In Situ Oil Sands SOR Reduction Initiative

Optimizing Reservoir Selection, Steam Based And
Non-Condensable Recovery Techniques And
Steam Quality To
Drive Down SOR And Reduce Capital And
Operating Expenditure In
In Situ Oil Sands Recovery
Delivering The Latest In Steam Based And
Non-Condensable Recovery Techniques And
Steam Quality To Drive Down SOR And Reduce
CAPEX And OPEX In In Situ Oil Sands Recovery
www.oil-sands-sor-reduction-2013.com (1) 800 721 3915 info@canadian-business-conferences.com
P OPTIMIZING COST SOR: Hearing How Producers Are Reducing The CAPEX
And OPEX Of Steam Generation And Increasing Recovery To Reach An SOR
Of 1.1 In Western Canadian In Situ Oil Sands
P UNDERSTANDING THE RESERVOIR: Defining The Composition Of The Reservoir
And Water Cut For Accurate Well Placement Decisions To Counter Lean
Zone Interaction Challenges
P AUTOMATED INJECTION TECHNOLOGIES: Examining Innovative Steam Assisted
Recovery Technologies For Optimal Bitumen Production
P STEAM-BASED RECOVERY TECHNIQUES: Examining The Latest Condensable
And Non-Condensable Coinjection Recovery Techniques To Reduce Steam
Requirements And Improve Production
P WATER TREAMENT SOR: Examining How Evaporators Affect Quality Of
Steam To Evaluate The Technology As Successor For Warm Lime Softeners
P PRODUCTION TECHNIQUES: Improving Production From Carbonate Reservoirs,
Tackling Sand Control And Managing Tripping Issues To Maximize Recovery
P WELL SPACING STEAM INJECTION PRESSURE – IMPACT ON SOR: Examining
How Varying Well Spacing And Injection Pressures Enable Producers To
Optimize SOR
PMANAGING DILUENT REQUIREMENTS: Investigating strategies to manage
diluent supply and technologies to eliminate diluent need altogether
THE ONLY EVENT COMBINING COMPLEX RESERVOIR
CHARACTERIZATION TECHNIQUES WITH ADVANCES IN PRODUCTION
TECHNOLOGIES TO DELIVER SOR REDUCTION SOLUTIONS FOR
EP COMPANIES IN WESTERN CANADA’S OIL SANDS
October 29-30, 2013
Calgary | Canada
Organized by
SAVE
$400
By Friday
August 09, 2013
Shabir Premji
CFO
Groundstar Resources Limited
Harris Naseer
Reservoir Development Team Lead
PTTEP
Alex Turta
Project Leader EOR, Light, Heavy Extra-
Heavy Oils
AlbertaInnovates-TechnologyFutures
Joseph Kuhach
Vice President of Engineering
Ivanhoe Energy
Daniel Yang
Director Reservoir Engineering
Laricina Energy Ltd.
Ken James
Co-President Co-CEO
Oak Point Energy
Dr. Bruce McGee
President CEO
E-T Energy
John Zahary
President CEO
Sunshine Oilsand Ltd.

While SAGD is the most efficient steam-based oil recovery process
yet to be demonstrated on a commercial scale in Western Canada,
more cost effective solutions to tackle the overwhelming challenge of
operating in the abnormally capital intensive In situ market are being
tested, pioneered and proven. With CAPEX requirements surging from
$3.3billion for a project start up in 2001 to $7.3 billion in 2011and
OPEX rising from $10/barrel in 2001 to $20/barrel today due to rising
natural gas prices, more cost effective recovery technologies are now
of critical importance to project economics.
There are of course limits to what can be accomplished with basic
SAGD, constrained by the physical properties of the reservoir, the
steam itself and of course economics. They key to tackling these
challenges lies in understanding reservoir dynamics and comparing
new techniques and technologies for SOR optimization with current
practices to optimize operating economics in a high cost, highly
competitive market.
