DOCSLIB.ORG

University of Alberta a Stratigraphie and Geochemical Investigation Of

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
University of Alberta a Stratigraphie and Geochemical Investigation Of University of Alberta A stratigraphie and geochemical investigation of Upper Devonian shale and marl aquitards, west-central Alberta, Canada. Catherine Cheryl SkiIliter O A thesis submitted to the Faculty of Graduate Studies and Research in partial fulfillment of the requirernents for the degree of Master of Science. Department of Earth and Atrnospheric Sciences Edmonton, Alberta SpRng. 2000 National Ubrary Bibliothèque nationale 191 du Canada Acquisitions and Acquisitions et Biûliographic Secvices seMces bbliographiques The author has granted a non- L'auteur a accordé une licence non exchisve licence allowing the excbve pexmettant à la National Liiof Canada to Bibliothèque nationale du Canada de reproduce, loan, distrite or sell reproduire, prêter, distriiuer ou copies of this thesis in microform, vendre des copies de cette thése sous paper or electronic formats. la forme de microfiche/film, de reproduction sur papier ou sur format électronique. The author retains ownership of the L'auteur conserve la propriété du copyright in this thesis. Neither the droit d'auteur qui protège cette thèse. thesis nor substantial extracts fkom it Ni la thèse ni des exIn& substantiels may be pimted or otherwise de celle-ci ne doivent être imprimés reproduced without the author's ou autrement reproduits sans son permission. autorisation. Abstract A regional investigation of Devonian aquitards in west-central Alberta has identified the aquitards as effective barrien to (paleo-)fluids since the Late DevonianIEariy Carboniferous. Aquitards thin progressively towards the disturbed beH, and in areas such as the Obed and Simonette fields, aquitards are absent, permitting interconnection between the four major Devonian carbonate aquifers (i.e., D-1 through D-4). Aquitard lithofacies Vary in depositional environments from basin, via dope (or ramp), to near-reef. Paragenetic sequences have been established for both near-reef and near-basinal lithofacies. Stable isotopic analyses (6"0 and 613c) reveal that aquitards have been relatively impene:ible to aqueous formation fluids since the Late DevoniadEarly Carboniferous. Mercury injection data show that the aquitards are relatively effective seals to hydrocarbons. The nearmarine ''~rhr ratios of the carbonate fractions within the aquitards differ significantiy from highly radiogenic (87~renriched), late-stage, carbonate cements within adjacent carbonate aquifers. This finding suggests the lafier were precipitated from fluids containing an extrabasinal fluid component. Extrabasinal fluids likely entered the Devonian system through tectonic expulsion during the Laramide orogeny. These fluids are confined to Devonian carbonate aquifers and have probably moved in a predorninantly northeast direction. in the vicinity of the disturbed belt region, cross formational fluid flow is likely, due to the absence of aquitards or in areas where the D-1 to the D-4 is hydrologically connected. Acknowledgements I would first like to acknowledge and thank Hans for his guidance and support throughout supervision of this thesis. Several othen at UofA made this project possible, including: Don Resultay and Mark Labbe for thin section preparation; Diane Caird for XRD analyses; Ted Evans for help with magnetic susceptibility; Olga Levner, Stacey Hagan, Kariis Muehlenbachs, and Rob Creaser for help with stable and radiogenic isotope analyses; Arndt Buhlmann for computer software support; and Ben Rostron for discussions on fluid flow mechanisms. In Calgary, thanks is extended to: Adam Hedinger, Jack Wendte, Mark Mallamo, Ken Watson, and Ross McLean for discussions regarding Devonian stratigraphy and structure; to the crew at the EUB, especially Lori, for assistance in core logging and sampling; to the AGS in Edmonton for use of the microfiche and copying services; to Regina Shedd and Jon Greggs at UofC for assistance in rounding up some valuable cross sections; to Soumini Reddy, Jeny Shaw, and Bemie Schulmeister at the Petroleum Recovery lnstitute (PR!) for their in- kind support in completing mercury injection tests. Accommodation in Calgary was most kindly provided by Kim Manzano, Chez Elizabeth and Marianne. A special mention to Mare, Betsy, Astrid, Rajeev, Karen, Andrea, Nancy, Steph, Leslie, Devon, Darlene, George, and Ted for their friendship, guidance, and plenty of helpful discussions along the way. 1 am indebted to present and past 'Gang" members including Maja, Matt, Karsten, Kim, Marianne, Lisa, and Jeff; it's been a pleasure working with you and I wish you success in al1 of your future endeavors! 