The First Congress Aimed Specifically At Production Professionals In The Eagle Ford http://www.eagle-ford-production-2014.com/

1. The First Congress Aimed Specifically At Production
Professionals In The Eagle Ford
SAVE
$400
REGISTER BY FRIDAY
NOVEMBER 22, 2013
January 29-30, 2014 | Houston | Texas
Examining How Eagle Ford Operators Are Selecting And Optimizing
Artificial Lift Techniques, Well Spacing
And Choke Management Strategies
To Manage Sharp Declines In Production,
Increase EURs And Extend The Life Of Every Well Drilled
For the first time, production professionals in the Eagle Ford will have the opportunity to discuss:
• ARTIFICIAL LIFT SELECTION OPTIMIZATION: Comparing ESP’s,
Gas Lift, Rod Lifts, Plunger Lifts and Jet Pumps to determine which yields
the highest production at the lowest failure rate
Expert Insight From 20+ Eagle Ford Experts:
Brian Alfro
President Primera
Energy
Scott McCarthy
Vice President Production
Lewis Energy
• CHOKE MANAGEMENT: Maximizing initial rates or choke restriction for
sustained production: identifying which leads to a higher ultimate recovery
• SAND MANAGEMENT: Examining what methods operators are using to
handle crushing and costly equipment failures caused by sand
• PARAFFIN SURFACTANTS: Assessing the use of chemical treatments
to effectively treat paraffin and minimize damage to the well
• EOR: Identifying options for tertiary recovery to determine the ability of
new tertiary recovery technologies to increase EURs and extend well life
Juan Carlos Carratu
Vice President Engineering Technology
Austin Exploration
Paul Lundy
Subsurface Manager
Statoil
David Jamieson
Reservoir Performance Supervisor
Conoco Philips
Subash Kannan
Optimation Engineer
Anadarko Petroleum
Matthew Fleharty
SCADA/Automation Lead US Onshore
Statoil
Organized By:
M Follow Us @UnconventOilGas
Kennedy Nwabuoku
Completions Manager
Penn Virginia
w w w. e a g l e - f o r d - p ro d u c t i o n - 2 0 1 4 . c o m

2. SAVE
$400
Latest reports show that the Eagle Ford is
currently producing 1.09 million barrels of
oil per day – a staggering number that is
even outperforming the Bakken. However,
the biggest points of contention surrounding
Eagle Ford wells are not how to get them
producing large volumes of oil but more
critically, how to keep them producing. A
recent Wood Mckenzie study shows that most
Eagle Ford wells typically drop off between
70 and 80 % in the first year. What is critical
to offset these declines and ensure that every
well reaches the highest possible net present
value, is for Eagle Ford operators to identify
the optimal production techniques to increase
EURs and extend the life of every well drilled.
optimize well spacing to minimize production
declines?
Studies have shown that choking a well could
improve the long-term recovery between
10-15% over a 30-year period – however,
what is the optimum choke strategy to
employ? How do you tailor choke strategies
to specific pressure regimes across Eagle
Ford reservoirs? And alongside that, what
artificial lift techniques have proven to yield
the highest production rates? What are the
optimum methods to manage sand and avoid
costly equipment failures? How can you
The two days will see VP’s, managers and
technical experts in Eagle Ford production,
discuss the following topics:
In light of so many questions and very little
available answers, we are delighted to
present for the first time ever, The Eagle
Ford Production, Artificial Lift and Choke
Management Congress 2014, taking place
in Houston on January 29 and 30. This is the
first congress designed solely for production
professionals in Eagle Ford and will be
bringing together EP experts from across the
play, to examine how Eagle Ford Operators
are selecting and optimizing artificial
lift techniques, well spacing and choke
management strategies to manage sharp
declines in production and increase EURs.
