bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Future of Petrotechnical Leadership: Developing Young Innovators for Tomorrow's Challenges through Volunteer Leadership
Authors: Barker D. C. , Girgawy L. , Tillmann N. 
Published: February 2017

Abstract
The EIA 2015 Annual Energy Outlook predicts great uncertainty in crude oil prices over the next 25 years; estimates range from $76/bbl to $252/bbl by the year 2040. Rapidly advancing technology is creating new opportunities and risks for the industry, ranging from automation to cybersecurity and more. Additionally, nearly 50% of the industry's employee base is anticipated to retire in the next 5-10 years. Of the 76 million baby boomers retiring over that time period, only 46 million younger professionals are predicted to be available to fill the gap. In light of these trends, how will the next generation of energy and drilling professionals prepare to lead when they are inevitably thrust into such an uncertain environment?
Clearly, such uncertainty will demand adaptive, agile leaders with broad experience and diverse backgrounds. However, gaining that experience is a protracted process; a balance must be struck between providing opportunities for young professionals to develop as leaders while also managing the inherent business risk. One well established solution to mitigating this problem is to encourage aspiring leaders to seek such opportunities outside the office in volunteer and nonprofit roles. However, while often cited, such vague instructions can leave these aspiring leaders in the dark about how to apply this experience to leadership within the industry.
In this paper, young industry and nonprofit leaders recount their experience partnering in local projects with a global impact, and how a rigorous approach to developing such partnerships and initiatives provides an ideal platform for future industry leaders. Results are detailed of how these partnerships directly address critical industry needs such as fostering an entrepreneurial culture, developing new technology, and promoting cross-cultural business exchanges. Parallels are drawn between this collaborative leadership experience outside the industry and its relation to solving key challenges faced within the industry.
While corporate career planning and leadership development programs typically value community service and nonprofit work, it is frequently a simple check-box in a list of desirable career growth categories. This studygoes one step furtherby detailing a structured approach to create collaborative relationships between industry and nonprofits that will help forge tomorrow's petrotechnical professionals, and ultimately build a more sustainable ecosystem for the energy industry in a high-tech, globalized world.
A New Method for Applying Natural Sand in High-Stress Reservoirs
Authors: Suzart Walter , Davis John , Khalifa Mohamed , Morad Aljlaidi , Buenrostro Adrian , Leal Jairo 
Published: February 2017

Abstract
Increased exploration and development of unconventional reservoirs is one of the main contributing factors to increased hydraulic fracturing activity. The primary aim of hydraulic fracturing is to provide a means for hydrocarbon productivity in tight formations at economic levels. The use of natural sand in high stress zones (greater than 5,000-psi closure stress) is known to lead to increased fines generation and subsequent migration. Thisresults in a detrimental decrease in hydrocarbon productivity, which reduces the value of and could even negate the purpose of conducting hydraulic fracturing. Manmade proppants are able to withstand elevated closure stress environments and have been a widely accepted means of overcoming the limits of natural sand as a propping agent for fracturing operations in medium to high stress environments.
A novel engineering procedure using natural sand to withstand higher stresses in proppant fracturing operations was evaluated both in the laboratory and at field scale. This methodology successfully demonstrated the ability of natural sand tokeep fractures open and support formation stresses while simultaneously allowing access to a highly conductive path typically achieved using intermediate- to high-strength manmade proppants in the associated stress regime. This technique also has shown to drastically reduce fines generation and migration along propped fracture geometry, maintain acceptable conductivity of the fracture throughout the stress process, and minimize diagenesis effects typically observed on existing proppant materials. This novel technique can be used to increase the conductivityof hydraulic fractures in unconventional reservoirs.
The paper describes a methodology to increase the strength range of natural sand to enable its use in high stress zones without risk of losing fracture conductivity resulting from fines migration. A laboratory scale model was designed to simulate the high temperatures and stresses present at reservoir conditions. The associated model showed natural sand can be used in elevated reservoir conditions up to 12,000 psi stress, resulting in increased hydrocarbon production and reduced costs as well as providing new opportunitiesfor economic fracturing applications in conventional and unconventional reservoirs.
Applications of Nanotechnology in Oilwell Cementing
Authors: Deshpande Abhimanyu , Patil Rahul 
Published: February 2017