1 offer a warm thank-you to my farnily for their support and to Simon for his constant love, cornmitment, and guidance. An extra special thanks is extended to: Pat Cavell for her endeanng support, never-ending discussions, and guidance throughout the entire project; and to Caroline Nixon, who was a great help in the initial stages of th8 project cieaning, cnishing, and drilling sarnples, and cornpleting magnetic susceptibility tests, and also near the end during some serious editing of the rough drafts of chapters. Your perseverance, persuasiveness, and encouragement moved me. Table of Contents 1. 1. Introduction and Previous Studies ....................... ........ .............. 1 1.2. Objectives of the Research Project .............................................. 5 1.3. Study Area and Core Control.............................. ............................. 6 2. Chapter 2 O Regional Geological Setting and Depositional History m....m....m 8 2.1 . Western Canada Sedimentary Basin ............................... ... ........... 8 2.2. Devonian Stratigraphy ................................................................ 8 2.3. The Alberta Basin .............................. ..............................................10 2.3.1. West Shale Basin ....................... ............................... 10 2.4. WCSB Structures lnfluencing Devonian Stratigraphy ....................... 10 2.5. Woodbend Group ............................ ................................................ 13 2.5.1 . Stratigraphy and Depositional history ................................. 13 2.6. Winterbum Group ................. ........ ......................................16 2.6.1. Stratigraphy and Depositional History ..................... .......... 16 Lower Winterbum Group ........................ ................... 17 Upper Winterburn Group ............................ ............ 17 2.7. Basin Fill Units ....................... ............. .. ................................ 19 2.8. Hydrostratigraphic Units of the WCSB ...................................... 21 2.9. Identification of Aquitards .. ............................. ........................... 23 2.1 0 . Shale and Marl Aquitards ....................... ... ........ ................... 23 2.1 0.1 . Wnterbum Group Aquitards ........................................... 23 2.1 0.2. WoodbendMlinterbum Aquitard ................... ....... ..... 23 2.1 0.3. Woodbend Group Aquitard ...................... ...... ............ 24 2.10.4. Majeau Lake Formation Aquitard ......................................24 2.1 0.5. Beavehill Lake Group Aquitards ..................................... 24 2.1 0.6. Watt Mountain Formation Aquitard ................... ... ...... 24 2.1 1. Carbonate Aquifers ....................................................................... 24 3. Chapter 3 .Stratigraphie and Structural Investigation of Middle to Upper Devonian Aquitardsmmmmmmmm........................................................ 25 3.1 . Introduction and Objectives ................... .... ............................... 25 3.2. Cross Section Methods .................... ........ ........................................ 27 3.3. Hydrocarbon Production in Wells .....................................................28 3.4. Stratigraphic Cross Section Methods .................. ... ...*..**......**..... 28 3.5. Structural Cross Section Methods .................................. ............. 29 3.6. Synopsis of Stratigraphic and Structural Investigations.................. 29 3.6.1 . Sumrnary of Cross Sections A-A' ........................................ 29 3.6.2. Summary of Cross Sections B-8' .................................. ... 32 3.6.3. Summaiy of Cross Sections C-C' ................... .... .... .... 32 3.6.4. Sumrnary of Cross Sections D-D' ......................... .. .......... 37 3.6.5. Summary of Cross Sections E-E' ............................... ...37 3.6.6. Summary of Cross Section F-Ç' ....................................... 42 4. Chapter 4 .Lithofacies and Mineralogical Facies of Regional Aquitards .................................................................................... 45 4.1. Introduction ......................... ....~........................................................45 4.2. Lithological Facies ....................... ... ........................................ 46 4.2.1. Introduction ..................... ......**.**.*.......*...*..*........*..........46 4.2.2. Lithofacies A .................................... ...................................49 4.2.3. Lithofacies B ....................... ................................................ 53 4.2.4. Lithofacies AD........... ......,.. ................. .. 53 4.2.5. lithofacies AE ............... ...... ........ .......... ....*..........*........58 4.2.6. Lithofacies C ......................... ........*..........*..........................61 4.2.7. Lithofacies G ................................. .....................................
