bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of a Wellbore Shield Eliminates NPT in South China Sea Wells
Authors: Bakar Muhammad Aizat , Nasrudin Khairul Anwar , Nor M Abshar , Mclellan Justin , Bradbury Andy , Syrapushchynski Sasha , Wilder Michael , Rockwood Jene 
Published: January 2018

Abstract
Owing to the high depletion and narrow drilling windows characteristic of many wells in the South China Sea, the risks of severe losses increase exponentially. Mud density, sufficient to maintain well control, typically exceeds the fracture gradient of the clastic and coal formations. Thus, operators face a dilemma in balancing the need for mud weight to remain below the fracture gradient to avoid losses, while also providing sufficient density to block influxes into the well.
This paper describes the development and application of a process that essentially stabilized troublesome zones and enabled the wells to be drilled with mud weights higher than the maximum density. The authors will describe the drilling process that stabilizes microfractures in the formations and mitigates many of the issues associated with wellbore instability. The presentation of a case history will illustrate the historical mud weights and properties used to drill offset wells, and the corresponding hole stability problems. The comparative analysis demonstrates how the use of a higher mud weight eliminated well influxes while simultaneously achieving zero mud losses to the formation.
Furthermore, the technology delivered additional wellbore strength to weak formations, allowing the drilling operation to be completed as per plan. Accordingly, the operator significantly reduced the wellbore stability challenges associated with lost circulation, stuck pipe and well instability, thereby facilitating easier logging and delivering a quality, and less costly, producing well.
Overview of Lubrication Regimes and Contact Pressure Distribution in Proprietary Tubular Connections for Special Drilling Environments
Authors: Meza O. Grijalva , Sinaga S. 
Published: January 2018

Abstract
As a significant contributor to Well Integrity, the use of Premium Connections has increased in modern oilfield developments, where combined mechanical loading and a growing need for fluid tightness are becoming more common than before. This type of "specialty connectors" feature a metal-to-metal seal (MTM) which assures enhanced fluid tightness by means of distribution of contact stress generated during the make up process. In applications in which high amounts of torque or where rough field handling are the norm (e.g. Casing Drilling), the risk for damage at the MTM are big enough to put at risk the integrity of the well against leakage events. By means of understanding the mechanical and tribological aspects impacting the performance of such connectors a better understanding of their importance can be given, at the same time well defined areas of opportunity can be identified in the context of challenging drilling processes like drilling with casing.
Synthesis & Evaluation of synthesized PAA/AMPS-g-Sesbania Gum Graft Copolymer in Water Based Drilling Mud System for Mitigation of Borehole Instability in Conventional and Troublesome Formations
Authors: Kumar Saket , Chaurasia Siddharth , Sundriyal Pankaj , Gautam Sandarbh 
Published: January 2018

Abstract
The major problems associated with shale formation when it interacted with water based mud are borehole instability. This Wellbore instability may be due to swelling and dispersion of clay present in shale and also leads to other well problems like pipe sticking, hole enlargement, improper rheological & fluid loss control properties, and additional reaming etc. In this research paper an attempt has been made to evaluate the feasibility of synthesized graft copolymer in the formulation of water based mud system for challenging formations. The microwave irradiation technique has been adopted for synthesizing PAA/AMPS-g-Sesbania gum copolymer. Further, it was processed in the formulation of mud system. The remarkable rheological and filtration properties of the mud system have been seen with synthesized additive. The developed mud has possessed strong pseudoplastic behavior which is a desired property of any mud which has been observed from shear rate vs. shear rate curve. In addition, shale stabilization properties were investigated with shale rotability test on the synthesized core sample prepared in the laboratory. Moreover, percentage reduction in permeability (i.e., formation damage effect) has been found lesser in developed copolymer system co paring to conventionally used PHPA system. Hence, the formulated mud system can be used as a potential drilling mud system for drilling any oil wells.
Operational Performance Improvement Plan: How to Boost the Performance and Reduce the Cost During well Construction
Authors: Ruzhnikov Alexey , Alzate Jose , Singh Rudra , Al-Wahedi Khalid , AL-Kindi Rashid 
Published: January 2018

