Comparison And Formation Specific Results-Driven Forum For Completions And Reservoir
Professionals Actively Optimizing The...
Identifying which completions work in which reservoirs and importantly,
which do not, is the key to Canadian horizontal we...
Day 1
Tuesday June 24, 2014
Day One will examine case st...
Day 1
Tuesday June 24, 2014
How Operators Are Selecting The Optimal Clus...
Day 2
Wednesday June 25, 2014 (1) 800 721 3915 info@canadian-business-conferenc...
Address For Invoice Purposes
Zip/Postal Code
Payment must be received in full prior to the event.
*	Option 1. CRED...
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Horizontal Completions Optimization Western Canada 2014


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Identifying which completions work in which reservoirs and importantly, which do not, is the key to Canadian horizontal well economics in 2014; and understanding how the optimal frac density, cluster spacing, fluid systems, proppant volumes and pump rates change with lithology is of course the most powerful cost-reduction insight an operator can attain.

But as new wells are drilled in new fields and indeed new formations such as the Swan Hills, Slave Point and Viking the lack of data is impending the rate at which operators can tailor their completions design to optimize recovery at the lowest costs on new wells.

The purpose of the first Horizontal Completions Optimization Western Canada 2014 congress taking place in Calgary on June 24-25, is to collate correlated data on reservoir characteristics and completions design with production performance to determine optimal completions strategies for new wells and reduce the cost of horizontal completions in liquid rich carbonate, shale, waterflooded and layered plays.

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Horizontal Completions Optimization Western Canada 2014

  1. 1. Comparison And Formation Specific Results-Driven Forum For Completions And Reservoir Professionals Actively Optimizing The Economics Of Horizontal Completions In The Duvernay, Montney, Cardium, Horn River, And Swan Hills Maximizing Well Economics By Correlating Completions Variables To Reservoir Characteristics To Production Performance: Optimizing Frac Modeling, Fluid And System Selection To Reduce The Cost Of Horizontal Completions In Liquids Rich Carbonate, Shale, Waterflooded, And Layered Plays Case Studies Tackling The Following Key Topics: June 24-25 | Calgary | Canada Glenna Jones EVP Engineering & Exploration Blaze Energy Over 20 Leading WCSB Speakers Including: M Follow Us: @UnconventOilGas Register By Friday May 16, 2014 SAVE $200 • COMPLETIONS DESIGN - LAYERED SHALE RESERVOIRS: Evaluating effective completion designs to contend with formation thickness, layering and complex stress changes in shale and tight oil reservoirs • FRAC SYSTEMS FOR SHALE RESERVOIRS: Evaluating comparative results of open hole, cased hole, plug and perf, ball drop, and sliding sleeve frac systems to determine the optimal system for HPHT wells • CARBONATE RESERVOIR COMPLETIONS: Comparing fluid selection and frac systems to optimize fracture propagation in carbonate plays • FRAC MODELING AND STRESS REGIMES: Strategies for interpreting reservoir data and microseismic to understand stress regimes, improve the accuracy of frac modeling and create complex fracture networks • PUMP RATE, SAND SELECTION AND FLOWBACK: Optimizing pump rate, sand and proppant selection to avoid sand off and maximize effective frac placement and strategies for optimizing flowback • CLUSTER SPACING, FRAC DENSITY, WELL SPACING AND DESIGN: Selecting the optimal cluster spacing, well placement and design to maximize reserve recovery without over-stimulation and unnecessary expenditure • DUVERNAY ECONOMICS: Understanding stratigraphy of the Duvernay shale and how its character changes across the fairway to identify sweet spots and optimize the economics of the play Paul MacKay President Shale Petroleum Organized By: Shaoyong Yu Sr. Reservoir Engineer ConocoPhillips Don Keith Supervisor Geoscience, Cardium Lightstream Resources Jesse Williams-Kovacs New Ventures Engineer TAQA North Bill Goodway Manager, Sr. Staff Geophysics Advisor Apache Doug Bearinger Geology Advisor, Shale Gas Nexen Energy Brad Wilson Drilling & Completions Manager Murphy Oil
