2017 Southwestern Petroleum Short Course Schedule

Wednesday, May 24th

09:00AM - 09:50AM (Wednesday)

Room 101
(06) CONVERSION OF ESP TO ROD PUMPING SYSTEM WITH AN IMPROVED GAS SEPARATOR SYSTEM IN DEPLETED WELLS
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The conversion from ESP to rod pump is needed when well-inflow is insufficient to supply enough fluid to the ESP. However, achieving good pump performance in rod pump systems operating in depleted wells with high gas/oil ratio can be limited as well. Creating a multi-stage gas separator system which removes free gas before fluid entered the pump intake increases volumetric efficiency in depleted wells. The first stage is a slotted intake where gas can coalesce. The second stage utilizes three large gas separator bodies for increased expansion of free gas which travels with the fluid by action of an extended dip tube. Finally, a vortex tool which creates a centrifugal force increases free gas separation efficiency.

A successful case study in Goldsmith is presented in this paper to demonstrate significant pump efficiency increase resulting from enhanced separator design based on downhole conditions to create a more efficient production system.
 

Presented by:

Gustavo Gonzalez, and Kyle Greer
Odessa Separators Inc.
Melinda Alleman and Brian Lewis, ConocoPhillips 

Artificial Lift
Room 102
(43) 2013-2015 ACID JOBS PERFORMANCE AND ANALYSIS ON EPS WELLS IN FIELD Y, INDONESIA
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Pertamina Hulu Energi Offshore North West Java (PHE ONWJ), which is a Production Sharing Contractor of the Government of Indonesia, operates a large number of offshore ESP wells in Java Sea, Indonesia. To stimulate the wells and increase near-wellbore permeability, PHE ONWJ has executed matrix acidizing from 2013 until 2015. During acid deployment, ESP was left in place (downhole). In fact, the ESP was also switched on to unload the spent acid. Given the acid corrosive properties on metals which make up some of the ESP components, a post-stimulation evaluation was conducted in May 2016. This paper attempts to analyze the effect of acid jobs on ESP components integrity and field production performance. Afterwards, this paper discusses some approaches that PHE ONWJ believes to be applicable to observe any need for periodical acid job in the field.

Presented by:

Nur Wiaya

Texas Tech University, Petroleum Engineering

Artificial Lift
Room 104
(10) PRODUCTION OPTIMIZATION THE BALANCE-PORTED VALVE IN THE PERMIAN BASIN
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The balance-ported valve is a gas-lift valve that allows full, available gas injection pressure to be used for the unloading and operating valves.  Using full injection pressure allows for a deeper point of gas injection, which lowers the FBHP, thereby increasing total production.  With standard IPO valves, it is necessary to design the valves with casing pressure drops in order to close the valves as the injection point moves deeper.  The balance-ported valve is configured such that no design casing pressure drops are required for closing.  The pilot valve can be utilized later in the life of the well, once the injection point is at the bottom valve and the well is producing less than 150 BFPD.  The pilot valve controls injection into the well in self-intermitting cycles, allowing the well to feed in between these cycles. This allows for lower gas injection rates and increased production.

Presented by:

Rick Haydel, Jack Brink, Gary Gassiott, Joseph Bourque, Ray Dees, Chris Daigle, and Jacob Leger  
Altec Inc. 

Artificial Lift
Room 108
(12) FOCUSED PRODUCTION MEASUREMENT
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With the proliferation of production from multiple zones within wells, a major challenge long recognized by industry is to understand which zones are contributing, and how much. This is even more of a challenge with multiphase flow from different zones and with the advent of hydraulic fracturing, correctly identifying which zones have the potential to contribute is critical for future operations. 

A new solution to this problem is to use a jet pump in combination with inflatable packers and a new PLT that uses Patent Pending Doppler sensors rather than spinners to measure flow. This allows the in-flow to be accurately measured while the zone is isolated, with the added benefit of being able to draw the pressure down to assess the potential of the zone when on lift. 

This paper discusses the application of this new method of production logging in a vertical well in West Texas. It will also show the logs obtained in the test well. 

Presented by:

Jay Miller

Tech-Flo Consulting, LLC

Artificial Lift
Room 110
(25) BEST OF BOTH WORLDS FROM PROPPANT DISTRIBUTION TO FRACTURE
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Horizontal drilling and the need for effective completion techniques has given birth to a wide variety of solutions in North American oil and gas plays. For many operators, it has become a top priority to optimize proppant distribution using buoyancy enhancer additives and to achieve fracture diversion with clean solutions that do not require intervention. At the heart of these initiatives is the Permian Basin, which is being revitalized through the use of intelligent completion technologies to make those priorities a reality.

This paper proposes two solutions that can be customized for an integrated fluid system that helps improve proppant distribution, deepen proppant penetration within the complex fracture network, increase proppant pack volume, and increase maximum proppant concentration that can be placed. By improving proppant placement and increasing the fracture volume occupied by proppant, operators can enhance conductivity of the fracture network, resulting in improvements to initial and long-term production.

Presented by:

Vidya S Bammidi
Keane Group

Drilling Operations
Room 111
(29) CHEMICALLY PERVENTABLE ROD PUMP FAILURE REDUCTION
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Rod pump failure tracking has become a crucial component to any rod pump program in order to maximize run life and more effectively evaluate failure mechanisms. This course will dive into chemically preventable failure causes for rod pump wells highlighting root cause analysis, corrosion/bacteria control, solids management, product selection and program evaluation. 

Presented by:

Matthew Boyer

Anadarko

Prod. Handling

10:00AM - 10:50AM (Wednesday)

Room 102
(45) THE EFFECT OF ANISOTROPY RATIO ON BUILD UP TEST DATA USING THE HORNER METHOD
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This study is directed toward investigating possible effects of the anisotropy ratio on the analysis and result of buildup tests using Horner method. Even though most reservoirs are more or less homogeneous but not necessarily isotropic, there is no direct method for estimating the anisotropy ratio at reservoir scale despite the fact that this parameter affects to a great extent the reservoir behavior.  
The approach used in this study is to solve numerically the one phase 3-D equations that governs the fluid flow in a reservoir. After checking the solution by simulating a test well under buildup, a parametric study to investigate a possible sensitivity of the results to the anisotropy ratio has been conducted.

A MATLAB computer program using a finite difference approach has been written for this purpose. Buildup tests have been simulated successfully and an estimation of the permeability using Horner analysis showed that the results are consistent with the data used for the simulated reservoir. Even though these preliminary results show that Horner method cannot discern between isotropic and non-isotropic reservoirs for fully penetrating wells, the behavior of partially penetrating wells shows clearly that the anisotropy ratio has a significant effect on the calculated permeability. More specifically, this study shows that the effect of the anisotropy ratio is proportional to the penetration ratio of the partially perforated wells.


These results have been generated by simulating very thick and pretty coarse reservoirs. It is expected that more simulation runs will shed more light on the effect of anisotropy ratio on well behavior during routine well testing procedure.
 

Presented by:

Vegard Elverhaug and Anders Torland

Texas Tech University, Petroleum Engineering

Reservoir Operation
Room 104
(05) INFERRED PRODUCTION TESTING OF OIL AND GAS WELLS
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Production testing with digital electronic devices has been discussed for about 20 years amongst a small group.  The idea has been implemented a few times with uncertain results.  The uncertainty exists because the measurements were done with turbine meters which are themselves uncertain.  

Recent testing has been accomplished by gauging calibrated tanks.  We believe these measurements of liquid volumes can be viewed as perfect.  Measurement of gas is done with computerized orifice meters which are known to be accurate as long as the correct orifice size is used.

This presentation compares perfect production tests made with tank gauges and test made with imperfect digital-electronic devices.  What would the oilfield look like if testing with digital0electronic devices became the norm?

Presented by:

S.G Gibbs and Ken Nolen, Greenshot, LLC

Rowland Ramos, Pioneer Natural Resources

Artificial Lift
Room 106
(36) FRACTURE LIKELIHOOD ANALYSIS USING TRIPLE COMBO LOG DATA IN THE STACKED CARBONATE PLAY OF MADISON COUNTY
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Understanding natural fracture systems plays a key role in tight carbonate fields where production is dependent on secondary porosity and pore connectivity. Locating geographic and stratigraphic areas with high natural fracture density and optimizing horizontal well plans to connect fractures can enhance well performance and asset value. A workflow to identify the influence of natural fractures on well performance was conducted in the stacked carbonate play in east Texas. Density, resistivity, and gamma ray logs were used to generate an index curve to identify natural fractures. In wells with image log data, a reasonable correlation was observed between the fracture zones selected by this model and the image log interpretation. The index curve was calibrated with image log interpretation, and applied in other wells without image logs. Identifying the optimal distance from the fault where fractures are still present has become the main criterion for selecting locations for horizontal wells. 

