bluuebunny/crossref_metadata_2025_split huggingface dataset:
Essential Leadership Attributes for Engineering Managers in the Petroleum Industry
Authors: Lau Hon Chung 
Published: October 2017

Abstract
Based on a review of the leadership literature and personal observations, the author proposes a new leadership model for engineering managers (EM) in today's petroleum industry. This model consists of five essential leadership attributes. They are technical leadership, task leadership, relational leadership, change leadership and authentic leadership. Technical leadership refers to the ability of the EM to manage projects that are technically complex, multi-disciplinary and are subject to a high degree of technical uncertainty, such as field development planning. Task leadership refers to the EM's ability to be result- focused so as to complete the project on time, within budget and according to scope. Relational leadership refers to the EM's ability to motivate, challenge and support his or her team members to do their best. Change leadership refers to the EM's ability to promote innovative improvements to the organization and adaptation to external changes. Authentic leadership, which underpins all other leadership attributes, refers to the EM's ability to lead according to his or her core values which are ethical, commendable and consistent with those of his or her company, key stakeholders and the community. Suggestions on what universities, companiesand technical professionals can do to provide or acquire leadership training are also given.
Stress Corrosion Cracking on an Insulated Austenitic Stainless Steel Pressure Vessel
Authors: Hapsoro Padang Wikar 
Published: October 2017

Abstract
Stress corrosion cracking (SCC) is one failure mode that may occurred on hot insulated austenitic stainless steel pressure vessels and piping. In 2007, Badak LNG experienced this problem on its Amine Regenerator pressure vessel where the shell are insulated and made of Austenitic Stainless Steel Grade 304L. The paper will share the fact and findings, failure analysis, improvement to prevent recurrence, repair methods and inspection.
During the Train E overhaul in May 2007, cracks were observed on the shell exterior of Amine Regenerator pressure vessel. The cracks mostly occurred above the external vessel stiffening rings. Results of the failure analysis concluded that the pressure vessel failed by chloride induced stress corrosion cracking, due to moisture accumulation and the presence of chlorides at the affected locations in combination with a vessel operating temperature of 99 °C to 125 °C. Repairs were made by a combination of flush patching and weld built up methods.
In addition to a 100% non destructive examination (NDE), a pneumatic leak test was conducted to ensure the integrity of the pressure vessel. Some improvements were implemented to prevent problem recurrence, i.e. coating application on shell external wall surface, implement new specification of thermal insulation and modify the stiffener ring. Further thorough inspections to ensure that no more SCC exists on the pressure vessel were performed using precise NDE tools, i.e. AE (Acoustic Emission) and TOFD (Time of Flight Diffraction). The results were no more cracks indication found.
Currently, the pressure vessel has been in service for almost 10 years and no operational issues found related with SCC.
Application of Enhanced Gel Strength Concept for PPD Chemical Optimization in Banyu Urip Export Pipeline
Authors: Dwitawidi Alinda 
Published: October 2017