  2. 2. Identifying which completions work in which reservoirs and importantly, which do not, is the key to Canadian horizontal well economics in 2014; and understanding how the optimal frac density, cluster spacing, fluid systems, proppant volumes and pump rates change with lithology is of course the most powerful cost-reduction insight an operator can attain. But as new wells are drilled in new fields and indeed new formations such as the the, Swan Hills, Slave Point and Viking the lack of data is impending the rate at which operators can tailor their completions design to optimize recovery at the lowest costs on new wells. The purpose of the first Horizontal Completions Optimization, Western Canada 2014 Congress, taking place in Calgary on June 24-25, is to collate correlated data on reservoir characteristics and completions design with production performance to determine optimal completions strategies for new wells and reduce the cost of horizontal completions in liquid rich carbonate, shale, waterflooded and layered plays. NEW TECHNOLOGIES - NEW DATA - NEW PLAYS Rapid technological advancements in completions systems, fluid types and proppants can allow operators to achieve greater depths and fracture layered formations with less expenditure on operation time and equipment costs, but only through effective tool deployment and combined knowledge of the reservoir. Improved diagnostics and core analysis techniques in the past two years have enabled operators to gain a heightened understanding of formation characteristics, lithology, rock composition and stress regimes across reservoirs. However, the challenge remains to isolate and compare completions variables and reservoir characteristics with production results to pinpoint the factors that will improve fracturing operations, achieve more accurate frac modeling and increase stimulated reservoir volumes. The Horizontal Completions Optimization Western Canada 2014 Congress will combine the foremost technological developments in completions design with comprehensive evaluation of formation specific challenges impacting fracture execution across the WCSB’s most lucrative plays, through comparison based technical talks and play specific case studies. The operator led sessions will evaluate completions design and fracture stimulation in the Montney, Cardium, Duvernay, Viking, Swan Hills and Bakken by comparing variables including system selection, frac fluids, proppant types, well spacing and design to determine the optimal completions design to combat formation characteristics including layered shale reservoirs, sandstone, carbonates, limestone, HPHT and formation heterogeneity throughout the WCSB. “Completions Have Eclipsed Everything Else From Both A Dollars And Complexity Perspective Over The Last Few Years.” WHATISUNIQUEABOUTTHISCONGRESS? • DATA DRIVEN SOLUTIONS: Correlated data between reservoir, completions types and production performance is key in optimizing well economics, therefore a full 2 days have been entirely dedicated to data driven solutions for the optimization of horizontal completions operations • EMPHASIS ON COST REDUCTION: As completions cost represent the highest expenditure in any well, the agenda has been designed to provide comparisons of production results, completion types used and overall costs to allow operators to gain practical solutions for improving long-term recovery and reducing overall completions costs • FORMATION SPECIFIC CASE STUDIES: Completions designs and executions need tailored to the formation specifications they are operating in therefore separate E&P led case studies will examine results from sandstone, limestone, carbonate, shale, tight and multi- layered formation completions in the most lucrative WCSB plays to demonstrate the most current and successful completions operations for various rock types • DUVERNAY FOCUS: With the Duvernay rapidly becoming potentially one of Canada’s most lucrative unconventional oil and gas prospects, a section has been dedicated specifically to the play. Case studies from leading Duvernay operators will provide results and learning’s on how to economically complete wells with high deliverability in the deep, tight Duvernay reservoir • RESERVOIR INTERPRETATION: Day 2 provides results-based studies for improving fracture stimulation through the analysis of stress regimes, rock type and micoseismic data analysis to improve frac modeling and maximize stimulated reservoir volume across every play (1) 800 721 3915 Register By Friday May 16, 2014 SAVE $200