Abstract
The primary objective of oilwell cementing is zonal isolation (i.e., restricting fluid movement across various zones within formations). Another equally important function is to support casing from various operationally induced mechanical and thermal stresses. To achieve successful zonal isolation, the cement sheath should possess important properties, including low permeability, high early compressive strength, good tensile strength, etc. This article presents a detailed experimental investigation of the effects of various nanomaterials on cement slurry properties.
Nanomaterials are used in several fields, including catalysis, polymers, electronics, and biomedical applications. Because of their small particle size, these materials have high surface energy and hence higher reactivity. For this reason, nanomaterials are often necessary in small quantities for enhancing specific properties of the base material. The development of high-performance fluid systems for oil and gas applications is possible through nanotechnology. In recent years, many studies have shown the usefulness of nanomaterials in enhanced oil recovery (EOR) and drilling fluid applications. Investigations have also shown the use of nanomaterials in oilwell cementing.
The experimental investigation of the effects of various nanomaterials on cement slurry properties shows that the addition of a mere 1.5% of halloysite increased tensile strength by approximately 141%. Similarly, the addition of nano-alumina resulted in achieving early compressive strength at temperatures as low as 40°F. Hence, these nanomaterials can act as nonchloride-based accelerators for low-temperature applications. Additionally, it was observed that, to obtain the greatest benefit of using nanomaterials, it is necessary to disperse them in desired media before use.
The results of this study on the applications of nanotechnology in oilwell cementing provide an opportunity to use nanomaterials for enhanced cement slurry properties with minimal cost.
Scale Inhibition: A Challenge and a Mitigation Study in Fracturing with High-Brine Water
Authors: Vo L. K. , Cortez J. , Hoeman K. , Rahal R. , Biyani M. 
Published: February 2017

Abstract
Mineral scales frequently form during oil production as the result of changes in temperature, pressure, or the mixing of incompatible formation and injection waters. For hydraulic fracturing, there has been an ongoing effort to replace the use of fresh water with seawater or produced water to address the fresh water shortage issue in many areas in the world. When seawater is injected into the formation, the scaling tendency is inevitable. Among many different types of scale, barite scale, which is a product of the encounter of sulfate ions (typically abundant in seawater) and barium ions (exist at high concentrations in various formations), poses a serious problem. To effectively mitigate this serious scale issue, a combination of water treatment and chemical scale inhibitor is recommended. Nanofiltration (NF) technology has proven to be a reliable water treatment method that specifically removes sulfate ions from water sources with high sulfate content. This paper presents the results of a NF water-treatment process and discusses how the treatment process is a feasible method for barite scale inhibition. In addition, a comparative study of different organic polymers as scale inhibitors was also conducted. For barite scale inhibition in particular, sulfonate polymers were more effective than phosphonate polymers. Scale inhibitor development was conducted using standard evaluation methods, including static bottle testing and a dynamic scale loop. A new, quick laboratory method using ultrasonic vibration was also developed to evaluate scale inhibitor performance during the bottle testing. A combination of NF technology and the new scale inhibitor enabled a new technology to help prevent scale formation during fracturing with seawater or heavy brine water.
Implementation of Lean Thinking in Planning Piping Hydro-Testing Activities
Authors: Ibrahim Mohamed Walid 
Published: February 2017

Abstract
The scope of work for this study is to implement lean management concepts while supervising contractor's hydrotesting activity in a NGL plant construction project and present the outcomes. The obtained results can be utilized as an indication that introduction of lean thinking into day-to-day project management can enhance time management resulting into up to 50 % reduction in initial projected time to complete a specific task. Then, continuous improvement will lead to significant tangible and intangible results.
Applicable lean principals were utilized as methods to achieve targets. The lean method included: Visual management of the 5 Ss, team (PMT, PID, Contractor, and Sub-Contractor) involvement, and Muda (defects) Elimination as a process improvement practice. This whole lean thinking introduction was introduced as a project management improvement process. The core objective was not only to achieve target by safely completing the activity on time and within the company required quality standards but to achieve that with minimum to zero new allocated capital investment.
The original proposal by contractor was to put the whole (Flaring) area hydrotesting activity on hold until the arrival of control panels to be shipped from the States. This would have resulted into a minimum of 3 months’ delays. While the turning around of the status and introducing lean thinking and planning, the hydrotesting activities was not postponed and were resumed instantly after root cause analysis and 5 Whys concepts implementation and re-planning, accordingly. The result was; by the time the panels arrived, 75.6 % of the test packages were completed, tested, and approved. Quality control and maintenance of the tested lines were also conducted successfully complying with Company recommended Standards and approved by PID.
It was observed that the performance of the team was significantly improved. Off course, as time passes, we were achieving targets that was originally scheduled for freeze. But it can be mainly attributed to the fact that every member of the team (PMT, PID, Contractor, and Sub-Contractor) was involved. The gravity of listening to suggestions and creating a 2-way communication channel from PMT made all team members take ownership into the process and keen on its success.
It can be concluded that planning and scheduling activities utilizing critical path analysis and PERT is essential as an initial planning step. Then, continuous improvement of the plans and schedules utilizing lean thinking can secure a completed project within budget and on a shorter projected period compared to projected periods estimated by standard scheduling tools alone.
A New Approach to Improve Recovery Efficiency of SAGD
Authors: Guo Erpeng , Jiang Youwei , Gao Yongrong , Shen Dehuang , Zhigang Chen , Yu Pengbo 
Published: February 2017

