Paper Presenters Price
(2015040) HYDRAULIC FRACTURING MODELING: PAST, PRESENT FUTURE

Modeling of hydraulic fracturing began after the early years of the first application of this technology. Since then, researchers have taken several modeling approaches and significant progresses are achieved in hydraulic fracture modeling. Developments are result of studying different complexities such as out of plane propagation, different problem scales, fluid flow, thermal stress etc. In addition to these complexities, uncertainty of the problem dictates the prediction of final fracture geometry before the real operation. Therefore, an effective modeling approach is needed to obtain a successful hydraulic fracture treatment. The objective of this study is to discuss the various approaches in hydraulic fracture modeling and present a review on history of hydraulic fracture model developments.


 


Simple 2D hydraulic fractures were among the early analytical models for prediction of fractures behavior. Inefficiency of these models for predicting fracture geometry in reservoirs with complex layers caused the development of so called P3D models. P3D short comes resulted in the development of fully 3D models with 2D fluid flow modeling capability. Several 3D models have been developed since then which include coupled fluid flow equations with fracture mechanics. Although 3D models gives more accurate results than other models, out of plane propagation was not considered in majority of them. They simply ignore the near-wellbore effects of deviated wells and assume a planar starting crack that has extended beyond this region. This problem was solved later using true 3D models.


Ali Rezaei, M. Y. Soliman, Texas Tech University Stephen Morse and Mehdi Rafiee, Statoil Gulf Services LLC $7.50
Paper: (2015040)HYDRAULIC FRACTURING MODELING: PAST, PRESENT FUTURE
Paper: (2015040)HYDRAULIC FRACTURING MODELING: PAST, PRESENT FUTURE
Price
$7.50
(2015041) PUMP SPACING ON FIBERGLASS SUCKER RODS

Pump spacing on fiberglass sucker rods is very important to the performance of the well and fiberglass rods.  As gas becomes more of  a problem in pumps, the gas compression ratio is even more important.  Edge Production Equipment has developed a chart for pump spacing that will help space wells more efficiently and increase the gas compression ratio. 


Eddie D. Guelker, Edge Production Company, LLC. $7.50
Paper: (2015041)PUMP SPACING ON FIBERGLASS SUCKER RODS
Paper: (2015041)PUMP SPACING ON FIBERGLASS SUCKER RODS
Price
$7.50
(21) VSP AN UPDATE FROM 2001

A tried and true method of reducing gas interference in rod pumps is to set the pump in a position below all the perforations. The liquid and gas separate with the liquid dropping down to the pump intake and the gas rising in the casing-tubing annulus. This is not possible in today’s horizontally completed wells where the preferred pump placement is in the vertical section. In 2000 and an update in 2001 Benny Williams with Harbison Fischer presented papers regarding the then new Harbison-Fischer Variable Slippage Pump® (VSP®) patent #6,273,690 . In the last 24 months there has been an increase of interest of the VSP®. Many of these pumps have gone into these horizontally completed wells. The timing is good to update the paper with the large number of new wells being completed horizontally.


Rodney Sands Harbison Fischer $7.50
Paper: (21) VSP AN UPDATE FROM 2001
Paper: (21) VSP AN UPDATE FROM 2001
Price
$7.50
(22) CREATE EFFICIENCY BY SKIPPING A STEP

Once horizontal wells expend their phase of natural flow and an artificial lift system is required, they are well known to have production challenges associated with downhole pump gas interference and solids issues. Gas lift is often implemented as a transitional artificial lift solution since it is solids-tolerant, it can handle high decline rates and it can manage sluggy flow conditions inherent to horizontal wells. Producing fields with gas infrastructure frequently default to this option to capitalize on existing equipment, but knowingly sacrifice longer term production and reserves from the limitations of gas lifting.


 


This paper will present an approach to replace gas lift in the intermediate lifting cycle of the life of a well. The paper will discuss the limitations of gas lift, introduce an alternative approach and demonstrate its efficiency with case study.


Jeff Saponja, Dave Kimery and Camille Jensen Production Plus Energy Services Inc. $7.50
Paper: (22) CREATE EFFICIENCY BY SKIPPING A STEP
Paper: (22) CREATE EFFICIENCY BY SKIPPING A STEP
Price
$7.50
(23) A NEW ADVANCED MATERIAL SUCKER ROD COUPLING MATERIAL: ECONOMICAL SOLUTION FOR DOWNHOLE WEAR IN DEVIATED BAKKEN UNCONVENTIONAL WELLS

In 2014, Hess initiated a project to manufacture 1-inch slim hole sucker rod couplings with a Cu15Ni8Sn high strength spinodal alloy, which provides higher toughness and corrosion resistance compared to other bronze alloys. 


