Oil and Gas Geoscience Reports 2013
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The Duvernay Resource
AB & BC Montney Technical Session Thursday, February 20th, 2020 801 Seventh +15 – 667 7 Street SW THANK YOU TO OUR SPONSORS! AB & BC Montney Day An Update on AB and BC’s Montney Resource Play February 20th, 2020 AB & BC Montney Technical Session Thursday, February 20th, 2020 801 Seventh +15 – 667 7 Street SW QUESTIONS & ANSWERS FORMAT For this workshop, we will use CSUR`s website to make it easy for everyone to share their ideas, opinions and most importantly, questions! How it works: 1) Go to our website through the respective link: Montney Overview Session visit: https://www.csur.com/question/mo Technical Session #1 Session visit: https://www.csur.com/question/1 Technical Session #2 Session visit: https://www.csur.com/question/2 Technical Session #3 Session visit: https://www.csur.com/question/3 2) Submit your question and it will be displayed on the screen 3) Please note that “write your answer” is where you should write your question and submit your answer will complete and post your question to the speaker(s). 4) Please, make sure you are in the right link and session. 1 Page Sponsored by: AB & BC Montney Technical Session Thursday, February 20th, 2020 801 Seventh +15 – 667 7 Street SW AGENDA 08:00 – 08:25 Registration, Networking and Breakfast 08:25 – 08:30 Welcome: Al Kassam and Dan Allan Montney Play Update Moderator: Karen Spencer, University of Calgary Moderator Bio: Ms. Spencer is an experienced oil and gas Professional Engineer with a Master’s Degree in Public Policy. Her unique background includes business and financial knowledge, strong technical experience, and a policy and regulatory focus. -
Helium in Northeastern British Columbia
HELIUM IN NORTHEASTERN BRITISH COLUMBIA Elizabeth G. Johnson1 ABSTRACT Global demand for helium is increasing at a time when world reserves are in decline. The price of grade A helium has quadrupled in the past 12 years. Liquefied natural gas (LNG) processing can be used to capture helium as a value-added byproduct at concentrations as low as 0.04% by volume. The Slave Point, Jean Marie (Redknife) and Wabamun formations of northeastern British Columbia preferentially have helium associated with many of their natural gas pools. The mechanism for this accumulation appears to be flow in hydrothermal brines from helium-enriched basement granitic rocks along deeply seated faults. Separately, the Evie member of the Horn River Formation also has anomalous helium accumulation in its shale gas related to uranium decay in organic-rich shales. Johnson, E.G. (2012): Helium in northeastern British Columbia; in Geoscience Reports 2013, British Columbia Ministry of Natural Gas Development, pages 45–52. 1Geoscience and Strategic Initiatives Branch, British Columbia Ministry of Natural Gas Development, Victoria, British Columbia; [email protected] Key Words: Helium, LNG, Jean Marie, Slave Point, Wabamun, Evie, Horn River Formation INTRODUCTION optical fibre technology (8% of global use; Peterson and Madrid, 2012; Anonymous, 2012). Helium is a nonrenewable resource that has developed In recognition of its strategic value, the United States important strategic value. Helium (atomic number of 2) ex- 4 created the Federal Helium Reserve in the Bush Dome Res- ists primarily as the stable isotope, He, which is produced ervoir, Texas, in 1925. The primary source for the Federal on the earth through alpha decay of radioactive elements Helium Reserve is the world-class Hugoton Reservoir in such as uranium and thorium. -
Pa 62-15.Pdf
GEOLOGICAL SURVEY OF CANADA CANADA PAPER 62-15 MIDDLE DEVONIAN AND OLDER PALAEOZOIC FORMATIONS OF SOUTHERN DISTRICT OF MACKENZIE AND ADJACENT AREAS B y Helen R. Belyea and A. W. Norris DEPARTMENT OF MINES AND TECHNICAL SURVEYS CANADA CONTENTS Page Introduction. • . • . • • . • • . • • . • • 1 Ordovician and older(?) . • . • . • • • • • . • . • 1 Old Fort Island Formation........................... 2 Mirage Point Formation ...•...•..•. ,................ 2 Pre-Chinchaga beds . • • • . • • . • . • • • • . • . • • . • 3 Middle Devonian • . • . • . • • . • . • . • . • • . • 3 Chinchaga Formation ..•.•.••.•........•.•••••. • . • • • 3 Keg River Formation . • . • . • . • . • . • • • . 4 Muskeg Formation.................................. 5 Pine Point Formation................. .............. 5 Lonely Bay Formation • . • • • • . • . • • • • . • • 9 Sulphur Point Formation . • • . • . • . • . • . • . • • . • • . • . 10 Presqu 1ile Formation............................... 11 Watt Mountain Formation. • . • • • • . • . • . • • • • • . • . • . 12 Slave Point Formation . • • . • • • . • • . • • • • • • . • • • 12 Horn River Formation . • . • • . • • . • • • . • . • 14 References.............................................. 16 Appendix-logs of wells . • • • . • • • • • • . • . • • . • • • • • . • • . 19 Illustrations Figure 1. Formational nomenclature ••......•... .. .....•. Frontispiec e 2. Correla tion diagram from Pan American et al. A-1 Snake River c-28-D well to Imperial Triad Davidson C reek P-2 well .. ... ... •. .... ... .. in pocket 3. Correlation -
