The document outlines the agenda for a completions congress focused on optimizing liquid-rich well completions in the Marcellus and Utica basins, scheduled for October 29-30, 2014. It highlights key topics including stage length optimization, cluster spacing reduction, and strategies for high-pressure frac design, featuring case studies from industry experts. The goal is to share advanced techniques that improve well economics and recovery, addressing the unique challenges faced in the Appalachian region.

1. A D V A N C I N G C O M P L E T I O N S T E C H N I Q U E S I N A P P A L A C H I A ’ S L I Q U I D R I C H R E S E R V O I R S
THEFIRSTE&PLEDLIQUIDRICHCOMPLETIONSOPTIMIZATIONCONGRESSDESIGNED
SPECIFICALLYFORCOMPLETIONSPROFESSIONALSINTHEMARCELLUS&UTICABASINS
Reducing Costs And Maximizing Recovery In
Liquid Rich Utica And Marcellus Wells:
Exchanging Advanced Case Studies On
How Incremental Cost And Performance Gains
Are Being Achieved Through
Reduced Cluster Spacing, Stage And Lateral Length
Optimization, Frac Design And Water Use
Hear From Operator Led Case Studies Tackling The Following Key Topics:
October 29 - 30, 2014 | Columbus, Ohio
Lisset Sousa
Principal Reservoir Engineer
Statoil
ExpertInsightFromOver20Marcellus&UticaExperts,
Including:
M Follow Us: @UnconventOilGas
www.marcellus-utica-completions-2014.com
Register By Friday
August 29, 2014
SAVE*
$400
• STAGE LENGTH OPTIMIZATION: The very first completions congress specifically focusing
on optimal stage length case studies from the Appalachian Basin, demonstrating results from
varying lengths to determine which will maximize SRV relative to costs
• CLUSTER SPACING REDUCTION CASE STUDIES: Focused on play-by-play case
studies from the Marcellus and Utica Basins demonstrating how increased expenditure on
reducing cluster spacing is leading to improved well economics
• LONGER LATERAL ECONOMICS: Quantifying the production profitability of longer laterals
versus local production in liquid rich wells on the basis of costs, EUR and downhole failures
• PUMP RATES AND PROPPANT CONCENTRATIONS – UTICA: Evaluating which
proppant volumes, concentrations and pump rates are delivering optimal SRV across varying
stage lengths in the highly pressured Utica
• HIGH PRESSURE FRAC DESIGN - UTICA: Demonstrating operator strategies for utilizing
near wellbore stimulation to balance frac costs on high pressured Utica wells
• PROPPANT AND WATER SUPPLY CHAIN MANAGEMENT: Demonstrating how
operators are designing responsive well sites, and proppant and water supply strategies to
prevent production from being affected by shortfalls
Peter Dorrins
President
Junex Inc
Steve Stengell
President & CEO
Encore Energy
Abhijeet Inamdar
Senior Reservoir Engineer
Statoil
Heath Auman
Director Water Operations
Atlas Energy
Organized By:
Supported By:Co-Sponsor:
Javad Paktinat
Project Production Engineering Advisor
Anadarko Petroleum
Ian Leslie
Completions Engineer
CONSOL Energy

2. A D V A N C I N G C O M P L E T I O N S T E C H N I Q U E S I N A P P A L A C H I A ’ S L I Q U I D R I C H R E S E R V O I R S
Register By Friday
August 29, 2014
www.marcellus-utica-completions-2014.com (1) 800 721 3915 info@american-business-conferences.com
The Marcellus play has been drilled and completed for many years and this congress isn’t aiming to
recallwhatoperatorsalreadyknow.LiquidRichHorizontalCompletionsOptimization:Marcellus
& Utica 2014 is focused entirely on exploiting remaining high value, liquid rich opportunities that lie
within the play in light of current gas prices, and emerging opportunities in the Utica.
Optimizing NPV In Liquid Rich Marcellus Wells
The current gas price situation in the US, means Marcellus operators need to be ahead of the
game by developing highly advanced techniques for making marginal wells economic and
developing completions strategies for optimizing liquid recovery. Operators are now
actively making progress in reducing cluster spacing and optimizing stage and lateral lengths in
liquid rich reservoirs to ensure incremental cost and performance gains. Due to the increasing
number of trials measuring changes in such variables, the industry at large is now at a point where
findings and information sharing could lead to significant commercial gains.