 


The couplings significantly reduce wear in deviated sections of unconventional wells. Hess’s pilot program includes ten wells and will be extended to sixty wells. 


Another pilot is underway wherein ¾-inch full size couplings and 1-inch slimhole couplings are installed at the bottom half of three wells. The purpose is to reduce friction in the lower portion of the string, thereby lowering the peak polished rod loads, lowering gear box loads, reducing power consumption, and increasing pump stroke length. Results will be presented in the paper.

Seth Silverman and Logan Stoner, Hess Corporation William Nielsen and Diane Nielsen, Materion Corporation $7.50
Paper: (23) A NEW ADVANCED MATERIAL SUCKER ROD COUPLING MATERIAL: ECONOMICAL SOLUTION FOR DOWNHOLE WEAR IN DEVIATED BAKKEN UNCONVENTIONAL WELLS
Paper: (23) A NEW ADVANCED MATERIAL SUCKER ROD COUPLING MATERIAL: ECONOMICAL SOLUTION FOR DOWNHOLE WEAR IN DEVIATED BAKKEN UNCONVENTIONAL WELLS
Price
$7.50
(24) ADAPTIVE POLISHED ROD VELOCITY PROFILE SELECTION ALGORITHM FOR OPTIMIZING PRODUCTION, EFFICIENCY AND RELIABILITY

While controllers for VSD-driven pumping units have the capability today to make manually programmed intra-stroke speed changes, they do not autonomously make these decisions. This work will describe a new control algorithm that autonomously chooses polished rod velocity profiles to maximize efficiency and production while protecting pumping units and rods from overloads. The algorithm uses surface and downhole cards from the earlier stroke, generating a new polished rod velocity profile for the following stroke. In particular, the algorithm modulates ramp rates and peak velocities of a smooth ‘trapezoidal’ velocity profile. Simulations of this algorithm suggest that rod fatigue, rod buckling and load violations can be corrected, while maintaining production. Results from full-load tests will be presented to show how the algorithm morphs surface cards to fit the permissible load envelope of pumping units. Using such an algorithm, overall power consumption of rod pumping can be expected to decrease by 10-20%.


Kalpesh Singal, Abhijit Khare, Justin Barton, Shyam Sivaramakrishnan, David Doyle, Qing Wu, Michael Honey, Darrell Stubblefield and Terry Stephenson GE Lufkin Rod Lift Systems $7.50
Paper: (24) ADAPTIVE POLISHED ROD VELOCITY PROFILE SELECTION ALGORITHM FOR OPTIMIZING PRODUCTION, EFFICIENCY AND RELIABILITY
Paper: (24) ADAPTIVE POLISHED ROD VELOCITY PROFILE SELECTION ALGORITHM FOR OPTIMIZING PRODUCTION, EFFICIENCY AND RELIABILITY
Price
$7.50
(25) HIGH LIQUID VOLUME PLUNGER LIFT IN THE PERMIAN BASIN

This paper will be on the use of high liquid volume plunger lift in the Permian Basin.  This method of lift was first considered in an effort to bridge the gap for taking high liquid volume wells from flowing to rod pump.  Historically in the Permian Basin this was accomplished with high cost electric submersible pumps, gas lift or rod pump.  One of the criteria for success was that plunger lift would be able to economically maintain a well on its natural decline.  Representative decline curves will be presented, along with operating pressures and histories on the successful wells.  This paper is will be an update of a previous paper presented in 2015 for wells in the Southern Delaware Basin.


Mike Swihart Production Lift Systems, Inc. $7.50
Paper: (25) HIGH LIQUID VOLUME PLUNGER LIFT IN THE PERMIAN BASIN
Paper: (25) HIGH LIQUID VOLUME PLUNGER LIFT IN THE PERMIAN BASIN
Price
$7.50
(26) ARTIFICIAL LIFT LEARNINGS IN BONE SPRING AND WOLFCAMP FORMATIONS OF WEST TEXAS DELAWARE BASIN

In the West Texas Delaware Basin, at Anadarko, we are very early in our development of the Bone Spring & Wolfcamp formations. Our current artificial lift strategy is to use gas lift or jet pump as intermediate lift, followed by rod pump. We implement these methods of artificial lift to produce high total fluid volumes and reduce downhole failures. This presentation covers what we have learned so far and the questions that remain to be answered as we determine the most effective way to produce these wells.