Abstract
SAGD (Steam Assisted Gravity Drainage) is commercially adopted as a main development methods for heavy oil reservoirs and oil sands. Improving recovery rate and heat efficiency of SAGD process is the main pursuit of all researchers. This paper aims to utilize a new additive with carbamide to reduce the steam consumption and lower down the residual oil saturation, hence to improve the recovery efficiency of this method.
Study on improving recovery efficiency of SAGD with carbamide in super heavy oil reservoir was carried out. 1-D flooding experiment were carried out at 50°C and 150°C to compare the sweep efficiency between different additives including carbamide, CO2 and alkali. Then simulation were run to evaluate the influence of carbamide to SAGD process. Different additives were compared and influences of different products from carbamide were analyzed in detail.
Study reveals that SAGD process can be greatly influenced by carbamide. Carbamide can gradually decompose into ammonia and CO2 in steam chamber. Great solubility of ammonia in water can effectively increase PH value of reservoir liquid and decrease residual oil saturation. The core flooding test results show that the oil displacement efficiency can be improved by 17.7% when 25% mass percent of carbamide was added at 150°C. And at 50°C, NH4OH showed 9% improve of sweep efficiency comparing to water. Solution of CO2 into oil can improve oil water mobility ratio. And in the simulation case the oil saturation in the core part of steam was reduced to 0.12 by ammonia (this value is 0.2 for steam). Distribution of CO2 and ammonia shows that oil drainage maybe start with viscosity reduction with CO2 solution and ends with ammonia flooding in steam chamber. With the result of this paper, the recovery factor of SAGD process can be improved by 15.4% and SOR can be improved by 20% when carbamide was co-injected with steam.
Reviving a Fractured Water Injection Well: The First Use of Clay Acid Stimulation in a Major Oil Field in Algeria
Authors: Shady Mohammed , Okafor Charles , Pazzi Jorge , Thomas Oluyinka , Sule Ayuba , Ali Ahmed Moge , Hamdane Toufik , Hachelaf Houari , Allal Abdelhalim , Collela Luigi , Latronico Roberto , Marfella Ferdinando 
Published: February 2017

Abstract
Berkine basin is one of the main oil producers in Algeria. The upper, middle, and lower TAG-I are the target oil-bearing sands. In this basin, the ROD field is under pressure maintained mainly through water injection together with, to a lesser extent, gas injectors. The southern part of the field, "ROD Tail" has four water injectors targeting the middle TAG-I. In recent evaluation conducted through pressure measurement and an interference test, reservoir pressure was found to have declined by 35 bar within 2 years. This has prompted questions about reservoir management, mainly about the effectiveness of injector well capacity in maintaining reservoir pressure. Extensive data were gathered through well intervention; cleanout, perforation, and a caliper log. Many failed acid jobs were also noted in the history of these wells. An engineered high-pressure jetting operation via coiled tubing was executed, but injectivity could not be restored.
A methodology and workflow were adopted to identify the source of formation damage and scale deposition in the near-well area and around perforations. Solid samples were collected from the well and sent to laboratory to characterize formation damage type. The injection water was also analyzed by performing a standard 12-ion concentration analysis. An aqueous model simulator was used to confirm that the water was supersaturated with CaSO4 and CaSO4.2H2O. Finally, clay acid treatment was found to be effective. The treatment fluid was designed to prevent proppant dissolution and to clean fracture matrix interface. This was the first time this type of operation was executed after many unsuccessful conventional acidizing operations.
Excellent results were obtained after the acid stimulation treatment. The injection rate was found to increase significantly from 120 m3/d to 360 m3/d. Water injection pressure was also found to decrease from 243 bar to 220 bar, and the injectivity index increased by three times. Near-wellbore formation damage was removed, and formation permeability recovered. The clay acid treatment was applied to other wells in the field and similar results were obtained.
Successful System Integration Test of Real-Time Drillstem Test String for Deepwater Using Fully Acoustic Telemetry Monitoring and Control of the Well Across Electrohydraulic Subsea Disconnect Tool
Authors: Vo Thinh , Cao Duc , Choo Bryan 
Published: February 2017

