Paper Presenters Price
(2019049) IMPACT OF PRODUCED WATER ON THE CORROSION OF STEEL BY CHLORINE DIOXIDE

The perceived impact of chlorine dioxide (ClO2) on the corrosion of steel used in the oil patch has been a controversial issue for many years.   Although a few studies on this issue have been published, those results have been contradictory. As concerns surrounding this issue continue to be raised, a systematic study has been undertaken to understand the corrosive effects of ClO2 towards steel in various produced waters.  Research shows that the baseline corrosion rate of untreated produced water is related to TDS, with other factors being involved, such as the presence of H2S and iron. This paper summarizes the results of other studies that have been done, and demonstrates the contradictory nature of such studies. The results of this on-going study show the relationship between the TDS of produced water and corrosion resulting from use of varying concentrations of ClO2.  The paper explains the contradictory nature of corrosion caused by ClO2.


Greg Simpson, Purleline Treatment Systems

$7.50
IMPACT OF PRODUCED WATER ON THE CORROSION OF STEEL BY CHLORINE DIOXIDE
IMPACT OF PRODUCED WATER ON THE CORROSION OF STEEL BY CHLORINE DIOXIDE
Price
$7.50
(2019020) INNOVATIVE PACKER TYPE GAS SEPARATOR:  OPERATING PRINCIPLES AND DESIGN CRITERIA

Wells with high depletion rate present high free gas at pump intake conditions. In all cases, the production of fluid with a high gas-liquid ratio leads to an inefficient performance of the rod pump systems. The initial solution to this problem is the installation of poor boy gas separators which capacity of gas separation is reduced and do not provide a high-performance solution.  Packer type gas separators are the most efficient downhole separators in the market, however, they usually have some operational limitations. This paper summarizes a new design of the packer type gas separator which uses more methods of separation than the traditional design and can be designed based on the conditions of each well overcoming the typical limitations. The design criteria are reviewed, and some operational guidelines are listed to reach the best performance in each application for gas separation.


Gustavo Gonzalez, Shivani Vyas, Luis Guanacas Neil Johnson
Odessa Separator Inc.

$7.50
INNOVATIVE PACKER TYPE GAS SEPARATOR:  OPERATING PRINCIPLES AND DESIGN CRITERIA
INNOVATIVE PACKER TYPE GAS SEPARATOR:  OPERATING PRINCIPLES AND DESIGN CRITERIA
Price
$7.50
(2019034) IRIS: A NEW ERA IN DOWNHOLE DATA TREATMENT

When optimizing a reciprocating rod lift installation, key control parameters must be extracted from the downhole data. Traditionally, downhole data in the form of position and load data is derived from surface data using the wave equation. Downhole position and load data must be carefully analyzed to extract key control parameters for reciprocating rod lift optimization.

IRIS introduces a new and innovative approach for downhole data analysis.





Through a change in coordinate system, IRIS transforms downhole position and load data into polar coordinates. This change in coordinates creates three new data sets, which greatly simplify the extraction of the above mentioned key control parameters.

Additionally, IRIS can be used to manage both viscous and mechanical friction through an extra friction detection algorithm and a viscous damping estimator.





In this paper, the IRIS algorithms and results are presented.

 


Victoria Pons, Baker Hughes, A GE Company

$7.50
IRIS: A NEW ERA IN DOWNHOLE DATA TREATMENT
IRIS: A NEW ERA IN DOWNHOLE DATA TREATMENT
Price
$7.50
(2019018) ITS ALL ABOUT THE END FITTING 3: PRESSURE DROP, EXTRA CORROSION CAPABILITY, COMPRESSION HANDLING