Presented by:

Courtney Beck, Anna Khadeeva, Bhaskar Sarmah, and Andrew Whitsett,
Halliburton


Trey Kimbell,
Burk Royalty

Well Completion and Simulation
Room 107
(14) TICKETLESS TRACKING OF PRODUCED WATER FROM THE CRADLE TO THE GRAVE WITHOUT HUMAN INVOLVEMENT
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This is a discussion of a newly developed and field tested system to measure and track fluids produced in the oilfield.  The system’s mission is to track the fluid movement from the cradle to the grave and is, for the most part, a “hands off-no humans needed” custody scheme that provides precise verifiable electronic information to the producer, the trucking company that hauls the fluids, and the companies that handle the final deposition of the fluids, either at the disposal well or the pipeline terminal. 

The discussion centers on a West Texas well where the use of this system saves over $10,000 per year in operating costs.  The paper discloses patented technology as well as how the implementation process evolved and overcame the paradigms and mindsets of the people and companies.  Developing new technology is cake walk when compared to altering the complexity of the “oilfield thought” process.
 

Presented by:

Fred Newman

Artificial Lift
Room 108
(18) CORROSION- FATIGUE RESISTANT SUCKER RODS
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Corrosion fatigue (CF) is an important concern for structures that are exposed to cyclic loads in corrosive environments, especially in the case of oil and gas operations like drilling, offshore risers or sucker rods in artificial lift. Considering the current combination of complex wells completions and the increase of water cuts, the CO2, H2S and Bacteria represent a higher risk for CF failures in sucker rods. This combined effect force operators to choose a steel for either corrosive environments or high loads and increase the chemical inhibition programs.

In response to the new downhole challenges, a research and development program (R&D) has been created to analyze the key factors that affect sucker rods performance under CF. As a result of this R&D program, a new corrosion-fatigue resistance sucker rod has been developed. The present paper summarizes the development process, the new sucker rod characteristics and its performance.

Presented by:

Rodrigo Ruiz, Gustavo Alvarez, Edgardo Lopez, 
James Few, and Jeff Harris
Tenaris

Artificial Lift
Room 110
(26) OPERATIONAL OPTIMIZATION THRU FAILURE MEETINGS
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Failure meetings are a proven optimization tool to reduce failures, cut costs, and increase production. However, many companies don’t utilize this tool or don’t properly optimize it. This paper will cover the basics of preparing for and holding a failure meeting along with a brief explanation of root cause analysis.  

Presented by:

Mike Brock, Dan Phillips, and Rob Vincent
PLTech LLC

General Interest
Room 111
(31) CONSIDERATIONS FOR INCREASED EFFECTIVENESS OF TANK VAPOR COMBUSTION SYSTEMS AT PRODUCTION FACILITIES
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With the recent proliferation of federal and state regulation in regards to allowable emissions limits from oil and gas production facilities, sound emissions control methods and their utilization have become increasingly more important.  Operator environmental compliance has been frequently emphasized by regulatory agencies, and using vapor combustion units (VCU’s) to limit the atmospheric exposure of volatile organic compounds (VOC’s) from on-site storage tanks is a practice that is seen with increasing regularity. The installation of VCU’s can be time sensitive to ensure regulatory compliance and, because of this, it is not uncommon for the importance of key variables to be underestimated or overlooked.  Throughout this paper, considerations are provided to bring several of these factors to the operators’ attention to ensure that the unit and associated piping is installed with maximum effectiveness.

Presented by:

Colyn Jurek, Ryan Duncan and Andrew Humphreys 
OXY USA Inc.

Prod. Handling

11:00AM - 11:50AM (Wednesday)

Room 101
(08) SAND CONTROL METHODS TO IMPROVE ESP OPERATIONAL CONDITIONS AND RUN TIME
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Sandy wells are a common problem for any artificial lift system. Calculating the correct allowable volume of sand and solids’ particle size may be the missing link in optimizing run-times and establishing solid pump performance.

Recent Colombian ESP case studies were conducted in fields with high sand/solids presence. Where run times typically lasted 5 months or less, a new design to improve ESP performance introduced a Cup Packer and screens below the ESP sensor.

Once ESP variables such as intake pressure, drive frequency, and temperature were considered, the unit conditions stabilized and improved performance followed, greatly extending run times, and reducing unnecessary intervention costs.
 

Presented by:

Gustavo Gonzalez and Luis Guanacas 
Odessa Separator Inc.

Artificial Lift
Room 104
(21) ADVANCED SUCKER ROD MATERIAL REDUCES WEAR IN UNCONVENTIONAL WELLS-CASE HISTORIES
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Tubing leaks account for half of the failures in the Bakken wells. The root cause is coupling on tubing wear due to the non-metallic guides wearing out.  

In order to combat this problem, ToughMet 3 TS95 sucker rod couplings were installed in up to 250 wells to significantly reduce the failure rate in the field.  Several individual case histories will be discussed to demonstrate the lifetime extension and reduced wear rates seen with the use of the new couplings.

Additional benefits have been observed, particularly increased fluid production, increased pump fillage, higher Fluid loads, and lower gearbox loads. XSPOC data will be presented for several wells to demonstrate the positive effects observed in the field.

Presented by:

Seth Silverman, Hess Corp.
Diane Nielsen and William Nielsen, Materion Corp.

 

Artificial Lift
Room 108
(20) MITIGATING SLUG FLOW AND TRANSITIONING FROM GAS LIFTING TO ROD PUMPING RESULTS IN SIGNIFICANT INCREASE IN MULTIPLE WELL NPVs
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Production challenges in horizontal wells are caused by slug flow behaviour from the horizontal. In response, Production Plus developed the flow conditioning HEAL System to mitigate slug flow before fluids enter the downhole separator and pump. Slug flow mitigation allows rod pumping to be more effective and efficient, offering a solution for low-cost OPEX to reliably maximize drawdown.

This paper analyzes multiple HEAL System installations in the Permian Basin that transition from gas lifting to HEAL System rod pumping. It explores requirements for intermediate artificial lift systems, challenges achieving production forecasts, slug flow and solids production mechanisms, and impact from horizontal trajectories.  The discussion compares recent long-term, multiple case studies that statistically demonstrate the impact of flow conditioning on well production economics. It offers insights into long-term NPV benefits achieved by transitioning from gas lifting to the HEAL System with rod pumping.

Presented by:

Jeff Saponja and Dave Kimery
Production Plus Energy Services Inc.
Greg Wilkes
Broad Oak Energy ll LLP
 

Artificial Lift
Room 111
(32) SIMPLICITY IN VRU BY USING A BGC
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Vapor Recovery Units are often expensive, complicated to operate and unable to deal with High H2S and liquids.  The Beam Gas Compressor is a product that has served the measure of time.. after 35 years of operation its durability is now being shown as a vapor recovery unit. Without the need of a control panel and scrubber tank the Hydraulically driven Beam Gas Compressor (HyBGC) can be easily serviced by most oil field personnel.  No special schooling or training is necessary.  Without the need for a control panel there is no need for special automation technical service.  Making the HyBGC the perfect VRU for small to medium size companies.  Majors too, anyone needing consistent and reliable emissions control.

Presented by:

Mark W.Lancaster and  Charlie McCoy

Permian Production Equipment, Inc.

Prod. Handling

01:00PM - 01:50PM (Wednesday)

Room 101
(07) PERFORMANCE CASE STUDY OF A STATIC/CENTRIFUGAL DOWNHOLE GAS SEPARATOR IN GASSY WELLS (BROAD OAK ENERGY)
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Poor performance in rod pumping wells using downhole gas separation tools is not uncommon. The stems from a lack of evaluating well conditions before inserting a template gas separation tool which can handle liquid production and free gas in the system. Evaluating well conditions before designing the downhole gas separation tool while applying static & centrifugal principals have led to increased success for recent installations.

This paper reviews cases studies where evaluations of well conditions dictated BHA design for downhole gas separation systems and improved the overall pump efficiency in poorly performing wells with high gas volume.

Presented by:

Gustavo Gonzalez, Luis Guanacas and Bob Greer
Odessa Separator Inc.

Greg Wilkes, Broad Oak Energy

 

Artificial Lift
Room 102
(41) A RE-INTRODUCTION TO OIL AND GAS WELL STIMULATION WITH CHLORINE DIOXIDE (CLO2)
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Chlorine Dioxide (ClO2) has been used as a well damage removal and stimulation fluid since the late 1980’s. It was originally investigated as a means to remediate reservoirs of the permanently damaging effects of polymer, monomer, and polyacrylamide floods popular in the 1980’s across many conventional oilfields, including those in the Permian Basin of West Texas, U.S.A. Chlorine Dioxide is a strong oxidizer and highly effective biocide, very popular today for preparing frac waters and aiding in recycling produced waters, also to be used in fracturing.  Many petroleum engineers and oilfield production personnel are not aware of the chemistry, or services available to remove the damaging effects of polymers, polyacrylamide, frac gel, gel filter cake, biomass / biofilms, Hydrogen Sulfide (H2S), Iron Sulfide (FeS), Iron Oxide (Fe2O3), all species of bacteria including Sulfate Reducing Bacteria (SRB’s), and many other oxidizable particles that have plugged and otherwise damaged all types of wells.  Chlorine Dioxide has proven to be extremely effective in salt water disposal (SWD’s) and injection wells, but has also found an important role in vertical and horizontal producers having production challenges such as Iron Sulfide, due to the infiltration of SRB’s into the reservoir and the subsequent H2S, FeS, and H2S corrosion. This paper forms a summary of the ways Chlorine Dioxide, in conjunction with Hydrochloric acid (HCL), is used to remove wellbore damage, drastically reduce H2S levels, and overall, restore the well’s injectivity or productivity.  In addition, the paper outlines to the key aspects of treatment design to insure success while concentrating on practical field applications, as demonstrated in wells across the Permian Basin.