DAY 1: ARTIFICAL LIFT CHOKE
MANAGEMENT
Day 1 will start by examining how a leading
Eagle Ford operator has designed their
primary, secondary and tertiary recovery
strategies to directly increase EUR. It will
look at how to calculate a reliable inflow
Sponsorship And Exhibition Opportunities Available At The Congress
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 Eagle Ford Artificial Lift Choke Management
Congress 2014. Our busy exhibit area is an integral part of the Congress and is of genuine
practical value to delegates, who are looking for new solutions and technologies. Exhibiting at
the congress 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 contact: info@american-business-conferences.com
REGISTER BY FRIDAY
NOVEMBER 22, 2013
performance relationship before moving
onto several case studies on how operators
are selecting between and optimizing
different artificial lift techniques such as Rod
Pumps, ESPs, Gas Lifts and Plunger Lifts.
The discussion will then move to discuss how
to tailor choke strategies to different Eagle
Ford reservoirs before looking at optimal
strategies for controlling sand.
DAY 2: CHEMICAL TREATMENT, WELL
SPACING EOR
Day 2 will start by examining different
chemical treatments to effectively treat
Paraffin in Eagle Ford wells. It will then
discuss the use of automation systems
to monitor well sites before exploring the
effectiveness of Tertiary recovery methods
like Waterfloods and CO2 to extend the
life of an Eagle Ford well. The next section
will cover well interference and frac hits determining the optimum well spacing to
maxmize production. Finally, the two days
will conclude with a discussion on identifying
optimum strategies for designing and
investing in surface infrastructure and will
finish with a discussion on how operator’s are
handling waste and salt water disposal.
Venue Information
Eagle Ford Artificial Lift Choke
Management Congress 2014 will be held at:
The Westin Galleria Houston
5060 West Alabama
Houston, Texas
77056 United States
Phone: (713) 960-8100
or + (1) 800 721 3915
www.eagle-ford-production-2014.com + (1) 800 721 3915 info@american-business-conferences.com

3. Day 1
Wednesday January 29, 2014
8.30 Chair’s Opening Remarks
°° Chaired By: Scott McCarthy, VP Production, Lewis
Energy
KEYNOTE PANEL: ARTIFICIAL LIFT SELECTION
8.40 Examining Key Criteria Used To Dictate
Optimal Artificial Lift Techniques For Specific
Reservoir Types And Geological Areas In The Eagle
Ford
°° Using analysis on reservoir quality, pressure
distribution and tubing pressure to choose the right
artificial technique
°° Designing artificial lift specific to the dry gas,
retrograde condensate and black oil windows to
increase efficiency and optimize run life of the pump
°° Comparing different artificial lift methods to
determine which yields the highest economic
recovery with the lowest failure rate in different areas
°° Assessing how cost, durability and failure rate are
analyzed to determine most appropriate artificial
techniques
°° Examining techniques for deciding when to pump,
what to pump the curve and for how long to pump
Brian Alfaro, President, Primera Energy
Juan Carlos Carratu, VP Engineering Technology, Austin
Exploration
Tom Krawietz, Production Engineering Manager, Murphy Oil
Jake Klein, Production Manager, Texas American Resources
Gus Vegas, Production Engineer, Carrizo Oil Gas
9.10 Question Answer Session
CASE STUDY: ARTIFICIAL LIFT SELECTION
9.20 Examining How An Operator Has Selected
The Optimal Artificial Lift Method Based On The
Parameters Of Cost, Run Life And Failure Rates
°° Assessing how cost, durability and failure rate
have been successfully used to select artificial lift
technique in the Eagle Ford
°° Evaluating how IP rates on past wells have been used
