NETWORKING BREAK SPONSOR

Exceed

PANELIST SPEAKER

MultiLift

AGENDA FOR 2016

DAY 1: ARTIFICIAL LIFT SELECTION CRITERIA AND ESP, GAS LIFT, PLUNGER AND HYDRAULIC JET PUMP OPTIMIZATION

Chaired By Mark Peavy, VP of Operations, Windy Cove Energy

8.45 Chair's Opening Remarks

KEYNOTE PANEL: SELECTION CRITERIA FOR ARTIFICIAL LIFT SYSTEMS

8.55 Discussing How E&Ps Have Selected The Right Artificial Lift Systems Relative To Well Conditions Such As Well Geometry And Gas-Liquid Ratio To Minimize Operating Costs

  • Outlining effective and concise criteria for optimal lift selection against wellbore conditions and characteristics to increase production rates across a well's lifespan
  • Presenting examples where effective implementation allowed a single lift system to run the length of a well's life and suggesting how to identify such potential scenarios
  • Discussing efficiency techniques for calculating the expected length of time a particular system can be implemented and suggesting cost-efficient ways of changing systems in multi-lift scenarios
  • Suggesting strategies for cost-effective management of multiple lift solutions to ensure downtime and expenditure is minimized when single-lift solutions are not possible

Moderator: Peter Oyewole, Senior Engineering Advisor, BOPCO

Gabriel Diaz, Team Lead Reliability and Optimization, Chevron

Mark Peavy, VP Operations, Windy Cove Energy

FIELD AND CASE HISTORIES

9.35 Reviewing Lessons Learned Regarding Rod Pumps, Electric Submersible Pumps, Gas Lift, And Jet Pumps In Various Downhole Situations

  • Discussing the importance of field history knowledge and conditions, experience of field and service company support,  "be-in" versus "buy-in" teamwork, and leadership.
  • Outlining case histories of lift applications and strategies in high GLR and water, steam and CO2 flooding reservoirs to promote knowledge and understanding
  • Considering lessons learned in rod pumping, ESP's and Gas lift in high GLR and flooding to drive forward developments in future applications
  • Passing on lessons learned in jet pumping heavy oil on offshore semi-submersibles to facilitate optimizations in these fields

Mark Peavy, VP Operations, Windy Cove Energy\

10.05 Question and Answer Session

EH9 CORROSION-PROOF SUCKER ROD

10.15 How The First Corrosion-Proof Sucker Rod Can Mitigate Workover Costs And Minimize Expenditure On Chemical Programs, Increasing Part Life Cycle To Several Years

Michael Murray, Region Sales, Exceed Oilfield Equipment

10.30 Morning Refreshments In Exhibition Showcase Area - Sponsored By Exceed Oilfield Equipment

ESP Optimization

Assessing Gas Interference And Solids Handling, Scale And Corrosion Mitigation And Sand Control For ESPs To Ensure Minimum Failure Rates And Costs

PANEL: ESP GAS INTERFERENCE AND SOLIDS HANDLING

11.00 Mitigating The Effect Of Gas And Solids Interference On ESPs To Maximize Production Runtimes

  • Comparing gas separation technologies specific for ESPs in wells with high gas volumes to mitigate the effect of gas interference
  • Achieving high efficiency in chemically remediating paraffin build-ups in ESP systems to mitigate equipment damage and tubing blockages
  • Optimizing ESP designs for effectively handing issues with cavitation gas to reduce the damage and downtime these cause
  • Assessing chemical injection methodologies to combat paraffin in ESPs at lower costs

Moderator: Peter Oyewole, Senior Engineering Advisor, BOPCO

Alex Freeman, Senior Production Engineer, ConocoPhillips

Paul Shotter, Managing Director, MULTILIFT Welltec

ESP EQUIPMENT OPTIMIZATION: SCALE AND CORROSION MITIGATION

11.40 Optimizing Chemical Programs For Mature Existing Fields Using ESP And Rod Pump To Mitigate Contamination And Improve Lifespan And Efficiency

  • Defining the focus of the chemical treatment program for ESP and Rod Pump to create context for best practice sharing
  • Predicting formation of organic and scale deposits downhole and outlining best practices for control
  • Laying out design considerations for downhole remedial treatments to ensure maximal efficiency in treatment selection and application
  • Demonstrating the usage of monitoring and control with database to create full understanding of chemical program costs

Zach Awny, Production Engineer, ConocoPhillips

12.10 Question and Answer Session

12.20 Lunch In Exhibition Showcase Area

MULTI-PHASE FLOW

1.20 Modeling Multi-Phase Flow For Life-of-Well Planning And Artificial Lift Operations To Predict And Account For Well Lifespans