As fluctuations in oil price continue, the industry has changed and is demanding improvements from each method of artificial lift. Required flow rates are increasing due to the longer laterals of new horizontal wells being added to inventory. Rod Lift is not immune and is being asked to enter the artificial lift cycle earlier and support the pumping of wellbores with added complexities due to geometries and/or production demands. The fiber reinforced plastic (fiberglass, FSR) rod continues to meet the ever-increasing demand and complexities. The two previous editions of ‘IT’S ALL ABOUT THE END FITTING’ focused on the design of the new generation of fiberglass rod, the added strength the industry has requested, the benefits regarding the handling of compression and methods to mitigate uncertainties of the wellbore dynamics. This edition will focus on benefits of the latest generation of the end fitting. It will explain how a new configuration of the wedge profile provides reduced pressure drop at each connection and/or adds corrosion resilience. The new wedge profile also increases the ability of the end fitting to handle compression. Data will be provided in support of increased production. The fiberglass rods have been delivering benefits for the last 30+ years to the industry and continue to maintain pace with growing demands of artificial lift through innovation and development of new generation FSRs. With an ongoing progress of FSR technology the glass rods are being adopted earlier in the well’s life cycle requiring us to make the product RUN LONGER & PRODUCE 


Ryan Gernentz, Karol Hricisak and Alex Booth
Endurance Lift Solutions

$7.50
ITS ALL ABOUT THE END FITTING 3: PRESSURE DROP, EXTRA CORROSION CAPABILITY, COMPRESSION HANDLING
ITS ALL ABOUT THE END FITTING 3: PRESSURE DROP, EXTRA CORROSION CAPABILITY, COMPRESSION HANDLING
Price
$7.50
(2019014) LEARNING IN TEXAS DELAWARE ROD PUMPING EXPERIENCE

Oxy Resources established the Texas Delaware Team in April 2013 when ~200 wells were purchased in the area of Pecos, Texas.  These primarily vertical wells produce from various commingled Delaware intervals located at 8,000’ to 12,000’ deep. The nature and deviation of these wells have made rod pumping them challenging and failure frequencies have been as high as 1.5 failures/year. Many lessons have been learned in driving the failure frequencies down to the current level of 1.0 failures/year. This paper will share some of the lessoned learned using various equipment types including fiberglass COROD, Poly-keytone Lined Tubing,  Poly-keytone Rod Glides, and Variable Slippage Pumps. 


Steve Gault and Tyler Anderson
OXY USA, Inc.

$7.50
LEARNING IN TEXAS DELAWARE ROD PUMPING EXPERIENCE
LEARNING IN TEXAS DELAWARE ROD PUMPING EXPERIENCE
Price
$7.50
(2019043) MANIPULATING CASING PRESSURE TO BETTER HANDLE GAS IN CERTAIN WELL TYPES

Rod pumps are not the ideal system of lift when it comes to handling gas. We can only do so much with the configuration downhole especially for wells with open hole completions. Despite the limited options, we are coming to find that we can do better by manipulating parameters at the surface. Historically, we have manipulated back pressure on the tubing in order to control when gas breaks out of solution in the tubing. Now we are finding, on certain well types, that manipulating back pressure on the casing in order to keep gas in solution through the pump is proving to be successful. By doing this, we are seeing beam wells that now face less equipment stress due to gas interference, more consistent, stable run time and production on a daily basis, and even optimized inflow where production increases for wells. 


Blake Whittington, OXY USA Inc.

$7.50
MANIPULATING CASING PRESSURE TO BETTER HANDLE GAS IN CERTAIN WELL TYPES
MANIPULATING CASING PRESSURE TO BETTER HANDLE GAS IN CERTAIN WELL TYPES
Price
$7.50
(2019041) MAXIMIZING PRODUCTION EFFICIENCY IN BEAM PUMP WELLS USING ROD GUIDE DESIGN OPTIMIZATION

There are many challenges associated with sucker rod lift in deviated wellbores that can lead to high failure rates and lost production. Tubing failures are amongst the costliest workovers and are often a result of metal to metal contact between the rod coupling and the tubing. Evaluating tubing on-site using both gamma and electromagnetic inspection allows for proper design optimization before returning to production. The tubing scan can be aligned with deviation data, previous rod design, and failure history to adjust the string design to effectively extend mean time between failures and improve asset value. An effective rod guide strategy was developed to mitigate tubing wear using proper guide type, material, and placement. The implementation of this strategy has helped to maximize production efficiency across the asset. 