to influence artificial lift selection on new wells in
close proximity
°° Hearing how initial lift performance during the
flumping period was used to determine which
method delivers with the lowest failure rate during
this period
°° Observing how well bore conditions should be used
to accurately select the appropriate artificial lift
technique
Joe Becnel, Production Engineering Supervisor, ConocoPhillips
9.50 Question Answer Session
10.00 Morning Refreshments In The Exhibition Area
PRODUCTION ECONOMICS
10.30 Planning Flexible Primary Recovery Schemes
To Reduce Downtime And Maximize Production
Economics For The Full Life Cycle Of The Well
• Evaluating strategies for optimizing artificial lift
equipment selection, sizing, and design to ensure
longevity of the equipment and continued production
• Analyzing site logistics and operational management
such as automation and crew requirements to
determine optimal means of monitoring production to
reduce downtime and operational cost
• Examining strategies for extending production time
between failures and ensuring workovers are being
executed properly to save on long term expenditure
• Understanding how to develop production facilities
and surface infrastructure to maximize production and
enable long term field development
Subash Kannan, Optimization Engineer, Anadarko
Petroleum
11.00 Question Answer Session
EAGLE FORD ARTIFICIAL LIFT OPTIMIZATION
ARTIFICIAL LIFT CHOKE MANAGMENT
Day 1 will examine key criteria used to dictate optimal artificial lift techniques for specific reservoir types, ways of
optimizing artificial lift techniques and determining most effective choke strategies for highest recovery
DETERMINING THE RIGHT ARTIFICIAL LIFT APPLICATION
FOR DIFFERENT GEOLOGICAL WINDOWS AND RESERVOIR
TYPES
ROD PUMP: CASE STUDY
11.10 Identifying Successful Flow Regimes And
Methods For Handling Dog Legs, Slugging And
Gas Interference To Increase The Run Time Of A
Rod Pump
°° Understanding how rod pumps are being operated
in the field: are strokes being pumped per minute or
are they being left to flow for 3 or 4 days?
°° Identifying optimum methods for dealing with
slugging and gas interference issues to increase the
efficiency of the rod pump
°° Examining sand and run time issues on deviated
wells to determine ways to prevent wear and tear and
shortened tube and rod lives
°° Evaluating the maximum angle needed to keep
doglegs down and find pumping units and wells
°° Using latest results to determine the optimum rod
centralizer program to use to increase run time
Jason Churchill, Operations Engineering Manager, Venado Oil
Gas
Bob Harris, Consultant, Venado Oil Gas
OIL GAS SEPARATION
11.40 Understanding, Predicting And Managing
Down Hole Gas And Liquids Separation To
Maximize Returns And Run Operations Efficiently
°° Assessing different gas separation technologies and
tools being used to prevent gas interference and
reduce maintenance costs
°° Determining the optimum placement of gas
separators in the well to handle high GOR wells
°° Identifying any new technologies that have been
effective in restraining gas from entering the system
and minimize gas ingestion
Jason Churchill, Operations Engineering Manager, Venado Oil
Gas
Bob Harris, Consultant, Venado Oil Gas
11.55 Question Answer Session
12.10 Lunch In Exhibition Area
PLUNGER LIFT: CASE STUDY
1.10 Delivering Production Results On A Plunger
Lift Application To Determine How Effective They
Are In High Condensate Areas Of The Eagle Ford
°° Examining the trend in Continuous Flow Plunger
for wells containing high levels of gas in order to
optimize production.
°° Understanding the maximum degrees in which a
plunger can work effectively: can they work effectively
at 60 or 65 degrees?