Presented by:

Brent Smith, Sabre Energy Services, LLC

Well Completion and Simulation
Room 104
(13) VORTEX TOOLS FOR HORIZONTAL LATERALS OIL PRODUCTION ENHANCEMENT
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Vortex Tools addresses the challenges of managing/optimizing hydrocarbon liquids recovery from horizontal wells with long laterals, thereby increasing their economic value. A 2014 five-well case study with a regional independent found that deploying Vortex downhole DX-I tubing tools (in conjunction with gas lift and plunger) saw beneficial increases in oil & gas production, along with a significant increase in water removal, in horizontal and deviated wells. Injection gas rates were also reduced after Vortex was added, but saw increased gas to sales, as well as lower/smoother tubing and casing pressures. Vortex was deployed at the end of tubing, in the horizontal/lateral portion of the well (~80° of deviation). With Vortex tools installed, oil production increased significantly. In one reported case, the oil production increased from 80 barrels to over 400 barrels per day. A two-year lookback on these wells also showed a beneficial decline curve in all cases.

Presented by:

Colin McKay Miller, Alan Miller,  and Richard C. Haas
Vortex Tools

Artificial Lift
Room 106
(39) FROM ZONE ABANDONMENT TO RESTORING WELLBORE INTEGRITY: MODERN EPOXY RESIN TECHNOLOGY WELL REMEDIATION CASE STUDIES
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This paper discusses Permian Basin examples of a modern epoxy resin system that is compatible with most water- and oil-based wellbore fluid systems. Its unique mechanical properties and resistance to contamination make it a good solution for issues too complex, costly, or difficult to resolve using traditional remediation methods and materials. These case studies include the following uses of this epoxy resin: 1) as a squeeze treatment to repair a well production casing leakage, re-establishing casing integrity, and allowing the planned stimulation treatment in 60 stages; 2) on a rigless intervention to spot a cap on a sand plug to abandon a set of perforations and help improve the injectivity profile in two wells; 3) during gas-tight re-cementing operations through casing perforations after poor primary cementing; and 4) during remediation of tight casing leaks in injection wells to meet mechanical integrity test regulations.

Presented by:

Olvin Hernandez, Brandon Kimble and Paul Jones 
Halliburton 

Well Completion and Simulation
Room 107
(03) IMPROVE HORIZONTAL ROD PUMP OPERATIONS UTILIZING ISOLATED TAILPIPE
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There is a growing awareness in the oilfield of the problems generated due to horizontal wells’ long lateral lengths, undulation fluid and gas trapping capabilities, inconsistent and aggressive unloading behaviors, and limitations on historically and widely applied separation methods.  Due to these impacting factors, horizontal rod pumped wells must address the resultant production behaviors as well as operational issues that can be worsened by poor application of old and non-optimal downhole separation and poor pump placement practices.  It has now been proven in a multitude of applications and formations across the US that the use of a safely and correctly placed isolated tailpipe used in series with a diverter style of separator can help alleviate challenging production issues in horizontal rod pumped wells, resulting in substantially increased production output as well as reduced failures and lower operational costs.    

Presented by:

Brian Ellithorp, James N. McCoy and Lynn Rowlan
Echometer Company

Artificial Lift
Room 108
(01) SUCKER ROD PUMP ROOT CAUSE FAILURE ANALYSIS
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Producers can spend a significant amount of money repairing a sucker rod pump system without fully understanding the root cause of a failure. Incomplete, missing or incorrect data and over reliance on a supplier to “fix the problem” can be ineffective. Following “best practices” developed in other fields or generic “rules of thumb” may also lead to higher than expected failure rate especially in unconventional reservoirs.

Common practice of a “like for like” replacement may experience an early life failure resulting in another workover. This increases lifting cost and contributes to unfavorable well and field economics.

Presented by:

Fred W. Clarke

Murphy Exploration and Production

 

Artificial Lift
Room 110
(34) OIL EFFECTS ON THE DEHYDRATION OF SUPER ABSORBENT POLYMERS
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This research was conducted to solve problems of Super Absorbent Polymers (SAPs) dehydration in oil field applications.  Two polymer sizes were used separately and mixed with various brines.  After allowing the polymers to fully swell, oil was added to the mixture and the effects of Brine was observed.  Initial readings of oil effects on swelling was taken.  The samples were allowed to hear to 100 degrees Celsius and the effects were recorded. Oil increases the hydration of SAP's for both types of polymers.  Also, for both sizes of polymers, high temperatures caused polymers to float.  The heat lessened density of the polymers.  Particle size was a factor in the behavior of the polymers.  These results can identify which particle size to use according to the brine concentrations, temperatures, and the reservoir fluid properties.  Knowing how oil effects the SAP's helps oil companies to create a formula for each circumstance.  

Presented by:

Mahmoud Elsharafi, Brandy Fields, and Kristen Moss
Medwestern State University

Reservoir Operation
Room 111
(30) CHEMICAL PROGRAM BASICS
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Most operating areas require chemical programs, but most operating companies do not have chemical knowledgeable personnel to help set a program up, evaluate its performance, and/or optimize the overall program.  This paper presents an overview of chemical programs along with a brief discussion of various potential parts of a program.  An operator will be able to use the information presented here to set up performance indicators to evaluate a program and decide how best to optimize their chemical program.    
 

Presented by:

Mike Brock - PL Tech LLC
Amber Helm - Anadarko

Prod. Handling

02:00PM - 02:50PM (Wednesday)

Room 102
(42) NEW HIGH PERFORMANCE RESIN FOR THERMOPLASTIC LINERS
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Corrosion enhanced abrasive wear is a common cause of failure in sucker rod systems. The combination of high side loads caused by deviation and the presence of corrosive chemicals creates a very difficult environment for operators. The cyclical loading nature of sucker rod system adds to the problem, leading to premature failures in rods and tubing. Operators are turning to many technologies to increase mean time between failures (MTBF) in these challenging wells. Thermoplastic liners is one of the many options to extend run life in deviated wellbores. Liners are extruded from specialty compounded resins, each with its own set of advantages and disadvantages. A new resin is now 
being extruded to fill the void between 200 and 250 degrees Fahrenheit, allowing operators to maximize the benefit of lined tubing at a more economical price than higher temperature resins. This paper summarizes the properties of the new resin in comparison to the other resins currently on the market.
 

Presented by:

Zach Stearman, Lightning Rod & Pipe

Well Completion and Simulation
Room 104
(19) PREVENTING FAILURES FROM THE POLISHED ROD CLAMP TO THE DIP TUBE
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This paper will discuss reducing failures in rod pumped wells by using best practices and design changes. The theme of the paper is to share solutions observed over the last 41 years while working with rod pumped wells. These best practices applied from the polished rod through the bottom hole assembly have been proven to improve run time between failures. The topics discussed are improper installation of equipment along with the effect of a properly designed bottom hole assembly. I will also highlight pump designs and accessory items to help with sand and gas issues. When you lower your failure frequency you are reducing exposure to potential accidents benefiting us all.

Presented by:

Rodney Sands
Dover ALS/Harbison Fischer

Artificial Lift
Room 106
(40) VENTURI JET JUNK BASKET TO CLEANOUT HORIZONTAL YESO PRODUCERS
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During the life of Yeso horizontal oil producers, well intervention and remediation is an essential step to ensure the maximum inflow volumes are being obtained and recovered volumes are matching the established production decline curves. Utilizing a Jet Junk Basket BHA with stick pipe has enabled Concho to successfully clean out a wellbore without the added cost of energized fluids and minimize the risk from getting stuck due to lost circulation. Frac sand that migrates into the wellbore during production and scale precipitation can hinder the well’s drawdown. One of the biggest challenges in being able to remove solids from the wellbore on the New Mexico Shelf is low bottom-hole reservoir pressure. Traditional cleanout methods that utilize reverse circulation and the assistance of energized fluids require higher bottom-hole reservoir pressures than that which is found on the New Mexico Shelf. The inability to maintain circulation during traditional cleanout operations has resulted in unsuccessful jobs and diminished economic efficiencies for projects in recent years prior to the application of the Venturi tool. This document describes case history and data complied over the workover results seen in 2015 and 2016. Overall, a total of 22 were successfully executed, providing an average of 35 barrels of oil per day.

