Permian Artificial Lift & Production Optimization Congress 2014

The F i rst Congress Designed Speci f ica l ly For Product ion Profess ionals In The Permian Basin

Increasing The Efficiency Of

Artificial Lift Design, Chemical Treatment Programs And Gas Separation In Permian Basin PlaysTo Extend Run Life, Minimize Well Failures And Drive Down Workover Costs In Horizontal Wells

Key Issues To Be Discussed Include:

March 26-27, 2014 | Houston | Texas

Hear From Leading E&P Permian Basin Production Experts, Including:

M Follow us @UnconventOilGas #Permian_P14

www.permian-production-2014.com

Register By FridayJanuary 31, 2014

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• ARTIFICIAL LIFT SELECTION AND OPTIMIZATION: Comparing rod pumps,

ESPs, gas lift, jet pumps to determine which yields the highest recovery with

the lowest failure rate in different areas of the Permian

• CHEMICAL TREATMENTS: Investigating the most cost-effective treatments for

asphaltene, scale, paraffin, H2S and corrosion to reduce chemical failures in

Permian wells

• GAS HANDLING: Examining optimal gas separation techniques downhole

and gas gathering solutions to identify cost-effective methods for handling

unwanted volumes of gas in the Permian

• CONFORMANCE: Evaluating key strategies for ensuring accurate zonal injection

to isolate shut off to excess water and gas and avoid shutting off oil

• WATER & CO2 FLOODING: Designing optimal water and CO2 flooding

strategies to optimize reservoir draw down

• OPTIMIZING WORKOVER RATES: Examining time and cost-effective

intervention practices to minimize downtime, reduce workover rates and

maximize the return on every Permian well

Tommy Folsom EVP & Director Of Exploration & Production Red Mountain Resources

Organized By:

Ben Bloys Manager - Los Alamos Technology Alliance Chevron

Greg Wilkes Manager Of Permian Basin Operations Broad Oak Energy II

Alan Barksdale CEO Red Mountain Resources

Rick Lester CEO Opal Resources

Stephen Lindsey Senior Director - Government & Community Affairs Quicksilver Resources

Stan Cullick Director Corporate Technology LINN Energy

David Smith Senior Fellow - Conformance Advisor ConocoPhillips

John Allred VP Production & Completions Opal Resources

Register By FridayJanuary 31, 2014

SAVE $400

www.permian-production-2014.com (1) 800 721 3915 [email protected]

Venue Information:

The Congress Will Be Held At:

The Westin Galleria HoustonWoodway Room Fourth Floor5060 West AlabamaHouston Texas 77056

Tel: (713) 960-8100Web: Please click to view the venue website

With production in the Permian increasing by 93,000 barrels a day year on year and accounting for 68% of overall production in Texas, the basin is without doubt re-establishing itself as one of the most prolific areas within North America for oil and gas exploration. High liquids-rich reserves, horizontal drilling and completions techniques have played a key part in this success, the continued high ultimate recoveries being seen in the basin by and large are driven by the selection and execution of the correct artificial lift and production optimization techniques.

OPTIMIZING ARTIFICIAL LIFT & PRODUCTION TECHNIQUES IN HORIZONTAL WELLS

Billions of dollars are spent yearly on artificial lift technologies and tackling obstructive scale and deposition within the wellbore, so the successful application of chemical treatment programs and mitigation of scale, ashphaltene, paraffin

and corrosion has become paramount to reducing well failures within the field and reducing costly workover rates.

We are therefore very pleased to announce the Permian Artificial Lift & Production Optimization 2014; the first congress designed specifically for production professionals in the Permian. The congress will focus heavily on the assessment and optimal application of artificial lift optimization, examining tried and tested chemical treatment programs as well as hearing case studies from leading E&P companies on how to optimize gas separation technologies, gas handling and saltwater disposal.

DAY 1: ARTIFICIAL LIFT & CHEMICAL TREATMENTS

Day one will focus on identification and application of the correct individual artificial lift technologies for different formations including rod pumps, gas lift, ESP and

jet pumps. Optimal chemical treatment methodologies to handle H2S will then be investigated based on case studies showing how operators have successfully managed paraffin, scale and corrosion to minimize well failures. Optimal techniques for gas separation downhole will also be examined.