Abstract
Banyu Urip crude contains 26% wax which can provide flow assurance (FA) challenges in a stabilized crude pipeline exposed to lower temperatures. Injection of Pour Point Depressant (PPD) chemicals has widely been considered as an effective method to ensure flow assurance for moderate waxy crude. For the Banyu Urip field in Indonesia, PPD injection was compared to other methods and found to be the best option from a cost and operability perspective. Nevertheless, it still contributes to almost 20% of Banyu Urip operating costs. Optimization of this chemical usage brings benefit both for the Operator and also for the government through lowering operating costs.
In the past, the flow assurance of waxy crude was determined by measuring \Pour Point (PP) temperature. At temperatures below this PP, the crude will stop flowing. PP measurement has several limitations, including providing a lower representation of the actual conditions. In this paper, a restart pressure simulation model and pilot experiments were used to provide a more realistic condition assessment and helped to avoid over-injection of PPD.
In the enhanced gel strength concept, a weak waxy crude gel may be formed in the pipeline below its PP and still be breakable by applying pressure within the pipeline's Maximum Allowable Working Pressure (MAWP). Furthermore, the size of pipeline and the wax's natural insulation capability provides a radial temperature profile which can prevent the core pipeline from seeing a rapid temperature reduction. A pilot experiment for establishing a radial temperature profile has been conducted in by the Operator leveraging local university support. The same approach will be conducted for an upcoming flow loop experiment for restart pressure validation.
In Banyu Urip, the initial PP target was set at 24°C based on the lowest seabed temperature observed in the offshore section of the pipeline. This target resulted in a PPD injection dosage of ~500 ppm. Using the enhanced gel strength concept, the required PPD injection rate was reduced to ~300 ppm. Further reduction is expected after conclusion of the radial temperature profile and flow loop experiments.
Temperature Dependent Influence of Nanoparticles on Rheological Properties of VES Fracturing Fluid
Authors: Sangaru Shiv Shankar , Yadav Prahlad , Huang Tianping , Agrawal Gaurav , Chang Frank F. 
Published: October 2017

Abstract
The use of nanoparticles has been demonstrated to enhance the rheological properties of the viscoelastic surfactant (VES) fluid. However, their influence on the rheological properties as a function of temperature is not well known. In this study, a detailed analysis of improved rheological properties and thermal stability of the VES fluid beyond their optimal working temperature was conducted. The effect of nanoparticles was also studied.
A base VES fluid was prepared with the required amount of surfactant along with an ionic strength agent dissolved in sea water. The desired type of nanoparticles in required amounts were added to the base VES fluid and homogeneously dispersed. Different types of nanoparticles were added to prepare corresponding nano-VES fluid. Rheological properties of the base VES fluid and different nano-VES fluids were measured against variable shear rate. The fluids were tested at a temperature at which the base fluid shows highest gelling behavior, and at temperatures above and below that value.
Results, Observations, Conclusions: The initial thermo-viscosifying effect and eventual thermo-thinning effect with temperature havebeen widely observed for viscoelastic surfactants based fluids. The effectshavebeen attributed to the effect of temperature on the structural changes of wormlike micelles. Nanoparticles being of the dimensions that are comparable with the thickness of these wormlike micelles are readily able to incorporate themselves into these structures and influence their rheological behavior. These interactions change both with respect to temperature and shear rate applied on them. Further, these interactions differ depending on whether the fluid is in the thermo-viscosifying region or the thermo-thinning region with respect to the temperature. Based on the kind of nanoparticle used, significant improvements in rheological behavior from a fracturing fluid perspective have been observed. In addition, shear rates at which a shift from Newtonian to non-Newtonian behavior with respect to shear rate occurs, has also been observed to change.
A greater insight into the effect of nanoparticle additives on temperature related rheology of VES fluids has been provided. This understanding is crucial for the optimization of a VES fracturing fluid based on the well-to-well changes in temperatures.
The Characteristics of Hydraulic Fracture Growth in Woodford Shale, the Anadarko Basin, Oklahoma
Authors: Hai Qu , Ying Liu , Chuande Zhou , Liancheng Ren , Qinwen Wei , Yancang Lv , Jun Hou 
Published: October 2017

Abstract
The Woodford shale in Oklahoma is an ultra-low permeability reservoir that must be effectively fracture stimulated for the development of shale oil. Hundreds of horizontal wells with 4000ft-5000ft lateral length were stimulated by hydraulic fracture technology. Several pilots with 9000ft lateral length were also tested to figure out the relationship between lateral length and outcome. The research found that the shape of manual fracturein Woodford(WDFD) formation is the most important factor affecting the production.
The wells were stimulated in stages with large hydraulic fracture treatments. However, production isn't directly related to the size of the stimulated volume. Microseismic mapping techniques, simulation method, post-production analysis and formationstress calculation are cooperated to study the characteristics of fracture extension. It is found that there are two kinds of fracture shape which are different from Barnett shale. This paper will test the effect of fracturing liquid and proppant on the fracture growth; The values of triaxial stresswere obtained in the neighboring layers and WDFD formation; Finally, the pilot wellisan example to illuminate fracture extension.
Understanding fracture growth in the Woodford shale will enhance the development of the play by helping operators optimize fracture completion and well placement strategies.
Augmenting Deepwater Well Control with Managed Pressure Drilling Equipment
Authors: Johnson Austin , Piccolo Brian , Pinkstone Henry , Anderson Bo , Fraczek Justin 
Published: October 2017