°° Examining if operators have been able to get
pressure up high enough in this condensate field to
use a plunger lift applicationIdentifying latest plunger
lift technologies to understand if you can perform
chemical injections on the same string to treat H2S
°° Comparing production results from chemical
injections against BAT and Capillers to determine
optimal treatment for plunger lifts
Cleon Dunham, President, Artificial Lift RD Council
ESP: CASE STUDY
1.25 Evaluating Whether The Improvement On
Decline Curves, Total Run Life And Failure Rate
Justify The Initial Capital Expenditure
°° Examining successful applications of ESP in Eagle
Ford to determine how successfully they have worked
°° Understanding the criteria to use when deciding
when to apply an ESP application
°° Explaining the lowest volume and maximum amount
of gas that an ESP can run on without failing to
determine the point at which it can’t be used
°° Assessing the technological developments in ESP to
avoid gas locks and internal erosion
°° Analyzing production performance seen by using
dual ESP Systems to understand if they are causing
big increments in production
°° Examining various tools such as ADV, SandCats and
other Tubing String and Pump Tools to enhance the
performance of the ESP
Cleon Dunham, President, Artificial Lift RD Council
1.40 Question Answer Session
GAS LIFT: CASE STUDY
1.50 Assessing IP Rates, Run Times And Failure
Rates Of Gas Lift To Determine If The Incremental
Production Justifies The Initial Infrastructure Costs
°° Considering the availability of surface infrastructure
and space needed to run a gas lift to determine to
accessibility of this application
°° Calculating the cost of the gas source, compression
equipment pipeline to assess the economics of
using this method
°° Outlining how an operator is removing H2S from gas
to use for gas lift
°° Examining results of using centralized compression
vs. pad compression to determine the most economic
method for extending the life of the wells
°° Uncovering new technologies with the potential to
make gas lift cheaper or more productive
2.20 Question Answer Session
2.30 Afternoon Refreshments In Exhibition Area
CHOKE STRATEGIES
3.00 Understanding How To Tailor Choke Strategies
To Specific Pressure Regimes Across Eagle Ford
Reservoirs To Optimize Draw Down Rate
°° Examining how to tailor choke strategies to varying
reservoir types and pressures to avoid damaging the
formation
°° Drawing down wells: how are they dropping the
pressure over a period and how are they drawing that
out?
°° Identifying which leads to higher ultimate recovery:
maximum initial rates or restricting chokes for
flatter, more sustained production
°° Determining a stable choke setting to ensure a stable
flow regime, avoid killing wells and produce as much
oil as possible
°° Assessing how an operator is designing facilities to
handle large fluctuations in flow rate with minimal
damage to equipment
David Jamieson, Reservoir Performance Supervisor,
ConocoPhillips
3.30 Question Answer Session
SAND MANAGEMENTEXAMINING STRATEGIES
FOR CONTROLLING SAND TO REDUCE DAMAGE
TO SURFACE EQUIPMENT AND PREVENT COSTLY
WORKOVERS
CRUSHING SAND MANAGEMENT
3.40 Determining Whether Resin Coated Or
Synthetic Proppants Can Be Justified Over White
Sand And Optimal Methods To Remove Sand And
Avoid Costly Equipment Failures
°° Assessing a case of embedment to determine the
point at which the sand grains start to break down
and crush
°° Understanding what methods an operator is using to
monitor the formation and identify when crushing is
occurring: at what point do you interfere?
°° Analyzing results from initial flow backs to
understand the types of equipment failures operators
are experiencing due to sand
°° Strategies from preventing sands from causing
trouble at pumps to avoid any impact to the
productivity of the well
°° Examining how operators are mitigating sand in their
flow stream to prevent equipment tear
°° Evaluating the costs involved in upgrading equipment
to improve sand handling to derive if it would be more
economical to change frack design
4.25 Question Answer Session
4.35 Chair’s Closing Remarks
4.45 - 5.45 Networking Drinks Reception In Exhibition Area
www.eagle-ford-production-2014.com + (1) 800 721 3915 info@american-business-conferences.com

4. Day 2
Thursday January 30, 2014
8.30 Chair’s Opening Remarks