Eric Winter Anadarko $7.50
Paper: (26) ARTIFICIAL LIFT LEARNINGS IN BONE SPRING AND WOLFCAMP FORMATIONS OF WEST TEXAS DELAWARE BASIN
Paper: (26) ARTIFICIAL LIFT LEARNINGS IN BONE SPRING AND WOLFCAMP FORMATIONS OF WEST TEXAS DELAWARE BASIN
Price
$7.50
(27) ADVANCE INTERMITTENT GAS LIFT UTILIZING A PILOT VALVE

The field trial is focused on utilizing a pilot valve to obtain low instantaneous FBHP for low rate, low reservoir pressure horizontal wells. The pilot valve system is an alternative use for a positive displacement pump application. The presentation will cover the operation and use of the pilot valve. As well as cover well application and total fluid rate recovery expected while on pilot valve intermittent service. Operational fixes, and improvements will be discussed and shown as a means to improve efficiency and reduce % loss during intermittent cycles. Production results from pilot valve tests will be indicated along with predicted FBHP to illustrate the change in FBHP and resulting drawdown from low reservoir pressure wells.


Matt Young Flowco Production Solutions $7.50
Paper: (27) ADVANCE INTERMITTENT GAS LIFT UTILIZING A PILOT VALVE
Paper: (27) ADVANCE INTERMITTENT GAS LIFT UTILIZING A PILOT VALVE
Price
$7.50
(29) BEST PRACTICES IN DIAGNOSTICS TO ADDRESS WELL INTEGRITY PROBLEMS AND REPAIRS

The values that can be obtained from understanding what problems or needs are required in resolving existing well performance are often not taken into account when applying solution treatments. Upfront in Best Practices, Diagnostics may be required to (A) identify well integrity issues, define the various well or reservoir conditions, or they may be needed to (B) define and develop a solution required to fix the various understood problems that may occur.

Prentice Creel, Independent Consultant Steve McLaughlin, Cardinal Surveys $7.50
Paper: (29) BEST PRACTICES IN DIAGNOSTICS TO ADDRESS WELL INTEGRITY PROBLEMS AND REPAIRS
Paper: (29) BEST PRACTICES IN DIAGNOSTICS TO ADDRESS WELL INTEGRITY PROBLEMS AND REPAIRS
Price
$7.50
(30) ETHICS IN ENGINEERING

The mission of the Texas Board of Professional Engineers (Board) is to protect the health, safety, and welfare of the people in Texas by ensuring that the practice of engineering in the state is carried out only by those persons who are proven to be qualified and by regulating the practice of Professional Engineering in Texas. 


 


The course provides a review of engineering ethics and professional responsibilities while highlighting important aspects of the Engineering Practices Act Rules and Regulations.  The one hour presentation also provides P.E.s the required one hour Continuing Education Credit for Ethics, Rules and Regulations as well as informs any Engineer on updated information related to the practice of engineering in Texas.


Robert Opiela Texas Board of Professional Engineers $7.50
Paper: (30) ETHICS IN ENGINEERING
Paper: (30) ETHICS IN ENGINEERING
Price
$7.50
(31) A CRITICAL REVIEW OF TWO-PHASE FLOW GAS-OIL HYDRODYNAMICS FOR HORIZONTAL WELL APPLICATIONS

The theoretical studies and experimental data of two-phase flow hydrodynamics currently available are mainly for the case of horizontal, inclined, and vertical flows.  There are some developments to understand the two- and three-phase flow hydrodynamics on the hilly-terrain and the severe-slugging in both onshore and offshore cases.  Yet, for the cases of horizontal well with the production tubing inside, the impact of the tubing location in the horizontal well at the curve section (the connection between the vertical and horizontal sections) are not clear.  This work provides the review on the two-phase flow hydrodynamic characteristics for the case of horizontal well and provide the fundamental understanding on the impact of toe-up and toe-down of the well to the case of two-phase gas-oil flows. The review also emphasizes on the applicable two-phase flow steady-state and transient models that can be using to analyze the horizontal well production successfully.