Presented by:

Michael James
COG Operating

Well Completion and Simulation
Room 107
(16) GAS SEPARATOR SELECTION AND PERFORMANCE
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Many sucker rod lifted wells are operating at less than 30% electrical efficiency, because the downhole gas separator installed in the well is inefficient.  Free gas interfering with liquid filling the pump is a major operational problem encountered in producing Sucker Rod Lifted wells.  Gas interference is when free gas at the pump intake enters the pump filling displacement volume with gas in place of liquid, then significant loss in liquid production, reduced drawdown, increased failures and inefficiency occurs.  Installing an incorrectly designed gas separator is the most common problem.  Installing very long separators does not increase separator capacity or efficiency.  Restrictions in the annulus above the pump intake such as tubing anchors result in reduced annular gas flow with gas preferentially entering the pump.  A downhole gas separator has a maximum liquid capacity.  Casing size restricts the maximum size gas separator that can be installed in a well.  The separator used in a well should be designed for the well configuration/conditions.  Gas Separators with high separation efficiency should be used to effectively produce sucker rod lifted wells.

Presented by:

Jim McCoy, Lynn Rowlan, Brian Ellithorp, Echometer Company

Tony Podio, Univeristy of Texas at Austin

 

Artificial Lift
Room 108
(22) ENHANCING FAILURE ANALYSIS THROUGH THE USE OF ROD PUMP SERVICE DATA
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Rod pump service data provides valuable insight into wellbore conditions and the efficacy of the rod lift system. Trend analysis of metrics such as reason for well pull and pump component evaluation provides increased visibility about individual well performance issues and more broadly, about field performance. Comprehensive pump service data is an indispensable supplement to an operator’s internal data in well review meetings for the purpose of improving optimization efforts. This paper will focus primarily on how this data may be used to benefit two key factors: performance and design.

Presented by:

Zackary D. Smith, and Jonathan Dove 
Don-Nan Pump & Supply

Artificial Lift
Room 110
(28) MULTI-POROSITY MODELING FOR UNCONVENTIONAL RESERVOIRS
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One of the challenges in unconventional gas/oil reservoirs is characterization and modeling. There are different models for describing the production in an unconventional reservoir, i.e. dual porosity, triple porosity, etc. In this paper we generalize the solution for a Multi-Porosity Model (MPM). Different MPMs are considered and an appropriate measure will be discussed to select the best model that describes the production data using any known reservoir properties. After selecting the best model, the sensitivity analysis will be done to determine the main parameters that effect production. These parameters can be estimated by matching the MPM to the well’s production history. All reservoir models have the inherent flaw of generating non-unique solutions, more than one correct answer. We offer a solution to this challenge by randomizing the input variables and generating a statically probably of the unique solution. Two wells have been analyzed and validated through history matching and used for forecasting production.

Presented by:

Timothy McNealy and Mohammadreza Ghasemi
Halliburton Energy Services

General Interest
Room 111
(33) PRODUCTION CHEMICAL APPLICATIONS: USING ANALYTICAL DATA TO MONITOR AND OPTIMIZE CHEMICAL TREATMENTS
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Advancing technology has enabled the oil and gas Industry to analyze and track constituents in fluid samples. However, without proper sampling, proper laboratory procedures, and the correct interpretation of such analyses, this data could be erroneous and could result in costly and unnecessary actions.  

Through proper analytical sampling, testing and understanding of these results operators can monitor and optimize chemical applications.

This paper discusses:
• Common analytical testing performed within the oil and gas production  
chemical industry.
• Identification of critical hold-points within these procedures.
• Common general rules for the identification of possible anomalies during  
such analyses.
• How these tests can be applied to assist optimization of chemical  
applications.

Presented by:

Becky L. Ogden
Multi-Chem, a Halliburton Service

Prod. Handling

03:30PM - 04:20PM (Wednesday)

Room 101
(09) STATIC GAS SEPERATION INCREASES ESP EFFICIENCY IN COLOMBIAN FIELD
More Information

Some Colombian oilfields have medium to heavy oil production and high gas volume in wells.  Gas production is one of the biggest limitations in an ESP system, as they have difficulty handling a high amount of free gas.  In many cases even when an ESP is used in conjunction with a gas separator and gas handlers, the amount of free gas exceeds the capacity of the system and the performance of the pump is not improved.

For a complex well of this oilfield which produced 2.2 MMCF/D (represented around 20% of the total gas produce in this Oilfield). (OSI) designed a double stage gas separation system.  The ESP design consisted of a vortex ESP gas separator, gas handler, shrouded ESP + downhole gas separator with the intake installed below the shroud.  This combination proved to be successful with strong pump performance.
 

Presented by:

Gustavo Gonzalez, Randy Simonds and Diego Pinto
Odessa Separator Inc.

Artificial Lift
Room 104
(04) FIBERGLASS ROD DESIGN AND LOAD HANDLING
More Information

The last few years there has been quite a bit of advancement in the fiberglass sucker rods (FSR).  The published ratings across the fiberglass industry have increased over 20% with some manufactures going much higher.   What other benefits have come along with this increase?  Have there been any drawbacks?  This paper will discuss proper design criteria including importance of well specific criteria.  With load ratings increasing as much as they have a better understanding of the dynamics of the wellbore are needed as many companies are realizing further cost savings by substituting smaller rod body diameters and getting similar productions.  Lastly this paper will present some preliminary data on compression testing being performed and how that has correlated into the successes for the FSR installed in the field.

Presented by:

Ryan Gernentz, Karol Hricisak, Jairo Ocando and Dustin Martin
Endurance Lift Solutions

Artificial Lift
Room 106
(37) A COMPLIMENTARY METHOD OF ASSESSING CLAY STABILIZERS USED IN HYDRAULIC FRACTURING APPLICATIONS
More Information

Reservoirs having clays that swell/migrate can potentially impair production. When these clays are present, it is advantageous to use clay stabilizers to mitigate this damage potential.  The industry has adopted several clay assessment methods including analytical procedures such as XRD, SEM and performance testing methods such as capillary suction test (CST) and roller oven test. This paper will describe a new performance test method for inhibitors used in shale reservoirs that complements the existing methods.  A modified core flow method has been developed using unconsolidated core material that indirectly measures the clay swelling and migration potential.  In this procedure, a packed column composed of tightly-sized shale material is used to simulate an infinite fracture network.  Treatment fluids are then pumped through the column at constant rate while measuring pressure drop.   The relative pressure change, together with the turbidity of the effluent, allows easy assessment of the clay stabilizer.

Presented by:

Jeff Dupont, Rick Mitchell, and Jeff Dawson
Innospec Oilfield Services

Well Completion and Simulation
Room 107
(17) OVER-TRAVEL CAN OCCUR ON BOTH THE UPSTROKE AND DOWN STROKE
More Information

The pump stroke can be longer than the surface stroke when the dynamic motion of the beam pump system adds momentum to the rod string, resulting in the pump stroke length increasing.  The pump stroke can be shorter than the surface stroke when sucker rods stretch to pick up the pump fluid load and other frictional forces.  Rod stretch creates under travel dynamometer card shape.  Pumping fast or high plunger velocities creates over travel cards. 

Pump position in the barrel changes when the pump is not full compared to a stroke when the pump is filled with liquid.  When incomplete pump fillage occurs, the plunger tends to over travels on the down stroke moving deeper into the barrel.  In some cases tagging can occur due to pump spacing, plus increased over travel.  This paper will use field collected dynamometer data to show excessive over-travel can occur on both the upstroke and the down stroke.  
 

Presented by:

O. Lynn Rowlan, Carrie Anne Taylor and Ryan P. Craig

Echometer Company

Artificial Lift
Room 108
(24) MATURE ASSETS IN THE PERMIAN BASIN SHOW SIGNIFICANT PRODUCTION INCREASES WITH PLUNGER LIFT
More Information

There are thousands of marginal wells in the Permian Basin with potential to produce significantly more oil and gas with the assistance of plunger lift.  Working with multiple operators in the Permian Basin, PLSI has installed plunger lift systems in these type wells and realized significant increases in oil and gas production.  The common characteristic is fluid downhole which never makes it to the surface production facilities.  This fluid loads up the wellbore downhole which increases hydrostatic back pressure on the formation that holds back production.  By installing a plunger lift system, we have seen wells that were producing a few barrels of fluid per day double oil or gas production. This paper will present production data from operators showing increases in production and revenue with minimum expense that resulted in significant increases in net operating income. 

Presented by:

Mike Swihart
Production Lift Companies

Artificial Lift
Room 110
(35) SINGLE WELL PRODUCTIVE MODEL BY USING SYSTEM NODEL ANALYSIS
More Information

There are a lot of multiphase flow correlations available in oil industry worldwide, but many times these correlations do not match with the real measured pressure data, consequently we need to get out the best correlation for this data which is give us the representative or reliable results close to measured data with the least error as possible as we can.