°° Chaired By: Scott McCarthy, VP Production, Lewis
Energy
KEYNOTE PANEL : EUR PRODUCTION
8.40 How Eagle Ford Operators Have Designed
Primary, Secondary And Tertiary Recovery
Strategies To Directly Increase EUR
°° Quantifying decline rates to predict projected well life
°° Observing how well bore conditions should be used
to accurately select the appropriate artificial lift
technique
°° Outlining the criteria used to design and budget for
wellbore materials and equipment for secondary and
tertiary recovery in advance
°° Determining how far in advance operators plan their
choke strategies to maximize EUR
Frank Starr, CEO, Crimson Energy Partners
9.10 Question Answer Session
CHEMICAL TREATMENTS
PARAFFIN CONTROL AND SURFACTANTSASSESSING
CHEMICAL TREATMENTS TO MITIGATE PARAFFIN AND
INCREASE OIL RECOVERY
PARAFFIN CONTROL
9.20 Identifying Optimal Techniques For Paraffin
Control To Prevent Reduced Oil Production As A
Result Of Plugging
°° Understanding the root causes of paraffin problems
to identify when and where they might occur
°° Examining the detrimental effects of paraffin to
production operations to determine how quickly it
needs to be dealt with
°° Identifying what treatment has been used to
successfully increase the production of a well that
has been under-performing
°° Monitoring methods (e.g. mapping temperatures)
to identify the high-risk areas and optimize paraffin
treatment programs
Patrick Shuler, Oil Field Chemist, PEERI
SURFACTANTS
9.40 Examining How Oil Production Can Be
Enhanced Through The Use Of Surfactant
Technologies
°° Assessing mechanisms for increased oil recovery via
surfactant technology
°° Evaluating surfactants included in frac fluids to
increase chemical contact and oil recovery
°° Understanding the side-effects of surfactants to
prevent any undesirable effectsIdentifying other
enhancements seen from the use of surfactants to
justify investment in surfactant technologies
Patrick Shuler, Oil Field Chemist, PEERI
10.00 Question Answer Session
10.10 Morning Refreshments In Exhibition Area
AUTOMATION
EXAMINING DIFFERENT TECHNIQUES FOR ACQUIRING
WELL DATA TO MONITOR WELLSITES REMOTELY
COMMUNICATION AUTOMATION
10.40 Evaluating The Use Of Automation Systems
To Effectively Acquire Data And Monitor Well sites
Effectively From A Remote Location
°° Assessing the automation system an operator is
using to acquire data and the method they are using
to collate the production data they are getting
°° Understanding the extent to which companies are
able to configure wells remotely to determine how
they control shut ins and bring new pumps on
°° Evaluating the ability to successfully monitor wells
and diagnose issues quickly and effectively to
minimize operational costs
°° Highlighting potential room for error to determine
the reliability of automated systems in handling
larger production volumes
CHEMICAL TREATMENT, WELL SPACING EOR
Day 2 will examine how operators are using chemical treatments to treat H2S and Paraffin, determine the optimal
well spacing, criteria for identifying optimum EOR regimes and will finish with a discuss on optimizing surface
facilities and water disposal
Matthew Fleharty, SCADA/Automation - US Onshore, Statoil
11.10 Question Answer Session
WELL INTERFERENCE: WELL SPACING FRAC HITS
DETERMINING THE OPTIMUM SPACING TO MANAGE
STEEPER PRODUCTION DECLINES RESULTING FROM
HIGH WELL DENSITY AREAS
WELL SPACING
11.20 Determining The Optimum Well Spacing
To Maximize Production Whilst Minimizing
Interference
°° Assessing the accuracy of different simulation
models in determining which well spacing will lead
to highest economic recoveryIdentifying the key
techniques being used to determining the correct
well spacing for optimum recovery
°° Balancing capital expenditure against well spacing to
identify the point at which an operator can produce
the most oil from the least amount of wells
°° Determining the optimum down spacing to minimize
well interference and ensure wells are not competing
for same reserves
Paul Lundy, Subsurface Manager, Statoil
11.50 Question Answer Session
12.00 Lunch In Exhibition Area
FRAC HITS
1.00 Examining How Operators Are Mitigating
Frac Hits From Off Set Wells And Handling Them
Once They Have Occurred To Minimize Loss To
Production
°° Examining processes in place to identify wells that
could be off set wells
°° Assessing how operators are recovering the well
once frac hits have occurred and the well has lost a