Abstract
Since the drilling started on the remote artificial islands located in UAE the operator used multiple initiatives to enhance the performance. One of them was the development of Operational Performance Improvement Plan(OPIP) targeting key aspects of the well planning and construction with an aim to improve the performance and reduce cost. The paper describes the thought process and steps taken to implement the OPIP and bring the performance to the new level for the operator.
The main objective in harsh economic conditions was to construct the wells safer, with less cost and more efficiently. To achieve the goal, several well construction optimization workshops were organized aiming to change the drilling processes, operations procedures, tools, equipment and well design, as well as to have a clear plan on smooth expanding the extended reach drilling envelop. As a result, the operational performance improvement planwas developed and joint well engineering, subsurface and operations team was set to ensure the implementation.
The main purpose of the plan was the standardization of all processes between few rigs, elimination of non-necessary activities and utilization of fit-for-purpose tools during execution phase. The OPIP had over80 items, and everyone of them was targeting specific drilling / completion activities. As part of the implementation, the process required a multi-discipline approach including but not limited to drilling, completions, equipment, subsurface, production, rig and service contractors with subsequent small task forces and focal point assigned to each individual action for time delivery, follow up and closure. At the same time not all the initiatives were implemented – some were rejected due to significant increase of operational risks and / or due to HSE associated risks.
The process uses a live tracker and it resulted in significant performance improvements, when time for some operations decreased by 25%(i.e. blow out preventer test time), some activities were eliminated (i.e. wiper trips), drilling practices were completely changed (i.e. use of integral packer) and as a result, the project duration was reduced by one year as of to date.
The manuscript describes a structural approach to the optimization of the well construction process with an objective to improve time and cost associated. The proposed ideas can be used at any project worldwide, especially on high cost, extended reach wells drilling projects.
Advantage of Studying Lithology of Dense Zones Formation to Avoid Well Bore Collapse between Sidetrack and Landing Point - Case Study - Offshore Abu Dhabi
Authors: Khemissa Hocine , Channa Zohaib , Nofal Salman F. , McNeilly Kevin Dean , AL-Felasi Ali , Al-Mazrooqi Laila Sayed , Al Qubaisi Salama Darwish , Al-Shamsi Latifa Ali 
Published: January 2018

Abstract
The company vision development plan to capitalize on oil production, sustainability, maximise recovery and as cost effective to reduce number of wells to be drilled requests to drill extended horizontal drains (Oil producer and water Injector).
Subsurface well location optimisation, focus in detail on targets location and the related risks. The present offshore case study, demonstrate furthermore how important to study in detail all hazards along the well path, such as lithology of side-track formation. The risk of well bore stability, collapse is very high in such formation. Subsequently, in case of collapse or drop of scratched portion of rocks, the horizontal drain will be plugged and cease to produce. This case study, demonstrate how this event happens and adequate solution was successfully applied.
To efficiently perform the proposed plan, and develop multilayer geological units with poor to moderate limestone, a detailed reservoir study was performed including all subsurface team and drilling division. It was proposed to drill and complete wells as extended horizontal drain (+3000 ft.), with several designs: multilateral drains or step down 6″open hole.
The first planned well was dual oil producer, two targets, one deviated and the second 6 inch horizontal 3000 ft. length. Feasibility with drilling engineer was performed to study all drilling parameters, drilling hazards, logging requirement, geosteering, equipment preparation and simulation for acid stimulation was showing easy to be executed with barge.
API 16A 4th Edition Changes in Testing for Drill-Through Equipment
Authors: Berckenhoff Mike , Bieneman Konstantin 
Published: January 2018

Abstract
API Specification 16A defines the requirements for design, testing, and other aspects of drill-through equipment. This includes ram and annular blowout preventers as well as connectors, spools, and adapters. The most recent edition contains changes that will drive a significant amount of rigorous testing to monogram pressure-control equipment going forward. This drill-through equipment will contain many operating system seals that are off-the-shelf but original equipment manufacturers (OEM) must also design custom seal assemblies to contain a flowing wellbore fluid. This requires optimizing the design of the assembly and selecting a compatible elastomer compound. Both steps are critical to meet performance requirements. Once designed, the prototype must undergo a battery of tests to qualify the design to API 16A. Here, formalized test standards divide equipment qualification into performance requirement (PR) levels, either PR1 or PR2. Previous editions of API 16A did not have PR levels.
Laboratory evaluation of elastomer compounds and full-scale component testing may be performed to improve the final product. Lab test results include immersion testing in hydrogen sulfide while product testing at elevated temperature and pressure may be performed in a full-size blowout preventer (BOP). API 16A test standards are used by the industry to monogram the finished product. However, there are limitations in API 16A qualification tests regarding chemical compatibility. Annular and ram BOP packers and seal designs serve as examples of the technological process used to improve performance and extend service life at elevated temperatures and pressures. All testing is tied back to API 16A validation and qualification requirements.
Gas Migration Modeling to Prevent Sustained Casing Pressure and Casing Vent Flow
Authors: Vu Manh-Huyen , Bois Axel-Pierre , Badalamenti Anthony 
Published: January 2018