DAY 2: AUTOMATION, CONFORMANCE, GAS HANDLING & WATER MANAGEMENT

Day two will start with a presentation examining time and cost-effective intervention practices to minimize downtime, reduce workover rates and maximize return on capital. Speakers will then go on to deliver presentations on conformance and ensuring electricity supply is available for production as well as examining the effectiveness of automation software for monitoring wells and reducing failures. Optimum methods for well spacing, gas and water handling will also be discussed.

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 Permian Artificial Lift

& Production Optimization 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 us at: [email protected] or + (1) 800 721 3915

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ARTIFICIAL LIFT AND CHEMICAL TREATMENTSDay one will identify the correct selection and application of individual artificial lift technologies for different formations and investigate ideal chemical treatment methodologies to handle H2S, paraffin, scale and corrosion. It will also determine optimal techniques for gas separation downhole.

Day 1Wednesday March 26, 2014

8.30 Chair’s Opening Remarks

Alan Barksdale, CEO, Red Mountain Resources

KEYNOTE ADDRESS: REDUCING FAILURE RATES8.40 Optimizing Artificial Lift And Chemical Programs To Reduce Failure Rates And Minimize Costly Workovers• Evaluating strategies for optimizing artificial lift selection,

sizing and design to ensure longevity of equipment and continued production

• Determining the most effective method of producing from deviated wellbores to avoid well failures

• Monitoring gas locking and gas breakouts to reduce workover rate

• Minimizing pressure drop in flowlines to separators to reduce failures due to friction or changes in pipe diameter

• Preventing liquid loading to prolong the life cycle of the wellTommy Folsom, Executive Vice President & Director Of E&P, Red Mountain Resources9.10 Question & Answer Session

ARTIFICIAL LIFT SELECTION AND OPTIMIZATIONOPTIMIZING ARTIFICIAL LIFTS RELATIVE TO THE WELL TO

REDUCE FAILURE RATE AND INCREASE WELL LIFE

PANEL DISCUSSION: ARTIFICIAL LIFT SELECTION9.20 Correlating Artificial Lift Selection To Well Performance: Optimizing Pump Design Based On Reservoir Type, Run Time, Failure Rate And Cost• Marrying the range of the pump and the turndown

capability with the expected productivity of the well to maximize well life

• Understanding the criteria used to vet different artificial lift mechanisms and determine the optimal selection relative to a particular well

• Assessing the IP rates and decline curves to determine how to adapt pump designs throughout the lifecycle of the well

• Examining how to design a pump to accommodate for high GORs and minimize primary failures due to compression or gas locking

Greg Wilkes, Permian Manager, Broad Oak Energy IIJason Vining, Operations Engineer, Legend Natural GasYouness El Fadili, Production Engineer, Oxy

9.50 Morning Refreshments In Exhibition Showcase Area

POOR BOY GAS LIFT10.20 Defining The Minimal Injection Rates Required For An Effective Gas Lift To Optimize MCF Per Barrel In The Permian• Assessing facilities upgrades, changes in surface

equipment, well heads and flowlines necessary to operate an efficient gas lift system

• Identifying common operational issues with gas lift to determine the optimum methods for troubleshooting once failure has occurred

• Examining the type of belt and run life of a gas lift application to evaluate its viability as an alternative to rod pumps

• Establishing the optimum injection rate while maintaining and prolonging compressor reliability to effectively lift from the toe of the well

• Understanding whether it is more beneficial to run gas lifts on higher or lower producing wells

Youness El Fadili, Production Engineer, Oxy

10.50 Question & Answer Session

ESP11.00 Examining The Use Of ESP Technology During A Drilling Development Program To Determine Optimum Drawdown In A High Water Cut Formation• Investigating how the wellbore can be optimized to allow

proper artificial lift installation• Identifying an ESP design able to handle high volumes of

water and oil and gas• Evaluating ESP performance to optimize artificial lift in a

proactive manner• Examining the various setting depths to optimize

drawdown• Optimizing production time by proactively planning

artificial lift methods for the life of the well Jason Edwards, Operations Engineering Advisor, Forge Energy


GAS LIFT VS. ESP

11.40 Comparing The Economics And Recoveries Of ESPs Vs. Gas Lift On Horizontal Bone Springs Wells In Eddy County, NM, And Analyzing The Optimum Drawdown With ESPs To Maximize Oil Deliverability• Analyzing well and LOE data to quantify the economic

gains of ESPs versus gas lift• Examining rate/cum data and total well performance to

find the effects on recoveries of ESP and gas lift wells• Using rate/time and bottomhole flowing pressure data to

determine the optimum drawdown to minimizer water cut• Looking at the operational pros/cons of ESP and gas lift

wells in relation to the reservoir and surface conditionsJason Vining, Operations Engineer, Legend Natural Gas