In our study we took well X-1; from Nakhla Field as a case study. Six production tests were used to estimate well productivity index at different time and flowing pressure survey were collected and analyzed by using Microsoft Excel and PROSPER software in order to calculate and plot the pressure gradient and to compare the results obtained by different methods with the actual one to find the best method that gives us the less value of error comparing with actual one used for construct IPR-VLP performance and make prediction for future performance by using sensitivity analysis for different reservoir pressure and gas oil ratio (GOR).

Based on this study, some of the multiphase correlations given acceptable results if compared with actual data measured ones, but didn’t have any solution in nodal analysis as in case of Mukherjee Brill correlation, and some of them given low value of error but there results and behavior in the nodal analysis not acceptable as in case of Beggs and Brill correlation.

Presented by:

Laila Saleh, University of Tripoli, Tripoli, Libya
Mahmoud Elsharafi and Haiat K. Alha, Midwestern State University

Reservoir Operation

Thursday, May 25th

09:00AM - 09:50AM (Thursday)

Room 102
(42) NEW HIGH PERFORMANCE RESIN FOR THERMOPLASTIC LINERS
More Information

Corrosion enhanced abrasive wear is a common cause of failure in sucker rod systems. The combination of high side loads caused by deviation and the presence of corrosive chemicals creates a very difficult environment for operators. The cyclical loading nature of sucker rod system adds to the problem, leading to premature failures in rods and tubing. Operators are turning to many technologies to increase mean time between failures (MTBF) in these challenging wells. Thermoplastic liners is one of the many options to extend run life in deviated wellbores. Liners are extruded from specialty compounded resins, each with its own set of advantages and disadvantages. A new resin is now 
being extruded to fill the void between 200 and 250 degrees Fahrenheit, allowing operators to maximize the benefit of lined tubing at a more economical price than higher temperature resins. This paper summarizes the properties of the new resin in comparison to the other resins currently on the market.
 

Presented by:

Zach Stearman, Lightning Rod & Pipe

Well Completion and Simulation
Room 104
(19) PREVENTING FAILURES FROM THE POLISHED ROD CLAMP TO THE DIP TUBE
More Information

This paper will discuss reducing failures in rod pumped wells by using best practices and design changes. The theme of the paper is to share solutions observed over the last 41 years while working with rod pumped wells. These best practices applied from the polished rod through the bottom hole assembly have been proven to improve run time between failures. The topics discussed are improper installation of equipment along with the effect of a properly designed bottom hole assembly. I will also highlight pump designs and accessory items to help with sand and gas issues. When you lower your failure frequency you are reducing exposure to potential accidents benefiting us all.

Presented by:

Rodney Sands
Dover ALS/Harbison Fischer

Artificial Lift
Room 106
(39) FROM ZONE ABANDONMENT TO RESTORING WELLBORE INTEGRITY: MODERN EPOXY RESIN TECHNOLOGY WELL REMEDIATION CASE STUDIES
More Information

This paper discusses Permian Basin examples of a modern epoxy resin system that is compatible with most water- and oil-based wellbore fluid systems. Its unique mechanical properties and resistance to contamination make it a good solution for issues too complex, costly, or difficult to resolve using traditional remediation methods and materials. These case studies include the following uses of this epoxy resin: 1) as a squeeze treatment to repair a well production casing leakage, re-establishing casing integrity, and allowing the planned stimulation treatment in 60 stages; 2) on a rigless intervention to spot a cap on a sand plug to abandon a set of perforations and help improve the injectivity profile in two wells; 3) during gas-tight re-cementing operations through casing perforations after poor primary cementing; and 4) during remediation of tight casing leaks in injection wells to meet mechanical integrity test regulations.

Presented by:

Olvin Hernandez, Brandon Kimble and Paul Jones 
Halliburton 

Well Completion and Simulation
Room 107
(16) GAS SEPARATOR SELECTION AND PERFORMANCE
More Information

Many sucker rod lifted wells are operating at less than 30% electrical efficiency, because the downhole gas separator installed in the well is inefficient.  Free gas interfering with liquid filling the pump is a major operational problem encountered in producing Sucker Rod Lifted wells.  Gas interference is when free gas at the pump intake enters the pump filling displacement volume with gas in place of liquid, then significant loss in liquid production, reduced drawdown, increased failures and inefficiency occurs.  Installing an incorrectly designed gas separator is the most common problem.  Installing very long separators does not increase separator capacity or efficiency.  Restrictions in the annulus above the pump intake such as tubing anchors result in reduced annular gas flow with gas preferentially entering the pump.  A downhole gas separator has a maximum liquid capacity.  Casing size restricts the maximum size gas separator that can be installed in a well.  The separator used in a well should be designed for the well configuration/conditions.  Gas Separators with high separation efficiency should be used to effectively produce sucker rod lifted wells.

Presented by:

Jim McCoy, Lynn Rowlan, Brian Ellithorp, Echometer Company

Tony Podio, Univeristy of Texas at Austin

 

Artificial Lift
Room 108
(22) ENHANCING FAILURE ANALYSIS THROUGH THE USE OF ROD PUMP SERVICE DATA
More Information

Rod pump service data provides valuable insight into wellbore conditions and the efficacy of the rod lift system. Trend analysis of metrics such as reason for well pull and pump component evaluation provides increased visibility about individual well performance issues and more broadly, about field performance. Comprehensive pump service data is an indispensable supplement to an operator’s internal data in well review meetings for the purpose of improving optimization efforts. This paper will focus primarily on how this data may be used to benefit two key factors: performance and design.

Presented by:

Zackary D. Smith, and Jonathan Dove 
Don-Nan Pump & Supply

Artificial Lift
Room 110
(28) MULTI-POROSITY MODELING FOR UNCONVENTIONAL RESERVOIRS
More Information

One of the challenges in unconventional gas/oil reservoirs is characterization and modeling. There are different models for describing the production in an unconventional reservoir, i.e. dual porosity, triple porosity, etc. In this paper we generalize the solution for a Multi-Porosity Model (MPM). Different MPMs are considered and an appropriate measure will be discussed to select the best model that describes the production data using any known reservoir properties. After selecting the best model, the sensitivity analysis will be done to determine the main parameters that effect production. These parameters can be estimated by matching the MPM to the well’s production history. All reservoir models have the inherent flaw of generating non-unique solutions, more than one correct answer. We offer a solution to this challenge by randomizing the input variables and generating a statically probably of the unique solution. Two wells have been analyzed and validated through history matching and used for forecasting production.

Presented by:

Timothy McNealy and Mohammadreza Ghasemi
Halliburton Energy Services

General Interest

10:00AM - 10:50AM (Thursday)

Room 101
(09) STATIC GAS SEPERATION INCREASES ESP EFFICIENCY IN COLOMBIAN FIELD
More Information

Some Colombian oilfields have medium to heavy oil production and high gas volume in wells.  Gas production is one of the biggest limitations in an ESP system, as they have difficulty handling a high amount of free gas.  In many cases even when an ESP is used in conjunction with a gas separator and gas handlers, the amount of free gas exceeds the capacity of the system and the performance of the pump is not improved.

For a complex well of this oilfield which produced 2.2 MMCF/D (represented around 20% of the total gas produce in this Oilfield). (OSI) designed a double stage gas separation system.  The ESP design consisted of a vortex ESP gas separator, gas handler, shrouded ESP + downhole gas separator with the intake installed below the shroud.  This combination proved to be successful with strong pump performance.
 

Presented by:

Gustavo Gonzalez, Randy Simonds and Diego Pinto
Odessa Separator Inc.

Artificial Lift
Room 102
(41) A RE-INTRODUCTION TO OIL AND GAS WELL STIMULATION WITH CHLORINE DIOXIDE (CLO2)
More Information

Chlorine Dioxide (ClO2) has been used as a well damage removal and stimulation fluid since the late 1980’s. It was originally investigated as a means to remediate reservoirs of the permanently damaging effects of polymer, monomer, and polyacrylamide floods popular in the 1980’s across many conventional oilfields, including those in the Permian Basin of West Texas, U.S.A. Chlorine Dioxide is a strong oxidizer and highly effective biocide, very popular today for preparing frac waters and aiding in recycling produced waters, also to be used in fracturing.  Many petroleum engineers and oilfield production personnel are not aware of the chemistry, or services available to remove the damaging effects of polymers, polyacrylamide, frac gel, gel filter cake, biomass / biofilms, Hydrogen Sulfide (H2S), Iron Sulfide (FeS), Iron Oxide (Fe2O3), all species of bacteria including Sulfate Reducing Bacteria (SRB’s), and many other oxidizable particles that have plugged and otherwise damaged all types of wells.  Chlorine Dioxide has proven to be extremely effective in salt water disposal (SWD’s) and injection wells, but has also found an important role in vertical and horizontal producers having production challenges such as Iron Sulfide, due to the infiltration of SRB’s into the reservoir and the subsequent H2S, FeS, and H2S corrosion. This paper forms a summary of the ways Chlorine Dioxide, in conjunction with Hydrochloric acid (HCL), is used to remove wellbore damage, drastically reduce H2S levels, and overall, restore the well’s injectivity or productivity.  In addition, the paper outlines to the key aspects of treatment design to insure success while concentrating on practical field applications, as demonstrated in wells across the Permian Basin.