significant portion of its production
°° Scrutinizing the relationship between frac hits and
well interference to infer if a correlation can be made
from micro-seismic analysis to production
°° Assessing results from rate transient analysis on
recent wells to gain insight into the drainage patterns
and interference
Kennedy Nwabuoku, Completions Manager, Penn Virginia
Corporation
1.30 Question Answer Session
EOR
INCREASING THE VALUE OF A WELL THROUGH TERTIARY
RECOVERY: ASSESSING THE EFFECTIVENESS OF
WATERFLOODS AND CO2 IN ENHANCING ULTIMATE
RECOVERY
WATERFLOOD CO2
1.40 Examining The Challenges Of Enhancing The
Recovery Of Shale Oil Wells And Predicting Their
Performance To Plan For Tertiary Recovery
°° Presenting the decline analysis results for 40 oil
producing wells in Eagle Ford to determine when
waterfloods are needed
°° Discussing the hyperbolic decline with b1 to
understand how this enhances ultimate recovery
°° Presenting simulation results for CO2 Flooding to
ascertain the viability of its use in Eagle Ford wells
°° Assessing the effect of different parameters on
EUR to identify the key parameters affecting the
simulation results
Mohabbat Ahmadi, Professor, University Of Alaska
Fairbanks
2.10 Question Answer Session
PANEL: WATERFLOOD CO2
2.20 Scrutinizing Water Flooding And CO2
Technologies To Determine Their Effectiveness In
Extending The Life Of An Eagle Ford Well
°° Analyzing latest production results from Water flood
pilots to determine the percentile increase seen in
EURs from tertiary recovery
°° Assessing the cost vs. recovery increase as a result of
CO2 Flooding to determine the commercial feasibility
of using it on Eagle Ford wells
°° Deducing the direction the industry is going to be
taking for tertiary recovery to understand which
method to undertake
°° Identifying any other potential tertiary recovery
options and the criteria used to determine the
optimum method to employ
Scott McCarthy, VP Production, Lewis Energy
Paul Lundy, Subsurface Manager, Statoil
Patrick Shuler, Oil Field Chemist, PEERI
Cleon Dunham, President, Artificial Lift RD Council
2.50 Afternoon Refreshments In The Exhibition Area
SURFACE INFRASTRUCTURE: CONDENSATE
STABILIZATION ELECTRICITY AVAILABILITY
EXAMINING HOW OPERATORS ARE EFFECTIVELY
DESIGNING SURFACE INFRASTRUCTURE AND
PRODUCTION FACILITIES TO DRIVE DOWN COST PER
BARREL
SURFACE INFRASTRUCTURE
3.20 Identifying Optimum Strategies For Designing
And Investing In Surface Infrastructure To Facilitate
Long-Term Field Development
°° Condensate Stabilization: examining how an operator
is designing and installing their production facilities
to facilitate condensate stabilization
°° Condensate Stabilization: do incremental production
volumes as a result of installing a condensate
stabilizer justify the costs
°° Electricity Availability: outlining the electrical
transmission, distribution and power generation
considerations that go into facilities design
°° Electricity Availability: Analyzing the best way to work
with co-ops and power companies to ensure well
sites get hooked up to a power supply
Ross Magee, Facilities Engineering Project Manager, Marathon
Oil
3.50 Question Answer Session
WASTE WATER DISPOSAL
IDENTIFYING OPTIMAL STRATEGIES FOR THE DISPOSAL
OF WASTE WATER ECONOMICALLY IN THE EAGLE FORD
WASTE WATER DISPOSAL
4.00 Examining How Operators Are Handling Waste
And Salt-Water Disposal To Remain Compliant
With Regulations
°° Understanding how operators are cost-effectively
handling waste water disposal in large volumes
°° Identifying if an operator has been able to
successfully implement an economic recycling
system to reduce long-term costs
°° Providing a cost-benefit analysis of disposal vs. reinjection to determine the optimal disposal method
for waste water in the Eagle Ford
°° Identifying the benefits of using digging pits to recycle salt waterUnderstanding if operators are using
line pits to manage their salt-water production
Cliff Davis, Production Engineer, Primera Energy
4.30 Question Answer Session
4.40 Chair’s Closing Remarks And End Of Conference
“Good diversity in topics and
speakers”
CONOCOPHILLIPS
“Relevant subject with high
quality speakers”
TALISMAN ENERGY INC
“Useful content and discussions”
CHEVRON
www.eagle-ford-production-2014.com + (1) 800 721 3915 info@american-business-conferences.com

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