Abstract
The objective of this paper is to describe howApplied Surface Back Pressure -Managed Pressure Drilling (ASBP-MPD) can be used to augment the limitations of conventionaldeepwater well control. This paper will discuss equipment design and operating philosophy as well as expand on what actions can be taken to respond to an influx while remaining within the primary well barrier.
A critical evaluation of deepwater well control has been performed uncovering several limitations which can be mitigated with anASBP-MPD system. As such, this paper will describe the disadvantages of shutting in the Subsea Blowout Preventer(SSBOP) such as the risk ofnon-productive time associated with stuck-pipe and the total influx volume increase associated with the process. Additional items discussed in this paper include managing an influx in the riser and inaccurate conventional kick detection methods.
The paper will explain howdeepwater well control can be augmented with anASBP-MPD system by sealing the wellbore with either an MPD annular preventer or an MPD riser seal. Closing the MPD annularforms a wellbore seal on drill pipebefore the mud pumps are shutdown enabling a closed system flow check and the ability to add back pressure with the MPD choke to reduce influx volume. The activation of an MPD riser sealing system provides an even faster influx response time, as drilling operations are executedin a closed system with a continuous wellbore sealwhile diverting flow through an MPD choke. Additionally, since the riser is already sealed, an MPD sealing system serves as reliable protection from a sudden riser gas unloading event which can occur in seconds. By redefining the primary well barrier in the above context, ASBP-MPD equipment can be used to circulate a small influx out of the wellbore without closing the SSBOP while remaining within the limits of the primary well barrier. Finally, accurate flowmetering of flow out and flow in provides a level of advanced down hole event detection that reduces influx volumes and further eliminates the need for a conventional flow check prior to confirming that an influx event has occurred.
Improve the Stability of Sand Feeding Process for Liquid CO2 Fracturing with Synergetic Multi Disciplinary Systems
Authors: Meng Siwei , Liu He , Yang Qinghai , Xu Jianguo , Duan Yongwei , Chen Shi 
Published: October 2017

Abstract
Liquid CO2 fracturing is a novel stimulation technology, which helps realize multiple objectives such as conservation of water, sequestration of greenhouse gases and enhancement of single-well productivity and ultimate recovery. The blender used in PetroChina Jilin Oilfield is a huge vertical pressure vessel with a short auger conveyer at its bottom, which has poor sand controllability on sand feeding process. Making matters worse, the viscosity of liquid CO2 is very low, resulting poor sand-carrying capacity, which further enhances the difficulty on sand feeding.
Stability of sand feeding process is improved via coordination of multi-disciplinary systems. 1) Develop new additive system for liquid CO2, which can enhance the viscosity efficiently and has little damage to reservoir; 2)Adjust the auger conveyer structure to increase its control ability; 3)Ensure the pressure difference between in-tank and outlet of blender less than 0.05 MPa, by adjusting phase behavior of CO2 during treatment, liquid supplement rate to blender and opening degree of butterfly valve; 4) Apply casing fracturing instead of tubing fracturing, to enhance the pump rate.
Results are as follows. 1) Two new additive systems are developed, both can enhance the viscosity to 5cp with a dosage of 1wt%. 2) Tilted auger conveyer is applied, thus increases its controllability on sand feeding and accuracy on sand ratio measurement. 3) Small positive differential pressure between in-tank and outlet of blender forms easily in winter, but difficultly in summer. The reason is that the temperature is high and large amount of CO2 is gasified, resulting in the increase of in-tank pressure. In this case a heat exchanger is needed to sub-cooling CO2. 4) By apply casing fracturing technique, the pump rate can rise from 3m3/min to 8m3/min, make the sand feeding process much easier.
The sand feeding process of liquid CO2 fracturing is optimized via coordination of multi-disciplinary systems, which increases the sand ratio and total sand volume during fracturing, improves the construction stability, and eventually enhances the stimulation effect.
New Generation Inflow Control Device to Maximize Well Productivity during Every Phase of a Well's Life
Authors: Sharma Hemant K , Al-Mulhim Abdulrahman K. , Al-Mutairi Saad M. , Al-Shammari Nayef S. 
Published: October 2017