Brian Wagner, NOV Tuboscope

$7.50
MAXIMIZING PRODUCTION EFFICIENCY IN BEAM PUMP WELLS USING ROD GUIDE DESIGN OPTIMIZATION
MAXIMIZING PRODUCTION EFFICIENCY IN BEAM PUMP WELLS USING ROD GUIDE DESIGN OPTIMIZATION
Price
$7.50
(2019022) MICRO-ENCAPSULATED TECHNOLOGY: NEW CHEMICAL TREATMENT FOR DOWNHOLE

The common surface chemical applications cannot reach or have low efficiency due to high fluid levels. This paper Introduces a new chemical technology for all types of artificial lift systems that guarantees an efficient downhole treatment at the entry point and summarizes the applications of this revolutionary method established to deliver chemical combinations by microencapsulating the compounds and packaging the completed formulation in a chemical screen that is placed at the bottom of the tubing (BHA) below any type of artificial lift systems. The new downhole Chemical treatment technology were designed and successfully applied in 3 wells in the Permian Basin to control scale and corrosion. The installation of the chemical tool is easily made up below the pump intake and not additional equipment is needed in the pump or in the surface facilities.


Gustavo Gonzalez, Renzo Arias, Luis Guanacas 
Odessa Separator Inc.

$7.50
MICRO-ENCAPSULATED TECHNOLOGY: NEW CHEMICAL TREATMENT FOR DOWNHOLE
MICRO-ENCAPSULATED TECHNOLOGY: NEW CHEMICAL TREATMENT FOR DOWNHOLE
Price
$7.50
(01) INTELLIGENT ROD LIFT SYSTEM: FAULT DETECTION AND ACCOMMODATION

 Unplanned rod lift system outages often lead to long and costly repairs in addition to direct production loss. Leveraging design knowledge of the rod lift system combined with real-time condition monitoring represents a promising avenue to mitigate this problem. This study will demonstrate an application of advanced monitoring and diagnostic analytics on data from vibration, strain, current and voltage sensors installed in critical locations of a beam pumping unit.


 


When pumping conditions deviate from the norm, the operators are alerted with regard to pending failures, and a supervisory control layer takes immediate action to adjust the operational pumping speed profile to maintain production at a safe operational level or shut down the equipment in the event of imminent catastrophic failure.


 


This paper will review the sensor installations and data acquisition approach. Experimental field test results will be presented and discussed.


Omar Al Assad, Justin Barton, Rogier Blom, Ravi YB, Mahalakshmi SB GE Global Research Gary Hughes, Eric Oestrich, Peter Westerkamp and Craig Foster GE Lufkin Automation $7.50
Paper: (01) INTELLIGENT ROD LIFT SYSTEM: FAULT DETECTION AND ACCOMMODATION
Paper: (01) INTELLIGENT ROD LIFT SYSTEM: FAULT DETECTION AND ACCOMMODATION
Price
$7.50
(02) THE MEASUREMENT OF DOWN STROKE FORCE IN ROD PUMPS

During the down stroke the plunger in a rod pump must fall through a barrel that is filled with fluid. The plunger will establish a free fall velocity that is determined by the forces resisting downward motion. The free fall of the plunger may not be large enough to correspond to the actual velocity necessary to match the pumping speed set by the pumping unit. In this case the plunger must be pushed into the barrel by a compressive force in order to match the pumping velocity. The compressive force may be large enough to cause buckling in the lowest section of sucker rods. The purpose of this paper is to test this hypothesis by presenting measurements of the free fall velocity of a plunger in a liquid filled barrel and the pushing force necessary to exceed the free fall velocity of the plunger in the barrel. Simple models are shown to relate the measurments to practice.


