bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Maturity Modeling Approach to Ensuring Effective Competency-Based Workforce Development
Authors: Johnson Jeffrey A. , Sim Darrell 
Published: November 2017

Abstract

Objectives & Scope
Developing your workforce is an ongoing exercise in remaining technically current and relevant in a culture of continuous improvement. With changing employee demographics, technologies, assets and business conditions, each competency-based development program requires strong governance and ongoing investment to ensure a sustainable system that supports the development of workforce capability, effectiveness and efficiency. This paper details a maturity modeling approach that defines a governance framework for ensuring an effective competency-based workforce development program.

Methods, Procedures, Process
A competency management framework is described which details the methods, processes and best practices supportive of workforce capability enhancement efforts. Implementation of the framework enables organizations to mature from ad hoc, inconsistent practices, to a consistent, disciplined, and continuously improved set of competency management processes. Specific descriptions are provided of five levels that define the competency program maturity plateaus, as defined below in Figure 1.
Consequently, the five levels of competency program maturity are further referenced to six key competency pillars, as outlined below in Figure 2.
The detailed characteristics, benefits, actions and obstacles that align each maturity level to the six defined pillars of competency are later examined in further specificity.
(Refer to ‘Presentation of Data & Results')

Results, Observations, Conclusions
Characteristics of each maturity level across the pillars are demonstrated. The maturity structure can be utilized to establish a competency program's organization, enable detailed action planning towards targeted and measurable process improvements, and set milestones aligned with strategic business objectives. Competency analytics provide management with a view into the state of organizational capability, clearly illustrating competency gaps and related development solutions. With a dedicated team and a view by management of program evolution, a working maturity model can be a framework that supports and directs a continuous improvement culture.

Novel/Additive Information
Establishing a consistent maturity model through industry collaboration can provide benchmarking opportunities that will benefit corporations as they pursue implementation of competency management best practices.
Optimization of Mercury Removal Unit MRU location in Gas Processing Facilities
Authors: Al-Sawafi Khalid , Al-Jabri Hilal 
Published: November 2017

Abstract
Feed gas from KLD fields has mercury content with around 125 micro g/Nm3. Mercury Removal Unit (MRU) will be designed to reduce the mercury content well below 5.5 micro g/Nm3 and meet export spec. The mercury removal unit (MRU) is located upstream of GSU, unlike other PDO plants as well as other places in oil& gas processing facilities where MRU is located downstream of GSU. The optimized location of MRU is to avoid contamination of GSU equipment with high Hg content.
Before entering the mercury bed the gas is heated approximately 10 °C above its water and HC dewpoints in the superheater to avoid liquid formation in the mercury bed due to pressure drop across the adsorbent. The superheater upstream of MRU ensures that gas to MRU is at single vapour phase. However, due to hydrocarbon carryover from the inlet KOD which mostely heavy components will increase significantly the gas dew point and thus higher superheater duty.
As a further optimization in order to remove liquids carryover and reduce the superheater duty, filter coalescer is added upstream of MRU superheater.
This paper demonstrate how this new approach and lineup was engineered overcoming various challenges.
Looking Beyond the Wellbore: Formation Evaluation Mitigates Risk and Reduces Uncertainty in Multi-Stage Unconventional Completions
Authors: Kotov Sergey , Stolyarov Sergey , Cazeneuve Eduardo , Walles Frank , Gadzhimirzaev David 
Published: November 2017

Abstract
Is there a proven methodology for designing optimum multi-stage completions in unconventional reservoirs? Where to place frac stages, perforation clusters, and how to avoid geo-hazards? This paper attempts to cover some of the fundamental aspects of stage placement and hydraulic fracturing designs by discussing lessons learned from several major US basins.
A holistic data-driven approach to completion optimization is based on the analysis of the production potential, favorable rock mechanical properties, and geological features along the entire wellbore. Lateral reservoir characterization, including advanced cuttings and gas analysis, high-definition imaging technologies of logging while drilling (LWD), and wireline (WL) deep shear wave imaging (DSWI) is used to optimize completion and stimulation designs. The suggested methodology goes beyond the wellbore proximity and provides insight to practical application of advanced formation evaluation (FE) technologies.
To address the challenges of lithological and horizontal stress heterogeneity of unconventional reservoirs and to optimize multi-stage completions, a combination of three primary categories of reservoir characteristics are considered: "producibility", "fracability", and geofeatures. Deep shear wave imaging technique identifies spatial natural fractures, faults, and other structural features up to 100 ft from the wellbore. This technology in combination with advanced cuttings and gas analysis helped identify and avoid faults, as well as target natural fractures for greater productivity and maximized economic return in several US basins. The analysis of field data suggests that geomechanical, petrophysical, and geochemistry data should be reviewed holistically. The post treatment analysis reveals a direct correlation of microseismic activity with the density of natural fractures obtained from DSWI processing. The strong correlation between surface treating pressure, breakdown pressure, and the fracture intensity was also observed. This information allows characterization of complex fracture networks, qualification of near-wellbore tortuosity, and estimation and modification of the hydraulic fracture design prior to the stimulation treatment. The intervals with lower horizontal stress and higher brittleness indexes are treated with lower pressure, and achieve the target pumping rates significantly faster than "ductile" stages. Case studies demonstrate up to 45% production increase compared to offset wells.
As opposed to geometric stage placement, the suggested integrated completion strategy ensures targeted stimulation with the optimum reservoir contact at the maximum operational efficiency. Advanced formation evaluation techniques provide insight to mitigate risk and reduce uncertainty, therefore maximizing return on investment in multi-stage completions.
Rotating Tension Anchor Improves Cement Bond Quality in Steam Well Applications in a Heavy Oil Field Onshore Germany
Authors: Ebrahimi Arian , Sieveke Clemens , Martin Helge 
Published: November 2017