Maximizing SRV And Well Economics In High Pressured Utica Wells
The liquid rich Utica is arguably an easy win for Marcellus operators and many are already seeing
significant production successes due to the delivery of optimal completions techniques. However,
the increase in near wellbore stimulation and lateral lengths, in the dense, typically higher-pressured,
Utica wells, present their own cost challenges. These include ensuring the availability and
development of higher PSI rated equipment, developing extended lateral completions strategies,
and creating frac designs suitable for high pressure wells; challenges that are often easily overcome
by hearing what others have already failed and succeeded at.
A Congress Dedicated To Identifying Which Completions Techniques And Designs
Are Delivering The Greatest NPV In Liquid Rich Marcellus And Utica Wells
The primary mission of the Liquid Rich Horizontal Completions Optimization: Marcellus
& Utica 2014 congress is to determine which advanced completion techniques are being used
by leading operators to improve well economics in the Appalachian Basin. Over two days, leading
completions managers and experts from E&P companies will be delivering data driven strategies to
optimize overall recovery by identifying which well design and frac design parameters are contributing
most to production in liquid rich, marginal and high pressured wells in the Marcellus and Utica.
Case studies delivered over the two days include: operator strategies for cluster spacing
reduction, stage length and lateral length optimization, pump rate and proppant concentration
decision making, and perforation techniques to optimize completions design to maximize SRV
and decrease operational costs in the Marcellus and Utica.
What Makes This Congress Unique?
• HIGH VALUE RESERVOIR FOCUS:
The Marcellus play has been drilled
and completed for many years and this
congress isn’t aiming to recall what
operators already know. This congress
is about looking at those remaining
challenges and high value opportunities
that lie within the play in light of gas
prices and increasing investment
opportunities in the Utica.
• FOCUSING ON ADVANCED CASE
STUDIES FOR EXPERIENCED
PROFESSIONALS: Operators in the
Marcellus are not new to fracing. This
congress has been created specifically
for completions professionals looking
to apply highly advanced completions
techniques to incrementally improve
costs and well performance.
• PLAY SPECIFIC: This is not a congress
looking at completion case studies in
general. The E&P case studies delivered
at this congress are from operators
overcoming challenges unique to the
Marcellus and Utica plays to deliver more
relevant and applicable learning benefits.
• FULLY E&P LED: This is an industry
collaboration congress, researched
directly with leading completions
engineers in the Appalachian Basin to
ensure the agenda reflects the most
current, time critical challenges being
faced in Marcellus and Utica completions.
• STAGE LENGTH AND CLUSTER
SPACING FOCUS: With stage and
cluster spacing being the most hotly
discussed completions variables in
the plays, speakers at the congress
will place special focus on examining
and comparing the very latest results
from varying stage and cluster lengths
being trialled in the Marcellus and Utica
to determine which is proving to yield
optimal results.