The commercial viability and sustainability of in situ oil sands
producers therefore relies on between seasoned and new operators
to identify tried and tested practices for driving down the CAPEX and
OPEX of steam generation and increasing oil recovery at the same
time reducing the SOR to a ratio of 1.1
The mission of the In Situ Oil Sands SOR Reduction Initiative 2013 is to
uncover the latest steam injection techniques, recovery technologies,
water treatment technologies and production techniques through
knowledge sharing between industry innovators. The conference will
see experienced operators delivering presentations on their successes
and failures on trials for novel steam generation and oil recovery
practices.
Speakers from EP companies actively operating in the Athabasca oil
sands region will focus on delivering tangible solutions for optimizing
reservoir selection, steam based and non-condensable recovery
techniques and steam quality to drive down SOR and reduce capital
and operating expenditure on In Situ Oil Sands recovery
The forum will address commonly shared production challenges at every
stage of the production cycle, from reservoir selection to steam injection
through to enhanced bitumen recovery from reservoirs and carbonates.
Day one will define the composition of reservoirs and identify optimal
water cut areas for accurate well placement decisions to counter lean
zone interaction challenges and explore innovative steam and non-
steam generated techniques to maximize oil recovery and optimize
SOR. Subsequent to an opening dialogue between producers on their
strategies for reducing the CAPEX and OPEX of steam generation,
the day will also examine innovative injection and recovery techniques,
deliver solutions for optimal bitumen production, and strategies for
reducing steam requirements to justify capital spending.
Day two will examine how the latest water treatment techniques
affect steam recovery to ensure re-used water generates high
quality steam. Speakers will then examine production solutions for
controlling sand and optimizing b itumen recovery from carbonates
to improve recovery and consequently, SOR. The day will conclude
with an investigative look at strategies for managing diluent supply
and technologies for eliminating the need for diluent altogether.
SponsorshipAndExhibitionOpportunitiesAt InSituOilSandsSORReductionInitiative2013
Need to generate new sales leads, launch a new product, engage key decision makers, build new future business relationships in key
markets, or simply educate the industry about a new product? Then you need to exhibit at the In Situ Oil Sands SOR Reduction Initiative
2013. Our busy exhibit area is an integral part of the Summit and is of genuine practical value to delegates, who are looking for new
solutions and technologies. Exhibiting at the conference will help you position yourself as a market leader and centre of excellence to the
key decision makers in the industry.
For further information, please email: info@canadian-business-conferences.com
or call: (1) 800 721 3915
October 29-30, 2013
Calgary | Canada
Well organized and well attended.
You can be proud.
Petrobank

Day one will explore the characteristics of the reservoir and
explore innovative steam and non-steam generated recovery
techniques to maximize oil recovery and optimize SOR
8.30 Chair’s Opening Remarks
Chaired By: Daniel Yang, Director Engineering, Laricina Energy Ltd.
KEYNOTE PANEL: OPTIMIZING COST SOR
8.40 Hearing How Producers Are Reducing The CAPEX
And OPEX Of Steam Generation And Increasing
Recovery To Reach An SOR Of 1 In Western Canadian
In Situ Oil Sands
• Assessing how producers are minimizing steam injection
and maximizing recovery by understanding the reservoir
characteristics
• Hearing how producers are minimizing the amount of facilities
needed for steam generation to reduce capital costs
• Identifying how producers are drilling longer horizontal lateral
wells to produce more oil with lower capital investment
• Hearing how outsourcing engineering work to Asia is enabling
lowered operating expenses
Shabir Premji, CEO, Groundstar Resources
John Zahary, CEO, Sunshine Oilsands Ltd.
Steven He, Principal Reservoir Engineer, Statoil Canada Ltd.
Freddy Martinez, Team Lead Kinosis, Nexen Inc.