Abstract
A rotating tension anchor was developed to improve the cement bond by enabling rotation of the production casing of steam injection wells during cementing. This would be a world-first application of this casing pre-tensioning system in the application of steam well design.
A good cement bond is crucial for the integrity of a well; this is especially true in the harsh environment created by a 300°C injection temperature in steam well applications. A common and relatively simple approach to improve the cement bond quality is to rotate the casing during cementing. The rotation creates a helical flow pattern, which has an improved displacement efficiency compared to a uniaxial flow.
The design of steam injection wells in this heavy oil field requires a deep-set anchor to pre-tension the casing string with the required pick-up force. The existing anchor system had to be engineered and modified to enable casing rotation during cementing.
Although no breach of integrity has been found in previous steam injection wells, the operator identified improvement potential for the long term cement integrity through ultra-sonic cement bond measurements of existing wells. The 7-in production casing of a steam injection well was pre-tensioned with 264.000 lbs [120 metric tons] overpull and rotated with 20 revolutions per minute during cementing.
This world-first field trial of a rotating anchor tensioning system demonstrates, that the existing tension anchor system can be modified to enable rotation of the casing. An ultra sonic cement bond run, several weeks after cementing, confirmed that use of this equipment produced an improved cement bond quality compared to offset wells of similar age and status.
Carbon Dioxide Saturated Water Injection for EOR in Carbonate Reservoir
Authors: Shimokawara Mai , Yogarajah Elakneswaran , Nawa Toyoharu , Takahashi Satoru 
Published: November 2017

Abstract
Carbon dioxide (CO2) injection is an attractive EOR technique that allows not only improving oil recovery but also protecting environment by reducing CO2 which is recognized as one of green house gases. Water alternating gas (WAG) process has been frequently applied to improve sweep efficiency that is one of the problems of CO2 injection. During the WAG process CO2 is dissolved with water phase, forming CO2 saturated water, that is, carbonated water.
Carbonated water injection has been investigated at laboratory-scale since 1940s, and incremental oil recovery was reported in various papers. A first commercial application of carbonated water was implemented in 1958. It was shown that the injectivity was improved and additional oil recovery was observed during carbonated water injection. Researchers indicated that the mechanisms of increasing in oil recovery during carbonated water injection were viscosity reduction, oil swelling, wettability alteration etc. from the experimental results. Although researchers indicated the interactions between carbonated water and rocks, which may affect multi-phase flow in porous media, a little focus is on the interactions between them.
This paper describes the interactions between injectant and carbonate rocks during carbonated water injection based on the results of core flood experiments at various conditions. The core experiments were conducted at 30 °C and 500 psig using carbonated rocks mainly composed of calcite. Results showed that the pH and Ca concentration increased in the effluents, indicating that the calcite was dissolved with carbonated water. Sucequently, the porosity and permeability are increased when carbonated water was injected. The experimental results are simulated using advection flow of carbonated water combined with calcite equilibrium. The simulation results agree with the experimental results of effluent of pH and calcium concentration for the case of without ageing and, the model did not reproduce the results of ageing samples. This indicates that the dissolution depends on the rock surface.
Atomic-Scale Theory of Relative Wettability of Surfaces for Enhanced Oil Recovery
Authors: Pantelides Sokrates T. , Prabhakar Sanjay , Liu Jian , Zhang Yu-Yang , Lai Chia-Yun , Chiesa Matteo , Alhassan Saeed 
Published: November 2017