Ekarit Panacharoensawad and Raymond Eghorieta Texas Tech University $7.50
Paper: (31) A CRITICAL REVIEW OF TWO-PHASE FLOW GAS-OIL HYDRODYNAMICS FOR HORIZONTAL WELL APPLICATIONS
Paper: (31) A CRITICAL REVIEW OF TWO-PHASE FLOW GAS-OIL HYDRODYNAMICS FOR HORIZONTAL WELL APPLICATIONS
Price
$7.50
(32) WATER SHUTOFF CANDIDATE SELECTION METHOD IN THE GRAYBURG FORMATION IN WORLD FIELD - CROCKETT COUNTY TEXAS

Excess water production is a wide-spread and costly issue in the oil and gas industry. Polymer gel water shutoff treatments provide a valuable means of decreasing water production and reducing operating costs; however, successful treatments are dependent upon selecting viable candidate wells. The industry has long sought a reliable means of identifying wells to target with polymer gel treatments. Most studies into this problem have looked into a potential link between formation permeability and the success of treatments. This paper explores a new method: a correlation which uses the porosity and height of the treated zone to evaluate the viability of polymer-based water shutoffs.


This study proposes a selection method for water shutoff candidates in a dolomitized, oolitic highly-permeable carbonate reservoir in the Grayburg formation. Wells completed in this field often have issues with a high water-oil ratio (WOR), creating a need for water shutoff. The candidate selection method took shape while reviewing the data of several recent treatments in the field. The selection method is based on the formation porosity and height (ϕH) of the treated interval. It is proposed that a ϕH value within a given range is indicative of a potentially-successful treatment.


 


Once the initial idea was defined, the results of the first wells were compared to the proposed correlation. Using the function to identify candidates, additional wells were selected and treated. Results of these wells are presented in the paper and support the proposed model. For additional confirmation, the method was applied to the data for a series of wells treated with polymer gel in the same formation and field in 1997-8. The results of this study are also presented.


Polymer gel treatments have valuable water shutoff capabilities, but they must be applied to the correct candidate wells. The correlation presented in this study provides a system by which wells can be selected for treatment. This paper will demonstrate the viability of the method in a classic carbonate reservoir with high permeability variations.


Michael Carey, Kyle Huckaba, Peter Stauband and Matthew Oyedeji Saga Petroleum John Gould and Sean Wood Baker Hughes, Inc. $7.50
Paper: (32) WATER SHUTOFF CANDIDATE SELECTION METHOD IN THE GRAYBURG FORMATION IN WORLD FIELD - CROCKETT COUNTY TEXAS
Paper: (32) WATER SHUTOFF CANDIDATE SELECTION METHOD IN THE GRAYBURG FORMATION IN WORLD FIELD - CROCKETT COUNTY TEXAS
Price
$7.50
(33) CONTROL PH VALUE FOR SUPERABORBENT POLYMERS (SAPS) SOLUTIONS BY USING HYDROCHLORIDE ACID (HCL)

The purpose of this study is to observe the effects of superabsorbent polymers AT-O3S and 2G-110 when introduced to brine solutions with varying pH values.  The polymer is intended to swell in order to block high permeability zones in existing oil wells.  The swelled polymer will decrease reservoir heterogeneity, diverting injected water to the oil rich zones/areas. Understanding the kinetics of the SAPs are crucial to their proper employment. However, when the AT-O3S and 2G-110, both Sodium crosslinked polyacrylic acids, are introduced to brine solutions containing Calcium, reactions involving the sodium crosslinker of the polymers occurs resulting in the destruction of the polymers.  To remedy this situation, we are testing if varying pH values of the brine will alter the reaction in order to find whether or not this problem is preventable.  Our results have been positive in that the reaction was delayed as the polymer precipitated out slower.


Mahmoud Elsharafi, Cody Chancellor, Jeong Tae Ok and Connor Kirby Midwestern State University $7.50
Paper: (33) CONTROL PH VALUE FOR SUPERABORBENT POLYMERS (SAPS) SOLUTIONS BY USING HYDROCHLORIDE ACID (HCL)
Paper: (33) CONTROL PH VALUE FOR SUPERABORBENT POLYMERS (SAPS) SOLUTIONS BY USING HYDROCHLORIDE ACID (HCL)
Price
$7.50
(34) EVALUATION OF RECOVERY PERFORMANCE OF MISCIBLE GAS DISPLACEMENT PROCESSES IN TIGHT OIL FORMATIONS

