DOCSLIB.ORG

Hydraulic Fracturing and Flow-Back Simulation in Unconventional Tight Reservoirs

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
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 Hydraulic Fracturing and Flow-back Simulation in Unconventional Tight Reservoirs (Unpublished master's thesis).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. At last, Design of Experiments and response surface methodology are conducted to explore well operational parameters affecting flow-back recovery and net present value (NPV). This study provides new insights on the hydraulic fracturing and can be a reference for fracturing treatments in unconventional tight reservoirs. ii Acknowledgements I would like to thank my nice supervisor, Dr. Shengnan (Nancy) Chen and my generous co- supervisor, Dr. Zhangxing (John) Chen for their guidance, patience and support during my master study at the University of Calgary. I would also like to thank my respectable committee members: Dr. Christopher Clarkson, Dr. Hossein Hejazi and Dr. Laurence R. Lines for reviewing my thesis and giving insightful comments. I would like to acknowledge the support from the Natural Sciences and Engineering Research Council (NSERC) of Canada and Seven Generations Energy Ltd. I also want to acknowledge the help from Reservoir Simulation Group (RSG) and Department of Chemical and Petroleum Engineering. In addition, I would like to extend the gratitude to all my great friends for making the experience at UCalgary wonderful. In particular, thank you to Mr. Jinze Xu, Mr. Mingxu Ma, and my officemates, Mr. Francisco J. Pacheco and Mr. Muhammad Fowaz Ikram, for their help on my master research. Last but not the least, I appreciate the love, encouragement and support from my family. iii Table of Contents Abstract ............................................................................................................................... ii Acknowledgements ............................................................................................................ iii Table of Contents ............................................................................................................... iv List of Tables ..................................................................................................................... vi List of Figures and Illustrations ........................................................................................ vii List of Symbols, Abbreviations and Nomenclature ........................................................... xi CHAPTER ONE: INTRODUCTION ..................................................................................1 1.1 Background ................................................................................................................1 1.1.1 Tight Resource in Western Canadian Sedimentary Basin .................................1 1.1.2 Hydraulic Fracturing in Tight Reservoirs ..........................................................8 1.2 Research Objectives .................................................................................................14 1.3 Thesis Organization .................................................................................................14 CHAPTER TWO: EFFECT OF FRACTURE GEOMETRY ON WELL PRODUCTION16 2.1 Abstract ....................................................................................................................16 2.2 Introduction ..............................................................................................................17 2.3 Geological Model ....................................................................................................18 2.4 Numerical Simulation Model ...................................................................................20 2.4.1 Reservoir and Fluid Properties ........................................................................20 2.4.2 Relative Permeability Curves and Initial Condition ........................................22 2.4.3 Hydraulic Fracture – Local Grid Refinement ..................................................23 2.4.4 History Matching .............................................................................................24 2.4.5 Microseismic Data ...........................................................................................25 2.4.6 Hydraulic Fracture Geometry Scenarios .........................................................27 2.4.6.1 Scenario 1 ..............................................................................................28 2.4.6.2 Scenario 2 ..............................................................................................29 2.4.6.3 Scenario 3 ..............................................................................................30 2.5 Results and Discussion ............................................................................................32 2.5.1 The Effect of Non-Darcy Flow in Hydraulic Fractures ...................................32 2.5.2 Ideal Planar Fractures - Effect of Main Fracture Length and Conductivity ....33 2.5.3 Effect of Fracture Geometry ............................................................................35 2.5.4 Effect of Secondary Fracture Permeability .....................................................37 