Load more

Recommended publications
  • Characterization of Geothermal Reservoir Units in Northwestern
    PROCEEDINGS, Thirty-Eighth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, February 11-13, 2013 SGP-TR-198 CHARACTERIZATION OF GEOTHERMAL RESERVOIR UNITS IN NORTHWESTERN ALBERTA BY 3D STRUCTURAL GEOLOGICAL MODELLING AND ROCK PROPERTY MAPPING BASED ON 2D SEISMIC AND WELL DATA Simon N. Weides1, Inga S. Moeck2, Douglas R. Schmitt2, Jacek A. Majorowicz2, Elahe P. Ardakani2 1 Helmholtz Centre Potsdam GFZ German Research Centre for Geosciences, Telegrafenberg, 14473 Potsdam, Germany 2 University of Alberta, 11322-89 Ave., Edmonton, AB, Canada e-mail: [email protected] the south-western part of the study area its temperature ABSTRACT is above 70 °C and the effective porosity is estimated with 10 % to 15 %. Foreland basins such as the Western Canada Sedimentary Basin (WCSB) host a variety of geoenergy Geothermal heat could play a role as energy source for resources. Often, the focus is on hydrocarbon resources district heating. In energy intensive in-situ oil sands but in times of discussions about climate change and extraction processes geothermal heat could be used for environmental aspects, additional green energy preheating of water for steam production. This would resources are under examination. This study explores lower the amount of natural gas used in oil sands Paleozoic formations in the north western WCSB with production and reduce climate gas emissions. regard to their usability as geothermal reservoirs. The study focuses on an area around Peace River in north – western Alberta. This research site covers an area of INTRODUCTION approx. 90 km * 70 km with a basin depth of 1.7 km to 2.4 km.
    [Show full text]
  • Faults and Associated Karst Collapse Suggest Conduits for Fluid Flow That Influence Hydraulic Fracturing-Induced Seismicity
    Faults and associated karst collapse suggest conduits for fluid flow that influence hydraulic fracturing- induced seismicity Elwyn Gallowaya, Tyler Haucka, Hilary Corlettb, Dinu Pana˘ a, and Ryan Schultza,1 aAlberta Geological Survey, Alberta Energy Regulator, Edmonton, AB T8N 3A3, Canada; and bDepartment of Physical Sciences, MacEwan University, Edmonton, AB T5J 4S2, Canada Edited by Paul Segall, Stanford University, Stanford, CA, and approved August 21, 2018 (received for review May 1, 2018) During December 2011, a swarm of moderate-magnitude earth- bore [up to hundreds of meters (18–21)]. Furthermore, geo- quakes was induced by hydraulic fracturing (HF) near Cardston, mechanical modeling reveals that poroelastic changes from HF Alberta. Despite seismological associations linking these two processes, are transmitted only locally (20). These results are in direct the hydrological and tectonic mechanisms involved remain unclear. In contradiction to HF-related earthquakes that are located kilo- this study, we interpret a 3D reflection-seismic survey to delve into the meters away from the closest well bore (e.g., refs. 2, 6, 11, 22, and geological factors related to these earthquakes. First, we document a 23). Specific to the Cardston case, earthquakes (located on re- basement-rooted fault on which the earthquake rupture occurred that gional arrays) were observed within the uppermost crystalline ∼ – extends above the targeted reservoir. Second, at the reservoir’s strati- basement, 1.5 km deeper than the target upper Stettler Big SI Appendix graphic level, anomalous subcircular features are recognized along the Valley Reservoir zone ( ,Fig.S1); this observation is fault and are interpreted as resulting from fault-associated karst pro- further complicated by the fact that the fault slip response oc- ∼ – cesses.