Abstract
Oil production from long horizontal wells can pose a challenge, due to reservoir heterogeneities and the presence of fractures. In such cases, the result is an imbalanced production profile leading to early water breakthrough. Once water coning occurs, oil production may be severely decreased, due to the resistance to oil flow from the water contributing zone. To reduce this imbalance, inflow control devices (ICDs) are placed in compartments across the entire lateral length of the horizontal, which compensates for permeability variation. The compartments are separated from each other using openhole packers and constrictors. The passive ICD's are always opened to production. In cases where specific ICDs starts to contribute undesired water production, water shut-off of the length below this ICDis performed; eliminating all flow contribution, below the ICD.
A new generation of Active/Adaptive ICD's has lately been installed in some openhole horizontal producers. The Active/Adaptive ICD's can be selectively closed/opened by a setting tool to control the water production. Using this completion, the oil production has been substantially increased (some wells more than 200 %) and consequent decrease in the water production to at least 50 % and even dry.
To operate the new generation of ICDs, a new generation modular anchor and Universal Shifting Tool (UST)is used. Thisis the first downhole application of this tool worldwide for selective shifting of ICDs in a horizontal wellbore. The tool uses hydraulic pressure created by an electric motor to generate force. It provides setting assurance by real time monitoring with controlled setting force, distance and speed. With the signature from the log, the position of the ICD sleeve can be confirmed — whether opened or closed and there is no need to have additional production logging runs to confirm the position of the sleeve.
This paper details the design and advantages of the new generation of active/adaptive ICDs in horizontal wells and how the new "modular anchor and UST" is being effectively used for selective operation of the ICDs.
A New Approach for Downhole Tools Deployment Training
Authors: Gonzalez Roberto E. , Chapman Lawrence D. , Geer Ronny K. 
Published: October 2017

Abstract
Advanced employee education represents the backbone of current competence management programs across the oil and gas industry while the demand for more efficient training programs is increasing over time. The employee education task becomes more difficult when the incorporation of hands-on training is essential. This document is to share the experiences gained by an oilfield service company in the successful development and deployment of different scenarios and delivery methods that let students practice downhole tools installations in a controlled environment using a fully operational rig.
Previous approaches to downhole tools training used slideshow presentations, tools schematics and tear-down simulations to explain the proper function of a tool. These techniques helped students understand how the tool mechanisms interacted and how the tool functioned. However, they were not very successful in helping students fully comprehend the operating procedure and associated key indicators in a rig environment. Special training assemblies were designed to simulate various downhole conditions and enable the students to execute the operation on a real rig.
Implementing these simulated scenarios in multiple product line training sessions helped the students move closer to full competence on individual qualifications. Depending on the specific task, students were required to complete additional "on-the-job" (OJT) tasks in the field under supervision of a qualified employee. Students also gained a full understanding of the tool behavior, allowing them to work with minimal supervision in real-life situations. Applying this methodology in the areas of completion and wellbore intervention operations has been particularly successful. Pipe manipulation and pressure application during the device activation is imperative, and is one of the most difficult tasks to explain without using simulated scenarios. Observed results in personnel with no previous experience in the areas of specific training have been also positive. The incorporation of a real rig and deployment of downhole devices helped these individuals understand the operation and processes associated with a rig-specific deployment or tool installation. This additional training has helped them to develop their work in other areas or product segments within the organization such as quality and reliability, finance, human resources, HSE, etc.
The service company consolidation of global product segment training into two primary locations enabled the interaction, optimization and standardization of existing programs and facilitated cross-product line knowledge sharing of common practices that used to be learned separately. The explanations of training scenarios shown in this document would help in the creation and development of training programs across the oil and gas industry.
HPHT Test Packer for Use in WBCU Applications; Reduce Trips, Increase Performance, Protect the Wellbore
Authors: Oberg Levi , Holloway Lan , Harrington Kevin 
Published: October 2017