Abstract
Depletion of shallow water oil reserves and growing energy demands have required exploration and development to extend into deepwater resources. Ever-changing environments in deepwater offshore locations present new challenges and require cutting-edge well-testing technology as well as advancements in cost optimization and operational safety.
This paper introduces a successful system integration test (SIT) in preparation for the first deepwater well test in Vietnam on a dynamic positioning vessel in 1117 m water depth for a 3764 m deep well. It was the first time both a real-time acoustic controlled well-testing system and an electrohydraulic (EH) controlled subsea safety system were to be deployed. The acoustically controlled well-testing system eliminated the use of electric lines to obtain real-time accurate reservoir information and minimized the use of annulus pressure to operate downhole tools. The EH-controlled subsea safety system introduced superior safety measures for emergency situations requiring less rig time.
The full system included the following: EH-controlled subsea safety system that uses the speed of EH actuation to perform emergency well shut-in and landing string secure disconnectAcoustically operated combined tester valve and circulating valveAcoustically triggered downhole samplersReal-time acquisition of reservoir pressure and temperature dataReal-time monitoring of downhole valve statusReal-time monitoring of seabed pressure and temperature data
During the SIT, the EH-controlled subsea safety system demonstrated an emergency shut-in including disconnecting the landing string in 8 seconds. Additionally, the acoustically controlled well-testing system demonstrated real-time acquisition of downhole pressure and temperature data, operated and monitored the status of downhole valves, and acoustically activated bottomhole samplers. Although the tool string was not deployed offshore because of dry holes, the success of the SIT validated the ability of this combined system to provide high performance, high safety levels, and high quality standards. This combined system would not only allow the operator to make immediate and accurate decisions to achieve intended well-test objectives, but also would provide effective safety measures in emergency situations in less rig time. The successful SIT should encourage exploration expansion in deepwater environments in the near future when solutions are available for additional challenges facing operators.
A Geomechanical Approach for Drilling Performance Optimization Across Shales in Safaniya Field—Arabian Gulf, Saudi Arabia
Authors: Alsahlawi Ziyad , Foster Herschel , Hussein Mohamed 
Published: February 2017

Abstract
Mud-weight selection is a critical factor for ensuring wellbore stability while drilling, especially in the presence of unstable shale formations. This paper describes a geomechanical approach that has been used to optimize the drilling of these types of wells. In an offshore field, the 12-¼-in. sections are typically drilled across well-known, unstable shale formations that have caused numerous stuck-pipe incidents and wellbore-related nonproductive time (NPT) in most of the offset wells. During the planning phase, the formation evaluation data, casing design, and directional profiles are reviewed and analyzed. These data are then used to perform a geomechanical study to identify the safe mud-weight window. The outcome of the study is then used to produce a set of guidelines for drilling these wells across the problematic 12-¼-in. section. These guidelines were applied to wells from an offshore field in Saudi Arabia in which the troublesome section was drilled to the casing point in each well, with no observed wellbore-stability issues. There were no losses induced and no formation collapse encountered. The planned reaming trips were eliminated, which significantly reduced the cost of drilling and completing these wells. Based on the outcome of this study and the results, this process, based on geomechanical analysis, can be used as a reference for optimal mud-weight selection to mitigate wellbore-stability problems in nearby platforms in this field of the Arabian Gulf.
The Evaluation of Micronized Barite As a Weighting Material for Completing HPHT Wells
Authors: Mohamed A. K. , Elkatatny S. A. , Mahmoud M. A. , Shawabkeh R. A. , Al-Majed A. A. 
Published: February 2017

Abstract
Barite is one of the most common weighting materials for drilling and completion fluids. Its good properties (high density, less environmental impact, and low production cost) outperform the other weighting materials and make it a good candidate for drilling and completing oil and gas wells. However, some problems were encountered in the industry while using solid particles to increase fluid density, solids invasion which causes formation damage and permeability reduction in the vicinity of the wellbore, and the tendency of these solid particles to settle therefore, the loss of well control is likely. Moreover, an erosion to the surface facilities will result when these solid particles are produced.
This study aims to investigate the effect of barite particle size on barite removal and completion fluids stability and how reducing barite particle size will help in resolving barite sag tendency and mitigating its effect. In this study, different samples of barite with different particle sizes were prepared using sieve analysis. Ball milling was used to reduce barite particle size to few microns. zeta potential and sag test were performed to evaluate the stability of micronized barite. Solubility test and high pressure high temperature filter press were used to study the effect of reducing barite particle size on barite removal.
Solubility tests showed a good enhancement in barite removal as the particle size was reduced, with a difference of around 11 g/L (20 wt.%) between the largest and the micronized size of barite. HPHT Filtration test results confirmed the solubility results with 5 wt.% enhancement in filter cake removal efficiency. Micronized barite showed a moderate stability with zeta potential measurements for a pH range greater than 8, while sag test showed insignificant enhancement in fluid stability as barite particle size was reduced to the micronized size.