Paper Presenters Price
(31) CONSIDERATIONS FOR INCREASED EFFECTIVENESS OF TANK VAPOR COMBUSTION SYSTEMS AT PRODUCTION FACILITIES

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.


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

$7.50
(31) CONSIDERATIONS FOR INCREASED EFFECTIVENESS OF TANK VAPOR COMBUSTION SYSTEMS AT PRODUCTION FACILITIES
Price
$7.50
(32) SIMPLICITY IN VRU BY USING A BGC

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.


Mark W.Lancaster and  Charlie McCoy

Permian Production Equipment, Inc.

$7.50
(32) SIMPLICITY IN VRU BY USING A BGC
Price
$7.50
(33) PRODUCTION CHEMICAL APPLICATIONS: USING ANALYTICAL DATA TO MONITOR AND OPTIMIZE CHEMICAL TREATMENTS

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.


Becky L. Ogden
Multi-Chem, a Halliburton Service

$7.50
(33) PRODUCTION CHEMICAL APPLICATIONS: USING ANALYTICAL DATA TO MONITOR AND OPTIMIZE CHEMICAL TREATMENTS
Price
$7.50
(34) OIL EFFECTS ON THE DEHYDRATION OF SUPER ABSORBENT POLYMERS

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.  


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

$7.50
(34) OIL EFFECTS ON THE DEHYDRATION OF SUPER ABSORBENT POLYMERS
Price
$7.50
(35) SINGLE WELL PRODUCTIVE MODEL BY USING SYSTEM NODEL ANALYSIS

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.


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

$7.50
(35) SINGLE WELL PRODUCTIVE MODEL BY USING SYSTEM NODEL ANALYSIS
Price
$7.50
(36) FRACTURE LIKELIHOOD ANALYSIS USING TRIPLE COMBO LOG DATA IN THE STACKED CARBONATE PLAY OF MADISON COUNTY

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. 


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


Trey Kimbell,
Burk Royalty

$7.50
(36) FRACTURE LIKELIHOOD ANALYSIS USING TRIPLE COMBO LOG DATA IN THE STACKED CARBONATE PLAY OF MADISON COUNTY
Price
$7.50
(37) A COMPLIMENTARY METHOD OF ASSESSING CLAY STABILIZERS USED IN HYDRAULIC FRACTURING APPLICATIONS

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.


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

$7.50
(37) A COMPLIMENTARY METHOD OF ASSESSING CLAY STABILIZERS USED IN HYDRAULIC FRACTURING APPLICATIONS
Price
$7.50
(39) FROM ZONE ABANDONMENT TO RESTORING WELLBORE INTEGRITY: MODERN EPOXY RESIN TECHNOLOGY WELL REMEDIATION CASE STUDIES

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.


Olvin Hernandez, Brandon Kimble and Paul Jones 
Halliburton 

$7.50
(39) FROM ZONE ABANDONMENT TO RESTORING WELLBORE INTEGRITY: MODERN EPOXY RESIN TECHNOLOGY WELL REMEDIATION CASE STUDIES
Price
$7.50
(40) VENTURI JET JUNK BASKET TO CLEANOUT HORIZONTAL YESO PRODUCERS

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.


Michael James
COG Operating

$7.50
(40) VENTURI JET JUNK BASKET TO CLEANOUT HORIZONTAL YESO PRODUCERS
Price
$7.50
(41) A RE-INTRODUCTION TO OIL AND GAS WELL STIMULATION WITH CHLORINE DIOXIDE (CLO2)

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.


Brent Smith, Sabre Energy Services, LLC

$7.50
(41) A RE-INTRODUCTION TO OIL AND GAS WELL STIMULATION WITH CHLORINE DIOXIDE (CLO2)
Price
$7.50
(42) NEW HIGH PERFORMANCE RESIN FOR THERMOPLASTIC LINERS

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.

 


Zach Stearman, Lightning Rod & Pipe

$7.50
(42) NEW HIGH PERFORMANCE RESIN FOR THERMOPLASTIC LINERS
Price
$7.50
(43) 2013-2015 ACID JOBS PERFORMANCE AND ANALYSIS ON EPS WELLS IN FIELD Y, INDONESIA

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.