  3. 3. FORMATION SPECIFIC COMPLETIONS DESIGN AND FRAC SYSTEM COMPARISONS Day 1 Tuesday June 24, 2014 Day One will examine case studies on how operators have tailored completions design to formation specificities to optimize costs and maximize production and operators will compare completions systems and fluid types to showcase advancements in matching fluids and frac systems with the reservoir 8.30 Chair’s Opening Remarks KEYNOTE PANEL: FORMATION SPECIFIC COMPLETIONS 8.40 Studying Formation Lithology Across The WCSB And Evaluating Completions Results To Optimize Field Selection And Frac Execution • Comparing completions results and analyzing operational challenges being seen throughout formation types to evaluate the feasibility of new investment • Determining trends in rock types across prolific WCSB formations to locate optimal economic zones for investment • Establishing which formations and zones are prone to natural fractures to navigate optimal frac placement within a formation • Evaluating oil types and current market value to optimize selection of reserves for long-term sustainability at market BarryStobo,VPEngineering&COO,YohoResources 9.10 Question & Answer Session FORMATION SPECIFIC COMPLETIONS DESIGN Examining Geological Analysis And Reservoir Characteristics Of Layered Formations, Tight Oil And Carbonate Reservoirs And Identifying Optimal Completions Design For Specific Reservoir Conditions DUVERNAY ECONOMICS 9.20 Understanding The Internal Stratigraphy Of The Duvernay Shale And How Its Character Changes Across The Fairway To Identify Sweet Spots And Optimize The Economics Of The Play • Locating carbonate layering, clay content, ductility and thickness throughout the region to identify areas of risk and opportunity for unconventional development in the play • Showing how this geological evaluation has aided sweet spot identification in the duvernay to optimize well placement and recovery potential • Analyzing the Kaybob reef complexes to understand the distribution of liquid yields across the Duvernay to aid in mapping and predictions for well placement • Examining the storage capacity of the rock for frac fluids and reserves across the Duvernay to optimize frac placement and modeling • Utiliyzing basin analysis, tight rock analysis, FIB-SEM imaging, advanced fluid analysis, pressured coring, and log analysis to improve SRV in the graded fairway of the Duvernay GlennKarlen,GeologicalAdvisor-DuvernayDevelopment,Encana MatthewDavis,GeologicalAdvisor,Encana 9.50 Question & Answer Session 10.00 Morning Refreshments In Exhibition Showcase Area SECOND WHITE SPECKS CASE STUDY 10.30 Understanding The Fracture Systems In The Second White Specks Formation To Determine Impact On Well Stimulation Design • Understanding how fluids move through the Second White Specks to map migration fairways and define sweet spots • Discussing the fracture distribution of the Second White Specs to reduce drilling risk and enhance production • Evaluating how optimum frac intervals may differ between natural fractures and induced fractures • Quantifying the level of recovery that can be attained as a result of the geology and completion applied in the play PaulMacKay,President,ShalePetroleum 11.00 Question & Answer Session COMPLETION DESIGN - CARBONATE RESERVOIRS 11.10 Comparing Results Of Acid Fracturing, Crosslink And Nitrogen Fluid Systems And Varying Frac Systems Deployed In Carbonate Reservoirs To Determine The Most Economic Completions Design • Studying characteristics of reefs and formation shelves in carbonate reservoirs to determine optimal completions design to frac specific conditions and facilitate production • Examining cumulative production, decline curves, and frac design employed in carbonate reservoirs that have been sand fracced vs. acid fracced to evaluate most cost effective design • Calculating the required percentage of HCL for acid fracturing and frac spacing to adequately break rock without over treatingContrasting completions results and costs of ball drop, ported collar, and braised jet cut completions to determine optimal frac system for carbonate plays • Evaluating chemical requirements, frac spacing and modelling to effectively deploy sand fracs in carbonate reservoirs to prevent emulsion and reduce cost of completions • Looking at seismic readings to determine if acid fracturing if more effective at creating matrix fractures in carbonate reservoirs KyleBaumgardner,VPProduction&Operations,ArcanResources 11.40 Question & Answer Session 11.50 Networking Lunch In Exhibition Showcase Area FRAC FLUID SELECTION Comparing The Selection Of Slickwater Vs. Crosslink Fluids, Evaluating Frac Fluid Compatibility And The Success Of Hybrid And Reverse Hybrid Designs To Effectively Place Sand And Overcome Formation Challenges SLICKWATER VS. CROSSLINK FLUIDS 12.50 Analyzing Reservoir Characteristics, Fluid Rheology And Compounds To Determine Required Fluids To Optimize Fracture Execution At Low Cost • Comparing cost and long-term production results of wells completed with slickwater vs. crosslink under similar well conditions to determine most cost-effective and successful