Paul Bommer, A.L. Podio and Grayson Carroll University of Texas at Austin $7.50
Paper: (02) THE MEASUREMENT OF DOWN STROKE FORCE IN ROD PUMPS
Paper: (02) THE MEASUREMENT OF DOWN STROKE FORCE IN ROD PUMPS
Price
$7.50
(03) A COMPARISON OF VARIABLE SPEED DRIVES AND PUMP-OFF CONTROLLERS IN AN UNCONVENTIONAL RESERVOIR

Variable Speed Drives (VSDs) are a popular rod lift control system for operators that are willing to pay a premium for the promise that they can squeeze every last drop from a producing formation. However, initial results from the Eagle Ford suggest that VSDs may not be worth the additional expense when compared to the performance of their less complex cousin, the Pump-Off Controller (POC). In particular, high CAPEX and maintenance costs along with performance issues on gassy, sand producing, shale wells are leading some operators to choose POCs over VSDs for unconventional reservoir applications. 


 


Furthermore, brief disruptions in production have less of an impact on the reservoir inflow of tight shales than that of higher permeable conventional reservoirs. This study is based on the examination of the performance of Eagle Ford wells that were initially controlled by VSDs and then swapped to POCs.


Hannah Mitchell and Lee Coggins Chesapeake Energy $7.50
Paper: (03) A COMPARISON OF VARIABLE SPEED DRIVES AND PUMP-OFF CONTROLLERS IN AN UNCONVENTIONAL RESERVOIR
Paper: (03) A COMPARISON OF VARIABLE SPEED DRIVES AND PUMP-OFF CONTROLLERS IN AN UNCONVENTIONAL RESERVOIR
Price
$7.50
(03) A COMPARISON OF VARIABLE SPEED DRIVES AND PUMP-OFF CONTROLLERS IN AN UNCONVENTIONAL RESERVOIR

Variable Speed Drives (VSDs) are a popular rod lift control system for operators that are willing to pay a premium for the promise that they can squeeze every last drop from a producing formation. However, initial results from the Eagle Ford suggest that VSDs may not be worth the additional expense when compared to the performance of their less complex cousin, the Pump-Off Controller (POC). In particular, high CAPEX and maintenance costs along with performance issues on gassy, sand producing, shale wells are leading some operators to choose POCs over VSDs for unconventional reservoir applications. 


 


Furthermore, brief disruptions in production have less of an impact on the reservoir inflow of tight shales than that of higher permeable conventional reservoirs. This study is based on the examination of the performance of Eagle Ford wells that were initially controlled by VSDs and then swapped to POCs.


Hannah Mitchell and Lee Coggins Chesapeake Energy $7.50
Paper: (03) A COMPARISON OF VARIABLE SPEED DRIVES AND PUMP-OFF CONTROLLERS IN AN UNCONVENTIONAL RESERVOIR
Paper: (03) A COMPARISON OF VARIABLE SPEED DRIVES AND PUMP-OFF CONTROLLERS IN AN UNCONVENTIONAL RESERVOIR
Price
$7.50
(04) UNDERSTANDING AND MITIGATING DOWNHOLE CORROSION AND WEAR FAILURES

A discussion on different types of corrosion and wear (and their associated mechanisms) will be followed by an overview of commercially available mitigation techniques including their practical field applications downhole. Commonly available information that can be used to determine exactly why downhole failures occur will be reviewed.  The importance of using preferred life extension procedures to maximize the Mean Time Between Failures (MTBF) and solve the root cause(s) of downhole failures are also covered.  Finally, this paper includes a review of various metallurgical options, nonmetallic materials, chemical treatments, mechanical methods, liners and coatings currently used downhole focusing on the advantages and limitations of each product.  Commonly accepted practices and myths about downhole corrosion and wear will be exposed.


The objective of this paper is to assist production, completion, artificial lift and enhanced recovery engineers in understanding and avoiding downhole corrosion and wear failures cost effectively.