Embassy Suites Columbus
Buckeye Ballroom, 2700 Corporate Exchange Drive, Columbus, Ohio 43231
Phone: +1 614 890 8600
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Venue Information:
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3. STAGE LENGTH OPTIMIZATION, CLUSTER SPACING REDUCTION, WELL SPACING &
MULTI-WELL PAD COMPLETIONS
Day 1
Wednesday October 29, 2014
8.50 Chair’s Opening Remarks
JavadPaktinat,ProjectProductionEngineeringAdvisor,Anadarko
Petroleum
KEYNOTE PANEL: STAGE LENGTH OPTIMIZATION
9.00 Exchanging Logging Data To Determine The
Extent To Which Different Stage Designs Contribute To
Production Performance In Liquid Rich Marcellus Wells:
Collectively Determining Optimal Stage Spacing
• Comparing and contrasting sonic log and stress analysis data
from different stage designs in the Marcellus to collectively
determine which deliver the greatest reservoir stimulation at
the lowest cost:
• <150 feet stages
• 150-250 feet stages
• 300 feet stages
• Evaluating logging data from these designs to assess the
extent to which reduced spacing has contributed to production
• Examining the sand and water costs of the different stage
designs to assess well economics of different spacing
strategies
• Quantifying the costs per business that could be saved, and the
extent to which progress could be expedited, if a data sharing
platform was established between Marcellus operators
• Speakers will each deliver a 10-minute presentation on their
stage spacing strategies and logging data. This will be followed
by an open discussion of ways to further improve designs led
by the chair
Panelist:SteveStengell,President&CEO,EncoreEnergy
9.30 Question & Answer Session
CLUSTER SPACING REDUCTION METHODS
9.40 Exploring Reduced Cluster Spacing Methods
Being Used To Optimize Production Performance In
Marcellus Wells: Comparing Increased Rate Of Return
With Added Costs
• Comparing results from different cluster spacing strategies
being used in Marcellus wells:
• 2 foot versus 3 foot clusters
• 3 foot versus 4 foot clusters
• 4 foot versus 5 foot clusters
• Assessing how logs are being used to pinpoint clusters to
ensure everyone contributes to production
• Analyzing the increased effectiveness of new generation
perforation charges to determine whether improved well
stimulation and cleaning is worth added costs
• Comparing diversion agents being used to determine which
are the most effective in ensuring fluid goes into every cluster
• Comparing cluster spacing strategies for single wells versus
multi-well pad developments to determine which delivers
highest ROR
10.10 Question & Answer Session
10.20 Morning Refreshments In Exhibition Showcase Area
CLUSTER SPACING CASE STUDY 2: MARCELLUS
10.50 Examining The Changes In Costs, Recovery And
Cycle Times Seen When An Operator Moved From 300
Ft To 150 Ft Cluster Spacing In The Marcellus
• Drainage: Evaluating the overall drainage increase as a result
of spacing reduction
• Cost: Examining the overall additional proppant, diversion
fluid and water costs incurred by reducing cluster spacing to
determine the economics of spacing reduction
• Cycle Time: Assessing the extent to which reducing cluster
spacing impacts cycle to determine whether extra frac crew
costs are likely to be incurred in future
11.20 Question & Answer Session
CLUSTER SPACING CASE STUDY 3: UTICA
11.30 Examining Microseismic Data From Recent Utica
Wells To Compare SRV And Drainage Ratios Seen From
Different Cluster Designs: Near Wellbore Stimulation Focus
• Examining how reduced cluster spacing is impacting initial
production rates versus costs and increasing EUR in the Utica
• Analyzing how the company measured whether increased
production performance was a result of changes in cluster
spacing versus other variables
• Understanding how the higher pressures in the more dense
Utica formation impact fracture efficiency to inform cluster
spacing strategy and decrease unnecessary expenditure
• Evaluating the extent to which perforations were reduced as a
result of changes to cluster spacing and how that impacted costs
12.00 Question & Answer Session
CHEMICAL TRACERS
12.10 Hearing How Tracers Are Being Used To Evaluate
Simulated Rock Volume And Monitor Well Performance:
Case Study
• Determining the effectiveness of tracers as a feasible
alternative to microseismic to accurately monitor well
performance
• Examining how using tracer data to design stimulations can
optimize fracture efficiency, production volumes and well
productivity