Abstract
One of the main objectives of primary cementing is to provide zonal isolation by preventing the percolation of gas through a cemented annulus, which could result in channels in the cement sheath. Gas channeling, once established, has proven to be extremely difficult and costly to repair.
The most current theory used to explain gas migration is the early gelation of the cement slurry, which leads to a decrease of hydrostatic pressure within the cement annulus. Over the years, various models have been developed, most of them revolve around the concepts of static gel strength (SGS), critical static gel strength, (CSGS), and transition time. Unfortunately, these approaches have failed to accurately predict gas migration. One of the main reasons for this failure is that these approaches are based on fluid-mechanics theories, and do not take into account the cement phase changes during hydration (fluid to solid) besides their effects on the SGS. Additionally, most models do not take into account the true mechanisms at the origin of gas percolation: Matrix, chimney, and micro-annulus.
This paper presents the use of a new gas migration model that eliminates these drawbacks, in order to investigate the effect of the cement composition on the cement sheath integrity. This model considers two different stages in the life of the cement sheath (fluid-type and porous-solid type), and is characterized by constitutive laws, which are integrated over the length of the cement column by time to determine if gas migration will occur and what are the mechanisms according to which it would occur. The simulations demonstrate the crucial role that the cement composition has on the state of stresses and pore pressure in the cement sheath, on the opening and closure of micro-annuli and on the vertical displacements of cement sheath during cement early ages. They highlight that an analysis of cement sheath integrity during hydration requires checking a combination of different mechanisms during the life of cement from fluid-type to porous-solid type.
Optimizing Well Integrity in Intelligent Oil Fields
Authors: Khreibeh Hanaa Abou , Shamsi Saoud Al , Vasallo Edilberto , Farag Fadi , Lunt Ged , Bhardwaj Jiten 
Published: January 2018

Abstract
As operators move towards intelligent wells and fields, data management systems need to be adapted to support the transformation. With technology advancements and a growing network of sensors that enable faster and higher frequency data gathering, there is a need to sustainably scale data management systems to the level required to handle higher volumes of data and faster processing response. The most comprehensive systems, however, are those that support efficient decision making.
A Middle Eastern operator embarked on a project to enhance the existing well integrity data management system to add new capabilities and extend the system to other fields in the Arabian Gulf. The updated well integrity management standards were also incorporated to reflect the operator's latest business principles.
The system was further integrated with a geographical information system and well integrity business workflows were developed. The system automatically monitors data and sends notifications on abnormal well conditions. This is being supported by a single repository of all necessary data, historical inspection, pressure trends and well intervention histories.
Through continuous monitoring of operating conditions by the system and automatic task assignment when conditions indicate the rise of well problems, engineers can work more proactively and manage a growing number of assets. Automated monitoring relieves engineers from the efforts previously exerted on manual processes and allows them to focus on the engineering analysis. Having a single repository with historical inspection, safety critical equipment test data, full pressure trends and well intervention histories, provides a wealth of information from which to make informed decisions.
A benefit of having such methodology, from a management viewpoint, is that there is a common approach to well integrity indicators and key performance indicators for all assets. This allows benchmarking from field to field so that a consistent decision making approach can be made and resources of different types properly focused on those places where the challenges and demands are higher. In a period where the industry has gone through some substantial rationalization, the fact that staff can be assigned to different assets through the use of a common system with which they are familiar helps them to quickly understand, analyze and tackle well problems.
This paper examines the application of intelligent software analytics and a robust system to optimize resources and enhance efficiency and performance. By collecting a wider range of data with increased frequency and applying intelligent software analytics, the operator has been able to greatly improve the asset management coverage, thus improving efficiency and performance; satisfying regulatory requirements and achieving production targets.
ATP Bioluminescence Assay for Onsite Microbial Assessment in Drilling Rig Operations
Authors: Hernandez Susana Amaya , Zhu Xiangyang , Al-Humaid Ghassan A. , Al-Attallah Fahd S. , Al-Humam Abdulmohsen A. 
Published: January 2018

Abstract
Deep drilling often requires the use of circulating fluids to facilitate the drilling process, carrying cuttings and rock fragments to the surface. In this practice, microbial contamination and extensive growth of bacteria in the drilling fluids impact drilling operation and reservoir integrity. An onsite and rapid microbial assessment technique is required to provide an early warning of microbial activities in drilling fluids, and manage microbial risks through proper countermeasures.
Bioluminescence method is a rapid testing technique for quantification of living cells based on the measurement of adenosine-5'-triphosphate (ATP) found in the sample. ATP test has been widely used in food and pharmaceutical industries; however, its application in the oil and gas industry has been hindered by many interference substances present in typical oil industry samples. In this study, we have validated an ATP-based bioluminescence test for its linearity and repeatability in various types of samples from drilling rig operations (make-up water, drilling mud, and cement mix fluid). The results from ATP test showed an excellent linear relationship with the microbial numbers in the samples determined by plate count method. The study proved ATP bioluminescence technique as a reliable method for onsite determination of microbial contamination in drilling operations, obtaining results in minutes, rather than days or weeks with traditional methods.
The action levels based on ATP measurements were recommended for drilling engineers to assess microbial risks in drilling fluids. The implementation of this onsite microbial monitoring technique in the field will facilitate real-time detection and immediate mitigation countermeasures for microbial control in drilling fluids, reducing risks such as loss of rheological properties of drilling fluids from biodegradation, H2S production during drilling downtime and deep in the formation, biomass plugging in the formation, and microbial corrosion. This is the first study of the use of ATP-based test to assess microbial contamination in drilling rig operations.
Self Healing Durable Cement; Development, Lab Testing, and Field Execution
Authors: Al-Yami A. S. , Alqam M. H. , Riefky A. , Shafqat A. U. 
Published: January 2018