9.10 Question Answer Session
UNDERSTANDING THE RESERVOIR
Defining The Composition Of The Reservoir And
Water Cut For Accurate Well Placement Decisions To
Counter Lean Zone Interaction Challenges
PREDICTING SOR FOR RESERVOIR SELECTION
9.20 Examining Petrophysical Characteristics To Enable
Accurate SOR Prediction And The Selection Of Optimal
Recovery Reservoirs
• Measuring composition of production to assess water cut vs oil
down hole to enable accurate SOR forecasting
• Evaluating the reliability and accuracy of Multi-Phase Flow
Meters vs. Test Separators to allow reliable SOR forecasts
• Examining reservoir history matching models to enable
correct representation of down hole activity and accurate SOR
predictions
Harris Naseer, Reservoir Development Tead Lead, PTTEP
WATER SATURATION FOCUS
10.00 Assessing How High Water Saturation Impacts
Steam Chamber Growth To Identify Opportunities For
Faster Oil Production
• Analyzing whether or not high water saturation enhances steam
chamber growth to predict well performance
• Evaluating the location of transition zones to enable the selection
of optimum reservoirs for well pair placement
• Assessingthethicknessofthetransitionzonetoforecast
performanceandassistwithwellpairplacement
• Identifying the location of bottom water and assessing its
interaction with the steam chamber assess to how it will affect
well performance
Michael Wu, Reservoir Engineer, Canadian Natural Resources Ltd.
10.40 Morning Refreshments In Exhibition Showcase Area
QUANTIFYING LEAN ZONES
11.10 Quantifying And Locating Lean Zones In The
Reservoir And Assessing How They Interact With The
Steam Chamber To Reduce Steam Loss
• Identifying and defining permeable lean zones in the reservoir to
map the direction and pressure of steam injection and lower SOR
• Gauging the interaction between bitumen lean zone and SAGD
steam chamber to develop viable operation strategies for
managing steam interaction
Day One
Tuesday, October 29, 2013
RESERVOIR SELECTION, STEAM INJECTION TECHNOLOGIES
AND BITUMEN RECOVERY TECHNIQUES
• Determining new thermal recovery technology for dealing with
bitumen lean zones to avoid heat transfer challenges and enable
maximum recovery
• Monitoring how new techniques currently applied are enabling
delayed contact with lean zones to achieve optimal SOR levels
Pingke Li, Senior Manager, Reservoir Engineering, Sunshine Oilsands Ltd.
AUTOMATED INJECTION TECHNOLOGIES
Examining Innovative Steam Assisted Recovery
Technologies For Optimal Bitumen Production
AUTOMATED STEAM INJECTION
11.50 Hearing How Producers Are Optimizing Oil Sands
Production Costs And Controlling The SOR Through
Automated Steam Injection
• Assessing the cost implications versus operational benefits of
automated steam injection to aid strategic investment decisions
• Examining improvements to existing and new facilities
to quantify the commercial benefits of automated steam injection
• Assessing the extent of technological compatibility with and
improvements to existing facilities to assess feasibility of automation
• Hearing how automated steam generation allows tie in between the
well and cavity to optimize the control loop
• Examining changes in environmental impact per barrel
of oil produced to and how automation could impact
social responsibility
Denis Martin, Asst Chief Power Engineer of Suncor Firebag SAGD, Suncor Energy
12.30 Lunch In Exhibition Showcase Area
STEAM-BASED RECOVERY TECHNIQUES
Examining The Latest Condensable And Non-Condensable
Coinjection Recovery Techniques To Reduce Steam
Requirements And Improve Production
SOLVENT-ASSISTED COINJECTION
1.30 Assessing The Economic Profile Of Solvent-Assisted
Recovery To Assess It As An Option For Reducing SOR
• Determining the cost vs. performance profile for solvent-assisted
recovery to aid resource allocation decisions
• Examining the impact of solvent and steam coinjection on the
reservoir and interaction down hole to facilitate SOR forecasting
• Assessing the optimum timing and composition of solvent and
steam injection needed to reduce SOR
• Examining facility requirements for processing and separating
emulsion after solvent reuse to manage operations
Mike Carlson, Manager Reservoir Engineering, Alberta Oil Sands
NON-CONDENSABLE RECOVERY TECHNIQUES
2.10 Understanding The Fundamentals Of Methane
And Nitrogen Assisted Steam Recovery Techniques To
Determine Whether Or Not They Can Reduce SOR On A
Commercial Scale
• Assessing cost and recovery parameters for non condensable
recovery techniques to ascertain their feasibility in driving
down costs
• Learning how to decide when to start using methane or nitrogen
with the steam
• Gauging the impact of methane and nitrogen down hole to enable
accurate SOR prediction
• Evaluating the optimum mix of gas and steam injected in the
reservoir to maximize recovery
• Learning how non condensable steam injection can reduce
green house gas emissions and improve the image of oil
sands internationally
Thomas Harding, Corporate Technology Senior Advisor, Nexen Inc.