• Calculating the speed at which tracers are flowing back to the
wellhead and assess impact on productivity
JonSpencer,BusinessDevelopmentCoordinator-Unconventional
Reservoir,Tracerco
12.25 Question & Answer Session
12.30 Networking Lunch In Exhibition Showcase Area
SAND LOADING & PUMP RATES
1.30 Evaluating Which Proppant Volumes,
Concentrations And Pump Rates Are Delivering Optimal
SRV Across Varying Stage Lengths In The Highly
Pressured Utica
• Examining results from different sand loading variations to
determine which lb. per foot of lateral yields the highest SRV from
• Understanding how to determine the optimal proppant
combinations for decreased stage length and reduced cluster
fracture designs to maximize well production
• Analyzing the efficiency of different sand sizes in maximizing
well conductivity:
• 100 mesh first stages
• 40/70
• 20/40
• Examining which companies are pre-blending sand to
determine whether blending delivers increased reservoir
conductivity
• Assessing whether investing in higher strength pumping
equipment for completions in the dense Utica formation is
worthwhile relative to added production
2.00 Question & Answer Session
LAYING FRAC STAGES
2.10 Examining The Most Efficient Strategies For
Increasing The Speed Of Laying Frac Stages To
Minimize Operational Downtime
• Comparing techniques for preliminary rigging up on well
sites to demonstrate the most efficient technique for differing
geologies
• Multi-stage completion systems designed for open and cased
hole stimulation
• Plug and Perf
• Demonstrating expedited flushing practices to minimize sand
off in the well hole
• Studying innovations in fluid and surfactants to assist
maintenance of the pumping machinery to enable lower pump
for expedited completions operations at well site
KyleBradford,CompletionsSuperintendent,EclipseResources
2.40 Question & Answer Session
SLIDING-SLEEVE: FRAC OPTIMIZATION IN THE MARCELLUS
2.50 Evaluating Results From The Latest Advancements
In Ball-Activated Sliding-Sleeve Fractures And
Perforating Guns To Identify The Most Cost-Effective
Method For Marcellus And Utica Wells
• Quantifying the cost-effectiveness of ball-activated sliding-
sleeve fracturing to identify opportunities for moving beyond
wire lines, completely eliminating coil and expediting
completions operations
• Examining advanced operator utilization of the sliding-toe
fracture design to eliminate coil use on the first stage and
reduce the cost of completions
• Comparing the advancing innovations in perforating guns and
demonstrating their increased efficiency against sliding sleeve
fractures to justify investment in upgrading
3.20 Question & Answer Session
3.30 Afternoon Refreshments In Exhibition Showcase Area
LATERAL LENGTHS
USING ADVANCED CASE STUDIES TO DETERMINE
THE PRODUCTION PROFITABILITY AND TECHNICAL
LIMITATIONS OF LONGER LATERALS TO COST
EFFECTIVELY MAXIMIZE RESERVOIR EXPOSURE IN THE
UTICA AND MARCELLUS
LONGER LATERAL ECONOMICS
4.00 Quantifying The Production Profitability Of Longer
Laterals Versus Local Production In Liquid Rich Wells
On The Basis Of Costs, EUR And Downhole Failures
• Examining case studies demonstrating the costs, EUR and
technical complexities of different lateral lengths:
• 5000 feet
• 6500 feet+
• Measuring the increased incremental recovery from longer
lateral case studies to identify the break over point at which
length begins to hinder well economics in liquids rich areas
• Examining how operators are using predicted EUR to
determine whether extra length is worth the extra drill time,
costs and technical risk
EddyBiehl,Manager,StonebridgeOperatingCompany
4.30 Question & Answer Session
UTICA LONGER LATERALS: COILED TUBING
4.40 Examining How Operators Are Managing Coiled
Tubing Limitations In Longer Lateral Utica Wells To
Determine The Optimal Lateral Length For Recovery In
The Context Of What Is Technically Feasible
• Examining the designs being applied and tools being used to
set plugs and perforations in longer laterals
• Coiled tubing rigs versus workover rigs: Examining which
operators are finding most effective in executing drill outs in
longer laterals
• Contrasting the effectiveness of coiled tubing versus the added
depth capabilities of stick pipe for drilling plugs to aid selection
• Identifying the limitations of coiled tubing being seen in
different lengths of lateral
• Determining the very latest improvements in coiled tubing to
enable longer lateral in high pressured Utica wells
IanLeslie,CompletionsEngineer,CONSOLEnergy
5.10 Question & Answer Session