fluid selection for frac propagation • Exploring innovations in cleaner crosslink fluids which eliminate residue in the wellbore to reduce risk of costly blockages • Determining reduced cost vs. risk of wellbore damage from use of slickwater to establish if potential formation damage outweighs cost saving • Matching fluid and surfactant blend to rock and oil type to optimize flowback and clean up operations • Examining flowback for scale, iron and solid production to determine fluid systems effect on pore throat and permeability to better match formation and fluid type in future completions • Evaluating the effectiveness of crosslinked fluids to propagate new fractures in high naturally fractured zones DonKeith,SupervisorGeoscience,Cardium,Lightstream Resources KeriYule,CompletionsConsultant,LightstreamResources 1.20 Question & Answer Session FRAC SYSTEM SELECTION Comparing Open Hole Vs. Cased Hole Liner Systems And Plug And Perf, Ball Drop, Cemented Sleeve And Coiled Tubing Frac Systems To Determine Optimal Selection For Specific Well Conditions OPEN HOLE VS. CASED HOLE PANEL 1.30 Evaluating Long-Term Production Results And The Overall Cost Of Open Hole Vs. Cased Hole Liner Systems To Determine Most Cost-Effective Selection • Comparing sand flowback and production results overtime between openhole vs. cased hole wells in similar formation conditions to determine impact on long-term production • Analyzing maximum temperature, depth, pressure and maximum pumping rates that can be achieved with open hole completions designs to evaluate feasibility of use in tight, deep formations • Deciphering the lateral lengths achievable with open hole vs. cased hole to determine optimal system for well specifications • Scrutinizing formation communication in open hole vs. cased hole completions to determine the optimal method to enhance flow without causing reservoir damage MikeCarlson,CompletionTeamLead,7GenerationEnergy 2.00 Question & Answer Session PLUG & PERF VS. SLIDING SLEEVE - HIGH RATE RESERVOIRS 2.10 Evaluating Results From The Use Of Shadow In Plugs And Dissolvable Sleeve Technology To Identify The Most Effective And Cost Saving System Innovations • Reviewing the implementation of shadow plugs in plug and perf to eliminate milling and enable full i.d. casing sizing • Comparing the reliability, temperature, pressures ranges and i.d. restrictions of cemented sleeve systems to tailor zone length and perf on the fly • Calculating well depth and required pumping rates to determine optimal frac system to manage formation requirements • Discussing the implementation of slickwire coated electric cable and innovations in plug design to evaluate cost and time savings in plug and perf operations 2.40 Question & Answer Session 2.50 Afternoon Refreshments In Exhibition Showcase Area BALL DROP - HPHT RESERVOIRS 3.20 Correlating Frac Results, Cost, And Reliability Of Dissolvable Ball Drop, Limited Entry And Single- Sized Ball Drop Systems To Determine Commercial Viability For Use In Deep, High Temperature Wells • Examining the cost, time and results of dissolvable drop ball fac systems to effectively create high flow i.d. and eliminate time and cost of milling • Determining if single-sized ball drop systems effectively minimize sand-off and enable full i.d to out perform traditional graduated ball systems • Scrutinizing the use of limited entry ball drop systems in cased hole completions to stimulate multiple, targeted fracs • Evaluating innovations in weight and pressure rating of ball drop systems to determine their ability to handle high pumping rates for hard rock reservoirs • Studying failure rates in ball drop systems to analyse risk and reliability of frac system to access zones • Averaging the number of runs taken to complete standard ball drop fracs and the cost of downtime if milling is required to evaluate risk and total cost 3.50 Question & Answer Session (1) 800 721 3915
  4. 4. Day 1 Tuesday June 24, 2014 CONTINUED... CLUSTER SPACING AND FRAC PERFORMANCE How Operators Are Selecting The Optimal Cluster Spacing And Maximizing Frac Performance To Improve Reserve Recovery Without Over-Stimulation And Unnecessary Expenditure UNDERSTANDING FRAC PERFORMANCE 4.00 Reviewing Frac Data, Flowback and Production Results To Accurately Understand Frac Performance • Analyzing high-frequency flowback rates and pressures to estimate key frac properties immediately following stimulation • Examining the value of collecting stage-by-stage flowback data to improve quantitative analysis and correlating completion techniques to individual stage performance to optimize future completion designs • Evaluating methods for analyzing large