Mohamad Al-Murayri, Nexen Inc.
MITIGATING LEAK OFFS IN BOTTOM WATER
2.50 Investigating Operating Procedures To Mitigate Steam
Travel Towards Bottom Water During Steam And Solvent-
Assisted Coinjection To Optimize SOR
• Understanding how the steam operating philosophy is adjusted to
counter leak offs in bottom water to optimize oil recovery and SOR
• Determining the direction of steam travel to enable accurate well
placement to mitigate leak offs
• Assessing how reservoir characterization is utilized to determine
the location of bottom water in reservoirs to counter steam
condensation and prevent leak offs
Micaela Streeter, Production Team Lead, Suncor Energy
3.30 Afternoon Refreshments In The Exhibition Showcase Area
NON-STEAM ASSISTED RECOVERY TECHNIQUES
Understanding Innovative Non-Steaming Techniques As
Feasible Alternative Methods Of Recovery
IN SITU COMBUSTION
4.00 Investigating The Practical Viability Of In Situ
Combustion To Facilitate Reduction In Production Costs
For A Higher API Crude
• AssessingrealtimeperformanceresultsofInsitucombustionto
enableaccurateCAPEXinvestmentdecisions
• Hearing how producers are effectively managing production
efficiencies bearing the extra costs associated with a high
temperature process
• Investigating the interaction of water saturation on fire generation
down hole to understand the impact on oil recovery
• Determining the runtime of fire flooding techniques to ensure
sustained oil flow back
• Evaluating the quality of oil recovered with fire flooding compared
to standard oil production to allow for calculated recovery technique
selection decisions
Alex Turta, Project Leader EOR, Light, Heavy and Extra-Heavy Oils, Alberta
Innovates -Technology Futures
SAGDOX AND SOR
4.40 Examining SAGDOX As A Hybrid Process Combining
The Benefits Of SAGD And In-situ Combustion To Optimize
Steam And Oxygen Ratios As The Process Matures
• Investigating results of the bitumen characterization, temperature
oxidation, and combustion tube tests to assess feasibility of the
SAGDOX process
• Understanding how the SAGDOX process can be applied to
reservoirs that are currently being developed with SAGD and to
non-SAGD reservoirs, thin pay, lean zone, and deep bitumen zones
to optimize bitumen recovery
• Deciphering how Oxygen’s greater energy density will enable
SAGDOX to significantly reduce SOR and OPEX
Thomas Harding, Corporate Technology Senior Advisor, Nexen Inc.