Tight oil reservoirs have become one of the main forces of oil reserves and production growth. Tight oil reservoirs are mostly developed by natural depletion. Only 5 % to 15 % of the oil can be recovered using natural deletion. Further improve of oil recovery of tight oil reservoir can be achieved by Appling miscible gas flooding process. This paper shows the feasibility of Appling miscible gas flooding as a method of enhancing oil recovery of tight oil reservoirs. The results of this compositional study show that the recovery factor of horizontal well with hydraulic fracture improved to about 30 % when the miscible gas displacement process was applied. Furthermore, the study shows the effect of the minimum miscible pressure (MMP) and the total gas injection volume on the gas flooding process.


Ahmed GH Mansouri and Talal Gamadi, Texas Tech University $7.50
Paper: (34) EVALUATION OF RECOVERY PERFORMANCE OF MISCIBLE GAS DISPLACEMENT PROCESSES IN TIGHT OIL FORMATIONS
Paper: (34) EVALUATION OF RECOVERY PERFORMANCE OF MISCIBLE GAS DISPLACEMENT PROCESSES IN TIGHT OIL FORMATIONS
Price
$7.50
(35) A NEW METHOD TO ASCERTAIN THE HF STRENGTH OF ACIDIZING FLUIDS USING ION SELECTIVE ELECTRODE

Ion selective electrodes (ISE) can accurately measure the strength of hydrogen fluoride (HF) acids used for acidizing jobs. The accurate measurement of free fluoride generated from the hydrolysis reaction, especially with weaker organic acids, is important to ensure that the desired acid fluid strength is delivered downhole during well stimulation operations. 


 


Unlike inorganic acids such as hydrochloric that dissociates completely, organic acids only partially dissociates in solution, and as such do not completely hydrolyze the fluoride ion source such as ammonium fluoride or ammonium bifluoride to generate the required amount of HF. Furthermore, the presence of multiple dissociable protons with different acid strengths on organic acids such as citric acid and Etidronic acid further exacerbates the problem.  Therefore, there is the need to accurately measure the amount of hydrogen fluoride generated for acidizing fluid treatments.


Nelson Akaighe and Sumitra Mukhopadhyay Superior Energy Services $7.50
Paper: (35) A NEW METHOD TO ASCERTAIN THE HF STRENGTH OF ACIDIZING FLUIDS USING ION SELECTIVE ELECTRODE
Paper: (35) A NEW METHOD TO ASCERTAIN THE HF STRENGTH OF ACIDIZING FLUIDS USING ION SELECTIVE ELECTRODE
Price
$7.50
(36) PARAFFIN INTERVENTION-CASE HISTORY, PRACTICES, PRODEDURES, AND ECONOMICS

Treating for paraffin in rod pumped wells is a critical operating cost driver that needs continuing attention.  While there are various prevention chemicals, operators still need periodic removal interventions.  This paper will summarize prior investigations regarding the removal of paraffin and provide a case history that illustrates the issues.


 


In addition, this paper will discuss the economic considerations related to common paraffin removal processes.  The economic considerations will include the direct costs as well as the indirect, hidden costs.  In general, paraffin removal in rod pumped wells by annular hot oiling has severe depth limitations that require periodic, supplemental treatments.  The economic benefits and trade-offs are largely dependent on the depth of paraffin deposition, the type of paraffin, and the wellbore configuration.


Carter Copeland and Bruce Martin Owl Energy Services, Ltd $7.50
Paper: (36) PARAFFIN INTERVENTION-CASE HISTORY, PRACTICES, PRODEDURES, AND ECONOMICS
Paper: (36) PARAFFIN INTERVENTION-CASE HISTORY, PRACTICES, PRODEDURES, AND ECONOMICS
Price
$7.50
(37) HYDRAULIC FRACTURING COMMUNICATION PERSPECTIVES

This paper will discuss the need for the oil industry at all levels to broaden its perspective regarding how the concept of hydraulic fracturing is communicated to the public.  The current level of communication is so narrowly focused that groups outside of the industry have been able to exploit this communication problem to the detriment of the industry.   This paper will discuss specific examples of the  communication problem and the corresponding economic and political impacts on the industry.