Sedimentology and Ichnology of Upper Montney Formation Tight Gas Reservoir, Northeastern British Columbia, Western Canada Sedimentary Basin
International Journal of Geosciences, 2016, 7, 1357-1411 http://www.scirp.org/journal/ijg ISSN Online: 2156-8367 ISSN Print: 2156-8359 Sedimentology and Ichnology of Upper Montney Formation Tight Gas Reservoir, Northeastern British Columbia, Western Canada Sedimentary Basin Edwin I. Egbobawaye Department of Earth and Atmospheric Sciences, University of Alberta, Edmonton, Canada How to cite this paper: Egbobawaye, E.I. Abstract (2016) Sedimentology and Ichnology of Upper Montney Formation Tight Gas Re- Several decades of conventional oil and gas production in Western Canada Sedi- servoir, Northeastern British Columbia, mentary Basin (WCSB) have resulted in maturity of the basin, and attention is shift- Western Canada Sedimentary Basin. Inter- ing to alternative hydrocarbon reservoir system, such as tight gas reservoir of the national Journal of Geosciences, 7, 1357- 1411. Montney Formation, which consists of siltstone with subordinate interlaminated http://dx.doi.org/10.4236/ijg.2016.712099 very fine-grained sandstone. The Montney Formation resource play is one of Cana- da’s prime unconventional hydrocarbon reservoir, with reserve estimate in British Received: January 19, 2016 Columbia (Natural Gas reserve = 271 TCF), Liquefied Natural Gas (LNG = 12,647 Accepted: December 23, 2016 Published: December 28, 2016 million barrels), and oil reserve (29 million barrels). Based on sedimentological and ichnological criteria, five lithofacies associations were identified in the study interval: Copyright © 2016 by author and Lithofacies F-1 (organic rich, wavy to parallel laminated, black colored siltstone); Li- Scientific Research Publishing Inc. thofacies F-2 (very fine-grained sandstone interbedded with siltstone); Lithofacies This work is licensed under the Creative Commons Attribution International F-3A (bioturbated silty-sandstone attributed to the Skolithos ichnofacies); Lithofacies License (CC BY 4.0). -
Geochemical, Petrophysical and Geomechanical Properties Of
Geochemical, petrophysical and geomechanical properties of stratigraphic sequences in Horn River Shale, Middle and Upper Devonian, Northeastern British Columbia, Canada by TIAN DONG A thesis submitted in partial fulfillment of the requirements for the degree of Doctor of Philosophy Department of Earth and Atmospheric Sciences University of Alberta © Tian Dong, 2016 ABSTRACT The Middle and Upper Devonian Horn River Shale, comprising the Evie and Otter Park members and the Muskwa Formation, northeast British Columbia, Canada is recognized as a significant shale gas reservoir in the Western Canada Sedimentary Basin. However, many aspects of this shale formation have not been adequately studied, and the published geochemical, petrophysical and geomechanical data are limited. This work aims to document the controls of geochemical composition variation on petrophysical and geomechanical properties and the relationship of rock composition to lithofacies and stratigraphic sequences. A detailed core-based sedimentological and wireline log analysis was conducted by my colleague Dr. Korhan Ayranci as a parallel study, in order to classify lithofacies, interpret depositional environments and establish sequence stratigraphic framework across the basin. Major and trace elements concentrations, key trace element ratios and Corg-Fe-S relationships were used to understand the effect of sea level fluctuation on detrital flux, redox conditions, productivity and therefore organic carbon enrichment patterns. Detrital sediment flux indicated by the concentration of aluminum and titanium to the basin was found to be higher during transgressions than regressions. Redox conditions, exhibiting strong correlation to TOC content, were the primary controls on the organic carbon deposition. The bottom water conditions are more anoxic during transgressions than regressions. -