Presented by:

Brent Smith, Sabre Energy Services, LLC

Well Completion and Simulation
Room 104
(04) FIBERGLASS ROD DESIGN AND LOAD HANDLING
More Information

The last few years there has been quite a bit of advancement in the fiberglass sucker rods (FSR).  The published ratings across the fiberglass industry have increased over 20% with some manufactures going much higher.   What other benefits have come along with this increase?  Have there been any drawbacks?  This paper will discuss proper design criteria including importance of well specific criteria.  With load ratings increasing as much as they have a better understanding of the dynamics of the wellbore are needed as many companies are realizing further cost savings by substituting smaller rod body diameters and getting similar productions.  Lastly this paper will present some preliminary data on compression testing being performed and how that has correlated into the successes for the FSR installed in the field.

Presented by:

Ryan Gernentz, Karol Hricisak, Jairo Ocando and Dustin Martin
Endurance Lift Solutions

Artificial Lift
Room 106
(37) A COMPLIMENTARY METHOD OF ASSESSING CLAY STABILIZERS USED IN HYDRAULIC FRACTURING APPLICATIONS
More Information

Reservoirs having clays that swell/migrate can potentially impair production. When these clays are present, it is advantageous to use clay stabilizers to mitigate this damage potential.  The industry has adopted several clay assessment methods including analytical procedures such as XRD, SEM and performance testing methods such as capillary suction test (CST) and roller oven test. This paper will describe a new performance test method for inhibitors used in shale reservoirs that complements the existing methods.  A modified core flow method has been developed using unconsolidated core material that indirectly measures the clay swelling and migration potential.  In this procedure, a packed column composed of tightly-sized shale material is used to simulate an infinite fracture network.  Treatment fluids are then pumped through the column at constant rate while measuring pressure drop.   The relative pressure change, together with the turbidity of the effluent, allows easy assessment of the clay stabilizer.

Presented by:

Jeff Dupont, Rick Mitchell, and Jeff Dawson
Innospec Oilfield Services

Well Completion and Simulation
Room 107
(17) OVER-TRAVEL CAN OCCUR ON BOTH THE UPSTROKE AND DOWN STROKE
More Information

The pump stroke can be longer than the surface stroke when the dynamic motion of the beam pump system adds momentum to the rod string, resulting in the pump stroke length increasing.  The pump stroke can be shorter than the surface stroke when sucker rods stretch to pick up the pump fluid load and other frictional forces.  Rod stretch creates under travel dynamometer card shape.  Pumping fast or high plunger velocities creates over travel cards. 

Pump position in the barrel changes when the pump is not full compared to a stroke when the pump is filled with liquid.  When incomplete pump fillage occurs, the plunger tends to over travels on the down stroke moving deeper into the barrel.  In some cases tagging can occur due to pump spacing, plus increased over travel.  This paper will use field collected dynamometer data to show excessive over-travel can occur on both the upstroke and the down stroke.  
 

Presented by:

O. Lynn Rowlan, Carrie Anne Taylor and Ryan P. Craig

Echometer Company

Artificial Lift
Room 108
(01) SUCKER ROD PUMP ROOT CAUSE FAILURE ANALYSIS
More Information

Producers can spend a significant amount of money repairing a sucker rod pump system without fully understanding the root cause of a failure. Incomplete, missing or incorrect data and over reliance on a supplier to “fix the problem” can be ineffective. Following “best practices” developed in other fields or generic “rules of thumb” may also lead to higher than expected failure rate especially in unconventional reservoirs.

Common practice of a “like for like” replacement may experience an early life failure resulting in another workover. This increases lifting cost and contributes to unfavorable well and field economics.

Presented by:

Fred W. Clarke

Murphy Exploration and Production

 

Artificial Lift
Room 110
(35) SINGLE WELL PRODUCTIVE MODEL BY USING SYSTEM NODEL ANALYSIS
More Information

There are a lot of multiphase flow correlations available in oil industry worldwide, but many times these correlations do not match with the real measured pressure data, consequently we need to get out the best correlation for this data which is give us the representative or reliable results close to measured data with the least error as possible as we can.

In our study we took well X-1; from Nakhla Field as a case study. Six production tests were used to estimate well productivity index at different time and flowing pressure survey were collected and analyzed by using Microsoft Excel and PROSPER software in order to calculate and plot the pressure gradient and to compare the results obtained by different methods with the actual one to find the best method that gives us the less value of error comparing with actual one used for construct IPR-VLP performance and make prediction for future performance by using sensitivity analysis for different reservoir pressure and gas oil ratio (GOR).

Based on this study, some of the multiphase correlations given acceptable results if compared with actual data measured ones, but didn’t have any solution in nodal analysis as in case of Mukherjee Brill correlation, and some of them given low value of error but there results and behavior in the nodal analysis not acceptable as in case of Beggs and Brill correlation.

Presented by:

Laila Saleh, University of Tripoli, Tripoli, Libya
Mahmoud Elsharafi and Haiat K. Alha, Midwestern State University

Reservoir Operation
Room 111
(33) PRODUCTION CHEMICAL APPLICATIONS: USING ANALYTICAL DATA TO MONITOR AND OPTIMIZE CHEMICAL TREATMENTS
More Information

Advancing technology has enabled the oil and gas Industry to analyze and track constituents in fluid samples. However, without proper sampling, proper laboratory procedures, and the correct interpretation of such analyses, this data could be erroneous and could result in costly and unnecessary actions.  

Through proper analytical sampling, testing and understanding of these results operators can monitor and optimize chemical applications.

This paper discusses:
• Common analytical testing performed within the oil and gas production  
chemical industry.
• Identification of critical hold-points within these procedures.
• Common general rules for the identification of possible anomalies during  
such analyses.
• How these tests can be applied to assist optimization of chemical  
applications.

Presented by:

Becky L. Ogden
Multi-Chem, a Halliburton Service

Prod. Handling

11:00AM - 11:50AM (Thursday)

Room 101
(07) PERFORMANCE CASE STUDY OF A STATIC/CENTRIFUGAL DOWNHOLE GAS SEPARATOR IN GASSY WELLS (BROAD OAK ENERGY)
More Information

Poor performance in rod pumping wells using downhole gas separation tools is not uncommon. The stems from a lack of evaluating well conditions before inserting a template gas separation tool which can handle liquid production and free gas in the system. Evaluating well conditions before designing the downhole gas separation tool while applying static & centrifugal principals have led to increased success for recent installations.

This paper reviews cases studies where evaluations of well conditions dictated BHA design for downhole gas separation systems and improved the overall pump efficiency in poorly performing wells with high gas volume.

Presented by:

Gustavo Gonzalez, Luis Guanacas and Bob Greer
Odessa Separator Inc.

Greg Wilkes, Broad Oak Energy

 

Artificial Lift
Room 102
(43) 2013-2015 ACID JOBS PERFORMANCE AND ANALYSIS ON EPS WELLS IN FIELD Y, INDONESIA
More Information

Pertamina Hulu Energi Offshore North West Java (PHE ONWJ), which is a Production Sharing Contractor of the Government of Indonesia, operates a large number of offshore ESP wells in Java Sea, Indonesia. To stimulate the wells and increase near-wellbore permeability, PHE ONWJ has executed matrix acidizing from 2013 until 2015. During acid deployment, ESP was left in place (downhole). In fact, the ESP was also switched on to unload the spent acid. Given the acid corrosive properties on metals which make up some of the ESP components, a post-stimulation evaluation was conducted in May 2016. This paper attempts to analyze the effect of acid jobs on ESP components integrity and field production performance. Afterwards, this paper discusses some approaches that PHE ONWJ believes to be applicable to observe any need for periodical acid job in the field.

Presented by:

Nur Wiaya

Texas Tech University, Petroleum Engineering

Artificial Lift
Room 104
(13) VORTEX TOOLS FOR HORIZONTAL LATERALS OIL PRODUCTION ENHANCEMENT
More Information

Vortex Tools addresses the challenges of managing/optimizing hydrocarbon liquids recovery from horizontal wells with long laterals, thereby increasing their economic value. A 2014 five-well case study with a regional independent found that deploying Vortex downhole DX-I tubing tools (in conjunction with gas lift and plunger) saw beneficial increases in oil & gas production, along with a significant increase in water removal, in horizontal and deviated wells. Injection gas rates were also reduced after Vortex was added, but saw increased gas to sales, as well as lower/smoother tubing and casing pressures. Vortex was deployed at the end of tubing, in the horizontal/lateral portion of the well (~80° of deviation). With Vortex tools installed, oil production increased significantly. In one reported case, the oil production increased from 80 barrels to over 400 barrels per day. A two-year lookback on these wells also showed a beneficial decline curve in all cases.