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4. FRACTURE DESIGN
EXAMINING TRIED AND TESTED FRACTURE DESIGNS FOR
HIGH PRESSURED UTICA WELLS AND EXAMINING HOW TO
GUARANTEE SUFFICIENT PSI EQUIPMENT FOR THE FRAC
8.50 Chair’s Opening Remarks
KEYNOTE: HIGH PRESSURE FRAC DESIGN
9.00 Case Study: Demonstrating Operator Strategies
For Utilizing Near Wellbore Stimulation To Balance Frac
Costs On High Pressured Utica Wells
• Examining the flow back for perforation fluids used through
simple gel systems to straight water in order to maximize
permeability in Utica wells
• Using thickness, pressure, porosity and further reservoir
characteristics to model fractures in the reservoir and
determine optimal fracture placement in varying geological
areas
• Determining the optimal pressure rates for Utica wells with
a 15,000 lbs. boundary to balance increased production with
economic outlay in completions
9.30 Question & Answer Session
MITIGATING PRESSURE BUILD UPS
9.40 Comparing Results From Trials Using Targeted
Circulation Squeeze And Resins To Determine Which
Methodology Is Most Effective In Mitigating Pressure
Build Ups On Annular Casing Vents: Trenton Black River
Case Study
• Examining common causes of vent flow issues that result in
decreasing production
• Highlighting the need for a long term strategy for pressure
build up in order to ensure consistent production
• Comparing the performance of perforate and squeeze, section
mill and squeeze and well lock circular squeeze methods to
identify the correct strategy for differing wells
• Determining the advantages from well lock resin in
conjunction with circular squeeze to increase success in
mitigating pressure build ups
10.10 Question & Answer Session
10.20 Morning Refreshments Served In Exhibition
Showcase Area
USING PRODUCED WATER IN FRACS: CASE STUDY
10.50 Comparing The Effects Of Produced Water On
Frac Performance In Different Appalachian Reservoirs
Versus Treatment Costs To Determine Whether Re-Use
Is Commercially Worthwhile
• Comparing frac results from a well that used fresh water and
a well that used treated produced water to quantify impact on
performance in different reservoirs
• Assessing different fluid chemistries being seen between
produced water, fresh water and frac chemicals and how
compatibilities of different combinations are affecting frac
performance
• Analyzing current and future water transport and disposal
regulations in Pittsburgh and Ohio to predict how they
could affect the costs and operational feasibility of different
treatment and disposal strategies
11.20 Question & Answer Session
SUPPLY CHAIN MANAGEMENT - FOCUS AFTERNOON
EXAMINING STRATEGIES FOR OVERCOMING LOGISTICAL
AND REGULATORY BOTTLENECKS IMPACTING SAND AND
WATER SUPPLY TO PREVENT OPERATIONAL DOWNTIME
AND DELAYS
PROPPANT SUPPLY
11.30 Demonstrating How An Operator Has Designed A
Responsive Well Site And Proppant Supply Strategy To
Prevent Production From Being Affected By Shortfalls
• Identifying the optimal response when proppant supply
runs short: pausing operations until supply returns versus
redesigning the job “on the fly”
• Demonstrating how an operator rapidly redesigned proppant
strategy when sand supply came offline in order to maintain
fracing operations
• Highlighting the most cost-effective and reliable transportation
model for proppant logistics in the Appalachian Basin
12.00 Question & Answer Session
12.10 Afternoon Refreshments In Exhibition Showcase Area
WATER SOURCING & LOGISTICS
1.10 Evaluating Innovative, Non-Traditional, Strategies For
Ensuring The Consistent Supply Of Fresh Water Within
The Regulatory Confines Of Pennsylvania And Ohio
• Examining a case study showing how an operator has reduced
costs and road traffic by developing a centralized water
transport system
• Evaluating the initial outlay of the centralized system versus
the long term costs savings to measure the cost benefit of
development
• Assessing how the operator developed a seasonal water
sourcing strategy to ensure consistent supply throughout dry
months in order to sustain production
• Examining the latest innovations in water storage to ensure
safe containment of processed water at high with minimal
integrity loss
• Forecasting EPA and regional regulatory developments in
Pittsburgh and Ohio to inform logistical strategies and disposal
programs with minimal water management expenditure
NickInkenhaus,SeniorEngineer-WaterResources,RangeResources
1.40 Question & Answer Session
MARCELLUS GAS WELL ECONOMICS
