An Arborescent Lycopsid Stem Fragment from the Palliser
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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. -
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. -
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EVALUATION OF POTENTIAL STACKED SHALE-GAS RESERVOIRS ACROSS NORTHERN AND NORTH-CENTRAL WEST VIRGINIA ABSTRACT Jessica Pierson Moore1, Susan E. Pool1, Philip A. Dinterman1, J. Eric Lewis1, Ray Boswell2 Three shale-gas units underlying northern and north-central West Virginia create opportunity for one horizontal well pad to produce from multiple zones. The Upper Ordovician Utica/Point Pleasant, Middle Devonian Marcellus, and Upper Devonian Burket/Geneseo 1 West Virginia Geological & Economic Survey, 2 U.S. DOE National Energy Technology Laboratory construction of fairway maps for each play. Current drilling activity focuses on the Marcellus, with more than 1,000 horizontal completions reported through mid-2015. Across northern West Virginia, the Marcellus is 40 to 60 ft. thick with a depth range between 5,000 and 8,000 ft. Total Organic Carbon (TOC) REGIONAL GEOLOGY is generally 10% or greater. Quartz content is relatively high (~60%) and clay content is low (~30%). Reservoir pressure estimates STRUCTURAL CROSS-SECTION FROM HARRISON CO., OHIO TO HARDY CO., WEST VIRGINIA range from 0.3 to 0.7 psi/ft and generally increase to the north. Volumetric assessment of the Marcellus in this area yields preliminary NW SE 81° 80° 79° 78° 1 2 3 4 5 original gas-in-place estimates of 9 to 24 Bcf/mi2. OH WV WV WV WV Pennsylvania Figure 2.—Location of seismic sections, wells, and major basement Harrison Co. Marshall Co. Marion Co. Preston Co. Hardy Co. 34-067-20103 47-051-00539 47-049-00244 47-077-00119 47-031-00021 UTICA SHALE PLAY GR 41 miles GR 36 miles GR 27 miles GR 32 miles GR Westmoreland The Burket /Geneseo interval is approximately 15 to 40 ft thick across the fairway. -
Carboniferous Coal-Bed Gas Total Petroleum System
U.S. Geological Survey Open-File Report 2004-1272 Assessment of Appalachian Basin Oil and Gas Resources: Carboniferous Coal-bed Gas Total Petroleum System Robert C. Milici U.S. Geological Survey 956 National Center Reston, VA 20192 1 Table of Contents Abstract Introduction East Dunkard and West Dunkard Assessment units Introduction: Stratigraphy: Pottsville Formation Allegheny Group Conemaugh Group Monongahela Group Geologic Structure: Coalbed Methane Fields and Pools: Assessment Data: Coal as a source rock for CBM: Gas-In-Place Data Thermal Maturity Generation and Migration Coal as a reservoir for CBM: Porosity and Permeability Coal Bed Distribution Cumulative Coal Thickness Seals: Depth of Burial Water Production Cumulative Production Data: Pocahontas basin and Central Appalachian Shelf Assessment Units Introduction: Stratigraphy: Pocahontas Formation New River Formation Kanawha Formation 2 Lee Formation Norton Formation Gladeville Sandstone Wise Formation Harlan Formation Breathitt Formation Geologic Structure: Coalbed Methane Fields: Coal as a Source Rock for CBM Gas-in-Place Data Thermal Maturity Generation and Migration Coal as a Reservoir for CBM: Porosity and Permeability Coal Bed Distribution Cumulative Coal Thickness Seals: Depth of Burial Water Production Cumulative Production Data: Assessment Results: Appalachian Anthracite and Semi-Anthracite Assessment Unit: Pennsylvania Anthracite Introduction: Stratigraphy: Pottsville Formation Llewellyn Formation Geologic Structure: Coal as a Source Rock for CBM: Gas-In-Place-Data Thermal -
Implications of Thermal Events on Thrust Emplacement Sequence in the Appalachian Fold and Thrust Belt: Some New Vitrinite Reflectance Data Sharon E
University of Kentucky UKnowledge Center for Applied Energy Research Faculty Center for Applied Energy Research Publications 11-1990 Implications of Thermal Events on Thrust Emplacement Sequence in the Appalachian Fold and Thrust Belt: Some New Vitrinite Reflectance Data Sharon E. Lewis Montana Tech James C. Hower University of Kentucky, [email protected] Right click to open a feedback form in a new tab to let us know how this document benefits oy u. Follow this and additional works at: https://uknowledge.uky.edu/caer_facpub Part of the Geology Commons Repository Citation Lewis, Sharon E. and Hower, James C., "Implications of Thermal Events on Thrust Emplacement Sequence in the Appalachian Fold and Thrust Belt: Some New Vitrinite Reflectance Data" (1990). Center for Applied Energy Research Faculty Publications. 