Presented by:

Colin McKay Miller, Alan Miller,  and Richard C. Haas
Vortex Tools

Artificial Lift
Room 106
(40) VENTURI JET JUNK BASKET TO CLEANOUT HORIZONTAL YESO PRODUCERS
More Information

During the life of Yeso horizontal oil producers, well intervention and remediation is an essential step to ensure the maximum inflow volumes are being obtained and recovered volumes are matching the established production decline curves. Utilizing a Jet Junk Basket BHA with stick pipe has enabled Concho to successfully clean out a wellbore without the added cost of energized fluids and minimize the risk from getting stuck due to lost circulation. Frac sand that migrates into the wellbore during production and scale precipitation can hinder the well’s drawdown. One of the biggest challenges in being able to remove solids from the wellbore on the New Mexico Shelf is low bottom-hole reservoir pressure. Traditional cleanout methods that utilize reverse circulation and the assistance of energized fluids require higher bottom-hole reservoir pressures than that which is found on the New Mexico Shelf. The inability to maintain circulation during traditional cleanout operations has resulted in unsuccessful jobs and diminished economic efficiencies for projects in recent years prior to the application of the Venturi tool. This document describes case history and data complied over the workover results seen in 2015 and 2016. Overall, a total of 22 were successfully executed, providing an average of 35 barrels of oil per day.

Presented by:

Michael James
COG Operating

Well Completion and Simulation
Room 107
(03) IMPROVE HORIZONTAL ROD PUMP OPERATIONS UTILIZING ISOLATED TAILPIPE
More Information

There is a growing awareness in the oilfield of the problems generated due to horizontal wells’ long lateral lengths, undulation fluid and gas trapping capabilities, inconsistent and aggressive unloading behaviors, and limitations on historically and widely applied separation methods.  Due to these impacting factors, horizontal rod pumped wells must address the resultant production behaviors as well as operational issues that can be worsened by poor application of old and non-optimal downhole separation and poor pump placement practices.  It has now been proven in a multitude of applications and formations across the US that the use of a safely and correctly placed isolated tailpipe used in series with a diverter style of separator can help alleviate challenging production issues in horizontal rod pumped wells, resulting in substantially increased production output as well as reduced failures and lower operational costs.    

Presented by:

Brian Ellithorp, James N. McCoy and Lynn Rowlan
Echometer Company

Artificial Lift
Room 108
(24) MATURE ASSETS IN THE PERMIAN BASIN SHOW SIGNIFICANT PRODUCTION INCREASES WITH PLUNGER LIFT
More Information

There are thousands of marginal wells in the Permian Basin with potential to produce significantly more oil and gas with the assistance of plunger lift.  Working with multiple operators in the Permian Basin, PLSI has installed plunger lift systems in these type wells and realized significant increases in oil and gas production.  The common characteristic is fluid downhole which never makes it to the surface production facilities.  This fluid loads up the wellbore downhole which increases hydrostatic back pressure on the formation that holds back production.  By installing a plunger lift system, we have seen wells that were producing a few barrels of fluid per day double oil or gas production. This paper will present production data from operators showing increases in production and revenue with minimum expense that resulted in significant increases in net operating income. 

Presented by:

Mike Swihart
Production Lift Companies

Artificial Lift
Room 110
(34) OIL EFFECTS ON THE DEHYDRATION OF SUPER ABSORBENT POLYMERS
More Information

This research was conducted to solve problems of Super Absorbent Polymers (SAPs) dehydration in oil field applications.  Two polymer sizes were used separately and mixed with various brines.  After allowing the polymers to fully swell, oil was added to the mixture and the effects of Brine was observed.  Initial readings of oil effects on swelling was taken.  The samples were allowed to hear to 100 degrees Celsius and the effects were recorded. Oil increases the hydration of SAP's for both types of polymers.  Also, for both sizes of polymers, high temperatures caused polymers to float.  The heat lessened density of the polymers.  Particle size was a factor in the behavior of the polymers.  These results can identify which particle size to use according to the brine concentrations, temperatures, and the reservoir fluid properties.  Knowing how oil effects the SAP's helps oil companies to create a formula for each circumstance.  

Presented by:

Mahmoud Elsharafi, Brandy Fields, and Kristen Moss
Medwestern State University

Reservoir Operation
Room 111
(30) CHEMICAL PROGRAM BASICS
More Information

Most operating areas require chemical programs, but most operating companies do not have chemical knowledgeable personnel to help set a program up, evaluate its performance, and/or optimize the overall program.  This paper presents an overview of chemical programs along with a brief discussion of various potential parts of a program.  An operator will be able to use the information presented here to set up performance indicators to evaluate a program and decide how best to optimize their chemical program.    
 

Presented by:

Mike Brock - PL Tech LLC
Amber Helm - Anadarko

Prod. Handling

01:00PM - 01:50PM (Thursday)

Room 101
(06) CONVERSION OF ESP TO ROD PUMPING SYSTEM WITH AN IMPROVED GAS SEPARATOR SYSTEM IN DEPLETED WELLS
More Information

The conversion from ESP to rod pump is needed when well-inflow is insufficient to supply enough fluid to the ESP. However, achieving good pump performance in rod pump systems operating in depleted wells with high gas/oil ratio can be limited as well. Creating a multi-stage gas separator system which removes free gas before fluid entered the pump intake increases volumetric efficiency in depleted wells. The first stage is a slotted intake where gas can coalesce. The second stage utilizes three large gas separator bodies for increased expansion of free gas which travels with the fluid by action of an extended dip tube. Finally, a vortex tool which creates a centrifugal force increases free gas separation efficiency.

A successful case study in Goldsmith is presented in this paper to demonstrate significant pump efficiency increase resulting from enhanced separator design based on downhole conditions to create a more efficient production system.
 

Presented by:

Gustavo Gonzalez, and Kyle Greer
Odessa Separators Inc.
Melinda Alleman and Brian Lewis, ConocoPhillips 

Artificial Lift
Room 104
(10) PRODUCTION OPTIMIZATION THE BALANCE-PORTED VALVE IN THE PERMIAN BASIN
More Information

The balance-ported valve is a gas-lift valve that allows full, available gas injection pressure to be used for the unloading and operating valves.  Using full injection pressure allows for a deeper point of gas injection, which lowers the FBHP, thereby increasing total production.  With standard IPO valves, it is necessary to design the valves with casing pressure drops in order to close the valves as the injection point moves deeper.  The balance-ported valve is configured such that no design casing pressure drops are required for closing.  The pilot valve can be utilized later in the life of the well, once the injection point is at the bottom valve and the well is producing less than 150 BFPD.  The pilot valve controls injection into the well in self-intermitting cycles, allowing the well to feed in between these cycles. This allows for lower gas injection rates and increased production.

Presented by:

Rick Haydel, Jack Brink, Gary Gassiott, Joseph Bourque, Ray Dees, Chris Daigle, and Jacob Leger  
Altec Inc. 

Artificial Lift
Room 106
(36) FRACTURE LIKELIHOOD ANALYSIS USING TRIPLE COMBO LOG DATA IN THE STACKED CARBONATE PLAY OF MADISON COUNTY
More Information

Understanding natural fracture systems plays a key role in tight carbonate fields where production is dependent on secondary porosity and pore connectivity. Locating geographic and stratigraphic areas with high natural fracture density and optimizing horizontal well plans to connect fractures can enhance well performance and asset value. A workflow to identify the influence of natural fractures on well performance was conducted in the stacked carbonate play in east Texas. Density, resistivity, and gamma ray logs were used to generate an index curve to identify natural fractures. In wells with image log data, a reasonable correlation was observed between the fracture zones selected by this model and the image log interpretation. The index curve was calibrated with image log interpretation, and applied in other wells without image logs. Identifying the optimal distance from the fault where fractures are still present has become the main criterion for selecting locations for horizontal wells. 

Presented by:

Courtney Beck, Anna Khadeeva, Bhaskar Sarmah, and Andrew Whitsett,
Halliburton


Trey Kimbell,
Burk Royalty

Well Completion and Simulation
Room 107
(14) TICKETLESS TRACKING OF PRODUCED WATER FROM THE CRADLE TO THE GRAVE WITHOUT HUMAN INVOLVEMENT
More Information

This is a discussion of a newly developed and field tested system to measure and track fluids produced in the oilfield.  The system’s mission is to track the fluid movement from the cradle to the grave and is, for the most part, a “hands off-no humans needed” custody scheme that provides precise verifiable electronic information to the producer, the trucking company that hauls the fluids, and the companies that handle the final deposition of the fluids, either at the disposal well or the pipeline terminal. 

The discussion centers on a West Texas well where the use of this system saves over $10,000 per year in operating costs.  The paper discloses patented technology as well as how the implementation process evolved and overcame the paradigms and mindsets of the people and companies.  Developing new technology is cake walk when compared to altering the complexity of the “oilfield thought” process.
 

Presented by:

Fred Newman

Artificial Lift
Room 108
(18) CORROSION- FATIGUE RESISTANT SUCKER RODS
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Corrosion fatigue (CF) is an important concern for structures that are exposed to cyclic loads in corrosive environments, especially in the case of oil and gas operations like drilling, offshore risers or sucker rods in artificial lift. Considering the current combination of complex wells completions and the increase of water cuts, the CO2, H2S and Bacteria represent a higher risk for CF failures in sucker rods. This combined effect force operators to choose a steel for either corrosive environments or high loads and increase the chemical inhibition programs.