2.6 Flow Regime Analysis .............................................................................................40 2.7 Conclusions ..............................................................................................................43 CHAPTER THREE: APPLICATION OF RESERVOIR FLOW SIMULATION COUPLED WITH ROCK GEOMECHANICS ..........................................................................45 3.1 Abstract ....................................................................................................................45 3.2 Introduction ..............................................................................................................46 3.3 Coupled Reservoir Simulation and Barton-Bandis Model ......................................48 3.4 Field Background .....................................................................................................50 3.4.1 Recombined Fluid Analysis ............................................................................51 iv 3.5 Fracturing Simulation ..............................................................................................52 3.6 Reservoir Simulation ...............................................................................................57 3.7 Results and Discussion ............................................................................................60 3.7.1 Effect of Non-Darcy Flow in Hydraulic Fracture ...........................................60 3.7.2 Effect of Pressure-Dependent Permeability of Natural Fractures ...................62 3.7.3 Effect of Well Bottom-hole Pressure ..............................................................65 3.8 Conclusion ...............................................................................................................66 CHAPTER FOUR: SENSITIVITY ANALYSIS ON FLOW-BACK RECOVERY AND NPV IN LIQUID RICH GAS WELL .......................................................................68 4.1 Abstract ....................................................................................................................68 4.2 Introduction ..............................................................................................................69 4.3 Injection and Flow-back of Fracturing Fluid ...........................................................72 4.4 The Effect of Capillary Pressure and BHP ..............................................................77 4.5 The Effect of Well Shut-in Time .............................................................................79 4.6 Sensitivity Study of Flow-back Recovery and NPV ...............................................81
Load more

Recommended publications
  • 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.
    [Show full text]
  • 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).
    [Show full text]
  • 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).
    [Show full text]
  • 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.
    [Show full text]
  • 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.
    [Show full text]
  • 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.
    [Show full text]
  • Origin of Sulfate-Rich Fluids in the Lower Triassic Montney Formation, Western Canadian Sedimentary Basin Mastaneh H
    Origin of Sulfate-Rich Fluids in the Lower Triassic Montney Formation, Western Canadian Sedimentary Basin Mastaneh H. Liseroudi*1, Omid H. Ardakani1,2, Hamed Sanei3, Per K. Pedersen1, Richard Stern4, James M. Wood5,6 1University of Calgary, 2Geological Survey of Canada, 3Aarhus University, 4University of Alberta, 5Encana Corporation, 6now with Calaber1 Resources Abstract This study investigates diagenetic and geochemical processes that control the regional distribution and formation of sulfate minerals (i.e., anhydrite and barite) in the Early Triassic Montney tight gas siltstone reservoir in the Western Canadian Sedimentary Basin (WCSB). Petrographic observations revealed two generations of early and late anhydrite and barite cement with distinct regional occurrence. The early anhydrite cement is dominantly present in northeastern BC (low H2S concentration zone), while late-stage anhydrite and barite cement and fracture- and vug-filling anhydrite are dominant in western Alberta (high 34 18 H2S concentration zone). The δ S and δ O variations of late anhydrite and barite in the studied samples suggest a mixing isotopic signature of Triassic connate water and Devonian evaporites as two major origins of sulfate-rich fluids to the Montney Formation. The isotopic composition of early anhydrite cement in both areas suggests sulfate-rich fluids largely originated from modified Triassic connate water, sulfide oxidation process, and/or basinal brines. In contrast, the late diagenetic anhydrite and barite cement as well as fracture- and vug-filling anhydrite from high H2S concentration zone represents a mixed isotopic signature of Triassic connate water and a significant contribution of Devonian evaporites. The similar isotopic composition of the late-stage anhydrite and barite cement as well as fracture- and vug-filling anhydrite in western Alberta with Devonian evaporites isotopic signature further supports the major role of deep-seated fault/fracture systems in the supply of sulfate-rich fluids.