12.20 Lunch In Exhibition Showcase Area

JET PUMP

1.20 Discussing How An Operator Is Varying Material Selection, Design And Applications Of Jet Pumps Across Different Wells To Determine Impact On Production• Examining new technologies and materials required to get

jet pumps around the curve and into the lateral• Evaluating the success different operators have had with

various depths in the Permian to identify to optimum depth for jet pump applications

• Optimum sizing and selection based on reservoir type to optimize production performance

• Assessing if increased depth and tolerance to high volumes of gas and solids justifies the expense

Greg Wilkes, Manager Permian Basin Operations, Broad Oak Energy II

ROD PUMP

2.00 Optimizing Rod Pump Design, Configuration, Depth And Sizing To Minimize Gas Locking And Rod And Tubing Wear When Pumping A Horizontal In The Permian• Identifying optimum sizing, stroke length, depth and angle

within the lateral to maximize production capacity• Reducing pump failures and treating rod and tubing wear

to minimize operational costs• Using modeling programs to design rod string bore in

deviated wellbores• Examining methods of handling gas with rod pumps in the

Permian to avoid gas locking• Determining the optimal rod configuration: effective

grades, coupling types and methods for guiding rods in accordance with the deviation

• Examining pump cards and determining the correct efficiency to run them at to extend run life of the rod pump

• Optimizing pump placement: between top vs. bottom of perfs - weighing up a reduction in hydrostatic pressure vs. sand production

Greg Wilkes, Manager Permian Basin Operations, Broad Oak Energy II


CHEMICAL TREATMENTSIDENTIFYING THE MOST COST-EFFECTIVE TREATMENTS

FOR SCALE, PARAFFIN, H2S AND CORROSION TO REDUCE CHEMICAL FAILURES IN PERMIAN WELLS

CHEMICAL EFFICIENCY: STRATEGIC OVERVIEW

2.30 Increasing Margins And Efficiency: Turning Leading Edge Practices And Technology Into Economic Value• Balancing production costs with recovery factors to ensure

return on investment• Identifying the optimum chemical program to minimize

downtime• Capital allocation: examining the key criteria used to

determine the best capital allocation• Determining the point of diminishing returns:

understanding the point at which additional expenditure no longer justifies cost

• Defining expectations: establishing base lines and key parameters to measure performance

Rick Lester, CEO, Opal Resources


3.10 Afternoon Refreshments In Exhibition Showcase Area

CHEMICAL INJECTION

3.40 Understanding The Benefits Of Using Pressurized Chemical Injection Systems To Optimize Chemical Injection And Improve Well Performance

• Examining how a pressurized system requires no balls and seats or sight glass just pulsed chemical injection via solenoid to eliminate the need for chemical pumps and treater trucks

• Providing integrated flush from flowline and eliminating outsourced commingled water transfers through a closed loop system

• Customizing chemical injection and flush to each well’s individual requirements to optimize performance, minimize maintenance and lower total lifecycle costs

• Preventing chemical fumes from leaving the container to eliminate moisture intrusion and minimize environmental impact

• Examining the efficiency of instantaneous satellite feedback of the treating program to enhance communication and identify failures

• Using the system telemetry to increase dependability of remote or critical applications

John Allred, VP Production & Completions, Opal ResourcesBobby Ayres, Chemical Advisor, Opal ResourcesGreg Darby, Chemical Advisor, Opal Resources

H2S, PARAFFIN, SCALE: TREATMENT CASE STUDY

4.10 Outlining Key Preventative Chemical Programs To Remediate H2S And Paraffin To Prevent Corrosive Damages To The Well

• Examining the results from using pressurized chemical injections in Permian wells in combating paraffin and H2S to determine their effectiveness

• Comparing gas treating, continuous injection, batch and truck treating to pressurized chemical injection to determine the most successful application

• Examining techniques to successfully inject chemicals in a flowing well

• Identifying optimal scale inhibitors to ensure functionality of artificial lift systems

• Combating challenges of high fluid levels to allow for the application of solvents where needed downhole