Abstract
Extraction of oil from wells is hampered by the fact that oil sticks to rock surfaces and water does not pry it loose easily. Technically, this is an issue caused by the relative wettability of rock surfaces. Experiments have shown that Na ions that are present in sea water have a negative effect on oil extraction, while Ca, Mg, and other ions enhance oil extraction. However, only limited understanding of the pertinent mechanisms has been achieved. Atomic-scale modeling of wettability is usually pursued using classical molecular dynamics based on empirical potentials. Only limited research based on quantum mechanical calculations has been reported so far. Here we describe the development and implementation of parameter-free, quantum-mechanical approaches, at different levels of approximation, that can provide detailed understanding of relative wettability and have predictive capabilities. At the lowest level of approximation, we calculate the binding energies of water and prototype oil molecules to calcite surfaces in vacuum as indicators of relative wettability. At the next level, we calculate binding energies in the presence of liquid water using quantum molecular dynamics. We find that the binding energy of Na acetate is larger than the binding energy of acetic acid, a prototype oil molecule, which suggests that, upon reacting with Na ions, a layer of oil becomes stickier on calcite rocks. On the other hand, Ca and Mg acetate desorb easier than acetic acid, facilitating oil extraction, as observed. At a much more sophisticated level of approximation, we calculate the wetting angle, a measurable quantity that serves as a measure of relative wettability. We applied this method to water on graphene and graphitic surfaces, which has been studied extensively and for which we have obtained new experimental data.
Mitigating Drilling Vibrations in a Lateral Section Using a Real-Time Advisory System
Authors: Bailey J. R. , Payette G. S. , Prim M. T. , Molster J. , Al Mheiri A. W. , McCormack P. G. , LeRoy K. 
Published: November 2017

Abstract
A real-time drilling data analysis and recommendation system that leverages surface drilling data was deployed in the lateral section of a well from an artificial island in Abu Dhabi. A key objective of this technology is to provide the driller with an easy-to-use display of a novel drilling performance map. This paper presents data from this demonstration run, illustrates the features of this technology, and provides general observations on optimization of drilling parameters in this hole section.
The prototype advisory system demonstrated value by recommending rotary speed and ROP (Rate of Penetration) values to continuously optimize the tradeoff between stick-slip vibrations and MSE (Mechanical Specific Energy), depending on depth and formation being drilled. The system relieves the driller of tedious drilling test calculations and seeks to continuously optimize drilling performance. The optimization objective function (OBJ) includes MSE, ROP, and TSE (Torsional Severity Estimate) and provides a surface map that is stoplight color-coded to display the optimal drilling parameter values. TSE is calculated from a drillstring model and observations of the cycle-by-cycle swing in the surface torque.
The typical drilling optimization paradigm holds that higher rotary speed can mitigate stick-slip vibrations at the expense of increased whirl vibrations, and higher WOB (Weight on Bit) tends to increase stick-slip and mitigate whirl. The operational challenge is that these tendencies can vary from run to run, and even within an individual section as pipe length, formation, bit condition, etc. all play a role in the balance between these dysfunctions.
In this application, the system demonstrated that increased rotary speed could mitigate stick-slip for about the first 2,500 ft of the lateral section. From this point on, the drillstring was in full stick slip for all available drilling parameters. However, whirl was sensitive to the effective WOB, determined by the ROP control setpoint in this application. To stay within torque limits and provide sufficient WOB to control whirl, the advisory system actually recommended lower RPM.
This application provided an opportunity to compare the calculated stick-slip levels with bit speed measured at a downhole sensor. Excellent agreement was found between measured stick-slip and the TSE determined from the drillstring model and surface torque throughout the 10 kft lateral. This field demonstration was a first application of the system in ROP control mode, providing new insights into drilling parameter tradeoffs. The system prioritizes objectives with high variability over those with lower variability to improve drilling performance. The data was initially unexpected and led to lower rotary speeds and increased WOB in spite of stick-slip, revealing that it was possible to control whirl without making stick-slip significantly worse.
Corrosion-Erosion Monitoring Systems for Manageing Asset Integrity
Authors: Instanes Geir , Pedersen Audun Oppedal 
Published: November 2017