Abstract
Pressure and temperature changes during the life of the well (drilling/production) cause some Casing-Casing annulus (CCA) pressure leaks in the annulus between 13 3/8" and 9 5/8" casings, and 13 3/8" and 18 5/8" casings thereby indicating that the well barriers failed to isolate all the zones and subsequently resulting in the migration of the fluid to the surface. Such failures in wellbore isolation prevent us from taking full potential of ourhigh performance wells.
Under most failure conditions, tensile strength of a cement has a greater impact on its failure as compared to the cement's compressive strength. Consequently, increasing tensile strength of a cement is higher priority than increasing its relative compressive strength. This can be achieved by using additives such as latex, polyvinyl alcohol or fibers or simply by increasing cement flexibility. The objective of this paper is to discuss the development, testing and field execution of a new type of cement, Self-Healing Durable Cement to mitigate such failures due to pressure or temperature cycling.
This new cement was developed utilizing novel components that results in a cement with a reduced Young's Modulus. Lower Young's Modulus makes the cement more elastic in order to resist pressure and temperature cycling, absorb applied stresses and prevent cement cracks. The developed Self-Healing Durable Cement also provides an additional benefit of mechanical properties enhancement as the included additive exhibits swelling and sealing capacity when contacted by hydrocarbon fluids. In the event cracks form in the cement, this will be a path for the fluid to trigger the swelling and self-healing mechanism.
The paper includes detailed testing data for thickening time, rheology, free water, settling at different ranges of densities. An additional test was also included to evaluate the durability of the system with time. Mechanical properties testing was performed for cement samples after 10, 20 and 30 days curing at representative targeted field conditions. Single stage triaxial tests were performed on dry cement core plugs to measure static and dynamic properties through ultrasonic and shear velocities. These properties were determined at confining pressures and included the Young's modulus, the Poisson's Ratio, and Peak Strength.
Offset wells cemented with conventional formulations have shown CCA pressure with slight oil flows. The developed Self-Healing Durable Cement was applied for 13 3/8" casing covering oil bearing zones. The deployments were declared successful since negative testing and temperature and pressure cycling did not result in any CCA. Ultimately, good cementing performance is always measured by having zero psi casing/casing annulus pressure.
Integrated Off-Bottom Cemented Inflow Control Device System Design Toward Well Delivery Optimization
Authors: Madan Mohammed A. , Khamseen Mazen Bu , Suherdiana Hedy , Abdulmohsen Ahmad Al 
Published: January 2018

Abstract
Off-bottom cementing (OBC) operations are unique to Saudi Arabia and also represents one of the most challenging types of drilling and workover operations, when deployed in combination with inflow control devices (ICDs) across horizontal sections. In a conventional ICD system, an inner string with packer setting tools is required for setting open hole packers, and to have 100% circulation at the bottom of the completion, to wash down any tight spots. As a consequence, this introduces additional issues such as health, safety and environment, logistics and additional rig time. The inner string also increases the ICD completion string weight, while deploying the system in the horizontal section, creating more drag and increasing the risk of getting stuck.
The multitasking valve (MTV) feature in the upgraded ICDs offers safe, simple and cost-effective deployment operations. The MTV allows the system to be deployed without the need for an inner string. This will positively impact the deployment by simplifying the complexity in the rig operation while achieving 100% circulation at the shoe. Besides, all the hydraulically activated equipment, such as the liner hanger packer, open hole mechanical packers, etc., can be pressurized and set simultaneously. Furthermore, the ICD completion will weigh less in the horizontal section, resulting in less friction and drag to reach total depth (TD). The MTV feature provides an opportunity to deploy the ICD system and the OBC liner system together in one trip. This paper will discuss the first deployment of a combined ICD system with an OBC system for a workover operation, in a historical oil well producer in the Kingdom of Saudi Arabia. The merged system was successfully deployed to depth, then cemented off-bottom, saving approximately 40 hours of rig operation time.