In response to the new downhole challenges, a research and development program (R&D) has been created to analyze the key factors that affect sucker rods performance under CF. As a result of this R&D program, a new corrosion-fatigue resistance sucker rod has been developed. The present paper summarizes the development process, the new sucker rod characteristics and its performance.

Presented by:

Rodrigo Ruiz, Gustavo Alvarez, Edgardo Lopez, 
James Few, and Jeff Harris
Tenaris

Artificial Lift
Room 110
(26) OPERATIONAL OPTIMIZATION THRU FAILURE MEETINGS
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Failure meetings are a proven optimization tool to reduce failures, cut costs, and increase production. However, many companies don’t utilize this tool or don’t properly optimize it. This paper will cover the basics of preparing for and holding a failure meeting along with a brief explanation of root cause analysis.  

Presented by:

Mike Brock, Dan Phillips, and Rob Vincent
PLTech LLC

General Interest
Room 111
(29) CHEMICALLY PERVENTABLE ROD PUMP FAILURE REDUCTION
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Rod pump failure tracking has become a crucial component to any rod pump program in order to maximize run life and more effectively evaluate failure mechanisms. This course will dive into chemically preventable failure causes for rod pump wells highlighting root cause analysis, corrosion/bacteria control, solids management, product selection and program evaluation. 

Presented by:

Matthew Boyer

Anadarko

Prod. Handling

02:00PM - 02:50PM (Thursday)

Room 101
(08) SAND CONTROL METHODS TO IMPROVE ESP OPERATIONAL CONDITIONS AND RUN TIME
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Sandy wells are a common problem for any artificial lift system. Calculating the correct allowable volume of sand and solids’ particle size may be the missing link in optimizing run-times and establishing solid pump performance.

Recent Colombian ESP case studies were conducted in fields with high sand/solids presence. Where run times typically lasted 5 months or less, a new design to improve ESP performance introduced a Cup Packer and screens below the ESP sensor.

Once ESP variables such as intake pressure, drive frequency, and temperature were considered, the unit conditions stabilized and improved performance followed, greatly extending run times, and reducing unnecessary intervention costs.
 

Presented by:

Gustavo Gonzalez and Luis Guanacas 
Odessa Separator Inc.

Artificial Lift
Room 104
(05) INFERRED PRODUCTION TESTING OF OIL AND GAS WELLS
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Production testing with digital electronic devices has been discussed for about 20 years amongst a small group.  The idea has been implemented a few times with uncertain results.  The uncertainty exists because the measurements were done with turbine meters which are themselves uncertain.  

Recent testing has been accomplished by gauging calibrated tanks.  We believe these measurements of liquid volumes can be viewed as perfect.  Measurement of gas is done with computerized orifice meters which are known to be accurate as long as the correct orifice size is used.

This presentation compares perfect production tests made with tank gauges and test made with imperfect digital-electronic devices.  What would the oilfield look like if testing with digital0electronic devices became the norm?

Presented by:

S.G Gibbs and Ken Nolen, Greenshot, LLC

Rowland Ramos, Pioneer Natural Resources

Artificial Lift
Room 108
(20) MITIGATING SLUG FLOW AND TRANSITIONING FROM GAS LIFTING TO ROD PUMPING RESULTS IN SIGNIFICANT INCREASE IN MULTIPLE WELL NPVs
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Production challenges in horizontal wells are caused by slug flow behaviour from the horizontal. In response, Production Plus developed the flow conditioning HEAL System to mitigate slug flow before fluids enter the downhole separator and pump. Slug flow mitigation allows rod pumping to be more effective and efficient, offering a solution for low-cost OPEX to reliably maximize drawdown.

This paper analyzes multiple HEAL System installations in the Permian Basin that transition from gas lifting to HEAL System rod pumping. It explores requirements for intermediate artificial lift systems, challenges achieving production forecasts, slug flow and solids production mechanisms, and impact from horizontal trajectories.  The discussion compares recent long-term, multiple case studies that statistically demonstrate the impact of flow conditioning on well production economics. It offers insights into long-term NPV benefits achieved by transitioning from gas lifting to the HEAL System with rod pumping.

Presented by:

Jeff Saponja and Dave Kimery
Production Plus Energy Services Inc.
Greg Wilkes
Broad Oak Energy ll LLP
 

Artificial Lift
Room 110
(25) BEST OF BOTH WORLDS FROM PROPPANT DISTRIBUTION TO FRACTURE
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Horizontal drilling and the need for effective completion techniques has given birth to a wide variety of solutions in North American oil and gas plays. For many operators, it has become a top priority to optimize proppant distribution using buoyancy enhancer additives and to achieve fracture diversion with clean solutions that do not require intervention. At the heart of these initiatives is the Permian Basin, which is being revitalized through the use of intelligent completion technologies to make those priorities a reality.

This paper proposes two solutions that can be customized for an integrated fluid system that helps improve proppant distribution, deepen proppant penetration within the complex fracture network, increase proppant pack volume, and increase maximum proppant concentration that can be placed. By improving proppant placement and increasing the fracture volume occupied by proppant, operators can enhance conductivity of the fracture network, resulting in improvements to initial and long-term production.

Presented by:

Vidya S Bammidi
Keane Group

Drilling Operations
Room 111
(32) SIMPLICITY IN VRU BY USING A BGC
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Vapor Recovery Units are often expensive, complicated to operate and unable to deal with High H2S and liquids.  The Beam Gas Compressor is a product that has served the measure of time.. after 35 years of operation its durability is now being shown as a vapor recovery unit. Without the need of a control panel and scrubber tank the Hydraulically driven Beam Gas Compressor (HyBGC) can be easily serviced by most oil field personnel.  No special schooling or training is necessary.  Without the need for a control panel there is no need for special automation technical service.  Making the HyBGC the perfect VRU for small to medium size companies.  Majors too, anyone needing consistent and reliable emissions control.

Presented by:

Mark W.Lancaster and  Charlie McCoy

Permian Production Equipment, Inc.

Prod. Handling

03:00PM - 03:50PM (Thursday)

Room 104
(21) ADVANCED SUCKER ROD MATERIAL REDUCES WEAR IN UNCONVENTIONAL WELLS-CASE HISTORIES
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Tubing leaks account for half of the failures in the Bakken wells. The root cause is coupling on tubing wear due to the non-metallic guides wearing out.  

In order to combat this problem, ToughMet 3 TS95 sucker rod couplings were installed in up to 250 wells to significantly reduce the failure rate in the field.  Several individual case histories will be discussed to demonstrate the lifetime extension and reduced wear rates seen with the use of the new couplings.

Additional benefits have been observed, particularly increased fluid production, increased pump fillage, higher Fluid loads, and lower gearbox loads. XSPOC data will be presented for several wells to demonstrate the positive effects observed in the field.

Presented by:

Seth Silverman, Hess Corp.
Diane Nielsen and William Nielsen, Materion Corp.

 

Artificial Lift
Room 108
(12) FOCUSED PRODUCTION MEASUREMENT
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With the proliferation of production from multiple zones within wells, a major challenge long recognized by industry is to understand which zones are contributing, and how much. This is even more of a challenge with multiphase flow from different zones and with the advent of hydraulic fracturing, correctly identifying which zones have the potential to contribute is critical for future operations. 

A new solution to this problem is to use a jet pump in combination with inflatable packers and a new PLT that uses Patent Pending Doppler sensors rather than spinners to measure flow. This allows the in-flow to be accurately measured while the zone is isolated, with the added benefit of being able to draw the pressure down to assess the potential of the zone when on lift. 

This paper discusses the application of this new method of production logging in a vertical well in West Texas. It will also show the logs obtained in the test well. 

Presented by:

Jay Miller

Tech-Flo Consulting, LLC

Artificial Lift
Room 111
(31) CONSIDERATIONS FOR INCREASED EFFECTIVENESS OF TANK VAPOR COMBUSTION SYSTEMS AT PRODUCTION FACILITIES
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With the recent proliferation of federal and state regulation in regards to allowable emissions limits from oil and gas production facilities, sound emissions control methods and their utilization have become increasingly more important.  Operator environmental compliance has been frequently emphasized by regulatory agencies, and using vapor combustion units (VCU’s) to limit the atmospheric exposure of volatile organic compounds (VOC’s) from on-site storage tanks is a practice that is seen with increasing regularity. The installation of VCU’s can be time sensitive to ensure regulatory compliance and, because of this, it is not uncommon for the importance of key variables to be underestimated or overlooked.  Throughout this paper, considerations are provided to bring several of these factors to the operators’ attention to ensure that the unit and associated piping is installed with maximum effectiveness.

Presented by:

Colyn Jurek, Ryan Duncan and Andrew Humphreys 
OXY USA Inc.

Prod. Handling