  • Modeling multi-phase flow in wellbores over the entire life-cycle of the well from bean-up to artificial lift to induce optimal implementation accuracy
  • Measuring the effect of wellbore trajectory on artificial lift design and performance so that systems can be optimally designed and installed
  • Understanding the use of multi-phase flow modeling to effectively implement best practice in ESP and gas-lift system design
  • Modeling multiphase compositional flows over the life of the well to ensure operating parameters and limitations are understood

Anand S. Nagoo, Research Fellow, The University of Texas At Austin

1.50 Question and Answer Session

ESP/GAS LIFT CHANGEOVER

2.00 Delivering A Permian Basin Case Study On ESP to Deep/Extended Gas Lift Changeover To Demonstrate A Successful Strategy

  • Outlining the challenges in designing and operating ESPs in high GOR/GLR horizontals to understand where optimization is needed
  • Outlining and discussing the results of an ESP/Gas Lift changeover case study to underline successful and efficient changeover technique
  • Considering the limitations of conventional gas lift and screening the appropriate candidate for Deep/Extended Gas Lift system
  • Delivering a comparison of project economics for ESP Vs. Gas Lift to make the right decision on lift selection

 Pallavi Hardin, Senior Production & Operations Engineer, OXY

2.30 Question and Answer Session

2.40 Afternoon Refreshments In The Exhibition Showcase Area

Gas Lift And Plunger Lift

Substantially Optimizing Gas Lift And Plunger Lift Operations And Reducing Failures Through Design Optimization And Automation Technologies

ROUNDTABLE GAS LIFT AND PLUNGER LIFT OPTIMIZATION

3.10 Considering Optimizations In Gas Lift Valve Automation To Achieve Lower Lift Failure Rates And Cap Costs And Evaluating Strategies For Plunger Lift Selection, Implementation And Optimization

  • Weighing the added costs of automating gas lift valves against the savings in failure repairs to determine whether the investment is justified
  • Outlining parameters for the automation of gas lift valve closures and openings under varying pressures to demonstrate best practices and increase efficiencies
  • Evaluating software systems for automating parameter adjustments for predictable and unpredictable well conditions to maximize gas lift efficiencies
  • Evaluating plunger lift valve sizing, well deviation degrees, reservoir characteristics and GLR to optimize plunger lift selection criteria
  • Reducing facility-related issues in plunger lift wells by emphasizing energy-saving and automation methodologies
  • Evaluating the extent to which an operators has reduced operational downtime by identifying optimum plunger speed rates
  • Correlating different plunger assemblies with the life of the pumps to determine whether these are durable enough to tolerate average scale and paraffin deposition levels

Moderator: Mark Peavy, VP Operations, Windy Cove Energy

3.50 Chair's Closing Remarks

4.00-5.00 Networking Drinks In The Exhibition Showcase Area

DAY 2: ARTIFICIAL LIFT SYSTEMS FOR HIGH GLR WELLS AND HIGHLY DEVIATED WELLS, ARTIFICIAL LIFT AUTOMATION, ROD PUMP OPTIMIZATION AND POWER GENERATION

Chaired By Mark Paevy, VP of Operations, Windy Cove Energy

8.45 Chair's Opening Remarks

KEYNOTE: HIGH GLR PRODUCTION OPTIMIZATION

8.55 Comparing The Costs Vs. Benefits Vs. Limitations Of Rod Pumps, Hydraulic Jet Pumps And ESPs For Ensuring Maximum Production Rates In High GLR Wells

  • Comparing and contrasting the efficiencies and limitations of employing ESPs, jet pumps and rod pumps in high GLR wells under various well geometries to identify an artificial lift selection criteria
  • Understanding the impact of various natural and aided gas separation techniques for ESP, jet pumps and rod pumps to optimize artificial lift in high GLR wells
  • Determining how and when to efficiently move from ESP to rod pump in high GLR wells to maximize effective lift and optimize production

Frederick Schoch, Production Superintendent, BOPCO

9.25 Question & Answer Session

Artificial Lift Automation

Implementing Automated Pump-Off Controls, Variable Speed Drives And Production Surveillance Technologies To Achieve Significant Reductions In Operational Costs

PUMP-OFF CONTROLS VS. VARIABLE SPEED DRIVES

9.35 Comparing The Cost Vs. Benefits Of Using Variable Speed Drives Over Pump-Off Controls To Achieve Optimum Failure Mitigation

  • Delivering data on the parameters of pump-off controls and variable speed drives to compare their production enhancement capabilities
  • Outlining different VSD types and explaining how best to set up automated VSD systems to effectively capitalize on their functionality
  • Moving from pump-off controls to variable speed drives: Is the investment justified?
  • Understanding VSD limitations in terms of reliability and maintenance issues to counteract existing failures in automated controls