Abstract
A liner-top test packer is a device that is used to verify the integrity of a liner top and cement job in the annulus of a liner. This operation can detect a liner top leak that could result in hydrocarbons migrating into a wellbore. One method to save a trip is to run a liner-top test packer in combination with casing cleanup tools in a combined test and wellbore cleanup run. This enables an operator to verify liner integrity, remove scale, debris, and metal shavings from a wellbore, polish a liner top, and displace fluids all in one trip.
As well integrity assessment becomes increasingly important, liner-top test packers must perform with reliability at higher temperatures and pressures, often in deviated wells, under high flow rate situations, and in aggressive muds and completion fluids. These high pressures require a tool that removes hydraulic loads from the liner top, while testing with up to 11,000 psi differential pressure.
Historically, liner integrity testing has been performed as an independent operation prior to running wellbore cleanup tools and displacing the well. Today, test packer tools are designed so these two independent operations may be combined into a single trip. Though value is added through reduction in operating time and risk, liner-top test packers must perform reliably while minimizing debris that could compromise subsequent completion operations.
This presentation will discuss typical high-pressure/high-temperature (HPHT) test packer applications and case studies for wellbore cleanup jobs. HPHT objectives were met by reliably sealing 11,000 psi pressure at 400° F and eliminating harmful loading on the liner top.
Improvement and Prospect of Ultrashort Radius Lateral Drilling Technique
Authors: Ming Eryang , Li Yiliang , Li Tao , Huang Shouzhi 
Published: October 2017

Abstract
The ultrashort radius lateral drilling technique has applied more than 20 wells in China, and it was reported that this technique increased the production of mature oil wells by 3 to 5 times in average. However, when the casing grade was relatively high, the flexible drilling tool was cut off by the sharp edge of open window. This paper will introduce a method to improve this technique.
By studying the failure case, there were two obvious defects for this drilling tool. First, the shell material was too soft. It was radially stripped of 2 to 3 mm. Second, the design of transmission fork was unreasonable. The cylindrical pins of transmission fork were placed from the outside of shell and were covered by welded discs. When the shell was stripped, pin was easy to drop off and causes disconnection. To find the essential cause, we deduce kinematics and dynamics analyzes, and redesign the structure of transmission fork. Test shows the performance of new tool is much better.
This paper introduces kinematics and dynamic to redesign the ultrashort radius lateral drilling tool, which improves the performance by principle. Though kinematics analyze, we found the rotational speed inhomogeneity might cause inefficient drilling depth, even sticking of tool in some extreme cases. Tough dynamic analyze, we found the additional torque caused by rotational speed inhomogeneity might cause the vibration of drilling tool, which may cause more serious problem. To solve these problems, the universal joint was design into constant velocity universal joint and the mounting position of transmission part was placed from inside to give enough margin for shell stripping off. After these work, the ultrashort radius lateral drilling tool has less vibration and provides continuous and stable torque. This method improves the efficiency and success rate of this technique.
This paper updates the design method of ultrashort radius lateral drilling technique, makes it much reliable and efficient. It will give the promise for the next generation technique, the ultrashort radius lateral coring technique.