Facies Analysis and Ichnology of the Upper Montney Formation in Northeastern British Columbia
Facies Analysis and Ichnology of the Upper Montney Formation in Northeastern British Columbia A.E. Gegolick, University of Alberta, Edmonton, AB, [email protected] C.M. Furlong, University of Alberta, Edmonton, AB T.L. Playter, University of Alberta, Edmonton AB D.T. Prenoslo, University of Alberta, Edmonton, AB M.K. Gingras, University of Alberta, Edmonton, AB J.-P. Zonneveld, University of Alberta, Edmonton, AB Gegolick, A.E., Furlong, C.M., Playter, T.L., Prenoslo, D.T., Gingras, M.K. and Zonneveld, J.-P. (2016): Facies analysis and ichnology of the upper Montney Formation in northeastern British Columbia; in Geoscience BC Summary of Activities 2015, Geoscience BC, Report 2016-1, p. 111–116. Introduction tion are very heterogeneous. This refers to the several sedi- mentological and ichnological factors that result in highly The Lower Triassic Montney Formation is a world-class variable reservoir characteristics (e.g., Clarkson et al., unconventional hydrocarbon reservoir hosted primarily in 2012; Wood, 2013). Subtle changes in the rock fabric both low-permeability siltstone and to a lesser extent, very fine laterally and vertically result in the compartmentalization grained sandstone. To date, most published research has fo- of resources within zones of distinctly different porosity cused on conventional plays in the eastern part of the basin, and permeability values. Another controlling factor on res- such as the Montney Formation turbidite interval and ervoir properties is the occurrence of bioturbation. Biogen- shoreface clastic and bioclastic units proximal to the Trias- ic permeability is important to reservoir properties because sic subcrop edge (Davies et al., 1997; Moslow, 2000; it has the ability to either enhance or reduce permeability or Zonneveld et al., 2010a). -
Pore-Scale Variability and Fluid Distributions in Montney Formation: New Insights from Three-Dimensional Reservoir Characterization and Modeling Sochi C
Pore-scale variability and fluid distributions in Montney Formation: New insights from three-dimensional reservoir characterization and modeling Sochi C. Iwuoha, Per K. Pedersen, and Christopher R. Clarkson Tight Oil Consortium, Department of Geoscience, University of Calgary, Alberta, Canada Fig.1 Montney Formation extent in Alberta and northeastern British Columbia Summary In the Triassic Montney Montney Formation in Alberta and British Columbia (Fig. 1 and 2), different fluids are produced (oil, gas condensate, dry gas). This study focuses on a Montney producing area in west central Alberta (Fig. 1) where thermal maturity and depth data are inconsistent with the production of different fluids. This evaluation reviews the potential control of pore size on fluid distributions in the study area. Our workflow utilizes well logs, core data and three-dimensional (3D) geological modeling techniques to map facies, petrophysical properties and pore size distribution in the study area. Our results show that gas and condensate producing areas have mean dominant pore throat sizes of 20 - 30nm with a wider range of pore size distribution (up to 55nm) occurring in the condensate producing area. The mainly oil producing area shows a lower mean dominant pore size of 10 - 20nm with a marked Fig. 2. Montney Formation and some overlying increase in siltstone and shale heterolithics eastwards. Although porosities in Cretaceous and Jurassic stratigraphy in the study area TVDSS GR RHOB the oil trend are relatively higher (mean ~4.5%) than those within the gas and 0 200 1.95 2.95 Kcardium Kcard_ss condensate producing areas (mean ~3% and 4% respectively), permeabilities Kkaskapau are lower in the oil trend (mean 0.27µD) compared to the gas (0.32µD) and condensate (0.48µD) producing areas. -
Shale Units of the Horn River Formation, Horn River Basin and Cordova Embayment, Northeastern British Columbia Sara Mcphail