11. https://uknowledge.uky.edu/caer_facpub/11 This Article is brought to you for free and open access by the Center for Applied Energy Research at UKnowledge. It has been accepted for inclusion in Center for Applied Energy Research Faculty Publications by an authorized administrator of UKnowledge. For more information, please contact [email protected]. Implications of Thermal Events on Thrust Emplacement Sequence in the Appalachian Fold and Thrust Belt: Some New Vitrinite Reflectance Data Notes/Citation Information Published in The Journal of Geology, v. 98, no. 6, p. 927-942. © 1990 by The nivU ersity of Chicago. All rights reserved. The opc yright holder has granted the permission for posting the article here. Digital Object Identifier (DOI) https://doi.org/10.1086/629462 This article is available at UKnowledge: https://uknowledge.uky.edu/caer_facpub/11 IMPLICATIONS OF THERMAL EVENTS ON THRUST EMPLACEMENT SEQUENCE IN THE APPALACHIAN FOLD AND THRUST BELT: SOME NEW VITRINITE REFLECTANCE DATAl SHARON E. -
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. -
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). -
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. -
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). -
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. -
Petroleum Systems and Quantitative Oil Chemometric Models for Heavy Oils in Alberta and Saskatchewan to Characterize Oil- Source Correlations Fay, M., Larter, S
Petroleum Systems and Quantitative Oil Chemometric Models for Heavy Oils in Alberta and Saskatchewan to Characterize Oil- Source Correlations Fay, M., Larter, S. Bennett, B., Snowdon, L., Fowler, M. Produced oils from western Canada in the Kindersley, Lloydminster and Cold Lake heavy oil belt are commonly believed to be genetically sourced from the Type IIS Exshaw shales (south central Alberta) based on the quantitative molecular geochemistry of >100 produced oils from previous work (Obermajer et al., 2004), plus hundreds of produced oil samples from the surrounding basin (Deroo et al., 1977; Brooks et al., 1988; Allan and Creaney, 1991; Creaney and Allan, 1992; Riediger et al., 1993; Osadetz et al., 1994; Li et al., 1996, 1997; Karavas et al., 1998; Stevenson, 1998; Riediger et al., 1999; Manzano-Kareah et al., 2004). However, seven potential source rocks that are thermally mature exist in south central Alberta through the Lower Cretaceous and Paleozoic section, and this study shows that multiple oil families do in fact exist in the heavy oil belt. Oils sourced from rocks other than the Exshaw shale surrounding the heavy oil belt based on biomarker and molecular composition include Ostracode and Duvernay (Q and D) oils observed in the Provost region (Riediger et al., 1999). Also, the Banff/Madison (M) and Exshaw oils are observed in the Medicine Hat region (Manyberries) (Manzano- Kareah et al., 2004). The potential for oil charge from other source rocks in the region, may in part, explain some of the minor but outstanding differences in biomarker compositions, molecular concentrations (e.g. diamondoids; Fay, 2010) and isotope evidence (Marcano et al., 2011) that are observed in produced oils from the heavy oil belt (Obermajer et al., 2004). -
Bibliography of the Publications of Patricia G. Gensel
Bibliography of the Publications of Patricia G. Gensel Compiled by William R. Burk, Ian Ewing, Elena M. Feinstein, Joy Mermin, Drew Posny, and Laurel E.D. Roe 1969 [Abstract]. (with H.N. Andrews and A.E. Kasper). An early Devonian flora from northern Maine, U.S.A., p. 4. In Abstracts of the Papers Presented at the XI International Botanical Congress, August 24-September 2, 1969 and the International Wood Chemistry Symposium, September 2-4, 1969, Seattle, Washington. [XI International Botanical Congress], Seattle, Washington. 260 pp. (with Andrew Kasper and Henry N. Andrews). Kaulangiophyton, a new genus of plants from the Devonian of Maine. Bulletin of the Torrey Botanical Club 96: 265-276. 1972 (with Tom L. Phillips and Henry N. Andrews). Two heterosporous species of Archaeopteris from the Upper Devonian of West Virginia. Palaeontographica, Abt. B, Palaophytol. 139: 47-71 + plates 36-45. 1973 [Abstract]. (with Henry Andrews and William Forbes). An apparently heterosporous plant from the Middle Devonian of New Brunswick. American Journal of Botany 60(4, supplement): 15. A new plant from the Lower Mississippian of southwestern Virginia. Palaeontographica, Abt. B, Palaophytol. 142: 137-153 + plates 33-40 + folder. [Abstract]. A new plant from the Lower Mississippian of southwestern Virginia. American Journal of Botany 60(4, supplement): 16-17. 1974 (with Henry N. Andrews and William H. Forbes). An apparently heterosporous plant from the Middle Devonian of New Brunswick. Palaeontology 17: 387-408 + plates 52-57. 1975 (with Henry N. Andrews and Andrew E. Kasper). A new fossil plant of probable intermediate affinities (Trimerophyte-Progymnosperm). Canadian Journal of Botany 53: 1719-1728.