    [Show full text]
  • Turboprop®Slickwater Surfactantnon-Turboprop® Foam Slickwaterturboprop™ Surfactantnon-Turboprop™ Foam Slickwater Surfactant Foam
    ® TURBOprop Superior by Nature, Quality by Badger ® ® TURBOprop utilizes a patented surface modification technology, which creates an attraction to gaseous phases present in the fluid. The result is a fluidized proppant that flows further, and allows for increased proppant concentration - all without the need for increased fluid viscosity. Typical Properties 20/40 30/50 40/70 50/140 Krumbein Shape Factor - Sphericity 0.7 - 0.8 0.7 - 0.8 0.7 - 0.8 0.6 - 0.7 Turbidity (NTU) 3.6 10.9 11.2 17.1 Acid Solubility < 1.5% Absolute Volume (gal / lb) 0.0453 Particle Size Distribution Meets API 19C Color Light Buff to White Physical State Free Flowing Solid Dry Bulk Density (lb./gal.) 13.05 12.81 12.74 12.35 Specific Gravity 2.65 Crush Resistance (K Value) 6,000 8,000 10,000 10,000 Conductivity and Permeability Closure Stress PSI 20/40 30/50 40/70 50/140 2,000 2521 141 1257 70 633 36 426 22 4,000 2075 117 1019 57 553 31 345 18 6,000 1452 83 753 43 457 26 243 13 8,000 933 55 542 31 350 20 145 8 10,000 531 32 340 20 243 14 77 5 * Data points represented by mean value of accumulated Stim-Lab 2 Conductivity md-ft Permeability Darcy data of testing run at 2 lb/ft and 250°C (121°C) www.badgerminingcorp.com [email protected] ® TURBOprop 1400 Cumulative Production (Mmcf) 1200 Case Study | Pouce Coupe Field - Montney Formation, British Columbia 1000 1400 1200 800 1200 1000 1000 600 800 800 600 400 600 Cumulative Production Cumulative (Mmcf) 400 400 200 Cumulative (Mmcf) Production Cumulative 200 200 Cumulative Production per Ton
    [Show full text]
  • Factsheet 3Col V
    National and Global Petroleum Assessment Assessment of Continuous Gas Resources in the Montney and Doig Formations, Alberta Basin Province, Canada, 2018 Using a geology-based assessment methodology, the U.S. Geological Survey estimated undiscovered, technically recoverable mean resources of 47.6 trillion cubic feet of gas and 2.2 billion barrels of natural gas liquids in the Montney and Doig Formations of the Alberta Basin Province in Canada. Introduction Shale Gas AU was defined to encompass areas of organic-rich shale The U.S. Geological Survey (USGS) quantitatively assessed within the overpressured gas-generation window. the potential for undiscovered, technically recoverable continuous Assessment input data are summarized in table 1. Input data (unconventional) gas resources in the Triassic Montney and Doig from wells within drainage areas in the upper part of the Montney Formations of the Alberta Basin Province of Canada (fig. 1). In this are based mainly on Schmitz and others (2014) and Kwan (2015). study, the upper Montney Formation siltstones were assessed as a Drainage areas (for shales of the Doig Formation), success ratios, tight-gas accumulation (Chalmers and Bustin, 2012), and the Doig and estimated ultimate recoveries of wells are taken from geologic Formation phosphatic shales were assessed as a potential shale-gas analogs in the United States. accumulation (Chalmers and others, 2012). Total Petroleum Systems and Assessment Units 126° W 122° W 118° W 114° W The USGS defined an Upper Montney Total Petroleum System (TPS) and a Doig TPS. The upper part of the Montney Formation consists of organic-bearing siltstones that represent distal shelf, slope, and basinal turbidite deposits.