Abstract
Throughout the oil and gas industry corrosion and erosion damage monitoring plays a central role in managing asset integrity. This paper describes a technology for monitoring of wall-loss rates across continuous areas of pipeline wall. Permanently installed ring arrays of non-invasive ultrasonic transducers delimit a monitored section. The arrays transmit and receive guided ultrasonic waves that insonify the entire pipe section. The received signals are processed by a numerical algorithm to produce a two-dimensional map of wall thickness loss. The algorithm measures wall thickness loss differentially, detecting change between an initial and a current state of the pipe. Wall loss can be estimated with accuracy beyond the pipe manufacturing tolerances. Moreover, a strategy that combines a robust temperature compensation scheme with the intrinsic stability of electromagnetic acoustic transducers (EMATs) is used to address the intrinsic thermal dependency of all ultrasonic technologies, always experienced in field applications. Full-scale experiments are presented demonstrating maximum-depth estimation uncertainty below 0.5 % of initial wall thickness with excellent thermal stability up to 175 °C.
A Step Forward to Assess Cement Blend Flowability and Proneness to Segregation: Cases Histories
Authors: Bourlon Arnaud Joseph , Roy-Delage Sylvaine Le , Taoutaou Salim 
Published: November 2017

Abstract
A recurring challenge in cementing concerns the effectiveness and the quality of cement blending and handling procedures. Some recent technologies involve dry-blending operations and cement-blend handling of specifically tuned blends that mix particles of different characteristics in terms of density, shape, size, and chemistry, including mineral and/or organic components. All blends are usually transported pneumatically, loaded to the rig, and then transferred to the rig silos. During the multiple transfers, depending on its characteristics, the blend may become difficult to flow and prone to segregation. This causes the blend to lose its homogeneity, and, consequently, it becomes difficult to use or even unusable.
Flowability and robustness to segregation are essential blend properties for the handling process. Overall, the differences between particles in chemical nature, density, size, and shape will influence the flowability and the tendency to segregate. Dealing with blends is, therefore, complex since they contain small, medium, and coarse particles, all of them in various proportions depending on the targeted cementing-fluid density and set cement properties.
To counter this challenge, an innovative methodology and equipment were systematically used in field cases to characterize the blend flowability and robustness to segregation.
This new approach is used during the cement-job design as a preventive measure to validate the design and quality control of the dry-blending operations and transportation to the rig. This process helped in designing robust homogeneous blends, thus reducing the likelihood of blend transfer problems.
Three case histories illustrate our new process. In the first case, we evaluated the blend selection between two designs that had good slurry performance for a critical job at a field location. We measured the shear under consolidation, the aerability, and the proneness to segregation of the two blends. Because both blends have good and equivalent flowing properties, we selected the blend that was less prone to segregation. In the second case, the field location designed four complex blends for lead and tail slurries having good slurry performance. We evaluated the shear under consolidation of the four blends, which were classified according to their flowability. Next, we measured the aerability of the blends as a second parameter to discriminate the blends, and then we considered segregation as the last screening parameter. In the last case, we used our flowability criteria to select the maximum acceptable concentration of an additive, which increased cement fluid performance but degraded blend handling.
The outcome of this multidisciplinary approach of blend characterization helps the oil and gas industry anticipate blend-handling issues and continuously improve quality and field handling of engineered complex blends with high confidence and consistency.
Innovative Casing Drilling Technology Improved the Ability to Set the Casing Deeper Through the Problematic Zone in Indonesia Geothermal Operation
Authors: Noviasta Bonar , Falhum Hanafi Muhamad , Setiawan Budi 
Published: November 2017

Abstract
Well A is a geothermal well in K field, located in the Jambi area of Sumatera. The pilot hole of the 17.5-in section was drilled to total depth (TD). However, a 13.375-in casing running difficulty was experienced afterwards. A dedicated cleanout bottomhole assembly (BHA) was run, but this became stuck. The decision was taken to plug the pilot hole with a cement plug and to perform an openhole sidetrack. The difficulty in running the 13.375-in casing is caused by collapsing formation from the borehole wall. The commonly run casing/liner tieback system has no rotational capability when an obstruction is encountered while running the casing.
The 13.375-in × 17.5-in nondirectional casing drilling technology was proposed as the solution. The main component of this technology is the drillable alloy casing bit, which drills on standard casing that is rotated at the surface. The casing bit is equipped with PDC cutters and nozzles with the same function as those in a conventional PDC bit. The casing can be fully rotated while applying weight to cut through the obstruction.
The casing drilling system successfully set the 13.375-in casing to 849.72-m measured depth (MD), 314 m deeper than the initial point of the casing running obstruction. The drilling/reaming capability of the casing bit helped in cutting all the formation filling the predrilled hole. The cementing process was executed well, with good integrity to the surface, shown not only by a surface return during the cement top job but also by a good cement bond log (CBL) result. This eliminated the requirement of having a casing/liner tieback system, which saved operating time and cost. The ability to set the casing deeper enabled sealing off the total loss zone. Consequently, the 12.25-in section drilling could be executed without penetrating the problematic zone, which improved drilling efficiency.