data sets to generate reliable and verified conclusions to advise on completions design • Comparing fracture properties estimated from different data sources to improve understanding of complex reservoirs and effective completion technique JesseWilliams-Kovacs,NewVenturesEngineer,TAQANorth 4.30 Question & Answer Ssssion CLUSTER SPACING 4.40 Promoting Simultaneous Hydraulic Fracture Growth From Multiple Perforation Clusters To Maximize Stimulated Reservoir Volume (SRV) And Aid In Selection Of Cluster Spacing • Explaining the use of a parallel Planar 3D simulator to model simultaneous growth of less constrained outer fractures and reduce the occurrence of stress shadowing • Evaluating how this model can alleviate the localization effect of stress shadowing through the strategic placement of interference fractures to increase the SRV • Showingtheresultsofthemodelingtodemonstrateincreased SRVofupto46%inafiveclusterarrayand74%inasix clusterarray AnthonyPeirce,Professor,UniversityOfBritishColumbia 5.10 Question & Answer Session 5.20 Chair’s Closing Remarks 5.30 - 6.30 Networking Drinks Reception In Exhibition Showcase Area Day Two will examine Duvernay completions economics, sand and proppant selection, frac spacing, well placement and design and hear how to incorporate reservoir characteristics, and microseismic data to optimize long- term well economics 8.30 Chair’s Opening Remarks KEYNOTE: DUVERNAY ECONOMICS 8.40 How A Small Independent Has Assessed Risk And Investment In The Duvernay And Strategically Developed Assets To Build Capital For Expenditure On Well Completions • Examining the capital expenditure that has been evaluated for completions design and execution in a Duvernay well to determine the feasibility of investment • Determining the selection criteria for expenditure on fluid, sand, and completions system selection to ensure an economic well without overspending • Detailing the rise in completions expenditure across prolific WCSB plays and comparing number of wells completed to company profile to understand the market breakdown and identify challenges for smaller companies • How a small company has effectively developed midstream assets to accommodate market fluctuations and provide capital for the completion of new wells GlennaJones,EVPEngineering&Exploration,BlazeEnergy 9.10 Question & Answer Session WELL SPACING AND DESIGN  How Operators Are Selecting The Optimal Well Placement, Spacing And Design To Maximize Reserve Recovery Without Over-Stimulation And Unnecessary Expenditure WELL SPACING AND DESIGN 9.20 Identifying How Reservoir Data And Completions Results Can Inform Well Spacing And Design To Maximize Field Potential And Recovery • Studying the reservoir structure and propensity of natural fractures in the formation to accurately space wells for maximum economic return • Hearing how drilling is reducing tortuosity and selecting mud systems for the lifecycle of the well to improve wellbore conditions for completions • Understanding the widest diameter wellbore that drillers can accomplish to facilitate completions while remaining cost effective • Determining required flow rate and fluid volumes to adequately frac the reservoir to select casing diameter that can handle rates • Examining subsurface formation communication and fracture network to understand optimal well spacing and avoid wellbore communication VickyWang,ReservoirEngineer,PennWest 9.50 Question & Answer Session 10.00 Morning Refreshments In Exhibition Showcase Area FRAC MODELING, MICROSEISMIC AND STRESS REGIMES Interpreting Well Results, Microseismic Data, Well Logs And Rock Characteristics To Improve Frac Modeling, Well Spacing And Placement And Long-Term Well Productivity MICROSEISMIC 10.30 Combining Microseismic And 4D Analysis To Calibrate And Confirm Surface 3D Azmuthal AVO/ LMR Predictions Of Completions And Production Performance • High-grading gas shales to optimize completions and maximize stimulated rock volumes • Using seismic data to estimate and map rock properties, in-situ stress, natural fractures and reservoir geometry to increase hydraulic fracture effectiveness • Evaluating the success of isotropic pre-stack inversion or quantitative Interpretation (to estimate in-situ stress and fracture growth • Estimating the presence of natural fractures that enhance in-situ permeability through azimuthal variations in amplitude • Investigating borehole microsismic with the use of 4D seismic for SRV mapping BillGoodway,AdvisorGeophysics,Apache 11.00 Question & Answer Session STRESS REGIMES 11.10 Evaluating Rock Characteristics To Determine Brittleness Across Formations And Maximize Successful Frac Placement • Examining