ELECTROMAGNETIC HEATING
5.20 Hearing Results From Electromagnetic Pilot Tests To
Evaluate It As Practical Alternative To Conventional SAGD
• Comparing oil quality produced through electromagnetic heating
versus conventional SAGD processes to assess commercial viability
• Examining the economics of an electricity driven recovery model to
enable accurate critical CAPEX allocation decisions
• Understanding how fossil fuel elimination resulting from
electromagnetic heating could impact greenhouse gas emissions
Bruce McGee, President, E-T Energy
6.00 Chair’s Closing Remarks
6.10 - 6.40 Networking Drinks Reception In Exhibition
Showcase Area

Day two will examine the latest water treatment capabilities
for ensuring re-used water generates high quality steam and
examine production solutions for controlling sand and optimizing
bitumen recovery from carbonates to improve recovery and
consequently, SOR
8.30 Chair’s Opening Remarks
Chaired By: Daniel Yang, Director Engineering, Laricina Energy Ltd.
WATER TREAMENT SOR
8.40 Examining How Evaporators Affect The Quality Of
Steam To Evaluate The Technology As Successor For
Warm Lime Softeners
• Hearing how operators have been using evaporators to treat
water and what resulting steam quality they have been seeing
• Assessing design options for evaporators to enable
optimal water reuse for varying steam pressures and
thermal efficiencies
• Determining the extent of operational fouling in evaporators to
avoid bottlenecks in water recycling processes
• Investigating scaling challenges in evaporator tubes to optimize
quality of reproduced water for steam generation
• Examining the CAPEX and OPEX requirements for evaporators
to determine process feasibility to enable maximized rate
of returns
Ken James, Co-President, Co-CEO, Oak Point Energy
FEED WATER QUALITY SOR
9.20 Investigating The Effect Of Blowdown
Evaporators On Boiler Feed Water Quality To Optimize
SAGD Operations
• Assessing how improving boiler feed water quality and boiler
thermal performances can reduce scaling and fouling inside
tubes to optimize SAGD operations
• Determining how concentrated brine can reduce disposal
requirements in Once Thru Steam Generation
• Evaluating how lowering blow down recycling and treating
can enable de-loading warm lime softener to optimize the In
situ process
Longhui Qiu, Process Engineer, Japan Canada Oil Sands
PRODUCTION TECHNIQUES
Improving Production From Carbonate Reservoirs,
Tackling Sand Control And Managing Tripping Issues
To Maximize Recovery
ESPs PROGRESSIVE CAVITY PUMPS
10.00 Comparing Cost Versus Performance Parameters
Of ESPs And PCPs To Identify Opportunities For Cost
Reduction During In Situ Production
• Comparing ESP and PCP field study results to identify
opportunities for cost reduction
• Assessing cost versus performance parameters for ESPs and
PCPs to facilitate decisions on which to use
• Examining reliability and predicted run life of ESPs and PCPs
to enable exponential cost saving over the extended production
life cycle
• Evaluating ability for sand control and sand filter compatibility to
assist selection decisions for sand control mechanisms
Carlos Torres, Subsurface Team Lead, Statoil
Day Two
Wednesday, October 30, 2013 STEAM QUALITY, PRODUCTION TECHNIQUES UPGRADING
SAND CONTROL
11.10 Evaluating Sand Control Parameters To Ensure
Equipment Reliability, Recovery Maximization Per Barrel
And SOR Optimization
• Assessing sand size distribution to facilitate filter selection decisions
to enable optimum sand filtration in wells
• Examining the functional efficiency of sand control filters to
determine best fit for varying sand sizes to maximize oil recovery
• Determining the optimum sand control filter spacing
requirements along producer wells to avoid recovery of water
enabling SOR optimization
Blair Flebbe, Staff Reliability Engineer, Cenovus Energy
TURBINE RELIABILTY
11.50 Addressing Operating Challenges And Tripping
Issues With Turbines For Steam Generators To Ensure
Steam Is Consistently Available For SAGD
• Assessing maintenance and maintainability of injection bulbs in
power turbines for steam generators to enable disruption-free
SAGD processes
• Investigating viable solutions to counter turbine tripping challenges
to maximize steam generation achieving optimal online factors
• Understanding process control system complexities to enable
effective communication for process disruption handling
Blair Flebbe, Staff Reliability Engineer, Cenovus Energy
12.30 Lunch In The Exhibition Showcase Area
BITUMEN RECOVERY FROM CARBONATES
1.30 Hearing Project Updates From Producers Exploiting
Bitumen Reserves In Western Canadian Carbonates
• Investigating the right pumps to enable efficient bitumen recovery
with minimum well operation failure keeping OPEX down
• Assessing the production technology innovations being used to
recover bitumen from carbonates
• Understanding how reservoir selection has been carried out on
carbonates to facilitate well placement decisions
• Examining tubing string configurations for effective and reliable well
operations in carbonates
Daniel Yang, Reservoir Engineering, Laricina Energy Ltd.