Rob Davis, Michael Naguib and Bill Snider Western Falcon Energy Services $7.50
Paper: (04) UNDERSTANDING AND MITIGATING DOWNHOLE CORROSION AND WEAR FAILURES
Paper: (04) UNDERSTANDING AND MITIGATING DOWNHOLE CORROSION AND WEAR FAILURES
Price
$7.50
(05) PUMP STROKE OPTIMIZATION: CASE STUDY OF TWENTY WELL PILOT

 The concept of Pump Stroke Optimization was introduced in September 2015 at the ALRDC Sucker Rod Pumping Workshop.  Significant benefits to the sucker rod pumping system are obtained by preferentially slowing the downstroke (when pump capacity exceeds a wells productivity), while keeping a fast upstroke. These benefits are: Less pump slippage, less gas interference, and higher pump fillage, which results in less strokes per day for the same production, which results in less downhole wear. Higher minimum load translate into less rod buckling forces. 


Pump Stroke Optimization also includes automatic adjustment of upstroke and downstroke speeds to keep from overpumping wells, and is particularly effective for horizontal oil wells.


The results of a 20 well 2016 test program will be presented.


William G. Elmer Encline Artificial Lift Technologies LLC $7.50
Paper: (05) PUMP STROKE OPTIMIZATION: CASE STUDY OF TWENTY WELL PILOT
Paper: (05) PUMP STROKE OPTIMIZATION: CASE STUDY OF TWENTY WELL PILOT
Price
$7.50
(06) A CASE HISTORY: 131 FAILURES TO 30 - FAILURE CONTROL PRINCIPLES IN THE MIDLAND BASIN

Depressed oil prices drive producers to reduce operating expenses and maximize profit margins. Some of these expenses are necessary for day-to-day operations, and are dictated by vendor pricing. Others are a function of the operator’s activity, and can be controlled within certain limits. Workover costs are a prime example of these “controllable” expenses. That being said, well failure control programs are essential to maximizing profits and limiting expenses.


In 2014, Resolute Energy recognized the need for a more effective failure program in their Gardendale, TX asset. Through organizational, managerial, and engineering efforts, Resolute successfully decreased well failures by nearly 90 year-to-year, resulting in expense savings of nearly $4.5 million. 


These savings, along with other expense control efforts, cut lifting cost in half throughout the 101 wells. This paper describes these control efforts in detail to reinforce their importance, particularly in current market conditions.


Kevin Flahive-Foro Resolute Energy Corp. $7.50
Paper: (06) A CASE HISTORY: 131 FAILURES TO 30 - FAILURE CONTROL PRINCIPLES IN THE MIDLAND BASIN
Paper: (06) A CASE HISTORY: 131 FAILURES TO 30 - FAILURE CONTROL PRINCIPLES IN THE MIDLAND BASIN
Price
$7.50
(07) SAND FLUSH PLUNGER PERFORMANCE IN THE HWY 80 FIELD

Field case studies for the patented Sand Flush Plunger™ (patent #8,535,024) have been performed at the Hwy 80 field operated by Pioneer Natural Resources. Pump repair and well conditions data was collected from the pump and well tracker systems used by the service providers of the field. 


 


Standard pump repair information dated since 1989, while the Sand Flush Pump begun usage on 2009.  Interestingly, the results show that the average run time for the Sand Flush Pump is 840 days out of 560 well workovers that used it, while for a Standard Pump (Metal and Grooved Plunger) is 561 days out of


5313 workovers. Within the 560 wells that have tested the Sand Flush Plunger, 165 used both types of plungers providing a more detail correlation. From these, the Sand Flush averaged 1307 run days compared to the 604 days of a Standard Pump.