• Identifying the most effective methods for removing sulfur without spending huge amounts of capital on processing facilities

John Allred, VP Production & Completions, Opal ResourcesBobby Ayres, Chemical Advisor, Opal ResourcesGreg Darby, Chemical Advisor, Opal Resources


GAS SEPARATION DOWNHOLEEXPLORING OPTIMUM OIL AND GAS SEPARATION

TECHNOLOGIES TO REDUCE DAMAGE TO EQUIPMENT DOWNHOLE

GAS SEPARATION DOWNHOLE

4.50 Examining Operational Strategies For Separating Gas Downhole To Prevent Gas Locking And Damage To Downhole Equipment

• Assessing different gas separation technologies and tools being used to prevent gas locking and reduce maintenance costs

• Evaluating different gas separators and their angle and placement in the well to determine optimal selection for varying GORs

• Determining the optimum angle and placement of gas separators in the well to handle high GOR wells

• Examining downhole tools including gas separators, pump and tubing string configurations to manage high GOR wells


5.30 Chair’s Closing Remarks

5.40 - 6.40 Networking Drinks Reception In Exhibition Showcase Area


8.30 Chair’s Opening Remarks

Alan Barksdale, CEO, Red Mountain Resources

KEYNOTE PANEL: OPTIMIZING WORKOVER RATES

8.40 Examining Time And Cost-Effective Intervention Practices To Minimize Downtime, Reduce Workover Rates And Maximize Return On Investment• Comparing the effectiveness of jointed pipe vs. coil tubing

to determine the most cost-effective methology for cleaning the well

• Examining the techniques an operator is using to optimize time taken to change pumps, fix rods and pull tubing on a well

• Balancing engineering success with economic failure to ensure that workovers are always within budget

• Evaluating production gained from workover against costs to determine the point where well intervention cannot be economically justified

John Allred, VP Production & Completions, Opal Resources


AUTOMATIONDETERMINING THE EFFECTIVENESS OF AUTOMATION

SOFTWARES FOR FIELD SURVEILLANCE AND DIAGNOSING OPERATIONAL ISSUES

SURVEILLANCE AND AUTOMATION

9.20 Utilizing Pump Surveillance Technology And Automation Systems To Monitor Wells Remotely And Decrease Failure Rates• Examining the impact of automation and surveillance

systems on failure rates and cost to determine if it is worth the investment

• Demonstrating a case study where utilizing latest automation software has led to pumping wells off more effectively

• Analyzing data surveillance and pattern surveillance to determine if a well is underperforming

• Understanding pump unit surveillance - fluid levels and effective reading of pump cards to provide optimum data systems

• Exploring benefits of connecting producer with the injector to monitor fluid patterns and decrease risk of zonal migration

Stan Cullick, Director Corporate Technology, LINN Energy


10.00 Morning Refreshments In Exhibition Showcase Area

RESERVOIR MANAGEMENT AND WELL SPACINGANALYZING THE ABILITY OF NEW RESERVOIR

TECHNOLOGIES AND OPTIMUM WELL SPACING TO INCREASE PRODUCTION AND ENHANCE RECOVERY

RESERVOIR MANAGEMENT TECHNOLOGIES

10.30 Using Production Results Seen From Three New Reservoir Technologies To Understand Their Ability To Enhance Daily Production And Ultimate Recovery• Examining how a new oil/water multiphase flow meter

provides accurate, cost-effective real-time data on liquids production from every well

• Evaluating the ability of wireless, unpowered data systems to give real-time downhole pressure and temperature data

• Exploring inexpensive wireless systems to determine their effectiveness in giving real-time liquid level data from any well to protect pumps, maximise flow rate and provide pressure build-up data

Ben Bloys, Manager - Los Alamos Technology Alliance, Chevron Corporation


WELL SPACING11.10 Correlating Well Spacing To Production Rate To Identify The Optimal Frac Radius To Prevent Well Interference And Offsetting Wells• Examining two different well spacing types to

understand the impact on the drainage radius being seen by associated fracs

• Understanding the impacts a certain type of well spacing can have on an individual wells frac radius and initial production

• Outlining the best practice of wells per pad to compare the effect on wellheads and tubing pressure

• Learning the parameters and criteria that are used to determine well spacing based on the geological characteristics in place