WELL SPACING STEAM INJECTION PRESSURE:
IMPACT ON SOR
Examining How Varying Well Spacing And Injection
Pressures Enable Producers To Optimize Sor
WELL PLACEMENT SOR
2.10 Identifying Modeling Tools And Techniques For
Selecting Accurate Well Placement And Spacing To
Achieve Favorable SOR Without Overspending
• Ensuring accurate well placement through the assessment of
elevation within the reservoir
• Evaluating geological mapping practices for locating resource
reserves to ensure highest recovery relative to well bore length
• Determining optimal well spacing requirements between well pairs
to achieve forecasted SOR levels
• Deciphering the efficiency of drilling tools to ensure wells are
straight and level to optimize oil recovery and SOR
Diomar Ferreira Prata, Reservoir Surveillance Optimization Supervisor.
Surmount SAGD Operations, ConocoPhillips Canada
STEAM INJECTION PRESSURE SOR
3.00 Determining How Steam Injection Pressure Is
Controlled Down Hole to Achieve Optimum Recovery,
Prevent Leak Offs And Lower SOR
• Assessing how steam injection pressures are altered to match
varying reservoir qualities and achieve optimum SOR
• Understanding how to lower SOR by controlling down hole injection
pressures as steam travels deeper in the reservoir
• Evaluating methods to manoeuvre steam injection pressures down
hole to avoid interaction with lean zones and bottom water.
Adeolu Adetowubo, Professional Engineer, Canadian Natural Resources Ltd.
3.40 Afternoon Refreshments In Exhibition Showcase Area
MANAGING DILUENT REQUIREMENTS
Investigating Strategies To Manage Diluent Supply And
Technologies To Eliminate Diluent Need Altogether
DILUENT SUPPLY MANAGEMENT
4.10 Investigating How Operators Plan To Manage Diluent
Shortfalls To Ensure Bottlenecks Are Avoided And
Continued Production
• Assessing production forecasts to estimate future diluent
requirements and assess where supply gaps are likely to fall
• Examining the impact of constrained supply on diluent prices to
predict the affect on the operators profitability equation
• Identifying alternate global supply markets for diluents to buffer
against diluent constraints
• Evaluating available and planned transportation routes to facilitate
diluent import from international markets
John Zahary, CEO, Sunshine Oil Sands Ltd.
HEAVY TO LIGHT UPGRADING
4.50 Assessing How In-Field Heavy Oil Upgrading Could
Optimize Bitumen Recovery And Increase The Speed
Of Takeaway
• Understanding in-field bitumen upgrading to eliminate diluent cost
requirements for heavy oil and bitumen transport
• Examining how advancements in heavy to light technology design
could maximize netbacks through cost effective infield upgrading
• Examining improvements in viscosity of recovered bitumen to
optimize value differentials between light and heavy oil
• Assessing the extent of carbon consumption and byproduct
energy recovery to eliminate the cost of natural gas imports for
steam generation
Joe Kuhach, VP Engineering, Ivanhoe Energy
5.30 Chair’s Closing Remarks
5.40 Chair’s Closing Remarks And End Of Conference
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