SHOWCASING HOW OPERATORS ARE MAKING
WELL ECONOMICS WORK IN DRY GAS MARCELLUS
RESERVOIRS
MAKING MARCELLUS GAS WELLS ECONOMICAL
1.50 Examining Completions Techniques, Supply
Strategies And Development Plans Being Used To Make
Economics Work In Marginal Dry Gas Marcellus Wells
During The Gas Market Decline
• Hearing how an operator has redesigned their completions
strategy in response to the fall in gas price to ensure their
wells remain economic
• Identifying areas of cost reduction that have been optimized to
reduce costs on marginal dry gas wells
• Forecasting market demand and gas prices for the next
5,10 and 20 years to inform forward allocation of upstream
investment in the Appalachian Basin
2.20 Question & Answer Session
PANEL: MOVING FROM THE MARCELLUS TO THE UTICA
2.30 Discussing The Key Technical And Cost Variables
That Need Changed When Moving From Marcellus To
Utica Completions To Ensure Well Economics Remain
Optimized
• Water: Studying how water availability and disposal facilities
differ between the plays to plan sourcing, logistics and
budgets accordingly
• Regulations: Summarizing the key regulatory differences that
need to be incorporated into completions plans when moving
to Ohio
• Pressure:Quantifyingthecostsofextrahorsepowerandhigh
pressurespecequipmentneededtoproducefromdeepUticawells
• Equipment: Identifying the differences in completions
equipment strength needed to ensure it can withstand higher
pressured Utica wells
Panelist:HeathAuman,DirectorWaterOperations,AtlasEnergy
Panelist:MichaelChadsey,DirectorPublicRelations,OhioOil&Gas
Association
3.00 Question & Answer Session
3.10 Afternoon Refreshments In Exhibition Showcase Area
4.10 Examining A Five Quarter Preliminary Investigation
Into Utica Shale Production Results
• Studying analysis of quarterly production results for 424 wells
to identify production trends in Utica shale production
• Considering spatial analysis for Utica wells to delineate gas,
wet gas and condensate production zones
• Identifying the greatest production (BOE) in wet gas and dry
gas zones to advise well selection
• Determining the consequences of an Average decline rate of
65 percent over five quarters
JeffDick,ProfessorandChair,GeologicalandEnvironmentalSciences,
YoungstownUniversity
4.40 Session To Be Confirmed
4.50 Question & Answer Session
5.00 Chair’s Closing Remarks
5.10 End Of Congress
Day 1 (Continued)
Wednesday October 29, 2014
Day 2
Thursday October 30, 2014
ADVANCED FRAC DESIGN AND PROPPANT
AND WATER SUPPLY
WELL SPACING & MULTI-WELL PADS
UTILIZING ADVANCED RESERVOIR CHARACTERIZATION
AND MICROSEISMIC TECHNOLOGY TO IDENTIFY THE
MOST PRODUCTIVE WELLBORE PLACEMENT STRATEGY
FOR MULTI-WELL PADS
WELL-BORE SPACING
5.20 Examining How An Operator Interpreted
Microseismic And Reservoir Data To Determine Optimal
Well Spacing For Cost Effectively Increasing Reservoir
Contact In Different Areas: Northeast And South West PA
• Comparing the costs versus rate of return from different
spacing strategies to assess which yield optimal development
economics:
• <500 feet
• 500 feet - 1000 feet
• 1000 feet>
• Evaluating the accuracy and usefulness of reservoir models
being used to the determine optimum well spacing for
maximum economic return in the Marcellus
• Utilizing the latest innovations in production logging to
determine optimal flow rate, proposed fluid volumes and
casing diameter to maximize stimulated reservoir volume
LissetSousa,PrincipalReservoirEngineer,Statoil
AbhijeetInamdar,SeniorReservoirEngineer,Statoil
5.50 Question & Answer Session
MULTI-WELL PADS: REDUCING INTERFERENCE
6.10 Assessing How Operators Are Determining
Maximum-Drainage Well Bore Spacing In Multi-Well
Pads, And Examining Techniques For Minimizing Fluid
And Pressure Loss When Interference Does Occur
• Examining a recent case study showing how an operator
tactically prevented interference and communication between
fracs on a multi-well pad
• Comparing approaches for determining whether to shut in
interfering wells or continue flowing at lower pressure to
determine which strategy has led to higher recovery relative
to costs
• Showcasing best practices for minimizing sand production and
liquid loading in multi-well pads
6.30 Question & Answer Session
6.40 Chair’s Closing Remarks
6.50 - 7.50 Networking Drinks In Exhibition Showcase Area
NEXEN
“I liked the honesty that
came from the E&P
companies about
their projects”
CONOCOPHILLIPS
“Great range of topics
covered with
good pace and structure.”
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