11.50 Lunch In Exhibition Showcase Area

EORASSESSING STRATEGIES TO ENSURE ACCURATE ZONAL

INJECTION

CONFORMANCE

12.50 Evaluating Key Strategies For Ensuring Accurate Zonal Injection To Isolate Shut Off To Excess Water And Gas And Avoid Shutting Off Oil• Comparing results from expandable casing, gel polymers

and cement squeezers to determine improvement of conformance in thePermian

• Examining how to prevent losing injection in a situation of high streaks and high channel flows from one injector to producer

• Examining the regularity of treatment required to ensure optimum results

• Identifying optimum concentrations of polymer, sizes, volumes and mixtures of cement slurries that are being pumped

• Examining the integrity of installing an expandable liner to understand if it is corrosion resistant

David Smith, Sr. Fellow - Conformance Engineering Advisor, ConocoPhillips


POWERINVESTIGATING SOLUTIONS TO POWER SUPPLY

CONSTRAINTS TO FACILITATE CONTINUED PRODUCTION

POWER AVAILABILITY

1.30 Evaluating How Permian Operators Are Obtaining Sufficient Power To Ensure Sustained Artificial Lift Applications And Continued Production• Evaluating what operators are doing to gain access to

power supplies to avoid reliance on generators• Examining how an operator is planning for sub stations

and bigger lines to facilitate increased production• Identifying generators that can put 10mb of power through

generation to determine the most suitable for long-term production

• Exploring natural or produced gas powered generators to ascertain the effectiveness of this power source relative to cost

John Bick, Power Advisor, Linn Energy


GAS HANDLINGIDENTIFYING COST-EFFECTIVE METHODS FOR

GATHERING AND UTILIZING GAS TO PREVENT FLARING

GAS GATHERING FACILITIES

2.10 Evaluating Cost-Effective Systems In Place To Enable The Gathering And Processing Of Gas To Reduce Flaring In The Permian Basin• Identifying the available capacity on current gas pipeline

projects to clarify gas takeaway options• Identifying new pipelines projects and compression plants

that are coming online to determine the capacity of these to handle volumes of gas being produced

• Understanding how an operator has cost-effectively gathered their gas to ensure gas reaches necessary processing facilities

• Evaluating the costs of installing on-site gas gathering systems against the value lost from flaring gas to determine if the investment costs are justified

• Discussing future strategies for ensuring that natural gas production can be capitalized upon

Doug Coleman, VP New Ventures, Prism Midstream


2.50 Afternoon Refreshments In Exhibition Showcase Area

UTILIZING GAS

3.20 Identifying Cost-Effective Methods Of Re-Using Surplus Gas In Future Operations To Ensure The Commerciality Of Natural Gas Production• Examining methods to utilize surplus gas for re-injection

to maintain bottom hole pressure• Exploring the potential processing gas for self power gas

generation to alleviate power constraints• Discussing the economic saving that would be made

through powering rigs through natural gas to determine the return on capital investment

• Learning how to maximize volumes of natural gas gathered to enable savings and maximize overall profits

Steven Ilkay, Oil & Gas Advisor, UTEP - CREIE3.50 Question & Answer Session

SALTWATER HANDLINGEXAMINING METHODS FOR THE DISPOSAL AND

UTILIZATION OF SALTWATER TO MAXIMIZE PRODUCTIVITY

SALTWATER DISPOSAL

4.00 Examining Efficient Methodologies For Handling Saltwater To Minimize Disposal Costs While Remaining Compliant With Regulations• Justifying optimum saltwater injection ratio in regards

to pressure, depth, temperature and the rock being disposed into

• Understanding how operators are cost-effectively handling wastewater disposal in large volumes

• Identifying optimum zones for injection and most effective injection intervals for maximum water disposition capacities

• Distinguishing methods of treating water and treatment levels required to enhance potential for re-use in future fracs

• Providing a cost-benefit analysis of disposal vs. re-injection to determine the optimal disposal method in the Permian

Stephen Lindsey, Senior Director - Government & Community Affairs, Quicksilver Resources4.30 Question & Answer Session

4.40 Chair’s Closing Remarks And End Of Conference

Day 2Thursday March 27, 2014

AUTOMATION, EOR, GAS HANDLING AND WATER MANAGEMENTDay two will evaluate strategies for optimizing workover rates, EOR and ensuring electricity supply as well as examining the effectiveness of automation softwares for monitoring wells and reducing failures. Optimum methods for well spacing, gas and water handling will also be discussed.


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