Shale units of the Horn River Formation, Horn River Basin and Cordova Embayment, Northeastern British Columbia Sara McPhail, Warren Walsh and Cassandra Lee British Columbia Ministry of Energy, Mines and Petroleum Resources Patrick A. Monahan, Monahan Petroleum Consulting/Penn West Energy Trust The Horn River Basin (HRB) and Cordova Embayment (CE) of northeastern British Columbia are bordered by the reef-fringed carbonate platforms of the Middle Devonian Upper Keg River, Sulphur Point, and Slave Point formations (Appendix A). Basinal shales laterally-equivalent to these carbonate units comprise the Evie, Otter Park, and Muskwa members of the Horn River Formation (Figure 1). These shales, particularly those of the Evie and Muskwa members that have high silica and organic contents are the target of a developing shale gas play. Figure 1: Middle and basal Upper Devonian units of the HRB and CE. basinal succession platform succession Fort Simpson Shale Muskwa Muskwa Upper Devonian Otter Park Slave Point Slave Pt/Sulphur Point basinal Middle Devonian equivalents Sulphur Point Evie Upper Keg River Lower Keg River Exploration activity for these shales in this lightly developed region has developed dramatically over the past two years (Adams et al, 2007). Total bonus paid for rights to the Horn River Shale exceeded $400 million in 2007. Experimental schemes, which allow an operator to hold well data confidential for 3 years, have been granted to several companies within the HRB and CE, and 48 wells have been licensed or drilled to test these targets since 2004 (Appendix A). Few results are available, but the recompletion of a vertical well in d-60-I/94-O-9 in the HRB resulted in a gas flow of 13 e3m3/, and EOG recently announced gas flow of 140 e3m3/d from their horizontal well in a-26-G/94-O-9. -
Depositional Framework of the Lower Triassic Montey Formation, West-Central Alberta and Northeastern British Columbia
Depositional Framework of the Lower Triassic Montey Formation, West-central Alberta and Northeastern British Columbia John-Paul Zonneveld1, Martyn Golding2, Thomas F. Moslow3, Michael J. Orchard4, Tiffany Playter1, Nick Wilson5 1Department of Earth and Atmospheric Sciences, University of Alberta, 1-26 Earth Sciences Building, Edmonton, Alberta T6G 2E3, Canada; [email protected] 2University of British Columbia 3Pace Oil and Gas Ltd., Calgary Murphy Oil Corporation 4Geological Survey of Canada, Vancouver, British Columbia 5Murphy Oil Corporation The Lower Triassic Montney Formation is a complex succession dominated by siltstone and sandstone with shale and bioclastic packstone / grainstone also occurring in some areas and intervals. The Montney was deposited on the western margin of the North American Craton with the thickest accumulation occurring in the vicinity of the collapsed Peace River Arch (Davies et al., 1997) (Figure 1). Deposition in the Montney Formation occurred in a wide variety of depositional environments, from distal offshore successions including turbidite channel and fan complexes to lower to upper shoreface deltaic intervals and estuarine successions (Mederos, 1995; Markhasin, 1997; Davies et al., 1997; Kendall, 1999; Moslow, 2000; Panek, 2000; Zonneveld et al., 2010a; 2010b). The Montney was deposited in an arid, mid- latitudinal setting, west of an extensive, low gradient continental interior. The aridity of the region, combined with exceptionally long transport distances from sediment source areas, resulted in dominantly fine-grained clastic deposition within all Montney facies associations (i.e. very little sand coarser than ~125 µm). Environmental conditions also dictated that deposition of diagenetic clay minerals was not favored and thus most Montney successions consist of either siltstone or very fine-grained sandstone. -
Hydraulic Fracturing and Flow-Back Simulation in Unconventional Tight Reservoirs
University of Calgary PRISM: University of Calgary's Digital Repository Graduate Studies The Vault: Electronic Theses and Dissertations 2016 Hydraulic Fracturing and Flow-back Simulation in Unconventional Tight Reservoirs Lin, Menglu Lin, M. (2016). Hydraulic Fracturing and Flow-back Simulation in Unconventional Tight Reservoirs (Unpublished master's thesis). University of Calgary, Calgary, AB. doi:10.11575/PRISM/26401 http://hdl.handle.net/11023/2965 master thesis University of Calgary graduate students retain copyright ownership and moral rights for their thesis. You may use this material in any way that is permitted by the Copyright Act or through licensing that has been assigned to the document. For uses that are not allowable under copyright legislation or licensing, you are required to seek permission. Downloaded from PRISM: https://prism.ucalgary.ca UNIVERSITY OF CALGARY Hydraulic Fracturing and Flow-back Simulation in Unconventional Tight Reservoirs by Menglu Lin A THESIS SUBMITTED TO THE FACULTY OF GRADUATE STUDIES IN PARTIAL FULFILMENT OF THE REQUIREMENTS FOR THE DEGREE OF MASTER OF SCIENCE GRADUATE PROGRAM IN CHEMICAL AND PETROLEUM ENGINEERING CALGARY, ALBERTA APRIL, 2016 © Menglu Lin 2016 Abstract At present, combination of the multistage hydraulic fracturing and horizontal wells has become a widely used technology in stimulating unconventional tight reservoirs in Western Canadian Sedimentary Basin (WCSB). It is important to understand hydraulic fracture propagation mechanism, effects of their properties and controlling factors affecting flow-back recovery. In this thesis, based on tight reservoir models in WCSB, firstly we examine different fracture geometry distributions and further discuss their effects on well productions. Then reservoir simulation coupled with rock geomechanics is employed to perform dynamic hydraulic fracturing for predicting hydraulic fracture dimensions and simulating fracturing liquid distribution. -