Nur Wijaya

Texas Tech University, Petroleum Engineering

$7.50
(43) 2013-2015 ACID JOBS PERFORMANCE AND ANALYSIS ON EPS WELLS IN FIELD Y, INDONESIA
Price
$7.50
(44) ENVIRONMENTAL IMPLICATIONS OF WATER RECLAMATION FOR PETROLEUM OPERATIONS

High costs of obtaining fresh water and produced water disposal, as well as low commodity prices have made water reclamation an attractive option for companies looking to increase their profit margins. Special environmental considerations arise when dealing with the handling and treatment of produced and reclaimed fluids for use in oilfield operations. These include the handling of wastes generated from treating large volumes of produced water, storing and transporting the water via properly designed tanks, ponds, pipes, and other equipment, and complying with existing environmental regulations while adequately assessing additional risks associated with water recycling. The paper will discuss the current technologies utilized to treat reclaimed water and the environmental risks associated with them, special facilities design considerations for handling reclaimed water, relevant environmental policies, and the general pros and cons of water recycling including economic factors, infrastructure requirements, and public perceptions.  


Berkleigh Gressett

Texas Tech University, Petroleum Engineering 

$7.50
(44) ENVIRONMENTAL IMPLICATIONS OF WATER RECLAMATION FOR PETROLEUM OPERATIONS
Price
$7.50
(45) THE EFFECT OF ANISOTROPY RATIO ON BUILD UP TEST DATA USING THE HORNER METHOD

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.

 


Vegard Elverhaug and Anders Torland

Texas Tech University, Petroleum Engineering

$7.50
(45) THE EFFECT OF ANISOTROPY RATIO ON BUILD UP TEST DATA USING THE HORNER METHOD
Price
$7.50
(46) A SIMULATION STUDY ON COMPARISON BETWEEN ANALYTICAL AND NUMERICAL SOLUTIONS FOR HORIZONTAL WELL PRODUCTIVITY INDEX

Because the flow regimes and drainage geometry of horizontal well are different from those of vertical wells, there is a need to develop a distinct analytical Productivity Index (PI) solution for horizontal well.  There have been several researches in the early 1990's  developing the solutions; however, each solution generates different PI values.  The degree of disparity depends on how conservative or optimistic the input values are, which possibly results in the reduction in confidence level when applying these analytical methods.  This paper presents a review on the available analytical solutions for horizontal well PI.  In addition, this paper attempts to conduct a comparative study between the analytical solutions an numerical simulation approach to investigate which analytical solution is the most useful and should be utilized with higher confidence level, assuming that the numerical simulation generates more accurate PI values.


Nur Wijaya, Texas Tech University

$7.50
(46) A SIMULATION STUDY ON COMPARISON BETWEEN ANALYTICAL AND NUMERICAL SOLUTIONS FOR HORIZONTAL WELL PRODUCTIVITY INDEX
Price
$7.50
(1) LEVERAGING BIG DATA AND QROD TO IDENTIFY UNDERUTILIZED PUMPING UNITS

Re-utilization of company owned artificial lift equipment and parts is a common practice among operators and service providers across the industry.  It is common practice for operators to resize artificial lift equipment at failure or proactively as economics allow. During resizing activity, it is not uncommon to utilize company owned equipment and inventory to satisfy the hydraulic lifting requirements of the system.



In this paper we share how we leveraged our internal data and along with Q-rod to classify and rank our pumping unit population of over 6000+ wells across our EOR and Unconventional Assets in the Permian Basin. This application was developed using industry standard object-relation database systems, languages, and visualization software. As a result, the project has promoted a company-wide reduction in new purchases of pumping units and motors for the last three years which has supported reducing operating expenses.

 


Scott K. Averett, Austin J. Moran and Steve Gault
OXY USA Inc.
 

$7.50
2018001 LEVERAGING BIG DATA AND QROD TO IDENTIFY UNDERUTILIZED PUMPING UNITS
Price
$7.50
(2) MEASUREMENT WHILE INSTALLING OPTIMIZE ESP INSTALLATION PROCESS FOR INCREASED SAFETY AND EFFICIENCY ON THE ESP INSTALLATIONS IN PERMIAN BASIN WELLS

This paper describes an artificial lift case study where three pilot test wells were installed using measuring-while-installing (MWI) equipment during the process. The final results enabled us to meet the goals and expectations of these test wells. The main test objectives were to reduce the time to run the electrical submersible pump (ESP) in the well, to 

increase the ESP reliability while installing, to monitor the installation with real-time data, and to concurrently monitor rig crew activity. The use of MWI equipment during the ESP installation is a technique that reduces unnecessary manual steps through automation, saving rig time. The technique also reduces HS&E concerns and provides the ability to continuously monitor real-time downhole gauge data such as automated cable conductor resistance measurements and cable integrity. The battery-operated equipment avoids the need for an electrical collector/slip ring system on the spooling unit.



This paper describes the equipment, process and final results after the well tests, where the MWI equipment was used to reduce the installation time by minimizing manual intervention during the electrical tests and to collect real-time data during installation. In addition, results are shared from an economic analysis that demonstrated cost savings achieved from using the MWI equipment compared with other traditional artificial lift installation methods. These results indicate the potential benefits to use this new 

technique and equipment in Permian artificial lift operations.