Sergio Granados, Brad Rogers, Rodney Sands, Harbison Fischer Rowland Ramos and Albert Garza, Pioneer Natural Resources Matt Horton and Johnny Bunsen, Tommy White Supply $7.50
Paper: (07) SAND FLUSH PLUNGER PERFORMANCE IN THE HWY 80 FIELD
Paper: (07) SAND FLUSH PLUNGER PERFORMANCE IN THE HWY 80 FIELD
Price
$7.50
(08) REVIEW OF CASE HISTORIES IN HYDRAULIC LIFT FOR DIFFERENT WELL CONDITIONS THAT DEMONSTRATE THE IMPORTANCE OF INTEGRATED DESIGN AND EQUIPMENT SELECTION AS WELL AS A NEED FOR INCREASED PRODUCT DEVELOMPENT

Gassy low pressure stratified reservoirs require special jet pump well completion and equipment selection considerations. These reservoirs often experience a 50% reservoir pressure decline within the first 14 months of production but can continue to produce for many years below the saturation pressure. Jet pumps can be installed in wells in many ways. The most common, lowest cost and simplest well completion design is the “casing free installation”, but as reservoir pressure declines below the saturation pressure, gas liberation often results in gas accumulation and slugging under the casing packer that is used in this design.


 


Beam pumping systems have proven successful in the Permian Basin for many years. The beam pumping system allows gas separation and gas flow up the casing annulus. A concentric coil tubing jet pump well completion offers downhole gas separation with options to improve desired effects. Successful case histories are presented to support the application.


Jesse Hernandez, Global Petroleum Technologies Luis Alberto and Diaz Martinez, CTX-Energy Dubai $7.50
Paper: (08) REVIEW OF CASE HISTORIES IN HYDRAULIC LIFT FOR DIFFERENT WELL CONDITIONS THAT DEMONSTRATE THE IMPORTANCE OF INTEGRATED DESIGN AND EQUIPMENT SELECTION AS WELL AS A NEED FOR INCREASED PRODUCT DEVELOMPENT
Paper: (08) REVIEW OF CASE HISTORIES IN HYDRAULIC LIFT FOR DIFFERENT WELL CONDITIONS THAT DEMONSTRATE THE IMPORTANCE OF INTEGRATED DESIGN AND EQUIPMENT SELECTION AS WELL AS A NEED FOR INCREASED PRODUCT DEVELOMPENT
Price
$7.50
(09) THE EFFECT RELIEVING CASING PRESSURE HAS ON BOTTOM HOLE PRESSURE

We will show in multiple cases studies the effect of relieving back pressure on a oil well has in relationship to the producing bottom hole pressure, pump efficiency and over all economics of the well.


Mark Lancaster and Charlie McCoy Permian Production Equipment, Inc. $7.50
Paper: (09) THE EFFECT RELIEVING CASING PRESSURE HAS ON BOTTOM HOLE PRESSURE
Paper: (09) THE EFFECT RELIEVING CASING PRESSURE HAS ON BOTTOM HOLE PRESSURE
Price
$7.50
(10) USING ROD GUIDES EFFECTIVELY IN VERTICAL WELLS: WEST TEXAS WATERFLOOD CASE HISTORY

Metal to metal contact shortens the run life of both tubing, steel and fiberglass sucker rods.  Using sacrificial rod guides can extend this life at the expense of increased side and axial loading enhanced by Coulomb friction effects.  The problem is not limited to directional and horizontal wells.  Just how crooked are our vertical wells?  Simple inclination surveys insufficiently describe the wellbore path drilled.  Knowledge of failure history, inclination and azimuth of wellbore path, plus access to a rod design program provide insight into effective placement of rod guides and longer run life.  A case history from an established West Texas waterflood is presented to illustrate the application.


Rebecca J. Larkin BOPCO, LP $7.50
Paper: (10) USING ROD GUIDES EFFECTIVELY IN VERTICAL WELLS: WEST TEXAS WATERFLOOD CASE HISTORY
Paper: (10) USING ROD GUIDES EFFECTIVELY IN VERTICAL WELLS: WEST TEXAS WATERFLOOD CASE HISTORY
Price
$7.50
(11) DYNOMOMETER CONCERNS

Downhole dynamometer cards can be generated by predictive and diagnostic wave computer programs. Those generated by the diagnostic program are best for trouble shooting as they are calculated from a measured surface card. Several aspects of the bottom cards are presented in discussed in this paper some of which are well known and used and some which are less recognized.