the XRD and XRF to determine the elemental composition of the formation and which reveal compositional factors that may facilitate or impair frac propagation • Understanding methodology for identifying the appropriate porosity cut off for tight oil plays to accurately calculate reserves in place • Determining how to match rock composition to Young’s Modulus and Poisson’s ratio to accurately understand brittleness of the various lithological units and fracability of the formation • Deciphering a strategy for identifying the stress regimes and rock properties across a formation to refine completions design and maximize frac placement in different zones Jean-YvesChatellier,TechnicalLead,TalismanEnergy 11.40 Question & Answer Session 11.50 Lunch In Exhibition Showcase Area (1) 800 721 3915 DUVERNAY CASE STUDY, SAND, PROPPANT, FLOWBACK AND RESERVOIR ANALYSIS Day 2 Wednesday June 25, 2014 Strategic Insights And Interactive Discussion Extended Networking Opportunities
  5. 5. Day 2 Wednesday June 25, 2014 (1) 800 721 3915 FORECASTING RESERVES 12.50 Using the Modified Stretched Exponential Production Decline (YM-SEPD) Method To Accurately Forecast Remaining Reserves For Tight Oil & Shale Gas Wells And Inform Calculations For Well Placement Of Future Completions • Employing a new specialized plot to find all related parameters and yield a much more reliable production and remaining reserve prediction for tight horizontal wells • Examining how more accurate production and reserve estimates can aid in forecasting well placement and frac modelling for new completions • Using longer production histories to forecast remaining reserves more accurately and with higher confidence levels • Combining the modified YM-SEPD method with Duong’s empirical method to Yield reasonable production forecasts for wells with less than two years production history ShaoyongYu,Sr.ReservoirEngineer,ConocoPhillipsCanada 1.20 Question & Answer Session ACCURATE FRAC MODELING 1.30 Using Combined Simulations To Understand How Hydraulic Fractures Connect To The Natural Fracture System And Significantly Enhance Drainage Volume • Integrating, interpreting and testing all fracture related information to allow more guided well development decisions and address critical data gaps • Using the Discrete Fracture network (DFN) code to construct realistic fracture models to model the interaction between hydraulic fracs and the natural fracture system • Overcoming the challenge of poor data when developing detailed models • Running simulations on more generic models: varying fracture length, fracture aperture and intensity to determine their impact on micro-seismic pattern • Using stress-flow modelling of hydraulic frac interaction and pressure evolution to create a more effective stimulation and well development design DougBearinger,GeologicalAdvisor,Nexen 2.00 Question & Answer Session 2.10 Afternoon Refreshments In Exhibition Showcase Area PREVENTING SAND OFF AND FLOWBACK ANALYSIS Optimizing Flowback Rate, Sand And Proppant Selection To Avoid Sand Off And Maximize Effective Frac Placement Through Flowback Analysis PANEL: PREVENTING SAND OFF 2.40 Evaluating Formation Type, Fluid Selection, Frac Density, Proppant And Production Results To Optimize Pump Rate And Avoid Sand Off • Disseminating frac data to determine calculation of rate per perf cluster and optimal casing and wellbore diameter to enable successful sand placement • Examining frac data to evaluate successful frac placement vs. sandoff ratio within similar completions variables to select optimal design • Determining ideal reservoir contact and pump rate to ensure shale does not fall back to prevent leak off and screenouts • Hearing innovations in fluid and surfactants to determine their ability to carry proppant at lower rates to enable lower pump rate for sand control • Comparing the use of resin coated proppant and screens to effectively control sand and prevent erosion without restricting flow • Analyzing the effectiveness of closable sleeve completions systems to block sand coming back into the wellbore and prevent costly cleanouts BradWilson,Drilling&CompletionsManager,MurphyOil 3.10 Question & Answer Session FLOWBACK: IMMEDIATE GAS PRODUCTION 3.20 Analyzing Flowback Rate And Pressure Data To Identify Key Mechanisms Responsible For Early Gas Production In Multi-Fractured Wells • Developing a representative mathematical model to project the amount of gas that is going to be produced • Examining the effectiveness of a two-phase flowback model to manage immediate gas production in mulit- fractured wells • Using gas/water pressure and rate data measured during flowback operations to estimate the