 


Marco Carrasquero, Regulo Quintero and Arsenys Larez
Baker Hughes
 

$7.50
2018002 MEASUREMENT WHILE INSTALLING OPTIMIZE ESP INSTALLATION PROCESS FOR INCREASED SAFETY AND EFFICIENCY ON THE ESP INSTALLATIONS IN PERMIAN BASIN WELLS
Price
$7.50
(3) NHT ROD GUIDES EXTEND LIFE IN HIGH TEMPERATURE WELLS

Synthetic Polyphthalamide (PPA) has greater resistance than many plastics to a broad range of chemicals and is widely used in the manufacture of sucker-rod guides when operating at depths where temperatures can reach 300℉ (149℃). However, while rated to 400℉, field experience has shown that under certain conditions, the service life of sucker-rod guides constructed of this material can be adversely affected at depths with temperatures as low as 220℉ in continuous use. After extensive research, followed by nearly two years of field testing, the solution was found: a new type of molded-plastic sucker-rod guide, with a proprietary polyether ether ketone (PEEK) blend. The new PEEK-blend sucker-rod guide is an ideal replacement for synthetic polyamide models in shale wells because PEEK is a thermoplastic that retains its mechanical and chemical-resistance properties even at high temperatures.


Jeff Done, Frosty Gray and Jason Hanner, Norris
Darla Bugg, UPCO
 

$7.50
2018003 NHT ROD GUIDES EXTEND LIFE IN HIGH TEMPERATURE WELLS
Price
$7.50
(4) INFLUENCE OF UNCONVENTIONAL METALLURGICAL VARIABLES ON MECHANICAL PROPERTIES OF API SUCKER RODS

Over 70% of the artificially lifted wells in the US are using sucker rod pumping systems. The sucker rod pumping system has been ameliorated during past years due to the high investment of companies and installers as performance of the sucker rod pumping system directly impacts production volume and consequently revenue of E&P companies. The sucker rod is one of the most vulnerable components of a sucker rod pumping system. The correlation between metallurgical variables and mechanical properties is of great importance to ensure proper functionality and to identify rod string optimization opportunities. The API 11B has classified different grades of sucker rods to aid the sucker rod utilization by operators as well as the standards for manufacturers. Corrosiveness of the wellbore fluid, well depths (loads), material susceptibility to H2S related cracking and other conditions are crucial to sucker rod’s continuous manufacturing improvement. A set of secondary or unconventional metallurgical factors have specific effects on mechanical properties that can aid in the sucker rod performance subject to these conditions. These factors are reviewed in this study along with its impact in the selection of suitable sucker rod grades to increase the life of sucker rod pump installations. This paper presents theoretical considerations and testing data to study metallurgical factors that affect the final mechanical properties of API grade sucker rods. Some of the metallurgical and mechanical variables testedand discussed include micro-alloying content, normalizing cooling rates, toughness and residual stresses developed at the steel mill and the sucker rod processing plant. Finally, an economical overview of these metallurgical and mechanical variables on different API grades are also discussed in this study.


Reza Eghtesad, Pablo E. Barajas and Wanru Shang
Norris
 

$7.50
2018004 INFLUENCE OF UNCONVENTIONAL METALLURGICAL VARIABLES ON MECHANICAL PROPERTIES OF API SUCKER RODS
Price
$7.50
(5) IMPROVED RESULTS IN ROD PUMPS WITH ISOLATED TAILPIPE THOUGH ADVANCEMENTS IN SYSTEM COMPONENTS AND ANALYSIS

Rod pumps with isolated tailpipe systems have been growing in popularity over the past few years and applied in basins all over the US.  Some earlier system component designs had vital shortcomings that became more evident over time with the growing install base.  

The important fact is that these lessons learned have been a driving force in making positive strides to improve installation procedures, component design, and material selections.  Another vital element leading to improved consistencies and better results is an accelerated and expanded knowledge regarding the required nodal analysis to properly predict required production and reservoir properties to yield optimal system function. 



This paper will cover the process that has been endured to get to the current improved state of operations and how further success is assumed to be obtained as rod pumps with isolated tailpipes are applied in unconventional wells for years to come. 

 


Brian Ellithorp, Echometer UPS and Ellithorp Energy Services
James N. McCoy, Echometer
 

$7.50
2018005 IMPROVED RESULTS IN ROD PUMPS WITH ISOLATED TAILPIPE THOUGH ADVANCEMENTS IN SYSTEM COMPONENTS AND ANALYSIS
Price
$7.50
(6) CASING GAS SEPARATOR - A SIMPLE METHOD TO DOUBLE GAS SEPARATION CAPACITY IN NEW WELLS

A casing gas separator (CGS) is a safe to run, low-risk, and efficiency altering tool that pairs naturally with existing wellbore design and work practices to vastly improve gas handling and capacity in virtually any form of artificial lift.