    [Show full text]
  • Petroleum System Modeling of the Western Canada Sedimentary Basin – Isopach Grid Files
    Petroleum System Modeling of the Western Canada Sedimentary Basin – Isopach Grid Files By Debra K. Higley1, Mitchell E. Henry, and Laura N.R. Roberts Report Series 2005-1421 U.S. Department of the Interior U.S. Geological Survey 1 Inquiries about this publication should be addressed to: Debra K. Higley U.S. Geological Survey, MS 939, Box 25046 Denver Federal Center, Denver, CO 80225 Tel: 303-236-5791 Email: [email protected] 1 U.S. Department of the Interior Gale A. Norton, Secretary U.S. Geological Survey P. Patrick Leahy, Acting Director U.S. Geological Survey, Reston, Virginia 2005 For products and ordering information: World Wide Web: http://www.usgs.gov/pubprod Telephone: 1-888-ASK-USGS For more information on the USGS–the Federal source for science about the Earth, its natural and living resources, natural hazards, and the environment: World Wide Web: http://www.usgs.gov Telephone: 1-888-ASK-USGS Suggested citation: Debra K. Higley, Mitchell Henry, and Laura N.R. Roberts, 2006, Petroleum System Modeling of the Western Canada Sedimentary Basin – Isopach Grid Files: U.S. Geological Survey Report Series 2005-1421, web publication and associated data files. Any use of trade, product, or firm names is for descriptive purposes only, and does not imply endorsement by the U.S. government. Although this report is in the public domain, permission must be secured from the individual copyright owners to reproduce any copyrighted material contained within this report. 2 Contents Introduction …………………………………………………………….. 3 Data Processing Steps …………………………………………….……. 4 Acknowledgments ………………………………….………………..…. 5 Zmap-Format Grid Files ..………………………….………………..…. 5 References and Software Cited …………………….……………..…….
    [Show full text]
  • Subsurface Characterization of the Pembina-Wabamun Acid-Gas Injection Area
    ERCB/AGS Special Report 093 Subsurface Characterization of the Pembina-Wabamun Acid-Gas Injection Area Subsurface Characterization of the Pembina-Wabamun Acid-Gas Injection Area Stefan Bachu Maja Buschkuehle Kristine Haug Karsten Michael Alberta Geological Survey Alberta Energy and Utilities Board ©Her Majesty the Queen in Right of Alberta, 2008 ISBN 978-0-7785-6950-3 The Energy Resources Conservation Board/Alberta Geological Survey (ERCB/AGS) and its employees and contractors make no warranty, guarantee or representation, express or implied, or assume any legal liability regarding the correctness, accuracy, completeness or reliability of this publication. Any digital data and software supplied with this publication are subject to the licence conditions. The data are supplied on the understanding that they are for the sole use of the licensee, and will not be redistributed in any form, in whole or in part, to third parties. Any references to proprietary software in the documentation, and/or any use of proprietary data formats in this release, do not constitute endorsement by the ERCB/AGS of any manufacturer's product. If this product is an ERCB/AGS Special Report, the information is provided as received from the author and has not been edited for conformity to ERCB/AGS standards. When using information from this publication in other publications or presentations, due acknowledgment should be given to the ERCB/AGS. The following reference format is recommended: Bachu, S., Buschkuehle, M., Haug, K., Michael, K. (2008): Subsurface characterization of the Pembina-Wabamun acid-gas injection area; Energy Resources Conservation Board, ERCB/AGS Special Report 093, 60 p.
    [Show full text]
  • Geochemical Studies of Natural Gas, Part 1
    , ~ ( j ? j f GeoehelDieaI Studies of Natural Gas I PART m. INERT GASES IN WESTERN CANADIAN NATURAL GASES* ~ By BRIAN HITCHONt -j (This is the last of a Series of three Parts presented by the author tor publication in the Journal. Parts I I, and II appeared, in the Summer and Fall issues respectively.) ABSTRAGr 1 INTRODUcrION GEOCHEMISTRY AND ORIGIN OF In natural gases, the stratigra­ NITROGEN l phic and geographic variations in J T HIS paper is the third aud final Downloaded from http://onepetro.org/JCPT/article-pdf/2/04/165/2165406/petsoc-63-04-03.pdf by guest on 30 September 2021 1 the contents of both nitrogen and part of a series concerned with Before considering this subject heIiwn are of geochemical interest, further it is very important to con­ although only helium is of com­ the geochemistry of natural gas in 1 mercial importance. Nitrogen may Western Canada. It is a discussion sider the units in which the analy­ l originate from a great variety of of the inert gases nitrogen and he­ tical data are reported. Ideally, sources, including air, either orig­ lium. The first paper (1) dealt knowledge of the mass of the in­ J inally trapped in the sediments or '~ introduced dissolved in percolating with the hydrocarbons and the sec­ dividual components of natural groWldwaters, the denitrification of ond (2) with the acid gases. Due gases in the sedimentary basin is nitrogenous compounds or the de­ to their generally unreactive na­ desirable. From the reports of cay of certain radioactive minerals. ture, chemically, compared to hy­ Buckley and his co-workers (5) it In contrast, there exist radioac­ drocarbons or the acid gases, both may be surmised that the bulk of tive sources for all natural helium, nitrogen and helium are common­ the material is methane, with much and thus the problem of the migra­ lesser amounts .of other components.