    [Show full text]
  • The Ultimate Potential for Unconventional Petroleum from The
    Permission to Reproduce Materials may be reproduced for personal, educational and/or non-profit activities, in part or in whole and by any means, without charge or further permission from the National Energy Board, the British Columbia Oil and Gas Commission, the Alberta Energy Regulator, or the British Columbia Ministry of Natural Gas Development, provided that due diligence is exercised in ensuring the accuracy of the information reproduced; that the National Energy Board, the British Columbia Oil and Gas Commission, the Alberta Energy Regulator, and the British Columbia Ministry of Natural Gas Development are identified as the source institutions; and that the reproduction is not represented as an official version of the information reproduced, nor as having been made in affiliation with or with the endorsement of the National Energy Board, the British Columbia Oil and Gas Commission, the Alberta Energy Regulator, or the British Columbia Ministry of Natural Gas Development. For permission to reproduce the information in this publication for commercial redistribution, please e-mail the National Energy Board at info@neb- one.gc.ca, the British Columbia Oil and Gas Commission at [email protected] the Alberta Energy Regulator at [email protected], or the British Columbia Ministry of Natural Gas Development at [email protected]. Autorisation de reproduction Le contenu de cette publication peut être reproduit à des fins personnelles, éducatives et/ou sans but lucratif, en tout ou en partie et par quelque moyen que ce soit, sans frais
    [Show full text]
  • Oil and Gas Geoscience Reports 2013
    Oil And Gas Geoscience Reports 2013 BC Ministry of Natural Gas Development Geoscience and Strategic Initiatives Branch © British Columbia Ministry of Natural Gas Development Geoscience and Strategic Initiatives Branch Victoria, British Columbia, May 2013 Please use the following citation format when quoting or reproducing parts of this document: Ferri, F., Hickin, A.S. and Reyes, J. (2012): Horn River basin–equivalent strata in Besa River Formation shale, northeastern British Columbia (NTS 094K/15); in Geoscience Reports 2012, British Columbia Ministry of Natural Gas Development, pages 1–15. Colour digital copies of this publication in Adobe Acrobat PDF format are available, free of charge, from the British Columbian Oil and Gas Division’s website at: http://www.empr.gov.bc.ca/OG/OILANDGAS/Pages/default.aspx Front cover photo by F. Ferri. Looking north at a syncline located approximately 15 km south of Hells Gate on the Liard. The exposed section consists of Toad Formation turbidite deposits (Montney - Doig equivalents). A section of Liard Formation (Halfway equivalent) sandstone marks the resistive rim. Shales of the lowermost Buckinghorse Formation sit unconformably above the Liard Formation. Page iii photo by F. Ferri. Looking north at the Alaska Highway, several kilometres south of Liard River. The bridge over the Liard River can be seen in the distance. Back cover photo by F. Ferri. Kindle Formation sandstone and siltstone exposed on a mountain near the head- waters of Vizer Creek. FOREWORD Geoscience Reports, together with its precursor the Summary of Activities, is in its ninth year of publication. This report is an annual publication of the Petroleum Geoscience Section of the Geoscience and Strategic Initiatives Branch, Oil and Gas Division, BC Ministry of Natural Gas Development.
    [Show full text]
  • Shale Gas Plays in North America – a Review
    Canadian Energy Research Institute North American Natural Gas Market Dynamics: Shale Gas Plays in North America – A Review Paul Kralovic Study No. 123 – Section I February 2011 Relevant • Independent • Objective NORTH AMERICAN NATURAL GAS MARKET DYNAMICS: SHALE GAS PLAYS IN NORTH AMERICA – A REVIEW North American Natural Gas Market Dynamics: Shale Gas Plays in North America – A Review Copyright © Canadian Energy Research Institute, 2011 Sections of this study may be reproduced in magazines and newspapers with acknowledgement to the Canadian Energy Research Institute Study No. 123 ISBN 1-896091-97-0 Author: Paul Kralovic* *Paul Kralovic is an external consultant and is the Director of Calgary-based Kralovic Economics Inc. Acknowledgements: The author of this report would like to extend his thanks and gratitude to everyone involved in the production and editing of the material, including, but not limited to George Eynon, Megan Murphy and Peter Howard CANADIAN ENERGY RESEARCH INSITTUTE 150, 3512 – 33 Street NW Calgary, Alberta T2L 2A6 Canada www.ceri.ca February 2011 Printed in Canada North American Natural Gas Market Dynamics: iii Shale Gas Plays in North America – A Review Table of Contents LIST OF FIGURES .............................................................................................................................. v LIST OF TABLES ................................................................................................................................ vii CHAPTER 1 INTRODUCTION AND REPORT STRUCTURE .............................................................
    [Show full text]