effective fracture volume and the equivalent fracture half-length • Understanding how the expansion of free gas within the fracture is the primary drive mechanism for production at the beginning of flow-back operation HassanDehghanpour,Professor,UniversityofAlberta 3.50 Question & Answer Session 4.00 Chair’s Closing Remarks And End Of Congress CONTINUED... Venue Information: Calgary Telus Convention Centre Exhibition Hall C 120 9th Avenue SE Calgary, Alberta Canada T2G 0P3 Website: Telephone: +1 403-261-8500 “A good opportunity to learn about the changes & regulations on emerging oil plays.” HUSKY ENERGY “A lot of completion information on these specific reservoirs.” LIGHTSTREAM RESOURCES “I enjoyed the technical presentations, candid questions and answer sessions, and variety of topics. Overall, very good congress” TALISMAN ENERGY “Excellent networking opportunities. Collaboration & sharing of latest technologies & knowledge on tight oil plays.” PENNWEST EXPLORATION
  6. 6. Address For Invoice Purposes Zip/Postal Code Country Payment must be received in full prior to the event. * Option 1. CREDIT CARD Please charge my *VISA *AMERICAN EXPRESS *MASTERCARD Expiry date Security Code / CVV (required) Signature of card holder Amount $ USD Card number Name on card I would like to register the delegate(s) below for the 2 day congress Horizontal Completions Optimization Western Canada 2014 PYes Details PLEASE USE CAPITALS - PHOTOCOPY FOR MULTIPLE DELEGATES Delegate Rates GUESTS ARE RESPONSIBLE FOR THEIR OWN TRAVEL AND ACCOMMODATION ARRANGEMENTS Payment PLEASE TICK APPROPRIATE BOXES AND COMPLETE DETAILS How To Finalize Your Registration * Option 2. INVOICE An invoice containing payment instructions will be sent electronically upon receipt of the completed registration form. Delegate 1 *Mr *Dr *Miss *Ms *Mrs *Other: Name Position Organization Email Telephone Delegate 2 *Mr *Dr *Miss *Ms *Mrs *Other: Name Position Organization Email Telephone WE HAVE GROUP DISCOUNTS So you can involve your whole team Call for rates: (1) 800 721 3915 All prices quoted above are inclusive of GST Now that your details are completed please send your registration form to our Customer Service Team using one of the following options: Option 1. Email: Option 2. Fax: (1) 800 714 1359 Enquiries And More Information Should you have any enquiries or if you would like to request more information please contact our friendly Customer Service Team on (1) 800 721 3915 or visit the congress website at Super Early Booking Discount Early Booking Discount Standard Rate Book And Pay By Friday April 25 Book And Pay By Friday May 16 From May 17 2 Day Conference Pass *$1399 CAD SAVE $400 *$1599 CAD SAVE $200 *$1799 CAD Add Video & Audio Recordings Of The Event *$399 CAD Terms & Conditions The conference is being organized by Canadian Business Conferences, a division of London Business Conferences Ltd, a limited liability company formed under English company law and registered in the UK no. 5090859. Cancellations received 30 days prior to the event taking place will be eligible for a refund less $150 administration fee, after which point no refund will be given. Cancellations must be made in writing, if you are unable to attend you may nominate a colleague to take your place at no additional cost. Receipt of this booking form, inclusive or exclusive of payment constitutes formal agreement to attend and acceptance of the terms and conditions stated. Alloutstandingfeesmustbepaidwithinourstandardpayment periodof7days.Anyoutstandinginvoiceswillremainvalid shouldcancellationofattendancebereceivedoutsideofthe aforementionedcancellationperiod. * If you are claiming the early booking discount this may not be used in conjunction with other discounts advertised elsewhere. All discount codes and offers must be claimed at the time of registration. Canadian Business Conferences reserves the right to alter or cancel the speakers or program. We would like to keep you informed of other Canadian Business Conferences products and services. This will be carried out in accordance with the Data Protection Act. Please write to the Head of Marketing, Canadian Business Conferences at the address below if you specifically do not want to receive this information. Canadian Business Conferences. Bankers Hall. West Tower, 888. 3rd Street SW. 10th Floor. Calgary. AB. T2P 5C5 Canadian Business Conferences will not accept liability for any individual transport delays and in such circumstances the normal cancellation restrictions apply. Canadian Business Conferences is a Division of London Business Conferences Limited. Registered in England No. 5090859 EIN. no: 98-0514924 (1) 800 721 3915