Gothenburg refinery As St1’s long-term partner, Digia has previously helped St1 to adopt Microsoft’s Azure cloud computing platform for its Dynamics AX ERP system in Finland and Norway.