 


For cards showing gas fill, the location of the TV closing is not the location in the downhole stroke where liquid fill begins. However it is close for low pressure wells. The shape of the load release can indicate if the well has low or high intake pressure. The pump load is indicated if the card is scaled correctly and generated by approximately correct damping or drag coefficients along the rod. A delayed opening of the SV on the upstroke can indicate that the pump is not tightly spaced. The load release distance is incorrectly identified as an area where compression is occurring but this does not indicate compression in the rod above the pump but is where gas, is present, is being compressed below the TV and above the SV. Example are shown of the above.


 


If looking at only the downhole card, excursions below where the load pick-up began indicate a compression load in the rod above the pump. However high damping coefficients will reduce the apparent fluid load shown on the bottom hole dynamometer and will  also reduce the amount the bottom card may be showing apparent rod compression at the pump so the damping coefficients have an effect on apparent compression at the bottom hole card and these effects are illustrated. The shape of the bottom card can suggest if the damping coefficients are low or high. In general the predictive programs do not indicate compression at the pump unless pump resistance is guessed by the user but the bottom cards can indicate compression but the magnitude of indicated compression also depends on input for the diagnostic computer program.


 


Both the predictive and diagnostic programs can, under certain circumstance, indicate compression uphole from the pump due to dynamic effects. This can occur even with no pump resistance or rod compression at the pump.  Rod failure characteristics can show if the rod broke after repeated compression (pump resistance) but this is after the fact.


 


These factors and more are discussed and illustrated to hopefully make problem recognition easier for the operator.


James Lea, Mark Garrett, Mike Brock, and Cort Visniesiki PLTech, LLC $7.50
Paper: (11) DYNOMOMETER CONCERNS
Paper: (11) DYNOMOMETER CONCERNS
Price
$7.50
(12) ROD GUIDE STRATEGY FOR UNCONVENTIONAL BEAM PUMPED WELLS IN THE EAGLE FORD SHALE

Murphy is currently operating 500 beam pumped wells in the unconventional Eagle Ford Shale play in South Texas. There are numerous challenges to beam pumping operations in the Eagle Ford, which included paraffin, corrosion, solids, deviated wellbores, slug flow, and foamy gassy fluid.


 


One of the challenges, deviated wellbores, led to an increased frequency of failures due to metal to metal contact between the rod coupling and the tubing. The development of a rod guide strategy has significantly reduced the failure frequency of tubing and parted rod couplings due to wear.


 


The development of the strategy includes data from the failure data base, the use of tubing scanning, the proper placement of the guides and the use of the proper guide material.


Leslie Malone Murphy Oil & Exploration Co. $7.50
Paper: (12) ROD GUIDE STRATEGY FOR UNCONVENTIONAL BEAM PUMPED WELLS IN THE EAGLE FORD SHALE
Paper: (12) ROD GUIDE STRATEGY FOR UNCONVENTIONAL BEAM PUMPED WELLS IN THE EAGLE FORD SHALE
Price
$7.50
(13) CASE STUDY - GAS INTERFERENCE: MANAGE OR MITIGATE

Murphy is currently operating 500 beam pumped wells in the unconventional Eagle Ford Shale play in South Texas. There are numerous challenges to beam pumping operations in the Eagle Ford, which included paraffin, corrosion, solids, deviated wellbores, slug flow, and foamy gassy fluid. 


 


One of the challenges, foamy gassy fluid, led to a study of the effectiveness of downhole separators. The results of the case study will be presented along with conclusions on the ability to manage or mitigate gas interference in the beamed pumped wells Murphy operates in the Eagle Ford Shale asset.