    [Show full text]
  • Duhamel: a Seismic Analysis of Differential Compaction in a Leduc Reef
    The Duhamel reef Duhamel: A seismic analysis of differential compaction in a Leduc reef R.J. Brown, N.L. Anderson1, D.A. Cederwall2, Z. Sun, P.M. Manning3, and Q. Zhang ABSTRACT The Duhamel reef is an isolated Frasnian limestone bioherm of the Leduc Formation in south-central Alberta. Although Duhamel has a relatively small basal area (less than 12 km2), the reef rises some 275 m above the platform facies. The seismic data show what we interpret to be a raised peripheral reef rim, which appears to be elevated about 25 m relative to the interior of the reef. Raised rims are commonly considered to be diagenetic in origin, and attributed to differential compaction within reef complexes. Although late-stage accretionary growth about the periphery of the reef complex may have contributed to its development, we interpret the raised rim at Duhamel to be principally of secondary origin. This thesis is supported by the incorporated seismic and well-top data. The seismic data also suggest that the facies within the reef rim have a lower seismic velocity than the facies within the structurally lower reef interior, consistent with the observation that raised rims are generally more porous than the encircled and structurally lower lagoon and, therefore, constitute a preferred well-completion site. Optimal hydrocarbon recovery could be realized if all producing wells were drilled into the raised reef rim. Our data for Duhamel show that even relatively small reefs can exhibit raised rims and that these rims may be seismically visible, especially if one can incorporate multicomponent and/or 3-D data.
    [Show full text]
  • Upper Devonian and Lower Mississippian Stratigraphy
    UPPER DEVONIAN AND LOWER MISSISSIPPIAN STRATIGRAPHY OF NORTHWESTERN MONTANA: A PETROLEUM SYSTEM APPROACH by Paul S. Schietinger A thesis submitted to the Faculty and the Board of Trustees of the Colorado School of Mines in partial fulfillment of the requirements for the degree of Master of Science (Geology). Golden, Colorado Date _____________ Signed: ____________________________ Paul S. Schietinger Signed: ____________________________ Dr. Stephen A. Sonnenberg Thesis Advisor Golden, Colorado Date _____________ Signed: ____________________________ Dr. John D. Humphrey Professor and Head Department of Geology and Geological Engineering ii ABSTRACT The Upper Devonian and Lower Mississippian stratigraphy in the Antler foreland basin of northwestern Montana is the current focus of exploration for several petroleum companies. Conodont zonation indicates that the Exshaw Formation of southern Alberta and northern Montana is Late Devonian and Early Mississippian in age, and is stratigraphically equivalent to the Bakken Formation in the Williston Basin and the Sappington Member of the Three Forks in southwestern Montana. The Exshaw, Bakken and Sappington are lithologically similar. Each formation is comprised of basal organic-rich shale, middle dolomitic siltstone and sandstone, and upper organic-rich shale. The Three Forks Formation in northwestern Montana consists of two members: the older Logan Gulch Member and the younger Trident Member. The Logan Gulch is 100 ft to over 450 ft thick and was subdivided in this study into three facies that were deposited in salina to sabkha environments. Locally, the Logan Gulch is termed the Potlatch Anhydrite. The Three Forks Formation in northwestern Montana is equivalent to the Stettler and Big Valley formations in southern Alberta. The younger Trident Member was subdivided into two facies that are transgressive, open marine deposits.
    [Show full text]
  • Interpretation of 3D Multicomponent Seismic Data for Investigating Natural Fractures in the Horn River Basin, Northeast British Columbia
    Natural fracture analysis from 3D-3C seismic data Interpretation of 3D multicomponent seismic data for investigating natural fractures in the Horn River Basin, northeast British Columbia Abdallah Al-Zahrani* and Don Lawton ABSTRACT A 3D multicomponent seismic dataset from the Horn River Basin was assessed for mapping fractures. The data had good fold, offset and azimuth distributions and several approaches were used to interpret the distribution of natural fractures. In addition to amplitude mapping, PP and PS curvature maps enhanced the structural interpretation of the data and enabled the lateral continuity of faults and fractures to be mapped across the area of the seismic survey. Both horizon and volume based most negative curvature were effective in mapping fault and fracture trends within both Exshaw and Muskwa shale gas targets. At the Exshaw level, the curvature shows two main fault trends: northwest- southeast trending normal faults that dip toward the southwest, as well as northeast- southwest strike-slip faults. At the Muskwa level, the curvature image shows different major fault trends, namely north, northeast-south, southwest (normal and reverse faults), and northwest-southeast faults. Fractures interpreted using curvature attributes are close to the major faults and their dominant trends are generally parallel to the major faults in the area. INTRODUCTION Shale gas is one of the three types of unconventional gas plays that are growing rapidly in North America (Kuuskraa and Stevens, 2009). What make this play attractive to the oil companies compared with conventional resources is that the shale gas formations are continuous over large areas, with giant reserves, and the gas is enclosed within microporosity of the shales, and the rocks, in this case act as source, reservoir and trap at the same time (Kuuskraa and Stevens, 2009).