Carter Copeland Owl Energy Services, Ltd $7.50
Paper: (37) HYDRAULIC FRACTURING COMMUNICATION PERSPECTIVES
Paper: (37) HYDRAULIC FRACTURING COMMUNICATION PERSPECTIVES
Price
$7.50
(38) COST EFFICIENCY OF POST FRAC OPERATIONS BY USING DISSOLVABLE METALS AND CASING BAFFLES: SET-A-SEAT

The Set a Seat is a tool that has been developed by Peak Completions Technologies that has reduced the cost of post frac operations.  Using Peaks patented technology, the Set a Seat make it possible to open up the well head and begin producing with milling out plugs. 

Ted Flores and Bryan Fitzhugh Peak Completions $7.50
Paper: (38) COST EFFICIENCY OF POST FRAC OPERATIONS BY USING DISSOLVABLE METALS AND CASING BAFFLES: SET-A-SEAT
Paper: (38) COST EFFICIENCY OF POST FRAC OPERATIONS BY USING DISSOLVABLE METALS AND CASING BAFFLES: SET-A-SEAT
Price
$7.50
(39) PINPOINT FRAC-ISOLATION TECHNOLOGY COMBINED WITH MEASURED DOWNHOLE DATA ENABLES CONTROLLED OPTIMIZATION OF MULTISTAGE COMPLETIONS

Today, E&P companies are being challenged to improve economic performance. Since completions are a major cost, it is imperative to improve completion efficiency and maximize production results.  A new controlled approach to multistage completions combines predictable frac placement (spacing and propped volume) with bottom-hole pressure and temperature data recorded during stimulation to enable progressive, formation-specific optimization of stimulation designs and frac delivery. The approach relies on single-point frac placement, using a coiled-tubing-deployed isolation system that incorporates downhole data recorders. The presentation describes single-point stimulation technology, discusses the value and interpretation of downhole pressure and temperature data, and reviews a number of optimization case histories.


Jason Frost NCS Multistage LLC $7.50
Paper: (39) PINPOINT FRAC-ISOLATION TECHNOLOGY COMBINED WITH MEASURED DOWNHOLE DATA ENABLES CONTROLLED OPTIMIZATION OF MULTISTAGE COMPLETIONS
Paper: (39) PINPOINT FRAC-ISOLATION TECHNOLOGY COMBINED WITH MEASURED DOWNHOLE DATA ENABLES CONTROLLED OPTIMIZATION OF MULTISTAGE COMPLETIONS
Price
$7.50
(40) NEWER METHOD OF HORIZONTAL WELL EVALUATION

Around the world, the focus of completing and stimulating wells has been based mainly on the efficiency of the completions and stimulation. While this is sound, too little focus has been paid to where the oil, gas and water is originating. Enormous opportunities abound to go back into these wells and evaluate them to determine the best candidates and zones to refrac.


 


This presentation will introduce an evaluation method, The Refrac Road Map,™ that has been tried and proven to be successful in several horizontal wells in West Texas. The Refrac Road Map™ is the updated version of this technology, designed to obtain more information than the previously mentioned system above. The previous system was designed and used to locate where water and oil were originating in an open hole carbonate well in West Texas and New Mexico. The updated version of the system has the following features:


• Isolates a perf cluster or sleeve


• Produces that isolated section of the well


• Directly measures


o  3 phase flow


o Static and Flowing bottom hole pressure


o Temperature


• Sensors


o Ultrasonic Doppler flow measurement


o Gas holdup: Optical Probe


o Water Hold Up: Electrical


o Oil Detection: Fluorescence Probe


 


The nature of horizontal wells makes standard production logs unreliable. This system isolates each zone, thus allowing true measurements rather than analysis of the mixed fluid in the lateral. With this data and mechanical diversion, we believe that refracs will become much more successful and profitable in the future.

Jay Miller, Tech-Flo Consulting, LLC $7.50
Paper: (40) NEWER METHOD OF HORIZONTAL WELL EVALUATION
Paper: (40) NEWER METHOD OF HORIZONTAL WELL EVALUATION
Price
$7.50
(41) THE EVOLUTION OF BALL-DROP COMPLETION TECHNOLOGY IN THE PERMIAN BASIN

Traditionally, ball-drop completion systems were limited not only by application, but by pressure, rates, and stage count. This paper shows the history of the ball-drop completion systems in the Permian Basin and looks at how the development of new technology has allowed ball-drop systems to be used in more than just open hole applications, as well as how this technology has overcome the aforementioned limitations.