Horn River Basin Aquifer Characterization Project Phase 2 Geological Report
HORN RIVER BASIN AQUIFER CHARACTERIZATION PROJECT PHASE 2 GEOLOGICAL REPORT Prepared for: HORN RIVER BASIN PRODUCERS GROUP GEOSCIENCE B.C. September, 2011 Petrel Robertson Consulting Ltd. 500, 736 – 8th Avenue S.W. Calgary, Alberta T2P 1H4 www.petrelrob.com EXECUTIVE SUMMARY Geoscience BC‟s Phase 1 Horn River Basin Aquifer Characterization Project (PRCL, 2010) concluded that the Mississippian Debolt-Rundle carbonate platform demonstrates the best potential to act as a productive water source and sink for the completions activities of producers in the Horn River Basin. Phase 2 of the study reinforces this conclusion and adds data from new wells drilled since completion of the Phase 1 report. Resulting map revisions increase the overall enhanced reservoir volume, particularly in the centre of the basin, where well control had been sparse. The Debolt-Rundle carbonate platform has been subdivided into four units that are mappable across the basin: the lower, middle and upper Rundle, capped by the Debolt. At the top of the upper Rundle and Debolt, reservoir quality is enhanced by leaching and dolomitization beneath the pre-Cretaceous unconformity, forming a unit referred to as the “Detrital Zone”. The highest-quality and most continuous water-bearing reservoirs thus occur within the upper Rundle and Debolt where they subcrop beneath the pre-Cretaceous unconformity in the eastern part of the Horn River Basin. Reservoir quality mapping was focused on the Debolt-Rundle succession. Net porous reservoir and porosity-thickness maps from the Phase 1 study were updated using sample cuttings observations and well logs from Phase 2 wells. As in Phase 1, approximations regarding reservoir quality had to be applied because of the highly heterogeneous nature of the “Detrital Zone”. -
Modeling Source Rock Distribution, Thermal Maturation, Petroleum Retention and Expulsion: the Case of the Western
See discussions, stats, and author profiles for this publication at: https://www.researchgate.net/publication/301200555 Modeling source rock distribution, thermal maturation, petroleum retention and expulsion: The Case of the Western... Poster · April 2016 DOI: 10.13140/RG.2.1.4506.9201 CITATIONS READS 0 172 5 authors, including: Pauthier Stanislas Benoit Chauveau IFP Energies nouvelles IFP Energies nouvelles 6 PUBLICATIONS 1 CITATION 28 PUBLICATIONS 27 CITATIONS SEE PROFILE SEE PROFILE Tristan Euzen W. Sassi ifp technologies (Canada) Inc., Calgary, Canada IFP Energies nouvelles 49 PUBLICATIONS 116 CITATIONS 75 PUBLICATIONS 1,181 CITATIONS SEE PROFILE SEE PROFILE Some of the authors of this publication are also working on these related projects: Biogenic Gas Modeling View project Mechanical model of fractured hydrocarbon reservoirs View project All content following this page was uploaded by Mathieu Ducros on 11 April 2016. The user has requested enhancement of the downloaded file. Renewable energies | Eco-friendly production | Innovative transport | Eco-efficient processes | Sustainable resources Modeling source rock distribution, thermal maturation, petroleum retention and expulsion: The Case of the Western Canadian Sedimentary Basin (WCSB) Stanislas Pauthier1, Mathieu Ducros1, Benoit Chauveau1, Tristan Euzen2, William Sassi1 1 IFP Énergies nouvelles, Geosciences Division, Rueil Malmaison, France 2 IFP Technologies (Canada) Inc., Calgary, AB, Canada. Contact: [email protected] Introduction Basin modeling is a multi-disciplinary approach We present solutions that allow to produce integrating varied sources of geological data. calibrated and geologically meaningful maps of Therefore, the main objective is to build models heat flow, initial TOC and hydrogen index based on consistent with the available information. both well measurements and on the geological information included in the basin model.