When a new well is drilled the hole is cased and cemented and during that process a CGS is run permanently into place on the casing with no alteration to the drilling program whatsoever.  The CGS is commonly placed at kickoff point or in a tangent further downhole and well work occurs with absolutely no alteration to normal completion processes.  



A CGS may be run and set with multiple flowpath options and separation capacity is essentially doubled by providing twice the casing flow area inside the tool.  The result is the most prolific and flexible gas separation technology any horizontal well has ever applied. 

 


Brian Ellithorp, BlackJack Production Tools

$7.50
2018006 CASING GAS SEPARATOR - A SIMPLE METHOD TO DOUBLE GAS SEPARATION CAPACITY IN NEW WELLS
Price
$7.50
(8) RELATING MPRL/PPRL AND PRV TO FAILURE FREQUENCY

Relating Polished Rod Velocity and ratio of MPRL/PPRL to Failure Frequency. This study uses historical data to understand these relationships. The data is primarily from San Andres and Clearfork water floods and CO2 floods located in the Permian Basin.


Daniel Fishkind, Jeff Jenneman and Steve Gault
OXY, USA Inc.
Lynn Rowlan, Echometer Company
 

$7.50
2018008 RELATING MPRL/PPRL AND PRV TO FAILURE FREQUENCY
Price
$7.50
(9) EFFORTS TO REDUCE THE COST OF STUCK PUMPS

Historically as many as 30% of bottom hold down pumps have been stuck. This can result in extra cost associated with pulling tubing on pump repairs or rod failures. This paper focuses on efforts with various tools and techniques that have been used to lessen the number of pumps stuck in tubing.


Steven Reedy, Saul Tovar Francisco Perez and Steve Gault
OXY USA Inc.
 

$7.50
2018009 EFFORTS TO REDUCE THE COST OF STUCK PUMPS
Price
$7.50
(12) NEW GAS MITIGATION SOLUTION FOR UNCONVENTIONAL WELLS IN ESP (CASE STUDIES IN THE PERMIAN BASIN)

New unconventional wells have been a huge challenge for ESPs in the Permian Basin because in horizontal wells with high-formation GORs or GLRs, the pumped fluid can cause issues such as gas interference, gas locking, short run life, low production, poor energy efficiency, increased failure rates, shutdowns, so forth. A major problem is gas presence around the ESPs, it causes the motor to rapidly overheat because the gas is incapable of adequately cooling.



For this application, a double stage of gas separation was designed to break the gas slug and avoid gas entrance into ESPs by forcing free gas to go around the shroud and produce through the casing, and the fluid is forced to pass through an additional gas separator (Guardian Shield), this tool helps to separate gas to keep lower motor temperature. These novel applications help operators to reduced OPEX (operating expense) by minimize well Interventions, decreasing failures in the pump due to overheat, and allow the ESP to operate in gassy wells with high GLR, stabilizing the production and reduce the unforeseen interruption.

 


Carlos Loaiza, Chevron
Gustavo Gonzalez, Odessa Separator Inc.
Roger Maxim, Summit ESP
 

$7.50
2018012 NEW GAS MITIGATION SOLUTION FOR UNCONVENTIONAL WELLS IN ESP (CASE STUDIES IN THE PERMIAN BASIN)
Price
$7.50
(13) GENTLE PUMP-OFFS CAN REDUCE OPERATING EXPENSES

Pumping wells hard involves a tradeoff between operating cost and production. Increased idle time or holding additional back pressure on the reservoir can decrease production but pumping a well harder will likely increase failure frequency. The existing reservoir pressure has a significant impact on the potential change in production.  Pump-Off Controllers (POCs) are used to regulate run time on many wells operated in Permian Basin water floods and are accepted as a failure reducing and cost saving tool. Moving set points in, changing the pump off strokes, and decreasing SPM should not affect production. Notably, conventional inflow models demonstrate that reductions in flowing bottom-hole pressure become less impactful when wells are operated at relatively low bottom-hole pressures. This paper will discuss specific examples of using POCs to pump wells gently and illustrate one mythology or calculator to evaluate the economic tradeoff.


Brett Williams, Jeff Jenneman and Steve Gault
OXY USA Inc.
 

$7.50
2018013 GENTLE PUMP-OFFS CAN REDUCE OPERATING EXPENSES
Price
$7.50