Justin R. Moos Packers Plus Energy Services USA, Inc. $7.50
Paper: (41) THE EVOLUTION OF BALL-DROP COMPLETION TECHNOLOGY IN THE PERMIAN BASIN
Paper: (41) THE EVOLUTION OF BALL-DROP COMPLETION TECHNOLOGY IN THE PERMIAN BASIN
Price
$7.50
(42) A NEW TECHNOLOGY THAT DELIVERS LONG-TERM CHEMICAL TREATMENT DURING WELL STIMULATION: ORGANIC DEPOSIT AND INORGANIC SCALE CONTROL

A new technique of delivering long-lasting treatment for damaging well conditions, such as scales, corrosion, or organic deposits, has been achieved using a novel technology. This new technology involves a viscoelastic, biopolymer-hydrogel as the matrix to incorporate and transport chemicals into the formation. When placed in the fracture length, the porous matrix controls the release of the treatment agent over long period of time.


 


The system is environmentally safe and cost-effective, and designed to be pumped with stimulation fluids during proppant transport. This technology has proven to provide a more efficient delivery, placement, and long-term chemical treatment compared to other existing technologies, where maximum loading of the product is restricted to below 2% of the total proppant.


Sumitra Mukhopadhayay and Nelson Akaighe Superior Energy Services Ailliam Nielnen and Oiane Nielnen Faterion $7.50
Paper: (42) A NEW TECHNOLOGY THAT DELIVERS LONG-TERM CHEMICAL TREATMENT DURING WELL STIMULATION: ORGANIC DEPOSIT AND INORGANIC SCALE CONTROL
Paper: (42) A NEW TECHNOLOGY THAT DELIVERS LONG-TERM CHEMICAL TREATMENT DURING WELL STIMULATION: ORGANIC DEPOSIT AND INORGANIC SCALE CONTROL
Price
$7.50
(44) PERMIAN BASIN OPERATOR OUTPERFORMS COMPETITORS THROUGH ENGINEERED WORKFLOW COMPRISING COLLABORATION AND APPLIED TECHNOLOGY

The Permian Basin (PB) presents many challenges in the development of unconventional plays, such as varying pore pressures, high treating pressures, and geological uncertainty. These challenges intensify in areas that are not well developed or understood. A collaborative partnership between the operator and service provider can significantly reduce such risks.


 


This paper discusses such a collaborative partnership in the PB wherein considerable benefits were gained during drilling and completion of six wells. Using lessons learned and new technologies, the operator and service company engineered a workflow to overcome challenges and deliver economic results, which significantly outperformed previous wells. Key challenges faced and how they were overcome are discussed.


 


These efforts resulted in a six-month cumulative BOE increase of 32% from offset wells. The foundation of this success is directly attributed to the collaborative partnership between the operator and service  company using an engineered workflow to achieve a common goal.


Russell Padalecki and Dean Prather, Halliburton Dylan Garrett and Craig Blair, Capitan Energy $7.50
Paper: (44) PERMIAN BASIN OPERATOR OUTPERFORMS COMPETITORS THROUGH ENGINEERED WORKFLOW COMPRISING COLLABORATION AND APPLIED TECHNOLOGY
Paper: (44) PERMIAN BASIN OPERATOR OUTPERFORMS COMPETITORS THROUGH ENGINEERED WORKFLOW COMPRISING COLLABORATION AND APPLIED TECHNOLOGY
Price
$7.50
(45) WAX DEPOSTITION MODEL ANALYSIS

Wax deposition in offshore and onshore pipeline is one of the significant current flow assurance problem.  There are several wax deposition models proposed in the literature.  However, all of them are validated based on the limited number of data and have not been crosschecked with other researchers’ data.  All of wax deposition model on turbulent flow contain the unknown physical parameters which required in wax deposition prediction.  


 


Nevertheless, the closure relationships of the unknown parameters are not provided in most models, and the available correlations require the validations against more experimental data.  This work provides the performance analysis of wax deposition models by testing the proposed models (such as Singh et al. (2000)) against the experimental data that are just recently available.  The contribution of this work is the understanding in the uncertainty and the limitation in wax deposition model currently available in several commercial software.


Ekarit Panacharoensawad, Arya Shahdi and Moldir Yermekova Texas Tech University $7.50
Paper: (45) WAX DEPOSTITION MODEL ANALYSIS
Paper: (45) WAX DEPOSTITION MODEL ANALYSIS
Price
$7.50