    [Show full text]
  • Conodont Biofacies in a Ramp to Basin Setting (Latest Devonian and Earliest Carboniferous) in the Rocky Mountains of Southernmost Canada and Northern Montana
    U. S. DEPARTMENT OF THE INTERIOR U. S. GEOLOGICAL SURVEY Conodont biofacies in a ramp to basin setting (latest Devonian and earliest Carboniferous) in the Rocky Mountains of southernmost Canada and northern Montana by Lauret E. Savoy1 and Anita G. Harris 2 Open-File Report 93-184 This report is preliminary and has not been reviewed for conformity with Geological Survey editorial standards or with the North American Stratigraphic Code. Any use of trade, product, or firm names is for descriptive purposes only and does not imply endorsement by the U.S. Government. \ Department of Geology and Geography, Mount Holyoke College, South Hadley, MA 01075 2 U.S. Geological Survey, Reston, VA 22092 1993 TABLE OF CONTENTS ABSTRACT 1 INTRODUCTION 2 LITHOSTRATIGRAPHY AND DEPOSITIONAL SETTING 2 CONODONT BIOSTRATIGRAPHY AND BIOFACIES 8 Palliser Formation 8 Exshaw Formation 13 Banff Formation 13 Correlative units in the Lussier syncline 15 PALEOGEOGRAPfflC SETTING 17 CONCLUSION 23 ACKNOWLEDGMENTS 23 REFERENCES CITED 24 APPENDIX 1 38 FIGURES 1. Index map of sections examined and major structural features of the thrust and fold belt 3 2. Correlation chart of Upper Devonian and Lower Mississippian stratigraphic units. 4 3. Selected microfacies of the Palliser Formation. 5 4. Type section of Exshaw Formation, Jura Creek. 6 5. Lower part of Banff Formation, North Lost Creek. 7 6. Conodont distribution in Palliser and Exshaw formations, Inverted Ridge. 9 7. Conodont distribution in upper Palliser and lower Banff formations, Crowsnest Pass. 11 8. Conodont distribution in upper Palliser, Exshaw, and lower Banff formations, composite Jura Creek - Mount Buller section. 12 9.
    [Show full text]
  • Forensic Chemostratigraphy in Geosteering Multilateral Wells: an Example from Devonian to Carboniferous-Aged Sequences in Southe
    URTeC Control ID # 1579996 1 URTeC Control ID Number: 1579996 Forensic Chemostratigraphy in Geosteering Multilateral Wells: An example from Devonian to Carboniferous-aged sequences in Southern Alberta Heather Stilwell1*, Nahysa Martinez1, Gemma Hildred1, Brian Zaitlin2 1. Chemostrat, Houston, TX, United States. 2. Native American Resource Partners, Calgary, AB, Canada. Copyright 2013, Unconventional Resources Technology Conference (URTeC) This paper was prepared for presentation at the Unconventional Resources Technology Conference held in Denver, Colorado, USA, 12-14 August 2013. The URTeC Technical Program Committee accepted this presentation on the basis of information contained in an abstract submitted by the author(s). The contents of this paper have not been reviewed by URTeC and URTeC does not warrant the accuracy, reliability, or timeliness of any information herein. All information is the responsibility of, and, is subject to corrections by the author(s). Any person or entity that relies on any information obtained from this paper does so at their own risk. The information herein does not necessarily reflect any position of URTeC. Any reproduction, distribution, or storage of any part of this paper without the written consent of URTeC is prohibited. Summary The results presented in this study test the efficacy of using whole-rock elemental data to characterize the stratigraphy penetrated when drilling lateral wells and use this information along with comparisons to a vertical offset well to stay in zone. This approach is tested in the Alberta Bakken Petroleum System (ABPS) in Southwestern Alberta, Canada, focusing on the Banff, Exshaw, Big Valley, and Stettler formations (Hildred et al 2013, Zaitlin 2013).