Leslie Malone Murphy Oil & Exploration Co. $7.50
Paper: (13) CASE STUDY - GAS INTERFERENCE: MANAGE OR MITIGATE
Paper: (13) CASE STUDY - GAS INTERFERENCE: MANAGE OR MITIGATE
Price
$7.50
(14) PATENTED OILFIELD RFID SOFTWARE AND HARDWARE PACKAGE DELIVERS IMPROVED DOWNWELL PRODUCT ACCOUNTABILITY, QUALITY CONTROL, INVENTORY MANAGEMENT AND ASSET TRACKING

RFG Petro Systems’ provides custom wireless and digital serial number tags for use within the well-bore infor and attached to the rod string components to assign its recorded quality control system data (batch mation, pressures, times, temperatures, manufacturing date/conditions) and logistics of the product from creation to end-of-life. RFG’s custom hardware and software package allows for the user to scan a product at any time and retrieve its manufacturing and logistics history, better controlling inventory management and asset tracking. By creating new time/date stamps and specific user-controlled instances within the system during the products use, data can be linked with a time-stamp to track and trace how great a product performs over time. Every instance and data-set taken is provided to the manufacturer for continuous product improvement. RFG can license this patented product, software, use and application to manufacturers leading to greater transparency and enhanced products for industry.


Jon Martin, Matt Herget AND Daniel Long RFG Petro Systems $7.50
Paper: (14) PATENTED OILFIELD RFID SOFTWARE AND HARDWARE PACKAGE DELIVERS IMPROVED DOWNWELL PRODUCT ACCOUNTABILITY, QUALITY CONTROL, INVENTORY MANAGEMENT AND ASSET TRACKING
Paper: (14) PATENTED OILFIELD RFID SOFTWARE AND HARDWARE PACKAGE DELIVERS IMPROVED DOWNWELL PRODUCT ACCOUNTABILITY, QUALITY CONTROL, INVENTORY MANAGEMENT AND ASSET TRACKING
Price
$7.50
(16) CONTINUOUS RODS - WOLFCAMP SHALE

This presentation will provide information about the operational advantages and disadvantages of continuous rods.  By removing the pins and couplings in a deviated well, side loading is distributed across a larger area reducing the severity of wear on the rods and the tubing.  The types of continuous rods will be reviewed and operational data presented to assist others in evaluating their potential use of continuous rods.


Blake Myers EP Energy $7.50
Paper: (16) CONTINUOUS RODS - WOLFCAMP SHALE
Paper: (16) CONTINUOUS RODS - WOLFCAMP SHALE
Price
$7.50
(17) GAS LIFT-JET PUMP HYBRID COMPLETION REDUCES NONPRODUCTIVE TIME DURING UNCONVENTIONAL WELL PRODUCTION

The addition of a sliding sleeve door (SSD) to the tubing string, installed between the deepest gas lift mandrel and the annular packer, will allow the deployment of a wireline-set jet pump. The backup jet pump provides a valuable and cost-effective alternative in several potential scenarios: when unloading fracking fluids before beginning gas-lift production, when restoring production after an unpredicted shutdown of the gas-lift compression system, and when the producing water cut becomes higher than expected.


This simple but ingenious dual-purpose completion approach has already proved to solve the problem of unconventional well production load-up during the early production stage of gas lifted systems. The information provided in this paper will help operators plan, design, deploy, and operate a dual-purpose gas lift-jet pump well completion.


Osman A. Nunez-Pinon, Toby Pugh and James Hubbard Weatherford International Inc. $7.50
Paper: (17) GAS LIFT-JET PUMP HYBRID COMPLETION REDUCES NONPRODUCTIVE TIME DURING UNCONVENTIONAL WELL PRODUCTION
Paper: (17) GAS LIFT-JET PUMP HYBRID COMPLETION REDUCES NONPRODUCTIVE TIME DURING UNCONVENTIONAL WELL PRODUCTION
Price
$7.50