Fred Clarke, Senior Artificial Lift Specialist, Murphy Oil

10.05 Question & Answer Session

10.15 Morning Refreshments In The Exhibition Showcase Area

PANEL: CALCULATING ARTIFICIAL LIFT FAILURE

10.45 Sharing Real Failure Data For Artificial Lift Systems And Analyzing The Results To Establish Failure Trends And Reduce Future Failures

  • Sharing empirical failure data from various artificial lift types to establish and analyze trends to facilitate failure prediction and mitigation
  • Demonstrating accurate and applicable techniques for predicting equipment failures
  • Accounting for margins of error in failure prediction to ensure calculations are as accurate as possible
  • Discussing data collection criteria to identify key data for artificial failure prediction

Moderator: Peter Oyewole, Senior Engineering Advisor, BOPCO

Fred Clarke, Senior Artificial Lift Specialist, Murphy Oil

COUNTERBALANCE HYDRAULIC PUMPING UNITS

11.25 Showcasing How Counterbalance Hydraulic Pumping Units Can Help Operators Reduce Power Consumption And CO2 Emissions

Derek Twidale, Engineering Manager, Cameron

11.45 Question & Answer Session

11.50 Lunch In The Exhibition Showcase Area

Highly Deviated Wells

Assessing Key Artificial Lift Optimization For Highly Deviated Wells To Ensure Maximum Pump Efficiencies In Wells Presenting High Deviation In The Vertical Section

HIGHLY DEVIATED WELLS

12.50 Evaluating Strategies To Rod Pump Eagle Ford Shale Wells Which Are Highly Deviated In The Vertical Section

  • Outlining causes of failure in highly deviated rod pumped wells, rod and tubing wear and premature pump wear to establish failure parameters
  • Evaluating the relative values of as drilled deviation surveys Vs. gyro surveys in rod design for optimal rod system design
  • Implementing learning from failure data to improve run times between failures, document failure depths and establish root causes of failures
  • Utilizing resources and building partnerships with vendors to evaluate run times and wear patterns, improve equipment and materials selection for well conditions

Leslie Malone, Senior Staff Engineer, Murphy Oil

1.20 Question & Answer Session

Rod Pump Optimization

Improving Rod Pump Implementation, Operations And Maintenance Of Rod Pumps To Maximize Pump Efficiency Whilst Minimizing Operational Costs

ROD PUMP: GAS INTERFERENCE HANDLING

1.30 Controlling of Slug Flow from a Horizontal Wellbore Leads to an Artificial Lift System Advancement that Maximizes Productivity, Lowers Lifting Costs And Improves Rod Pump Life-Cycles

  • Presenting empirical data on the negative consequences of slug flow to rod pumping equipment and operating cost
  • Trials and experiments conducted seeking to effectively control horizontal wellbore slug flow and discovery of an artificial lift system advancementReview of the results of the artificial lift system advancement that has now been applied throughout North America in more than 75 horizontal wells

Jeff Saponja, President and CEO, TriAxon Oil Corporation

2.00 Question & Answer Session

2.10 Afternoon Refreshments In The Exhibition Showcase Area

PUMP BY EXCEPTION: REDUCING COSTS

2.40 Evaluating Pump By Exception, Centralized Monitoring And Other Well Site Automation Strategies To Reduce Workforce Costs For Operators

  • Delivering a step-by-step guide to a 'Pump By Exception' strategy to reduce the head count per well ratio
  • Detailing the use of central control rooms to monitor the wellsite to reduce field personnel costs and the number of trips to the well
  • Considering the employment of data driven decision support centers to aid the decision making process on the well pad
  • Reviewing automated personnel safety procedures to avoid lost revenue through liability

Sarah Tamilarasan, VP Oilfield Services, Petro Lucrum

3.10 Question & Answer Session

ROUNDTABLE DISCUSSION: SMART ROD PUMPS VS. HYDRAULIC JET PUMPS

3.20 Considering Methodologies And Solutions For Implementing Smart Rod Pump Technology And Hydraulic Jet Pumps To Understand Which Artificial Lift Systems Works Better

  • Detailing different methods for using SCADA technologies to monitor operations and predict the lifespan of rod pumps
  • Considering the application of smart rod pump equipment for reducing equipment failure rates and operational downtime
  • Advising on methods for minimizing the effect of extraneous variables on monitoring rod pump systems
  • Comparing The Cost Vs. Benefits Of Hydraulic Jet Pumps And Piston Pumps To Clarify Their Cost-Effectiveness And Selection Criteria
  • Considering chemical vs water injection methods and facilitating understanding of effective injection system for hydraulic lift
  • Outlining the cost structure of implementing a hydraulic lift system and identifying areas where reductions can be made to minimize costs
  • Identifying which type of wells are good candidates for utilizing jet pumps to ensure maximum well production rates

Moderator: Mark Peavy, VP Operations, Windy Cove Energy

4.20 Chair's Closing Remarks & End of Conference

Group Discount

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