    [Show full text]
  • Assessment of Undiscovered Conventional Oil and Gas Resources of the Western Canada Sedimentary Basin, Canada, 2012
    Assessment of Undiscovered Conventional Oil and Gas Resources of the Western Canada Sedimentary Basin, Canada, 2012 The U.S. Geological Survey mean estimates of undiscovered conventional oil and gas resources from provinces in the Western Canada Sedimentary Basin of central Canada are 1,321 million barrels of oil, 25,386 billion cubic feet of gas, and 604 million barrels of natural gas liquids. Introduction Basin Province of Saskatchewan, southeastern Alberta, and southern Manitoba; and (3) the Rocky Mountain Deformed The U.S. Geological Survey (USGS) recently completed Belt Province of western Alberta and eastern British Colum- a geoscience-based assessment of undiscovered oil and gas bia (fig. 1). This report is part of the USGS World Petroleum resources of provinces within the Western Canada Sedimentary Resources Project assessment of priority geologic provinces Basin (WCSB) (table 1). The WCSB primarily comprises the of the world. The assessment was based on geoscience ele- (1) Alberta Basin Province of Alberta, eastern British Columbia, ments that define a total petroleum system (TPS) and associated and the southwestern Northwest Territories; (2) the Williston assessment unit(s) (AU). These elements include petroleum 129° 125° 121° 117° 113° 109° 105° 101° 97° 93° 89° Mackenzie Northern Interior Basins Foldbelt NUNAVUT NORTHWEST TERRITORIES 60° Hudson Bay HUDSON CANADA Basin BAY 58° EXPLANATION ALBERTA SASKATCHEWAN Middle and Upper Cretaceous Reservoirs AU Triassic through Lower Cretaceous Reservoirs AU 56° Alberta Basin Mississippian through Canadian Permian Reservoirs AU Shield Upper Devonian and Older Reservoirs AU 54° BRITISH MANITOBA COLUMBIA Williston Basin Edmonton 52° Rocky Mountain Deformed Belt Saskatoon ONTARIO CANADA 50° Area Calgary of map Regina Winnipeg UNITED STATES 48° 0 100 200 MILES WASHINGTON NORTH MONTANA UNITED STATES DAKOTA 0 100 200 KILOMETERS IDAHO Figure 1.
    [Show full text]
  • Devonian Petroleum Systems and Exploration Potential, Southern Alberta, Part 3 Core Conference
    Devonian Petroleum Systems and Exploration Potential, Southern Alberta, Part 3 Core Conference Andy Mort (1), Leonard Stevens (2), Richard Wierzbicki (2) Abstract Part 1: Devonian Petroleum Systems Dr. Andy Mort (Presentation 1) The Devonian in Southern Alberta has many porous and permeable reservoirs but few major hydrocarbon traps and limited exploration drilling. Part of the concern with this stacked carbonate dominated system is questions about source rock presence, quality, maturity, migration and charge. Previous work has shown there is proven source rock and hydrocarbon being generated in the Winnipegosis, Nisku, and Exshaw/Lower Banff in Southern Alberta. There is associated hydrocarbon production in the Lower Banff to Big Valley (Alberta Bakken), in the Nisku, and in the Winnipegosis. There are oil shows and oil stain in the Leduc and in the Beaverhill Lake equivalents and minor production from a DST in the Cooking Lake. Figure 1: Summary Chart: Source, Reservoir, Seal Intervals, Southern Alberta In the last few years Andy Mort of the GSC has been doing source rock evaluation of selected samples from core in the Beaverhill Lake and Winnipegosis in the study area. These samples show the presence of oil prone source rocks within these intervals. The oils evaluated in the Nisku, Leduc, Beaverhill Lake and Winnipegosis all indicate an evaporite related source. This paper is a synthesis of existing data and the new information and an evaluation of the remaining exploration potential of known reservoirs in the Devonian of Southern Alberta in light of the current understanding of the petroleum system. Part 2: Reservoirs and Traps Len Stevens, Rick Wierzbicki (Presentation 2) Existing and potential reservoirs in the Devonian of Southern Alberta will be reviewed in relation to the identified source rock intervals.
    [Show full text]